CN115387755B - CO (carbon monoxide) 2 Temporary plugging method for leakage along fault during geological storage - Google Patents
CO (carbon monoxide) 2 Temporary plugging method for leakage along fault during geological storage Download PDFInfo
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- CN115387755B CN115387755B CN202210948968.1A CN202210948968A CN115387755B CN 115387755 B CN115387755 B CN 115387755B CN 202210948968 A CN202210948968 A CN 202210948968A CN 115387755 B CN115387755 B CN 115387755B
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/20—Displacing by water
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/10—Locating fluid leaks, intrusions or movements
Abstract
The invention provides a CO 2 Temporary plugging method along fault leakage during geological storage, and CO is proposed 2 The critical concept of temporary plugging is implemented along fault leakage, and CO is realized by injecting water into an overlying stratum to form a hydraulic barrier 2 And (3) a temporary plugging method along fault leakage, and verifying the effectiveness of the temporary plugging method through a field test. Determining the maximum and minimum speed of water injection into the overlying stratum through stratum fracture conditions and the golden time for completing temporary plugging, carrying out field test by using temporary plugging parameters, and verifying CO through field monitoring data 2 The leakage speed is greatly reduced by more than 97%. The invention designs a CO 2 Temporary plugging site test along fault leakage greatly reduces CO 2 CO before complete of omnibearing repairing leakage 2 Leakage amount, contrast temporary plugging field test and non-temporary plugging field test, CO 2 Leakage amount is reduced (-0.069 t) 2 +8.49t‑4.9)m 3 T is the time of completion of the omnibearing leak repair, day.
Description
Technical Field
The invention belongs to CO 2 The field of geological sequestration, which relates to a CO 2 Temporary plugging method and field test method along fault leakage during geological storage.
Background
CO 2 Geological sequestration is an important technological means to achieve the "two carbon" goal. In this context, consider CO 2 Safe sealing and storing weightEssentially, CO 2 The problem of leakage along faults during geological sequestration has become a research hotspot. Some undetected faults in the cap layer are at CO 2 Is activated after injection, resulting in supercritical CO 2 Overburden formation (CO) along fault 2 Upper adjacent formation of the reservoir) leak. CO 2 After leakage along faults, an omnibearing repair strategy needs to be formulated by a professional team to ensure CO 2 And the sealing and storage are safe. Considering the characteristics of complex and long-time omnibearing repair process, the advanced formation of CO based on-site existing equipment is urgently needed 2 A temporary blocking method along fault leakage wins time for realizing omnibearing restoration for a professional team. From this point, the temporary plugging method and concept proposed by the invention are to realize CO 2 Critical steps for omnibearing repair of leakage along fault.
From the pressure balance point of view, water can be injected into an overlying stratum to increase pore pressure to form a hydraulic barrier so as to realize temporary plugging. From this point, the temporary plugging is realized in close relation with the water injection speed and time of the overlying strata. The shorter the time to complete temporary plugging, the greater the water injection rate required. In particular, the maximum water injection rate is controlled by overburden fracture conditions. However, subject to existing equipment in the field, the water injection rate may not reach the maximum water injection rate, and for this reason, the minimum water injection rate to achieve temporary plugging needs to be calculated, which involves the definition of "golden time to complete temporary plugging". The invention defines the golden time for completing temporary plugging as 72 hours by referring to the golden rescue time of accidents such as earthquake, mine disaster and the like. In view of this, there is an urgent need to propose a CO 2 And (3) a temporary plugging method for leakage along a fault during geological storage, and verifying the effectiveness of the temporary plugging method through field tests.
At present, students have developed experimental devices and methods to simulate CO 2 Leakage problems in the geological storage process, such as a method and a device for monitoring geological storage carbon dioxide leakage (CN 201110358126.2), a method for judging a carbon dioxide geological storage leakage point by using temporary plugging agents (CN 202010514938.0) and a monitoring system for carbon dioxide geological storage leakage (CN 201110221982.3). However, the experimental device and method are mainly used for monitoring CO 2 Is arranged in the leakage position of the (c),CO is not given 2 And repairing measures along fault leakage. In view of this, a CO is proposed 2 Temporary plugging methods and field tests along fault leakage during geological sequestration are imperative.
Disclosure of Invention
The invention provides a CO 2 Temporary plugging method and site test method for leakage along faults during geological storage, and CO is realized by injecting water into an overlying stratum to form a hydraulic barrier 2 And (3) a temporary plugging method along fault leakage, and verifying the effectiveness of the temporary plugging method through a field test.
To achieve the above object, one aspect of the present invention provides a CO 2 The temporary blocking method for leakage along faults during geological storage comprises the following operation steps: (1) Determination of CO 2 The fault location of the leak; (2) flooding the overburden with water at a flooding velocity v; (3) When the water injection time is t, forming a hydraulic barrier to finish temporary blocking; wherein the water injection speed v is controlled to be at the minimum water injection speed v for realizing temporary plugging and preventing the overlying stratum from cracking min And a maximum water injection velocity v max Simultaneously controlling the water filling time t to be at the minimum water filling time t min And "golden time to complete temporary blocking" t a Between them.
