CN115078102B - Geological sequestration CO 2 Leakage channel healing capacity evaluation system and method - Google Patents
Geological sequestration CO 2 Leakage channel healing capacity evaluation system and method Download PDFInfo
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Classifications
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N3/00—Investigating strength properties of solid materials by application of mechanical stress
- G01N3/08—Investigating strength properties of solid materials by application of mechanical stress by applying steady tensile or compressive forces
- G01N3/10—Investigating strength properties of solid materials by application of mechanical stress by applying steady tensile or compressive forces generated by pneumatic or hydraulic pressure
- G01N3/12—Pressure testing
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01L—MEASURING FORCE, STRESS, TORQUE, WORK, MECHANICAL POWER, MECHANICAL EFFICIENCY, OR FLUID PRESSURE
- G01L13/00—Devices or apparatus for measuring differences of two or more fluid pressure values
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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
- G01N15/00—Investigating characteristics of particles; Investigating permeability, pore-volume, or surface-area of porous materials
- G01N15/08—Investigating permeability, pore-volume, or surface area of porous materials
- G01N15/082—Investigating permeability by forcing a fluid through a sample
- G01N15/0826—Investigating permeability by forcing a fluid through a sample and measuring fluid flow rate, i.e. permeation rate or pressure change
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
- G01N33/24—Earth materials
Abstract
The invention discloses a geological sequestration CO 2 A leak path healing capacity evaluation system and method, the evaluation system comprising: a first core holder adapted to a reservoir rock sample and a second core holder adapted to a fracture-containing cap/cement rock sample; a first injection device, which is respectively communicated with the first core holder and the second core holder and is configured to inject simulated formation water or saturated CO into at least one of the first core holder and the second core holder 2 Supercritical CO of formation water or saturated water 2 The method comprises the steps of carrying out a first treatment on the surface of the A second injection device in communication with the first core holder and the second core holder, respectively, configured to apply confining pressure to the first core holder and the second core holder simultaneously or independently; a differential pressure sensor configured to detect a pressure differential across the second core holder; and a pressure sensor configured to detect pressure of a side of the second core holder away from the first core holder.
Description
Technical Field
The present invention relates to CO 2 The technical field of geological sequestration and utilization, in particular to a geological sequestration CO 2 Leak path healing capability evaluation systems and methods.
Background
CO 2 The greenhouse effect caused by excessive emissions is globalOne of the major challenges is faced, and carbon emission reduction is a necessary way to solve the above challenges. CO 2 Geological sequestration, the most economical and efficient carbon emission reduction route at present, refers to the reduction of CO 2 Delivering the mixture to geologic bodies such as salty water layers, coal layers, depleted oil and gas reservoirs and the like, and realizing CO by mineralization sealing, dissolution sealing, constraint sealing and structural sealing modes 2 And the purpose of long-term and safe sealing and storage is achieved. However, CO 2 Geological sequestration also suffers from numerous drawbacks and deficiencies, especially CO 2 Leakage problem of CO 2 Once leaked into underground water and the atmosphere, serious harm is caused to the ecological environment and human health.
CO 2 Leak paths in the body include overburden, cement sheath, and wellbore, where the cement sheath is a barrier to wellbore leakage. The matrix pores of the cover layer and the cement sheath belong to nanopores, CO 2 The breakthrough pressure in the catalyst can reach several megapascals, and the catalyst can be used for CO 2 Has better sealing effect. However, the cover layer and the cement sheath are provided with primary weaknesses such as faults, cracks and the like; in addition, CO injection 2 Stress disturbance and CO 2 Chemical reactions with the rock may induce fracture of the cap/cement sheath to create secondary weaknesses. These weaknesses are typically in the order of micrometers to millimeters in size, CO 2 The breakthrough pressure therein is only a few tens of kilopascals, CO is very easy to generate 2 Leakage. When CO 2 When invading the weakness, mineral erosion/precipitation, particle migration, clay swelling and wettability changes are induced; under the combined action of the factors, the leakage channel can gradually heal, thereby being beneficial to CO 2 Leakage plays a certain role in inhibiting.
Known techniques (see Liteanu and Spiers, 2011, chem. Gel., 281:195-210; ellis et al, 2013, environ, eng. Sci., 30:187-193; cao et al, 2015, water resource. Res., 51:4684-4701) saturate CO by comparison 2 The permeability of the overburden rock sample/cement rock sample changes before and after displacement or soaking of the aqueous solution, for CO in the overburden/cement sheath 2 The ability of the leak path to heal was evaluated. However, the prior art has the following two disadvantages:
(1) Prior artReservoir production of particulates versus CO in the cap/cement sheath is not considered 2 Influence of leakage behavior, CO 2 Before entering the overburden/cement sheath, the overburden/cement sheath has reacted with the reservoir rock to cause a large number of particulates to be generated that are highly entrained by the fluid into the overburden/cement sheath and clog the leak path, thereby accelerating the healing of the leak path;
（2）CO 2 CO formation in the channels during leakage 2 Dissolution zone (i.e. saturated CO 2 Formation water single phase flow zone) and CO 2 -formation water two-phase flow zone, leak path and saturated CO 2 Formation water single phase flow and CO 2 Formation water two-phase flow reaction, the prior art only considers saturated CO 2 The influence of the single-phase flow of stratum water on the healing behavior of a leakage channel is neglected, and CO is ignored 2 -the effect of a formation water two-phase flow.
In view of this, this patent proposes a geological sequestration of CO 2 The invention adopts a spatial configuration relation of reservoir stratum rock samples and cover layers/cement rock samples which are connected in series to simulate reservoir stratum-cover layers/cement rings, and saturated CO is sequentially injected into saturated stratum water rock samples 2 Formation water and saturated water supercritical CO 2 Simulation of CO 2 Leakage process, and employing permeability and CO 2 The change in breakthrough pressure characterizes the leak path healing ability. The invention considers that the reservoir produces particles and saturated CO 2 Formation water single phase flow and CO 2 Comprehensive influence of stratum water two-phase flow on leakage channel healing behavior, and CO can be realized 2 Rapid, accurate characterization of leak path healing capability. The invention is applicable to CO 2 The leakage risk evaluation and leakage prevention and control have important guiding significance.
