CN109490507A - The experiment test device and method of fracturing fluid recovery (backflow) rate after shale gas well volume fracturing - Google Patents
The experiment test device and method of fracturing fluid recovery (backflow) rate after shale gas well volume fracturing Download PDFInfo
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Abstract
The invention discloses the experiment test devices and method of fracturing fluid recovery (backflow) rate after a kind of shale gas well volume fracturing, the device mainly includes clamper, press machine, insulating box, constant speed and constant pressure pump, intermediate receptacle, constant speed and constant pressure pump discharge valve, fluid inlet valve, fluid outlet valve, nitrogen cylinder outlet valve, nitrogen cylinder, outlet valve, test method is main comprising steps of 1) prepared by rock sample；2) shale physical parameter is tested；3) test parameter calculates；4) fracturing fluid preparation and fracturing fluid density measurement；5) test parameters is tested；6) shale returns row and leads calculating；The present invention comprehensively considers formation temperature, reservoir stress, Fluid pressure and returns the influence that row leads to shale, and it will affect Factors Factor quantification characterization, it is able to reflect shale and returns the test method that row leads under the conditions of true stratum, return the optimization of row's system for shale and theoretical foundation is provided.
Description
Technical field
The present invention relates to shale gas well body a kind of in natural petroleum gas field field, especially shale hydraulic fracturing process products
The experiment test device and method of fracturing fluid recovery (backflow) rate after pressure break.
Background technique
Important component of the shale gas as unconventional petroleum resources, it is huge and the energy clear due to its stock number
Clean characteristic has obtained the extensive attention and exploitation of people.Because its reservoir enbrittle height, poor permeability, natural microcrack development etc.
Feature, the extensive multistage volume fracturing technology of horizontal well, it has also become the one of the untraditional reservoirs economical and effective such as shale gas exploitation
The development scheme that kind generallys use.During shale gas reservoir hydraulic fracturing, the fracturing fluid in upper all places is injected into reservoir,
But the result of mining site statistics but shows that the row of returning of fracturing fluid leads extremely low and differs greatly, most of shale gas well, which returns row and leads, to be less than
50%, same shale gas reservoir, the different gas wells of same well group are led in the post-fracturing row of returning to differ greatly.It is different with conventional sandstone,
The phenomenon that there is the low row of returning and leads in shale gas well, high yield, it can be seen that accurately prediction shale gas well returns row and leads to shale gas
Well capacity is particularly important.But it is numerous to influence the factor that the row of returning leads, including the parameters such as reservoir properties, pressing crack construction, Production development, and
It is different because being known as interference so that after shale gas well pressure the row of returning lead predict it is very difficult.Studies have shown that shale formation temperature, stratum
Stress, Fluid pressure etc., which all lead the row of returning, to be had an impact, but current research does not consider these factors simultaneously.Therefore quantitative table
The row of returning leads after levying true formation condition shale gas well pressure, returns the optimization of row's system to shale gas well and improves single well productivity with important
Directive function.Shale gas well, which returns row and leads prediction technique, at present mainly method for numerical simulation and experimental method, and particular content is such as
Under:
(1) opening great waves etc., (Zhang Tao, Li Xiangfang, Yang Lifeng closing well opportunity return row to shale gas well and lead and the influence of production capacity [J]
Natural gas process, 2017,37 (8): 48-59) this method according to the actual production data of shale gas well, establishes typical oil reservoir number
It is worth model, studies different production systems row is returned to shale gas well and lead and the influence of production capacity.This method effectively considers fluid pressure
The factors such as power, but formation temperature is not accounted for, while model simplification factor is more.
(2) (shale reservoir fracturing fluid recovery (backflow) numerical simulation [J] under the driving of Wang Fei, Pan Ziqing difference in chemical potential such as Wang Fei
Petroleum finance, 2016,43 (6): 971-977) this method establishes the base for considering stickiness power, capillary force and osmotic pressure
Matter and crack gas-water phases flowing mathematical model simulate the fracturing fluid recovery (backflow) dynamic under difference in chemical potential driving, to shale gas well
The row of returning, which leads, after pressure has carried out prediction and analysis of Influential Factors.This method considers the factors such as Fluid pressure, but numerical solution is assumed
Condition is more, and analog result error is larger, while not accounting for the factors such as formation temperature and returning the influence that row leads to shale.
(3) (Kang Yili, Zhang Xiaoyi, You Lijun shale gas reservoir natural flowback alleviate Water trapping damage experiment to Kang Yili etc.