In the invention, the maximum water injection speed v max The method is calculated by the following steps:
(1) Determining overburden fracture pressure allowance
Wherein P is w f 、
The fracture pressure of the overburden stratum is an allowable value of the fracture pressure, and the pressure is MPa; n is a safety coefficient and is dimensionless; p (P) p upper To overburden the initial pore pressure, obtained from the applied pore pressure,MPa；σ H 、σ h the maximum and minimum horizontal main stress of the overlying stratum are respectively obtained by the applied horizontal confining pressure and MPa; alpha is the specific austenite coefficient, typically 0.85; sigma (sigma) t The tensile strength of the overburden stratum is obtained by Brazilian split test, MPa;
(2) Determining pore pressure distribution caused by water injection of the overburden:
wherein P is r upper Pore pressure distribution of the overburden formation, MPa; v is the water injection speed, m 3 ·s -1 ；
Is water weight, kN.m -3 The method comprises the steps of carrying out a first treatment on the surface of the T is the water conductivity coefficient of the overburden formation, m 2 ·s -1 The method comprises the steps of carrying out a first treatment on the surface of the t is water injection time, s; r is the horizontal distance between the fault position and the water injection well, and m; s is the water storage coefficient of the overlying stratum, and is dimensionless;
(3) With the maximum pore pressure (r.fwdarw.0) in (2) equal to the allowable value of the fracture pressure
To control the condition, calculate the maximum water injection speed v max ：
In the invention, the minimum water injection time t min The method is calculated by the following steps:
(1) At maximum water filling speed v max Under the condition, the pore pressure P of the overlying stratum at the leakage position is calculated by adopting an iteration method t upper And bottom brine layer pore pressure P t lower ：
Wherein DeltaP t upper 、ΔP t lower The iteration increment of pore pressure at the leakage position of the overburden stratum and the bottom saline layer in the time t and delta t is MPa; p (P) p lower Initial pore pressure for the bottom brine layer, obtained from the applied pore pressure, MPa; r is (r) 1 The horizontal distance between the water injection well and the leakage position is m;
for time t CO 2 Leakage rate, m 3 ·s -1 ；P float Is supercritical CO 2 Buoyancy caused by the difference between the water density and the buoyancy, and MPa;
(2) Determining the minimum water injection time t by using the pore pressure of the overlying stratum at the leakage position at the iteration step k equal to the pore pressure of the bottom saline layer min ：
t min ＝k·Δt
In the invention, the golden rescue time of accidents such as earthquake, mine disaster and the like is used as reference, the golden time for completing temporary blocking is defined as 72 hours, and is recorded as t a And calculating the minimum water injection speed by taking temporary plugging completed in 72 hours as a control condition. The minimum water injection speed v min The method is calculated by the following steps:
(1) Adopting a trial algorithm to give a trial-and-computation initial value v trial Calculate t=t a Pore pressure at the leak-off site of overburden and bottom brine layer:
in the method, in the process of the invention,
respectively for the given water injection speedPore pressure at the leak site of the layer, bottom brine layer, MPa;
(2) Adjusting the initial value of trial calculation to enable
At this time, the initial value v 'is calculated' trial I.e. the minimum water injection speed v min ：
v min ＝v′ trial
In the invention, under the condition of a given water injection speed v, the corresponding water injection time t is obtained through the following steps:
(1) At a given water filling rate v (v min ≤v≤v max ) Under the condition, the pore pressure P of the overlying stratum at the leakage position is calculated by adopting an iteration method t upper And bottom brine layer pore pressure P t lower ：
Wherein DeltaP t upper 、ΔP t lower The iteration increment of pore pressure at the leakage position of the overburden stratum and the bottom saline layer in the time t and delta t is MPa; p (P) p lower Initial pore pressure for the bottom brine layer, obtained from the applied pore pressure, MPa; r is (r) 1 The horizontal distance between the water injection well and the leakage position is m;
for time t CO 2 Leakage rate, m 3 ·s -1 ；P float Is supercritical CO 2 Buoyancy caused by the difference between the water density and the buoyancy, and MPa;
(2) Determining the water injection time t under the condition of a given water injection speed v by using the pore pressure of the overlying stratum at the leakage position in the iteration step j to be equal to the pore pressure of the bottom saline layer:
t＝j·Δt
in the invention, the microseism monitoring technology is adopted to determine the fault position.
In the invention, in order to save time, a water injection well with the nearest horizontal distance from the fault leakage position in the overlying stratum is selected for water injection.