Disclosure of Invention
The proposal aims at the problems and the demands, and provides a geological sequestration CO 2 The leakage channel healing capacity evaluation system and method can achieve the technical purposes and bring about other technical effects due to the following technical characteristics.
One object of the present invention is to propose a geological sequestration of CO 2 A leak path healing capacity evaluation system comprising:
the first constant temperature box is used for adjusting the temperature of the evaluation system;
the first core holder is adapted to a reservoir rock sample, and the second core holder is adapted to a cap rock sample or a cement rock sample containing cracks;
a first injection device, which is respectively communicated with the first core holder and the second core holder and is configured to sequentially inject simulated formation water and saturated water supercritical CO into at least one of the first core holder and the second core holder 2 Saturated CO 2 Formation water;
a second injection device, in communication with the first core holder and the second core holder, respectively, configured to apply confining pressure to the reservoir rock sample in the first core holder and the fracture-containing overburden rock sample or the cement rock sample in the second core holder simultaneously or independently;
Differential pressure sensors, arranged on both sides of the second core holder, configured to detect a pressure difference on both sides of the second core holder;
a pressure sensor, disposed on a side of the second core holder away from the first core holder, configured to detect a pressure of the side of the second core holder away from the first core holder;
a first on-off valve and a second on-off valve are respectively arranged between the first injection device and the first core holder as well as between the first injection device and the second injection device; a third on-off valve is arranged between the first core holder and the second core holder; and a fourth shut-off valve is arranged at one end, far away from the first core holder, of the second core holder.
In one example of the present invention, the first injection device includes:
a first injection pump;
three first intermediate containers connected in parallel in turn, each of the first intermediate containers comprising a container body and a movable fittingA piston arranged in the container body, wherein the container body is divided by the piston into two chambers, one chamber is communicated with the first injection pump, and the other chamber is respectively used for storing simulated formation water and saturated water supercritical CO 2 Saturated CO 2 And the formation water is respectively communicated with the first core holder and the second core holder.
In one example of the present invention, a fifth on-off valve is disposed at two ends of each of the first intermediate containers, and configured to adjust on-off of the first intermediate containers with the first injection pump, the first core holder, and the second core holder.
In one example of the present invention, the second injection means includes:
a second injection pump;
and the two sixth on-off valves are respectively arranged between the second injection pump and the first core holder or the second core holder and are used for switching on and off the pressure of the second injection pump towards the first core holder or the second core holder.
In one example of the present invention, further comprising: a first gas-liquid separator is provided, which comprises a first gas-liquid separator,
arranged on one side of the second core holder far away from the first core holder and used for collecting CO in produced liquid 2 And simulating formation water.
In one example of the present invention, further comprising: the first back-pressure regulator is provided with a first back-pressure regulator,
is disposed between the first gas-liquid separator and the pressure sensor for providing back pressure to a fractured overburden or cement rock sample within the second core holder.
Another object of the present invention is to propose a geological sequestration of CO as described above 2 The leakage channel healing capacity evaluation method comprises the following steps:
s10: vacuumizing the prepared reservoir rock sample, the fractured overburden rock sample or the cement rock sample to simulate formation water for more than a preset time, then respectively placing the reservoir rock sample and the fractured overburden rock sample or the cement rock sample in a first core holder and a second core holder, opening a second injection device, applying a certain confining pressure to the reservoir rock sample and the fractured overburden rock sample or the cement rock sample, opening a first back pressure regulator and a first constant temperature box, and respectively setting the back pressure and the system temperature to preset values;
s20: opening a first injection device, injecting simulated formation water into the fractured overburden rock sample or the cement rock sample until the pressure difference between two ends of the rock sample is kept constant, and calculating the permeability of the fractured overburden rock sample or the cement rock sample before leakage through Darcy's law;
s30: injecting saturated water supercritical CO into a fractured overburden or cement rock sample 2 Until bubbles are produced at the outlet end, then closing a second break valve, a third break valve and a fourth break valve at the upstream and downstream of the second core holder to gradually attenuate the upstream pressure, continuously increasing the downstream pressure until the pressure reaches balance, and recording the upstream and downstream pressure difference in the balance, namely the CO of the cap rock sample or the cement rock sample containing cracks before leakage 2 Breaking through the pressure;
s40: injecting saturated CO into a reservoir rock sample and a fracture-containing overburden or cement rock sample in series 2 Formation water until the pressure reaches equilibrium, and then injecting saturated water supercritical CO into the reservoir rock sample and the overburden rock sample or cement rock sample containing cracks connected in series 2 Until the pressure reaches equilibrium, the purpose of this step is to simulate CO 2 Is a leakage process of (1);
s50: repeating steps S20 and S30, and determining the permeability and CO of the cover layer rock sample or cement rock sample containing cracks after leakage 2 Breaking through the pressure;
s60: comparing permeability and CO of cap rock sample or cement rock sample containing cracks before and after leakage 2 Breakthrough pressure, calculating permeability reduction rate of cover layer rock sample or cement rock sample containing cracks and breakthrough pressure increase rate, and comprehensively evaluating CO 2 The healing ability of the leakage path.
In one example of the present invention, the space between the second on-off valve, the third on-off valve and the core inlet end face in the second core holder forms an upstream container, the space between the fourth on-off valve and the core outlet end face in the second core holder forms a downstream container, and the volumes of the upstream container and the downstream container are 2.0-3.0 ml.
In one example of the present invention, in step S60, the rate of decrease in the permeability and the rate of increase in the breakthrough pressure are calculated by the following formulas:
wherein:R k permeability decrease rate,%;R b the breakthrough pressure increase rate of the rock sample,%;k a0 andk a the permeability of the rock sample before and after leakage, mD;p b0 andp b rock sample CO before and after leakage, respectively 2 Break through pressure, MPa.
In one example of the present invention, in step S20, the flow rate of the injected simulated formation water is 0.3 to 0.5 mL/min; in steps S30 and S40, saturated water supercritical CO is injected 2 And saturated CO 2 The flow rate of the stratum water is 3.0-5.0 mL/min.
Preferred embodiments for carrying out the present invention will be described in more detail below with reference to the attached drawings so that the features and advantages of the present invention can be easily understood.
Compared with the prior art, the geological sequestration CO of the invention 2 The leakage channel self-healing capacity evaluation system and method have the following beneficial effects:
(1) The invention adopts a reservoir rock sample and a cover layer rock sample or a cement rock sample containing cracks which are connected in series to develop CO 2 Leakage channel healing ability evaluation experiments, taking into account CO 2 The influence of reservoir produced particles on the healing behavior of a leakage channel in the leakage process;
(2) The method sequentially injects the saturated CO into the saturated stratum water rock sample 2 Formation water and saturated water supercritical CO 2 Is simulated by CO 2 Leakage process, can evaluate saturation CO 2 Formation water single phase flow and CO 2 -the combined effect of the formation water two-phase flow on the healing behaviour of the leak path;
(3) The invention can analyze the healing behavior of different types and sizes of leakage channels in the cover layer/cement ring under the simulated in-situ condition, and can pass the permeability and CO before and after leakage 2 Breakthrough pressure variation comprehensively characterizes the healing capacity of a leakage channel, and can be on-site CO 2 The leakage risk evaluation and the selection of targeted leakage prevention and control measures provide technical guidance;
(4) The invention adopts the pressure attenuation method to test the CO 2 The breakthrough pressure of the test system is simple and convenient to operate, the test speed is high, the accuracy is high, and the pressure attenuation method can simulate CO 2 The pressure evolution process from occurrence to stopping of leakage is more in line with the actual situation.
Drawings
In order to more clearly illustrate the technical solution of the embodiments of the present invention, the following description will briefly explain the drawings of the embodiments of the present invention. Wherein the showings are for the purpose of illustrating some embodiments of the invention only and not for the purpose of limiting the same.
FIG. 1 is a geological sequestration CO according to an embodiment of the present invention 2 A structural schematic diagram of a leakage channel healing capacity evaluation system;
FIG. 2 is a schematic diagram of a saturated water supercritical CO configuration in accordance with an embodiment of the present invention 2 And saturated CO 2 A structural schematic diagram of a configuration device of formation water;
FIG. 3 is a geological sequestration CO according to an embodiment of the present invention 2 A flow chart of a leakage channel healing capacity evaluation method.
List of reference numerals:
an evaluation system 1000;
a first core holder 10;
a second core holder 20;
a first injection device 30;
a first injection pump 31;
a first intermediate container 32;
a fifth on-off valve 33;
a second injection device 40;
a second injection pump 41;
a sixth on-off valve 42;
a differential pressure sensor 50;
a pressure sensor 60;
a first on-off valve 70;
a second on-off valve 80;
a third on-off valve 90;
a fourth shut-off valve 100;
a first gas-liquid separator 110;
a first back pressure regulator 120;
a first incubator 130;
a preparing device 200;
a second intermediate container 210;
high pressure CO 2 A gas cylinder 220;
a formation water pump 230;
a hydraulic oil pump 240;
a second back pressure regulator 250;
a second gas-liquid separator 260;
a second incubator 270.
Description of the embodiments
In order to make the objects, technical solutions and advantages of the technical solutions of the present invention more clear, the technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings of specific embodiments of the present invention. Like reference numerals in the drawings denote like parts. It should be noted that the described embodiments are some, but not all embodiments of the present invention. All other embodiments, which can be made by a person skilled in the art without creative efforts, based on the described embodiments of the present invention fall within the protection scope of the present invention.
Unless defined otherwise, technical or scientific terms used herein should be given the ordinary meaning as understood by one of ordinary skill in the art to which this invention belongs. The terms "first," "second," and the like in the description and in the claims, are not used for any order, quantity, or importance, but are used for distinguishing between different elements. Likewise, the terms "a" or "an" and the like do not necessarily denote a limitation of quantity. The word "comprising" or "comprises", and the like, means that elements or items preceding the word are included in the element or item listed after the word and equivalents thereof, but does not exclude other elements or items. The terms "connected" or "connected," and the like, are not limited to physical or mechanical connections, but may include electrical connections, whether direct or indirect. "upper", "lower", "left", "right", etc. are used merely to indicate relative positional relationships, which may also be changed when the absolute position of the object to be described is changed.
Geological sequestration of CO according to the first aspect of the present invention 2 Leakage path healing capacity evaluation system 1000, as shown in fig. 1, includes:
a first thermostat 130 for adjusting the temperature of the evaluation system 1000;
a first core holder 10 and a second core holder 20 which are sequentially connected in series, wherein the first core holder 10 is adapted to a reservoir rock sample, and the second core holder 20 is adapted to a cap rock sample or a cement rock sample containing cracks;
a first injection device 30, which is respectively communicated with the first core holder 10 and the second core holder 20 and is configured to sequentially inject simulated formation water and saturated water supercritical CO into at least one of the first core holder 10 and the second core holder 20 2 Saturated CO 2 Formation water;
a second injection device 40 in communication with the first core holder 10 and the second core holder 20, respectively, configured to apply confining pressure to reservoir rock samples within the first core holder 10 and to fractured overburden rock samples or cement rock samples within the second core holder 20 simultaneously or independently;
differential pressure sensors 50, disposed on either side of the second core holder 20, configured to detect a pressure differential across the second core holder 20;
a pressure sensor 60, disposed on a side of the second core holder 20 remote from the first core holder 10, configured to detect a pressure of the second core holder 20 on a side remote from the first core holder 10;
Wherein a first on-off valve 70 and a second on-off valve 80 are respectively configured between the first injection device 30 and the first core holder 10 and between the first injection device and the second core holder 20; a third on-off valve 90 is arranged between the first core holder 10 and the second core holder 20; the end of the second core holder 20 remote from the first core holder 10 is configured with a fourth shut-off valve 100.