In a second aspect the invention provides a CO 2 The temporary plugging site test of fault leakage during geological storage comprises the following specific operation steps:
step 1: layout field test device
CO (carbon monoxide) 2 The temporary plugging field test device for leakage along faults during geological storage comprises a foundation pit, a bottom saline layer, a cover layer, an overburden stratum, faults, rock particles, a steel plate, a fluid velocity sensor, an anti-seepage box body, a hydraulic support, a balancing weight, a liquid booster, a pressure-bearing steel pipe and supercritical CO 2 Gas tank, CO 2 Injection well, fluid pressure sensor, constant pressure water tank, water injection well; the bottom saline layer, the cover layer and the overlying stratum form a target stratum together, and an impermeable box body is arranged outside the target stratum; setting faults in the cover layer, filling the faults with rock particles, and activating the faults by drawing the steel plate; the outer side and the top of the foundation pit are respectively applied with horizontal confining pressure and vertical shaft pressure through a hydraulic bracket and a balancing weight; injecting the water pressurized by the liquid booster into a target stratum through a pressure-bearing steel pipe to realize initial pore pressure application; the water injection well is responsible for injecting water into an overlying stratum; CO 2 The injection well is responsible for injecting CO into the bottom brine layer 2 The method comprises the steps of carrying out a first treatment on the surface of the The constant-pressure water tank is communicated with a target stratum through a pressure-bearing steel pipe; a fluid velocity sensor is arranged in the fault, and a fluid pressure sensor is arranged in the CO 2 The bottom of the injection well;
step 2: developing temporary plugging field test
(1) Applying a horizontal confining pressure, a vertical axial pressure and an initial pore pressure to the target formation;
(2) By CO 2 Injection well injecting CO into bottom brine layer 2 Stopping CO after reaching the preset injection amount 2 Injecting;
(3) The drawing steel plate activates faults to cause CO 2 Edge breakLayer leakage;
(4) Setting a water injection speed v, calculating water injection time t, and implementing water injection of an overburden stratum; forming a hydraulic barrier to finish temporary plugging;
(5) Ending the test and recording CO 2 Real-time leak rate;
step 3: verifying validity of temporary plugging method
(1) At maximum water injection speed v max Minimum water injection time t min Developing a first set of field trials; at minimum water filling speed v min Golden time t for completing temporary blocking a Developing a second set of field tests; at any given water filling rate v 1 (v min ≤v 1 ≤v max ) Corresponding water injection time t 1 Developing a third set of field tests;
(2) Respectively obtaining CO of three groups of field tests 2 Initial leakage rate and CO at the end of the test 2 If the leakage speed is reduced to less than 3% of the initial leakage speed after the test is finished, the temporary plugging method can meet the field engineering;
step 4: determining temporary plugging advantage
(1) Developing a fourth group of field tests without temporary plugging, and monitoring CO 2 Real-time leakage velocity, acquiring 'CO' by integrating the real-time velocity 2 CO before complete of omnibearing repairing leakage 2 Leakage amount;
(2) CO by testing on a first set of sites 2 Integrating the leakage speed in real time to obtain CO 2 CO before complete of omnibearing repairing leakage 2 Leakage amount;
(3) Comparing the CO of (1) and (2) 2 The leakage quantity can be confirmed to greatly reduce CO by temporary blocking 2 Leakage quantity, embody temporary blocking in CO 2 The necessity and unique advantages in leak omnibearing remediation processes.
In the present invention, CO 2 The leak rate is monitored by a fluid velocity sensor disposed within the fracture.
In the present invention, "CO 2 CO before complete of omnibearing repairing leakage 2 Leakage amount through CO 2 Real-time dischargingLeakage velocity versus time integral acquisition, i.e
V leak Is CO 2 Leakage amount, m 3 ；v leak Is CO 2 Real-time leak rate, m 3 ·s -1 ；t start Is the omnibearing repair start time (integral lower limit), s; t is t finish And s is the omnibearing repair completion time (integral upper limit).
Compared with the prior art, the invention has the following beneficial effects:
1. the invention provides CO 2 Firstly, implementing a temporary plugging key concept along fault leakage, defining a design concept of completing temporary plugging by using a field device to fill water into an overlying stratum to increase pore pressure to form a hydraulic barrier, and proving the feasibility of completing temporary plugging through the hydraulic barrier in an actual environment through a demonstration test;
2. the invention provides a CO 2 A temporary plugging method along fault leakage determines the maximum and minimum speeds of water injection to an overlying stratum through stratum fracture conditions and the golden time for completing temporary plugging, performs site tests with temporary plugging parameters, and verifies CO through site monitoring data 2 The leakage speed can be greatly reduced by more than 97%;
3. the invention designs a CO 2 Temporary plugging site test along fault leakage greatly reduces CO 2 CO before complete of omnibearing repairing leakage 2 Leakage amount, contrast temporary plugging field test and non-temporary plugging field test, CO 2 Leakage amount is reduced (-0.069 t) 2 +8.49t-4.9)m 3 T is the time of completion of the omnibearing leak repair, day.
Drawings
FIG. 1 is a schematic diagram of a demonstrative test structure of the invention;
FIG. 2 is a schematic diagram of a field test structure of the present invention;
FIG. 3 is a top view of the field test apparatus of the present invention;
FIG. 4 is a schematic diagram of a fault structure of the present invention;
FIG. 5 is a diagram showing the result of embodiment 1 of the present invention;
FIG. 6 is a comparative verification chart of the temporary plugging method of the present invention;
FIG. 7 is a comparative graph of the results of example 2 of the present invention;
in the figure: 1. a demonstrative testing device; 101. a transparent case; 102. an interlayer; 103. a leakage path; 104. a highly elastic thin layer; 105. an injection tube; 2. a foundation pit; 3. a bottom brine layer; 4. a cover layer; 5. coating a stratum; 6. a fault; 601. rock particles; 602. a steel plate; 603. a fluid velocity sensor; 7. an impermeable box body; 8. a hydraulic support; 9. balancing weight; 10. a liquid pressurizer; 11. a pressure-bearing steel pipe; 12. supercritical CO 2 A gas tank; 13. CO 2 An injection well; 14. a fluid pressure sensor; 15. a constant pressure water tank; 16. and (3) a water injection well.
Detailed Description
The details of the invention will be more clearly understood in conjunction with the accompanying drawings and description of specific embodiments of the invention. However, the specific embodiments of the invention described herein are for the purpose of illustration only and are not to be construed as limiting the invention in any way. Given the teachings of the present invention, one of ordinary skill in the related art will contemplate any possible modification based on the present invention, and such should be considered to be within the scope of the present invention.