Firstly, vacuumizing and saturating simulated formation water for more than a preset time on the prepared reservoir rock sample, the fractured overburden rock sample or the cement rock sample, then respectively placing the simulated formation water in the first core holder 10 and the second core holder 20, opening the second injection device 40 and the two sixth on-off valves 42, applying certain confining pressure on the reservoir rock sample and the fractured overburden rock sample or the cement rock sample, opening the first back pressure regulator 120 and the first constant temperature box 130, and respectively setting the back pressure and the system temperature to preset values; secondly, opening the first injection device 30, the fifth on-off valve 33, the second on-off valve 80 and the fourth on-off valve 100 at the two ends of the first intermediate container 32 containing simulated formation water, injecting the simulated formation water into the fractured overburden rock sample or the cement rock sample until the pressure difference at the two ends of the rock sample is kept constant, and calculating the permeability of the fractured overburden rock sample or the cement rock sample before leakage through Darcy's law; then, switching to supercritical CO containing saturated water 2 The fifth on-off valve 33 at both ends of the first intermediate container 32 is opened, and saturated water supercritical CO is injected into the fractured overburden rock sample or cement rock sample 2 Until bubbles are produced at the outlet end, then closing the second break valve 80 and the fourth break valve 100 at the upstream and downstream of the second core holder 20 to gradually attenuate the upstream pressure, continuously increase the downstream pressure until the pressure reaches balance, and recording the upstream and downstream pressure difference at the time of balance, namely the CO of the cap rock sample or the cement rock sample containing cracks before leakage 2 Breaking through the pressure; then, switch toContaining saturated CO 2 The first intermediate container 32 of formation water is opened, and the fifth on-off valve 33, the first on-off valve 70, the third on-off valve 90 and the fourth on-off valve 100 at both ends thereof are opened to inject saturated CO into the reservoir rock sample and the overburden rock sample or cement rock sample containing cracks connected in series 2 Formation water, until pressure reaches equilibrium, is then switched to contain saturated water supercritical CO 2 The fifth on-off valve 33 at both ends of the first intermediate container 32 is opened, and then the saturated water supercritical CO is injected into the reservoir rock sample and the cover rock sample or cement rock sample containing cracks which are connected in series 2 Until the pressure reaches equilibrium, the purpose of this step is to simulate CO 2 Is a leakage process of (1); again, switching to the first intermediate container 32 containing simulated formation water, opening the fifth on-off valve 33 and the second on-off valve 80 at both ends thereof, closing the first on-off valve 70 and the third on-off valve 90, injecting simulated formation water into the fractured overburden rock sample or the cement rock sample until the pressure difference across the rock sample is kept constant, and calculating the permeability of the fractured overburden rock sample or the cement rock sample after leakage by darcy's law; switching to supercritical CO with saturated water 2 The fifth on-off valve 33 at both ends of the first intermediate container 32 is opened, and saturated water supercritical CO is injected into the fractured overburden rock sample or cement rock sample 2 Until bubbles are produced at the outlet end, then closing the second break valve 80 and the fourth break valve 100 at the upstream and downstream of the second core holder 20 to gradually attenuate the upstream pressure, continuously increase the downstream pressure until the pressure reaches balance, and recording the upstream and downstream pressure difference at the time of balance, namely the CO of the fractured overburden rock sample or the cement rock sample after leakage 2 Breaking through the pressure; finally, the permeability and CO of the overburden rock sample or the cement rock sample containing cracks before and after leakage are compared 2 Breakthrough pressure, calculating permeability reduction rate of cover layer rock sample or cement rock sample containing cracks and breakthrough pressure increase rate, and comprehensively evaluating CO 2 The healing ability of the leakage path.
It should be noted that the first core holder 10 and the second core holder 20 are both vertically disposed, and the simulated formation water and saturated CO 2 Formation water and saturated water supercritical CO 2 Are all from belowAnd injected up into the core holder to form upstream and downstream of the first core holder 10 or the second core holder 20.
It should be noted that the first core holder 10 and the second core holder 20 are both prior art.
In one example of the present invention, the first injection device 30 includes:
a first injection pump 31;
three first intermediate containers 32 connected in parallel in turn, each first intermediate container 32 comprising a container body and a piston movably arranged in the container body, wherein the container body is divided by the piston into two chambers, one of the chambers is communicated with the first injection pump 31, and the other chamber is respectively used for storing simulated formation water and saturated water supercritical CO 2 Saturated CO 2 The formation water is respectively communicated with the first core holder 10 and the second core holder 20.
That is, the piston of the first intermediate container 32 is moved by the first injection pump 31 from a side close to the first injection pump 31 to a side away from the first injection pump 31, so that the piston presses the simulated formation water or saturated CO in the chamber 2 Supercritical CO of formation water or saturated water 2 Thereby simulating formation water or saturated CO 2 Supercritical CO of formation water or saturated water 2 The first core holder 10 and the second core holder 20 are injected, and three first intermediate containers 32 are arranged to simulate formation water or saturated CO 2 Supercritical CO of formation water or saturated water 2 Injection into the first core holder 10 and the second core holder 20. For example, the first injection pump 31 may be a hydraulic oil pump that pushes the piston to move by injecting hydraulic oil into the first intermediate tank 32.
In one example of the present invention, a fifth on-off valve 33 is disposed at two ends of each of the first intermediate containers 32, and configured to adjust on-off of the first intermediate containers 32 with the first injection pump 31, the first core holder 10, and the second core holder 20;
for example, when it is desiredWhen simulated formation water is injected, the fifth on-off valves 33 at the two ends of the simulated formation water are opened, the fifth on-off valves 33 at the two sides of the other two first intermediate containers 32 are in a closed state, and the simulated formation water is injected into the first core holder 10 and the second core holder 20 under the driving of the first injection pump 31. It will be appreciated that when saturation CO injection is required 2 Supercritical CO of formation water or saturated water 2 In this case, the operation method is similar to that described above, and will not be described here again.