In one embodiment, a CO 2 The temporary blocking method for leakage along faults during geological storage comprises the following operation steps: (1) Determination of CO 2 Leak (fault) location; (2) flooding the overburden with water at a flooding velocity v; (3) When the water injection time is t, a hydraulic barrier is formed, and temporary blocking is completed; wherein the water injection speed v is controlled to be at the minimum water injection speed v for realizing temporary plugging and preventing the overlying stratum from cracking min And a maximum water injection velocity v max Simultaneously controlling the water filling time t to be at the minimum water filling time t min And "golden time to complete temporary blocking" t a Between:
step 1: calculating the maximum water injection speed v max
Determining the distribution of the water injection wells Zhou Yingli of the overburden formation 5 according to the elastomehc, wherein the distribution is represented by the following formula (1):
wherein P is w The pressure in the water injection well 16 well is the pressure in the overburden stratum 5 and is MPa; p (P) p upper Initial pore pressure for overburden 5, obtained from the applied pore pressure, MPa; sigma (sigma) H 、σ h The maximum and minimum horizontal main stresses of the overburden stratum 5 are respectively obtained by the applied horizontal confining pressure and MPa; alpha is the specific austenite coefficient, typically 0.85;
the fracture pressure of the overburden layer 5 is determined by formula (1) and the maximum tensile stress criteria, as shown in formula (2):
P w f ＝3σ h -σ H -αP p upper +σ t (2)
in engineering practical application, a safety coefficient is generally introduced to convert the fracture pressure into a fracture pressure allowable value, and the following formula (3) is adopted:
wherein P is w f 、
The allowable value of the fracture pressure and the fracture pressure of the overburden stratum 5 is MPa; sigma (sigma) t The tensile strength of the overburden layer 5 is obtained by a Brazilian split test, MPa; n is a safety coefficient and is dimensionless.
According to a Jacob formula of groundwater dynamics and a water head pressure calculation formula, determining pore pressure distribution caused by water injection of an overburden stratum, wherein the pore pressure distribution is represented by the following formula (4):
wherein P is r upper Pore pressure distribution, MPa, for overburden formation 5;
is water weight, kN.m -3 The method comprises the steps of carrying out a first treatment on the surface of the v is the water injection speed, m 3 ·s -1 The method comprises the steps of carrying out a first treatment on the surface of the T is the water conductivity coefficient of the overburden stratum 5, m 2 ·s -1 The method comprises the steps of carrying out a first treatment on the surface of the t is water injection time, s; r is the horizontal distance from the water injection well 16, m; s is the water storage coefficient of the overburden stratum 5, and has no dimension.
With the maximum pore pressure (r.fwdarw.0) in formula (4) equal to the allowable value of the fracture pressure
To control the condition, calculate the maximum water injection speed v max The following formula (5):
step 2: calculating the minimum water injection time t min
At maximum water filling speed v max Under the condition, calculating the minimum water injection time t min Firstly, calculating the pore pressure of the overburden layer 5 and the pore pressure of the bottom saline layer 3; pore pressure P at the leak-off site of overburden 5 t upper The calculation adopts an iteration method, and the iteration formula is shown as the following formula (6):
wherein DeltaP t upper The iteration increment of pore pressure at the leakage position of the overburden stratum 5 in the time t and delta t is MPa; r is (r) 1 A horizontal distance m between the water injection well 16 and the leakage point;
for time t CO 2 The leakage speed can be obtained by the up-down pressure difference at the leakage position and Darcy law, and the following formula (7):
wherein k is the permeability coefficient of the fracture zone of fault 6, m.s -1 The method comprises the steps of carrying out a first treatment on the surface of the h is the height of the fault 6, m; p (P) p lower Initial pore pressure, MPa, for bottom brine layer 3; a is the horizontal cross-sectional area of fault 6, m 2 ；
Pore pressure at the leak location for bottom brine layer 3 is measured at time t- Δt from CO in Δt time 2 The iteration increment caused by leakage, i.e.)>
Middle->
Items, MPa;
pore pressure P at the bottom brine layer 3 leak site t lower The calculation adopts an iteration method, and the iteration formula is shown as the following formula (8):
wherein DeltaP t lower The iteration increment of pore pressure at the leakage position of the bottom brine layer 3 in the time t and delta t is MPa; p (P) float Is supercritical CO 2 Buoyancy, MPa, caused by the difference in water density, can be determined by the following formula (9):
in the method, in the process of the invention,
is of water density, kg.m -3 ；/>
Is supercritical CO 2 Density of，kg·m -3 ；
When iterating step k, the overburden 5 pore pressure at the leak-off location is equal to the bottom brine layer 3 pore pressure, from the pressure balance, the CO 2 The leakage will not continue, temporary plugging is completed, and the water injection time at this time is the minimum water injection time, which is equal to the product of the iteration step number and the time step length, and the following formula (10):
t min ＝k·Δt (10)
step 3: calculating a minimum water injection velocity v min
The golden rescue time of accidents such as earthquake, mine disaster and the like is used as reference, the golden time for completing temporary plugging is defined as 72 hours and is recorded as t a And calculating the minimum water injection speed by taking temporary plugging completed in 72 hours as a control condition.
Adopting a trial algorithm to give a trial-and-computation initial value v trial Substituting the initial trial calculation values into formulas (6) and (8) to perform iterative calculation, when the total step length of iterative time is equal to the given time t a Obtaining the trial calculation result
The following formula (11):
in the method, in the process of the invention,
pore pressures at the leakage positions of the overburden layer 5 and the bottom saline layer 3 under the given water injection speed are respectively expressed in MPa;
adjusting the initial value of trial calculation to enable
At this time, the initial value v 'is calculated' trial The minimum water injection speed is as follows:
v min ＝v′ trial (12)
step 4: calculating the water filling time t given the water filling speed v
Given the water filling rate v (v min ≤v≤v max ) Calculating the water injection time t by using formulas (6) to (10), wherein v max V is required to be replaced;
the second embodiment provides a hydraulic barrier demonstrative test, which comprises the following operation steps:
in particular, since the hydraulic barrier formed under actual site conditions is difficult to observe directly, a demonstrative test of the hydraulic barrier under one scale condition was carried out, intuitively revealing the formation of the hydraulic barrier.
Step 1: layout demonstrative test
As shown in fig. 1, the hydraulic barrier demonstrative test comprises a demonstrative test device 1, a transparent box 101, a barrier layer 102, a leakage channel 103, a high-elasticity thin layer 104 and an injection pipe 105;
manufacturing a transparent box body 101 with the volume of 1m x 0.6m high, arranging a separation layer 102 with the thickness of 0.1m in the transparent box body 101 to divide the transparent box body 101 into an upper box body and a lower box body, wherein the separation layer 102 is positioned in the middle of the transparent box body 101; a leakage channel 103 with the width of 0.02m is arranged at a position 0.2m away from the right wall surface of the transparent box body 101, and an activation switch and a closing switch are arranged on the leakage channel 103; a highly elastic lamina 104 is provided above the leakage path 103; injection pipes 105 are arranged in the upper tank body and the lower tank body and are respectively responsible for injecting water into the upper tank body and gasoline into the lower tank body (adopting the gasoline to simulate supercritical CO 2 Without direct use of supercritical CO 2 Mainly because of supercritical CO at normal temperature and normal pressure 2 Unable to maintain its state);
step 2: developing a demonstrative test
Closing the leakage channel 103, setting the initial pressures of the upper tank and the lower tank to be equal, injecting water into the upper tank and injecting gasoline into the lower tank through the injection pipe 105; after the upper tank and the lower tank reach the initial pressure, the upper tank stops filling water, the lower tank continues to fill gasoline, and the leakage channel 103 is activated by the switch; as the gasoline starts to leak along the leak path 103, the high elastic thin layer 104 starts to bulge and deform upwards, and when the maximum value of bulge deformation reaches a preset value, the lower tank stops injecting gasoline, and the upper tank starts to inject water again; after the upper tank is refilled with water, the change process of the convex deformation of the high-elasticity thin layer 104, namely 'increasing before decreasing', is observed, and the forming process of the hydraulic barrier is intuitively revealed; when the convex deformation of the highly elastic sheet 104 disappears, the test is stopped.
In a third embodiment, a CO is provided 2 The temporary plugging site test of fault leakage during geological storage comprises the following operation steps:
step 1: layout field test
As shown in fig. 2-4, the one kind of CO 2 The temporary plugging site test device for leakage along faults during geological storage comprises a foundation pit 2, a bottom saline layer 3, a cover layer 4, an overburden layer 5, faults 6, rock particles 601, a steel plate 602, a fluid speed sensor 603, an impermeable box 7, a hydraulic support 8, a balancing weight 9, a liquid booster 10, a pressure-bearing steel pipe 11 and supercritical CO 2 Gas tank 12, CO 2 Injection well 13, fluid pressure sensor 14, constant pressure water tank 15, water injection well 16;
excavating a foundation pit 2 with the volume of 3km multiplied by 100m in depth, and sequentially filling a bottom saline layer 3, a cover layer 4 (a fault 6 and a groove are required to be reserved) and an overlying stratum 5 with the heights of 50m, 10m and 40m in the foundation pit 2 from bottom to top to form a target stratum; the bottom saline layer 3 and the overlying stratum 5 are mixed with cement: sand: water is equal to 1:0.33:0.42, the mixture ratio of the mortar of the cover layer 4 is cement: sand: water is equal to 1:0.11:0.42; the outside of the target stratum is provided with a seepage-proof box body 7 (made of thin steel plates) for preventing water and CO stored in the target stratum 2 Oozing out under high pressure conditions; the outside and the top of the foundation pit 2 are respectively applied with horizontal confining pressure and vertical shaft pressure through a hydraulic bracket 8 and a balancing weight 9; injecting the water pressurized by the liquid booster 10 into a target stratum through the pressure-bearing steel pipe 11 to realize initial pore pressure application;
designing a fault 6 at the position 1km to the right of the center of the cover layer 4, wherein the fault 6 is filled with rock particles 601 and is used for simulating a broken belt in an actual fault; the upper side and the lower side of the fault 6 are provided with steel plates 602, grooves are reserved in the cover layer 4, and the fault 6 is activated and closed by pulling the steel plates 602 into the grooves; a fluid velocity sensor 603 is arranged in the fault 6 for monitoring the leakage velocity in real time;
the water injection well 16 is arranged in the center of the target stratum and is responsible for injecting water into the overburden stratum 5; CO 2 Injection well 13 is connected with supercritical CO 2 A gas tank 12 arranged at 1km left side of the water injection well 16 and responsible for injecting CO into the bottom saline layer 3 2 The method comprises the steps of carrying out a first treatment on the surface of the In CO 2 A fluid pressure sensor 14 is arranged at the bottom of the injection well 16 and is responsible for monitoring the pore pressure of the bottom saline layer 3; a constant pressure water tank 15 (constant pressure and equal to the initial pore pressure) is in communication with the target formation through a pressure-bearing steel pipe 11 for simulating CO 2 The subsurface fluid seepage process (namely self-regulating function of pore pressure in an infinite stratum) under the actual conditions caused by the injection of water into the overburden stratum 5;
step 2: developing temporary plugging field test
(1) Applying horizontal confining pressure and vertical axial pressure to a target stratum through a hydraulic support 8 and a balancing weight 9; after being pressurized by the liquid pressurizer 10, the water is conveyed to a target stratum by the pressure-bearing steel pipe 11 to apply initial pore pressure;
(2) By CO 2 The injection well 13 injects CO into the bottom brine layer 3 2 Stopping CO after reaching the preset injection amount 2 Injecting;
(3) The drawing steel plate 602 activates fault 6, causing CO 2 Leakage along fault 6;