In one example of the present invention, the second injection device 40 includes:
a second injection pump 41;
two sixth on-off valves 42, respectively disposed between the second injection pump 41 and the first core holder 10 or the second core holder 20, configured to switch on and off the pressure from the second injection pump 41 toward the first core holder 10 or the second core holder 20;
that is, the confining pressure may be applied to both the first core holder 10 and the second core holder 20 (both the fifth on-off valves 33 are open) or may be applied to one of the first core holder 10 and the second core holder 20 (only one of the fifth on-off valves 33 is open) under the drive of the second injection pump 41. For example, the second injection pump 41 may be a hydraulic oil pump that generates confining pressure by injecting hydraulic oil into the first core holder 10 or the second core holder 20.
In one example of the present invention, further comprising: the first gas-liquid separator 110 is provided with,
arranged on the side of the second core holder 20 away from the first core holder 10 for collecting CO in the produced fluid 2 And simulating formation water;
the CO in the output of the evaluation system 1000 can be collected by providing a first gas-liquid separator 110 2 And simulating formation water.
In one example of the present invention, further comprising: the first back-pressure regulator 120 is configured to,
is disposed between the first gas-liquid separator 110 and the pressure sensor 60 for providing back pressure to the fractured overburden or cement rock sample in the second core holder 20.
It will be appreciated that the first incubator 130 in the evaluation system 1000 is used to regulate the temperature of the evaluation system 1000, wherein, as shown in fig. 1, the remaining components are disposed within the first incubator 130 except that the first gas-liquid separator 110, the second injection pump 41, and the first injection pump 31 are disposed within the first incubator 130, thereby ensuring that the evaluation system 1000 is able to effectively simulate a geological environment.
Geological sequestration of CO according to a second aspect of the invention, as described above 2 The leakage path healing ability evaluation method, as shown in fig. 3, includes the steps of:
s10: vacuumizing the prepared reservoir rock sample, the fractured overburden rock sample or the cement rock sample to simulate formation water for more than a preset time, then respectively placing the reservoir rock sample and the fractured overburden rock sample or the cement rock sample in the first core holder 10 and the second core holder 20, opening the second injection device 40, applying a certain confining pressure to the reservoir rock sample and the fractured overburden rock sample or the cement rock sample, opening the first back pressure regulator 120 and the first constant temperature box 130, and respectively setting the back pressure and the system temperature to preset values;
S20: opening the first injection device 30, injecting simulated formation water into the fractured overburden rock sample or cement rock sample until the pressure difference across the rock sample remains constant, and calculating the permeability of the fractured overburden rock sample or cement rock sample before leakage by darcy's law;
s30: injecting saturated water supercritical CO into a fractured overburden or cement rock sample 2 Until bubbles are produced at the outlet end, then closing the second on-off valve 80, the third on-off valve 90 and the fourth on-off valve 100 at the upstream and downstream of the second core holder 20 to gradually attenuate the upstream pressure, continuously increasing the downstream pressure until the pressure reaches balance, and recording the upstream and downstream pressure difference at the time of balance, namely the CO of the cap rock sample or the cement rock sample containing cracks before leakage 2 Breaking through the pressure;
s40: to reservoir rock samples and to fractured overburden or cement rock samples in seriesMedium injection of saturated CO 2 Formation water until the pressure reaches equilibrium, and then injecting saturated water supercritical CO into the reservoir rock sample and the overburden rock sample or cement rock sample containing cracks connected in series 2 Until the pressure reaches equilibrium, the purpose of this step is to simulate CO 2 Is a leakage process of (1);
s50: repeating steps S20 and S30, and determining the permeability and CO of the cover layer rock sample or cement rock sample containing cracks after leakage 2 Breaking through the pressure;
s60: comparing permeability and CO of cap rock sample or cement rock sample containing cracks before and after leakage 2 Breakthrough pressure, calculating permeability reduction rate of cover layer rock sample or cement rock sample containing cracks and breakthrough pressure increase rate, and comprehensively evaluating CO 2 The healing ability of the leakage path.
The specific procedure of the evaluation method is as follows:
vacuumizing the prepared reservoir rock sample, the fractured overburden rock sample or the cement rock sample to saturate and simulate formation water for more than a preset time, then respectively placing the reservoir rock sample, the fractured overburden rock sample or the cement rock sample in the first core holder 10 and the second core holder 20, opening the second injection device 40 and the two sixth on-off valves 42, applying a certain confining pressure to the reservoir rock sample and the fractured overburden rock sample or the cement rock sample, opening the first back pressure regulator 120 and the first constant temperature box 130, and respectively setting the back pressure and the system temperature to preset values;
opening the first injection device 30, the fifth on-off valve 33, the second on-off valve 80 and the fourth on-off valve 100 at both ends of the first intermediate container 32 containing simulated formation water, injecting the simulated formation water into the fractured overburden rock sample or the cement rock sample until the pressure difference across the rock sample is kept constant, and calculating the permeability of the fractured overburden rock sample or the cement rock sample before leakage by darcy's law;
Switching to supercritical CO with saturated water 2 The fifth on-off valve 33 at both ends of the first intermediate container 32 is opened, and saturated water supercritical CO is injected into the fractured overburden rock sample or cement rock sample 2 Until bubbles are produced at the outlet end, then closing the second on-off valve 80 and the fourth on-off valve 1 at the upstream and downstream of the second core holder 2000, the upstream pressure is gradually attenuated, the downstream pressure is continuously increased until the pressure reaches balance, and the upstream and downstream pressure difference in balance is recorded, namely the CO of the cover layer rock sample or the cement rock sample containing cracks before leakage 2 Breaking through the pressure;
switching to contain saturated CO 2 The first intermediate container 32 of formation water is opened, and the fifth on-off valve 33, the first on-off valve 70, the third on-off valve 90 and the fourth on-off valve 100 at both ends thereof are opened to inject saturated CO into the reservoir rock sample and the overburden rock sample or cement rock sample containing cracks connected in series 2 Formation water, until pressure reaches equilibrium, is then switched to contain saturated water supercritical CO 2 The fifth on-off valve 33 at both ends of the first intermediate container 32 is opened, and then the saturated water supercritical CO is injected into the reservoir rock sample and the cover rock sample or cement rock sample containing cracks which are connected in series 2 Until the pressure reaches equilibrium, the purpose of this step is to simulate CO 2 Is a leakage process of (1);
switching to a first intermediate container 32 containing simulated formation water, opening a fifth on-off valve 33 and a second on-off valve 80 at two ends of the first intermediate container, closing the first on-off valve 70 and the third on-off valve 90, injecting the simulated formation water into the fractured overburden rock sample or the cement rock sample until the pressure difference between the two ends of the rock sample is kept constant, and calculating the permeability of the fractured overburden rock sample or the cement rock sample after leakage through Darcy's law; switching to supercritical CO with saturated water 2 The fifth on-off valve 33 at both ends of the first intermediate container 32 is opened, and saturated water supercritical CO is injected into the fractured overburden rock sample or cement rock sample 2 Until bubbles are produced at the outlet end, then closing the second break valve 80 and the fourth break valve 100 at the upstream and downstream of the second core holder 20 to gradually attenuate the upstream pressure, continuously increase the downstream pressure until the pressure reaches balance, and recording the upstream and downstream pressure difference at the time of balance, namely the CO of the fractured overburden rock sample or the cement rock sample after leakage 2 Breaking through the pressure;
comparing permeability and CO of cap rock sample or cement rock sample containing cracks before and after leakage 2 Breakthrough pressure, calculating permeability decrease of fractured overburden rock sample or cement rock sample Rate and breakthrough pressure increase rate, comprehensive evaluation of CO 2 The healing ability of the leakage path.
It should be noted that, under the initial condition of the evaluation system, all the on-off valves are closed, and in the method, the logic sequence of the on-off valve state adjustment is described by taking an opening mode as a main line.
The invention adopts a reservoir rock sample or a cover layer rock sample or a cement rock sample which are connected in series and contain cracks to develop CO 2 The leakage channel healing capacity evaluation experiment considers the influence of reservoir produced particles on the healing behavior of the leakage channel; by sequential injection of saturated CO into saturated formation water rock samples 2 Formation water and saturated water supercritical CO 2 Is simulated by CO 2 Leakage process, can evaluate saturated CO 2 Formation water single phase flow and CO 2 -the combined effect of the formation water two-phase flow on the healing behaviour of the leak path; the healing behavior of different types and sizes of leakage channels in the cap layer/cement ring can be analyzed under simulated in-situ conditions and can be measured by the permeability and CO before and after leakage 2 Breakthrough pressure variation comprehensively characterizes the healing capacity of a leakage channel, and can be on-site CO 2 The leakage risk evaluation and leakage prevention and control measures provide technical guidance; testing CO using pressure decay method 2 The breakthrough pressure of the test system is simple and convenient to operate, the test speed is high, the accuracy is high, and the pressure attenuation method can simulate CO 2 The pressure evolution process from occurrence to stopping of leakage is more in line with the actual situation.
In one example of the present invention, the space between the second on-off valve 80, the third on-off valve 90 and the core inlet end face in the second core holder 20 forms an upstream container, the space between the fourth on-off valve 100 and the core outlet end face in the second core holder 20 forms a downstream container, and the volumes of the upstream container and the downstream container are 2.0-3.0 ml.
In one example of the present invention, in step S60, the rate of decrease in the permeability and the rate of increase in the breakthrough pressure are calculated by the following formulas:
wherein:R k permeability decrease rate,%;R b the breakthrough pressure increase rate of the rock sample,%;k a0 andk a the permeability of the rock sample before and after leakage, mD;p b0 andp b rock sample CO before and after leakage, respectively 2 Break through pressure, MPa.
In one example of the present invention, in step S20, the flow rate of the injected simulated formation water is 0.3mL/min to 0.5 mL/min; in steps S30 and S40, saturated water supercritical CO is injected 2 And saturated CO 2 The flow rate of the stratum water is 3.0 mL/min-5.0 mL/min.
In one example of the invention, the prepared reservoir rock sample and the prepared fracture-containing overburden rock sample or cement rock sample are each 2.5 to cm in diameter and 5.0 to 7.0 cm and 2.0 to 3.0 cm in length, respectively.
Examples
This embodiment targets a basin saline layer. The reservoir lithology of the salty water layer is argillaceous siltstone, the top burial depth of the reservoir is about 1270 m, the thickness of the reservoir is 110 m, the initial reservoir pressure is 12.5 MPa, the reservoir temperature is 64 ℃, the average porosity of the reservoir is 10% -23%, the permeability is 5-298 mD, and the main components of stratum water are shown in table 1; the salt water layer has a cover layer lithology of mudstone and sandy mudstone, a single layer of mudstone has a thickness of 21 m, an average porosity of 7.5%, and an average permeability of 3.3X10 -3 mD; the well cementation cement slurry selected by the injection well comprises A-grade ordinary Portland cement with the water cement ratio of 0.4.
TABLE 1 analysis of formation Water composition of certain salt water layer and Total mineralization thereof
| Component types | NaCl | CaCl 2 ‧2H 2 O | MgCl 2 ‧6H 2 O | KCl | Na 2 SO 4 | Totalizing |
| Content (g/L) | 139.33 | 22.00 | 5.23 | 4.12 | 0.52 | 160 |
The rock samples used in this example include reservoir rock samples, fractured overburden rock samples and fractured cement rock samples, and the fluids used include simulated formation water, saturated water supercritical CO 2 And saturated CO 2 The preparation method of the formation water comprises the following steps:
according to the SYT5358-2010 rock sample preparation method, core columns with the lengths of 6.0cm and 3.0 cm and the diameters of 2.5 cm are respectively drilled from a reservoir rock block and a overburden rock block which are collected on site; preparing a cement slurry system by adopting A-level ordinary Portland cement according to a water-cement ratio of 0.4, pouring the cement slurry system into a core mold, casting a cement rock sample with the length of 3.0 cm and the diameter of 2.5 cm, and curing the cement rock sample for 4 weeks under the conditions of 100% humidity, atmospheric pressure and room temperature; then, manually making joints on the overburden rock sample and the cement rock sample by adopting a Brazilian splitting method to obtain the overburden rock sample and the cement rock sample with different joint width cracks; after the rock sample is cleaned and dried, wrapping the surrounding of the rock sample by using an adhesive tape, and then measuring the outside of the adhesive tape and then wrapping the surrounding by using a thermoplastic plastic pipe.