(4) Given the water filling speed v, the water filling time t is calculated by using the formulas (6) - (10) (v is needed to be calculated when the water filling speed v is calculated) max Replacing v) to implement overburden flooding; forming a hydraulic barrier to finish temporary plugging;
(5) Ending the test, recording CO by fluid velocity sensor 603 2 Real-time leak rate;
step 3: verifying validity of temporary plugging method
(1) At maximum water injection speed v max Minimum water injection time t min Developing a first set of field trials; at minimum water filling speed v min Golden time t for completing temporary blocking a Developing a second set of field tests; given an arbitrary water injection velocity v 1 (v min ≤v 1 ≤v max ) Calculating the water injection speed by the formulas (6) to (10)Is filled with water for a period t 1 (v is calculated max Replaced by v 1 ) In v 1 、t 1 Developing a third set of field tests;
(2) Respectively obtaining CO of three groups of field tests 2 Initial leakage rate and CO at the end of the test 2 If the leakage speed is reduced to less than 3% of the initial leakage speed after the test is finished, the temporary plugging method can meet the field engineering;
step 4: determining temporary plugging advantage
(1) Developing a fourth group of field tests without temporary plugging, and monitoring CO 2 Real-time leak rate, via CO 2 Real-time leakage velocity versus time integral acquisition of CO 2 CO before complete of omnibearing repairing leakage 2 Leakage amount, i.e.
V leak Is CO 2 Leakage amount, m 3 ；v leak Is CO 2 Real-time leak rate, m 3 ·s -1 ；t start Is the omnibearing repair start time (integral lower limit), s; t is t finish Complete time (upper integral limit) for omnibearing repair, s;
(2) By testing CO on a first group of sites 2 Real-time leakage velocity versus time integral acquisition of CO 2 CO before complete of omnibearing repairing leakage 2 Leakage amount;
(3) Comparison of the COs in (1) and (2) 2 The leakage quantity can be confirmed to greatly reduce CO by temporary blocking 2 Leakage quantity, embody temporary blocking in CO 2 Unique advantages in leak omnibearing remediation processes.
Example 1:
according to the hydraulic barrier demonstrative test provided in the second embodiment, the demonstrative test is arranged according to the step 1; according to step 2, an initial pressure value of the upper tank body and the lower tank body is set to be 10kPa, a preset value of the maximum bulge deformation of the high elastic thin layer 104 is set to be 8cm, a water injection speed of the upper tank body and a gasoline injection speed of the lower tank body are set to be 1kg/s, a demonstrative test is carried out, and bulge deformation results are recorded every 10 minutes after the upper tank body is refilled with water, as shown in fig. 5;
as can be seen from fig. 5, the maximum value of the bulge deformation shows a tendency of increasing and then decreasing with time after refilling the upper tank, from 8cm to 9.8cm, and from 8cm to 9.3cm, 5.1cm and 0.7cm, and the formation of the "hydraulic barrier" is verified.
Example 2:
according to a CO provided in embodiment three 2 Temporary plugging field test along fault leakage during geological storage, laying field test according to step 1, and obtaining tensile strength sigma of bottom saline layer 3 and overlying stratum 5 through rock strength test t 6MPa; the permeability experiment shows that the water conductivity coefficient T and the water storage coefficient S of the overburden stratum are respectively 3 multiplied by 10 -5 m 2 /s、1×10 -5 The method comprises the steps of carrying out a first treatment on the surface of the Setting horizontal x-direction and y-direction confining pressure and vertical axial pressure to be 20MPa, 16MPa and 18MPa, setting initial pore pressure to be 12MPa, setting safety coefficient n to be 1.3 and setting CO to be 1.3 2 The injection speed is 5kg/s, and the omnibearing leakage repairing completion time is 30d; obtaining water and supercritical CO 2 The weight is 9.8 KN.m -3 、4.48KN·m -3 The method comprises the steps of carrying out a first treatment on the surface of the Calculating the maximum water injection speed v according to formulas (1) - (5) max The minimum water filling time t is calculated according to formulas (6) to (10) at 242.5kg/s min For 32.9h, a minimum water injection velocity v was calculated according to formulas (11) - (12) min 178.6kg/s; developing the maximum water injection speed v through the field test step 2 max (242.5 kg/s, 32.9 h), minimum fill velocity v min Temporary plugging field test under (178.6 kg/s, 72 h); carrying out a non-temporary plugging field test through the steps (1) and (2) in the field test step 2;
obtaining CO at the maximum water injection speed through the step (2) in the step 3 2 Initial leakage Rate and CO at the end of the test 2 Leakage speed and comparison, and acquisition of CO at minimum water injection speed 2 Initial leakage Rate and CO at the end of the test 2 Leakage rates are compared and shown in fig. 6; the results show that the temporary plugging method under the maximum and minimum water injection speeds is used for carrying out field tests, and the initial leakage speed is respectively reduced by 98.3 percent and 97.2 percent, so that the temporary plugging method can meet the field engineering requirements;
obtaining CO of the non-temporary plugging field test through the step (1) in the step 4 2 Before complete of all-round repair of leakage "CO 2 Leakage amount; acquiring CO of a temporary plugging field test under the maximum water injection speed through the step (2) in the step (4) 2 Before complete of all-round repair of leakage "CO 2 Leakage amount; comparing CO tested in temporary plugging and non-temporary plugging sites in the step (3) 2 The amount of leakage, as shown in fig. 7; the results show that the temporary plugging site test of the invention is compared with the CO of the site test without temporary plugging 2 The leakage amount is reduced by 186.4m 3 The method comprises the steps of carrying out a first treatment on the surface of the In particular for different CO' s 2 The complete time of the omnibearing leak repairing can be obtained by fitting the test data in the figure 7, and the CO under the condition of temporary plugging ratio without temporary plugging 2 Leakage amount is reduced (-0.069 t) 2 +8.49t-4.9)m 3 T is the completion time of the omnibearing leak repair, and is the day.