Preparing simulated formation water according to the formation water components in table 1; by supercritical CO 2 And simulating stratum water as base liquid to prepare saturated water supercritical CO 2 And saturated CO 2 Formation water, a formulation apparatus 200 is shown in fig. 2. The apparatus comprises a second intermediate container 210, high pressure CO 2 A gas cylinder 220, a formation water pump 230, a hydraulic oil pump 240, a second back pressure regulator 250, a second gas-liquid separator 260, and a second incubator 270. The hydraulic oil pump 240 is connected with the first liquid inlet of the second intermediate container 210 and is used for pushing the piston to move; the second liquid inlet of the second intermediate container 210 is respectively connected with the high-pressure CO through three branch lines 2 The gas cylinder 220, the stratum water pump 230 and the liquid inlet of the first back pressure regulator are connected, and the liquid outlet of the second back pressure regulator 250 is connected with the second gas-liquid separator 260; the second intermediate container 210 is 1000mL in volume and is placed in a second incubator 270.
Injecting simulated formation water into the piston type second intermediate container 210, wherein the injection volume is 1/10 of the volume of the second intermediate container 210, and then injecting supercritical CO into the residual volume of the second intermediate container 210 under the conditions of the pressure of 12.5 MPa and the temperature of 64 DEG C 2 To be CO 2 After the water balance 48 and h, the second intermediate container 210 is inverted to push the piston to discharge the excessive water, thus obtaining the saturated water supercritical CO 2 The method comprises the steps of carrying out a first treatment on the surface of the Injecting simulated formation water into the second intermediate container 210, wherein the injection volume is 2/3 of the volume of the second intermediate container 210, and then injecting supercritical CO into the residual volume of the second intermediate container 210 under the conditions of the pressure of 12.5 MPa and the temperature of 64 DEG C 2 After balancing 48 and h, pushing the piston to discharge the excessive CO 2 Saturated CO is obtained 2 Formation water.
Geological sequestration of CO in this embodiment 2 The leakage channel healing capacity evaluation method comprises the following steps:
step 1: vacuumizing the prepared reservoir rock sample, the fractured overburden rock sample or the cement rock sample to be more than 48 and h of saturated simulated formation water, then respectively placing the reservoir rock sample and the fractured overburden rock sample or the cement rock sample in the first core holder 10 and the second core holder 20, opening the second injection device 40, applying 25.0MPa confining pressure to the reservoir rock sample and the fractured overburden rock sample or the cement rock sample, opening the first back pressure regulator 120 and the first constant temperature box 130, and setting the back pressure and the system temperature to 12.5 MPa and 64 ℃ respectively;
step 2: the first injection device 30 was turned on to inject simulated formation water into the fractured overburden or cement rock sample at a flow rate of 0.3 mL/min until the differential pressure across the rock sample was maintained constant, and the permeability of the fractured overburden or cement rock sample before leakage was calculated by darcy's law.
Step 3: injecting saturated water supercritical CO into a fractured overburden or cement rock sample 2 The injection flow rate is 3.0 mL/min until bubbles are produced at the outlet end, then the second on-off valve 80, the third on-off valve 90 and the fourth on-off valve 100 at the upstream and downstream of the second core holder 20 are closed to gradually attenuate the upstream pressure and continuously increase the downstream pressure until the pressure reaches balance, and the upstream and downstream pressure difference in the balance is recorded to be the CO of the cover rock sample or the cement rock sample containing cracks before leakage 2 Breaking through the pressure;
step 4: injecting saturated CO into a reservoir rock sample and a fracture-containing overburden or cement rock sample in series 2 The stratum water is injected at the flow rate of 3.0 mL/min until the pressure reaches balance, and then the saturated water supercritical CO is injected into the reservoir rock sample and the cover layer rock sample or the cement rock sample which are connected in series and contain cracks 2 The injection flow was 3.0 mL/min until the pressure reached equilibrium, the purpose of this step was to simulate CO 2 Is a leakage process of (1);
step 5: repeating steps S20 and S30, and determining the permeability and CO of the cover layer rock sample or cement rock sample containing cracks after leakage 2 Breaking through the pressure;
step 6: comparing permeability and CO of cap rock sample or cement rock sample containing cracks before and after leakage 2 Breakthrough pressure, the permeability reduction rate and the breakthrough pressure increase rate of the rock sample are calculated through the following formulas, and the CO is comprehensively evaluated 2 Healing ability of leakage path:
wherein:R k permeability decrease rate,%;R b the breakthrough pressure increase rate of the rock sample,%;k a0 andk a the permeability of the rock sample before and after leakage, mD;p b0 andp b rock sample CO before and after leakage, respectively 2 Break through pressure, MPa.
The geological sequestration of CO as proposed by the present invention is described in detail hereinabove with reference to the preferred embodiments 2 Exemplary embodiments of the leak path healing capability evaluation system 1000 and method, however, those skilled in the art will appreciate that numerous variations and modifications may be made to the specific embodiments described above without departing from the spirit of the invention, and that numerous combinations of the various features and structures presented herein may be implemented without departing from the scope of the invention, which is defined in the appended claims.
Claims (10)
1. Geological sequestration CO 2 A leak path healing capacity evaluation system, comprising:
a first thermostat (130) for regulating the temperature of the evaluation system (1000);
a first core holder (10) and a second core holder (20) which are sequentially connected in series, wherein the first core holder (10) is adapted to a reservoir rock sample, and the second core holder (20) is adapted to a cap rock sample or a cement rock sample containing cracks;
A first injection device (30) respectively communicated with the first core holder (10) and the second core holder (20) and configured to sequentially inject simulated formation water and saturated water supercritical CO into at least one of the first core holder (10) and the second core holder (20) 2 Saturated CO 2 Formation water;
a second injection device (40) in communication with the first core holder (10) and the second core holder (20), respectively, configured to apply a confining pressure to a reservoir rock sample in the first core holder (10) and a fracture-containing overburden rock sample or cement rock sample in the second core holder (20) simultaneously or independently;
differential pressure sensors (50) disposed on both sides of the second core holder (20) configured to detect a pressure difference across the second core holder (20);
a pressure sensor (60) disposed on a side of the second core holder (20) remote from the first core holder (10) and configured to detect a pressure of the side of the second core holder (20) remote from the first core holder (10);
wherein a first on-off valve (70) and a second on-off valve (80) are respectively arranged between the first injection device (30) and the first core holder (10) and between the first injection device and the second injection device (20); a third on-off valve (90) is arranged between the first core holder (10) and the second core holder (20); a fourth shut-off valve (100) is arranged at one end of the second core holder (20) away from the first core holder (10).