Claims (8)
1. CO (carbon monoxide) 2 The temporary blocking method for leakage along faults during geological storage is characterized by comprising the following specific operation steps: (1) Determination of CO 2 The fault location of the leak; (2) flooding the overburden with water at a flooding velocity v; (3) When the water injection time is t, forming a hydraulic barrier to finish temporary blocking; wherein the water injection speed v is controlled to be at the minimum water injection speed v for realizing temporary plugging and preventing the overlying stratum from cracking min And a maximum water injection velocity v max Between them;
the maximum water injection speed v max The method is calculated by the following steps:
(1) Determination of the overburden fracture pressure tolerance value P w f ]：
Wherein P is w f 、[P w f ]The allowable value of the fracture pressure and the fracture pressure of the overlying stratum are respectively MPa; n is a safety coefficient and is dimensionless;
initial pore pressure for the overburden formation, derived from the applied pore pressure, MPa; sigma (sigma) H 、σ h The maximum and minimum horizontal main stress of the overlying stratum are respectively obtained by the applied horizontal confining pressure and MPa; alpha is the specific austenite coefficient, typically 0.85; sigma (sigma) t The tensile strength of the overburden stratum is obtained by Brazilian split test, MPa;
(2) Determining pore pressure distribution caused by water injection of the overburden:
in the method, in the process of the invention,
pore pressure distribution of the overburden formation, MPa; />
Pore pressure increment caused by water injection of an overburden is increased by MPa; v is the water injection speed, m 3 ·s -1 ；/>
Is water weight, kN.m -3 The method comprises the steps of carrying out a first treatment on the surface of the T is the water conductivity coefficient of the overburden formation, m 2 ·s -1 The method comprises the steps of carrying out a first treatment on the surface of the t is water injection time, s; r is the horizontal distance between the fault position and the water injection well, and m; s is the water storage coefficient of the overlying stratum, and is dimensionless;
(3) With the pore pressure maximum in (2), i.e. the pore pressure at r.fwdarw.0 equal to the allowable value of the fracture pressure [ P ] w f ]To control the condition, calculate the maximum water injection speed v max ：
The golden rescue time of the earthquake and mine accident is used as reference, the golden time for completing temporary blocking is defined as 72 hours and is recorded as t a Calculating the minimum by taking temporary blocking completed in 72 hours as a control conditionThe water injection speed; the minimum water injection speed v min The method is calculated by the following steps:
(1) Adopting a trial algorithm to give a trial-and-computation initial value v trial Calculate t=t a Pore pressure at leak-off site of overburden and bottom brine layer:
in the method, in the process of the invention,
respectively calculating initial value v trial Lower t a Pore pressure of the time-overlaid stratum and the bottom saline layer at the leakage position is MPa; />
Respectively calculating initial value v trial Lower t a Pore pressure increment of the time overlying stratum and the bottom saline layer at the leakage position is increased by MPa; v trial To calculate initial value, m for water injection speed 3 ·s -1 The method comprises the steps of carrying out a first treatment on the surface of the Δt is the time increment, s;
at t a Time of day CO 2 Leakage rate, m 3 ·s -1 ；/>
Is supercritical CO 2 Severe, kN.m -3 ；/>
Initial pore pressure for the bottom brine layer, obtained from the applied pore pressure, MPa; r is (r) 1 The horizontal distance between the water injection well and the leakage position is m; p (P) float Is supercritical CO 2 Buoyancy caused by the difference between the water density and the buoyancy, and MPa;
(2) Adjusting the initial value of trial calculation to enable
At this time, the initial value v 'is calculated' trial I.e. the minimum water injection speed v min ：
v min ＝v′ trial
The corresponding water filling time t is calculated under the condition of the given water filling speed v through the following steps:
(1) At a given water injection rate v, where v min ≤v≤v max Calculating overburden pore pressure P at leak-off location using iterative methods t upper And bottom brine layer pore pressure P t lower ：
Wherein DeltaP t upper 、ΔP t lower The iteration increment of pore pressure at the leakage position of the overburden stratum and the bottom saline layer in the time t and delta t is respectively MPa;
for time t CO 2 Leakage rate, m 3 ·s -1 ；
(2) Determining the water injection time t under the condition of a given water injection speed v by using the pore pressure of the overlying stratum at the leakage position in the iteration step j to be equal to the pore pressure of the bottom saline layer:
t＝j·Δt。
2. a CO according to claim 1 2 Temporary plugging method for leakage along fault during geological sealing, which is characterized in that the water injection time t is controlled to be at the minimum water injection time t min And "golden time to complete temporary blocking" t a Between them;
the minimum water injection time t min By the following stepsAnd (3) calculating to obtain:
(1) At maximum water filling speed v max Under the condition, the pore pressure P of the overlying stratum at the leakage position is calculated by adopting an iteration method t upper And bottom brine layer pore pressure P t lower ：
Wherein DeltaP t upper 、ΔP t lower The iteration increment of pore pressure at the leakage position of the overburden stratum and the bottom saline layer in the time t and delta t is respectively MPa;
initial pore pressure for the bottom brine layer, obtained from the applied pore pressure, MPa; r is (r) 1 The horizontal distance between the water injection well and the leakage position is m; />
For time t CO 2 Leakage rate, m 3 ·s -1 ；P float Is supercritical CO 2 Buoyancy caused by the difference between the water density and the buoyancy, and MPa;
(2) Determining the minimum water injection time t by using the pore pressure of the overlying stratum at the leakage position at the iteration step k equal to the pore pressure of the bottom saline layer min ：
t min ＝k·Δt。
3. A CO according to claim 1 2 A temporary blocking method for leakage along a fault during geological storage is characterized in that a microseism monitoring technology is adopted to determine the position of the fault.