2. Geological sequestration CO according to claim 1 2 A leakage channel healing capacity evaluation system is characterized in that,
the first injection device (30) comprises:
a first injection pump (31);
three first intermediate containers (32) connected in parallel in sequence, each first intermediate container (32) comprises a container body and a piston movably arranged in the container body, wherein the container body is divided by the piston into two chambers, one chamber is communicated with the first injection pump (31), and the other chamber is respectively used for storing simulated formation water and saturated water supercritical CO 2 Saturated CO 2 The formation water is respectively communicated with the first core holder (10) and the second core holder (20).
3. Geological sequestration CO according to claim 2 2 A leakage channel healing capacity evaluation system is characterized in that,
a fifth on-off valve (33) is respectively arranged at two ends of each first intermediate container (32), and is configured to adjust on-off of the first intermediate container (32) and the first injection pump (31), the first core holder (10) and the second core holder (20).
4. Geological sequestration CO according to claim 1 2 A leakage channel healing capacity evaluation system is characterized in that,
the second injection means (40) comprises:
a second injection pump (41);
and two sixth on-off valves (42) respectively arranged between the second injection pump (41) and the first core holder (10) or the second core holder (20) and configured to switch on and off the pressure of the second injection pump (41) towards the first core holder (10) or the second core holder (20).
5. Geological sequestration CO according to claim 1 2 A leakage channel healing capacity evaluation system is characterized in that,
further comprises: a first gas-liquid separator (110),
is arranged at one side of the second core holder (20) away from the first core holder (10) and is used for collecting CO in produced liquid 2 And simulating formation water.
6. Geological sequestration CO according to claim 5 2 A leakage channel healing capacity evaluation system is characterized in that,
further comprises: a first back pressure regulator (120),
is disposed between the first gas-liquid separator (110) and the pressure sensor (60) for providing back pressure to a fractured overburden or cement rock sample within the second core holder (20).
7. A geological sequestration CO as claimed in any one of claims 1 to 6 2 The evaluation method of the leakage channel healing capacity evaluation system is characterized by comprising the following steps of:
s10: vacuumizing the prepared reservoir rock sample, the fractured overburden rock sample or the cement rock sample to simulate formation water for more than a preset time, then respectively placing the reservoir rock sample and the fractured overburden rock sample or the cement rock sample in a first core holder (10) and a second core holder (20), opening a second injection device (40), applying a certain confining pressure to the reservoir rock sample and the fractured overburden rock sample or the cement rock sample, and opening a first back pressure regulator (120) and a first constant temperature box (130) according to the method of claim 6, and respectively setting the back pressure and the system temperature to preset values;
s20: opening a first injection device (30), injecting simulated formation water into the fractured overburden rock sample or the cement rock sample until the pressure difference between two ends of the rock sample is kept constant, and calculating the permeability of the fractured overburden rock sample or the cement rock sample before leakage through Darcy's law;
s30: injecting saturated water supercritical CO into a fractured overburden or cement rock sample 2 Until bubbles are produced at the outlet end, then closing a second break valve (80), a third break valve (90) and a fourth break valve (100) at the upstream and downstream of the second core holder (20) to gradually attenuate the upstream pressure and continuously increase the downstream pressure until the pressure reaches balance, and recording the upstream and downstream pressure difference when the balance is achieved, namely the CO of the fractured overburden rock sample or the cement rock sample before leakage 2 Breaking through the pressure;
s40: injecting saturated CO into a reservoir rock sample and a fracture-containing overburden or cement rock sample in series 2 Formation water until the pressure reaches equilibrium, and then injecting saturated water supercritical CO into the reservoir rock sample and the overburden rock sample or cement rock sample containing cracks connected in series 2 Until the pressure reaches equilibrium, the purpose of this step is to simulate CO 2 Is a leakage process of (1);
s50: repeating steps S20 and S30, and determining the permeability and CO of the cover layer rock sample or cement rock sample containing cracks after leakage 2 Breaking through the pressure;
s60: comparing permeability and CO of cap rock sample or cement rock sample containing cracks before and after leakage 2 Breakthrough pressure, calculating permeability reduction rate of cover layer rock sample or cement rock sample containing cracks and breakthrough pressure increase rate, and comprehensively evaluating CO 2 The healing ability of the leakage path.
8. Geological sequestration CO according to claim 7 2 A method for evaluating the healing capacity of a leakage channel is characterized in that,
the space between the second on-off valve (80), the third on-off valve (90) and the core inlet end face in the second core holder (20) forms an upstream container, the space between the fourth on-off valve (100) and the core outlet end face in the second core holder (20) forms a downstream container, and the volumes of the upstream container and the downstream container are 2.0-3.0 mL.
9. Geological sequestration CO according to claim 7 2 A method for evaluating the healing capacity of a leakage channel is characterized in that,
in step S60, the rate of decrease in permeability and the rate of increase in breakthrough pressure are calculated by the following formulas:
wherein:R k permeability decrease rate,%;R b the breakthrough pressure increase rate of the rock sample,%;k a0 andk a the permeability of the rock sample before and after leakage, mD;p b0 andp b rock sample CO before and after leakage, respectively 2 Break through pressure, MPa.
10. The ground according to claim 7Mass sequestering CO 2 A method for evaluating the healing capacity of a leakage channel is characterized in that,
in the step S20, the flow rate of the injected simulated formation water is 0.3-0.5 mL/min; in steps S30 and S40, saturated water supercritical CO is injected 2 And saturated CO 2 The flow rate of the stratum water is 3.0-5.0 mL/min.
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