4. A CO according to claim 1 2 Geological sealA temporary plugging method for leakage along faults during the storage period is characterized in that a water injection well with the nearest horizontal distance from the fault leakage position in an overlying stratum is selected for water injection.
5. CO (carbon monoxide) 2 The temporary plugging field test method for leakage along faults during geological storage is characterized by comprising the following specific operation steps of:
step 1: layout field test device
Step 2: developing temporary plugging field test
(1) Applying a horizontal confining pressure, a vertical axial pressure and an initial pore pressure to the target formation;
(2) By CO 2 Injection well injecting CO into bottom brine layer 2 Stopping CO after reaching the preset injection amount 2 Injecting;
(3) The drawing steel plate activates faults to cause CO 2 Leakage along the fault;
(4) Setting a water injection speed v, calculating water injection time t, and implementing water injection of an overburden stratum; forming a hydraulic barrier to finish temporary plugging;
(5) Ending the test and recording CO 2 Real-time leak rate;
step 3: verifying the validity of a temporary plugging method according to any one of claims 1-4
(1) At maximum water injection speed v max Minimum water injection time t min Developing a first set of field trials; at minimum water filling speed v min Golden time t for completing temporary blocking a Developing a second set of field tests; at any given water filling rate v 1 Corresponding water injection time t 1 Developing a third set of field trials, wherein v min ≤v 1 ≤v max ；
(2) Respectively obtaining CO of three groups of field tests 2 Initial leakage rate and CO at the end of the test 2 If the leakage speed is reduced to less than 3% of the initial leakage speed after the test is finished, the temporary plugging method can meet the field engineering;
step 4: determining temporary plugging advantage
(1) Developing a fourth set of field trials without implementing temporary pluggingTesting, monitoring CO 2 Real-time leakage velocity, acquiring 'CO' by integrating the real-time velocity 2 CO before complete of omnibearing repairing leakage 2 Leakage amount;
(2) CO by testing on a first set of sites 2 Integrating the leakage speed in real time to obtain CO 2 CO before complete of omnibearing repairing leakage 2 Leakage amount;
(3) Comparing the CO of (1) and (2) 2 The leakage quantity can be confirmed to greatly reduce CO by temporary blocking 2 Leakage quantity, embody temporary blocking in CO 2 The necessity and unique advantages in leak omnibearing remediation processes.
6. A CO according to claim 5 2 Temporary plugging site test method for leakage along fault during geological storage is characterized by comprising the following steps of 2 The leak rate is monitored by a fluid velocity sensor disposed within the fracture.
7. A CO according to claim 5 2 Temporary plugging site test method for leakage along fault during geological storage is characterized by comprising the following steps of 2 CO before complete of omnibearing repairing leakage 2 Leakage amount through CO 2 Real-time leak rate versus time integral acquisition, i.e
V leak Is CO 2 Leakage amount, m 3 ；v leak Is CO 2 Real-time leak rate, m 3 ·s -1 ；t start S is the omnibearing repair starting time; t is t finish And s is the completion time of the omnibearing repair.
8. A CO according to claim 5 2 A temporary plugging site test method for leakage along faults during geological storage is characterized in that the site test device comprises a foundation pit, a bottom saline layer, a cover layer, an overlying stratum, faults, rock particles, a steel plate, a fluid velocity sensor, an anti-seepage box body, a hydraulic support, a balancing weight and liquid pressurizationDevice, pressure-bearing steel pipe and supercritical CO 2 Gas tank, CO 2 The device comprises an injection well, a fluid pressure sensor, a constant pressure water tank and a water injection well; the bottom saline layer, the cover layer and the overlying stratum form a target stratum together, and an impermeable box body is arranged outside the target stratum; setting faults in the cover layer, filling the faults with rock particles, and activating the faults by drawing the steel plate; applying horizontal confining pressure on the outer side of the foundation pit through a hydraulic support, and applying vertical shaft pressure on the top of the foundation pit through a balancing weight; injecting the water pressurized by the liquid booster into a target stratum through a pressure-bearing steel pipe to realize initial pore pressure application; the water injection well is responsible for injecting water into an overlying stratum; CO 2 The injection well is responsible for injecting CO into the bottom brine layer 2 The method comprises the steps of carrying out a first treatment on the surface of the The constant-pressure water tank is communicated with a target stratum through a pressure-bearing steel pipe; a fluid velocity sensor is arranged in the fault, and a fluid pressure sensor is arranged in the CO 2 At the bottom of the injection well.
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