Study [J] natural gas geoscience, 2017,28 (6): 819-826) this method using experiment means, utilize river Dong Longmaxi
Group shale samples fracturing fluid self-priming and return in experiment simulation storey increase design on core column scale and are drained through journey, discuss hole knot
Structure, fracture intensity return row pressure difference and time effects self-priming-flowback effect mechanism.This method is considered using arranging device is returned
The influence that displacement pressure difference and stratum confining pressure lead the row of returning, but it is to carry out rock sample after spontaneous imbibition to return row that row is returned in the experiment,
Dynamic process without simulating shale true self-priming and the row of returning, while formation temperature does not account for yet.
Above-mentioned 3 kinds of methods, which all do not comprehensively consider the factors such as formation temperature, reservoir stress, Fluid pressure, to be returned row to shale and leads
Influence, there is no method at present at the same consider these factors and quantification characterization, it is therefore necessary to study shale on true stratum
Under the conditions of the test method that leads of the row of returning, return the optimization of row's system for shale and theoretical foundation be provided.
Summary of the invention
The purpose of the present invention is comprehensively considering formation temperature, reservoir stress, Fluid pressure to return the influence that row leads to shale, and
It will affect Factors Factor quantification characterization.
It is returned in order to achieve the above object, providing fracturing fluid after a kind of shale gas well volume fracturing in one embodiment of the present of invention
The experiment test device that row leads, which is characterized in that test device include clamper, press machine, insulating box, constant speed and constant pressure pump, in
Between container, constant speed and constant pressure pump discharge valve, fluid inlet valve, fluid outlet valve, nitrogen cylinder outlet valve, nitrogen cylinder, outlet valve, wherein
Clamper includes upper and lower cover plates, front shroud, back shroud, side cover plate, fluid-infusing port, fluid outlet, diversion trench, sealing rubber ring,
Wherein the front shroud and back shroud and rock sample obtain contact surface equipped with diversion trench, and cover board edge is equipped with sealing rubber ring, front shroud
And it is respectively equipped with fluid-infusing port and fluid outlet on back shroud, rock sample is placed in insulating box when experiment and utilizes press machine
Three-dimensional stress is loaded to rock sample by clamper.
The experiment that fracturing fluid recovery (backflow) rate after a kind of shale gas well volume fracturing is provided in one embodiment of the present of invention is surveyed
Method for testing, specifically includes the following steps:
1) prepared by rock sample: it is 7cm ± 1mm's that side length, which is made, in the underground rock core of shale reservoir section or same layer position outcropping rock
Cube rock sample, and place and dried in 100 DEG C of baking ovens to constant weight, and weigh it is dry after rock sample quality be denoted as m0；
2) shale physical parameter is tested: using porosity measuring instrument using helium as working media testing procedure 1) described in
The porosity of rock sample after drying；
3) experiment parameter determines: determining experiment load item according to reservoir stress, formation temperature, hydraulic fracturing construction parameter
Part, wherein experiment load three-dimensional effective stress is determined by expression formula (1)~(3), experimental temperature is depth of reservoirs pair where rock sample
The temperature answered, Experimental Flowing Object injection pressure are determined that experiment returns row pressure difference and returns row pressure difference really by mining site well is practical by expression formula (4)
It is fixed；
σ'z=σz-αPp (1)
σ'H=σH-αPp (2)
σ'h=σh-αPp (3)
Pinj=PISI-Pp (4)
In formula: σ 'zFor vertical effective stress, MPa；σ'HFor maximum horizontal principal effective stress, MPa；σ'hHave for minimum level
Imitate principal stress, MPa；σzFor vertical stress, MPa；σHFor maximum horizontal principal stress, MPa；σhFor minimum horizontal principal stress, MPa；α
For effective stress coefficient, decimal；PinjTo test injection pressure, MPa；PISIFor instant shut-in bottom pressure after hydraulic fracturing,
MPa；PPFor formation pore pressure, MPa；
4) according to the fracturing fluid recipe configuration fracturing fluid of construction site, mini-frac liquid density, and fracturing fluid is poured into perseverance
In the intermediate receptacle of fast constant pressure pump；
5) shale rock sample after the test of porosity described in step 2) is put into shale and returns the folder that row leads experiment test device
In holder, three-dimensional stress is loaded to rock sample using press machine according to the experiment loading stress determined in step 3), and rock sample is added
The experimental temperature determined in heat to step 3)；
6) the pump injection pressure power pumped according to the injection pressure setting constant speed and constant pressure determined in step 3), and pumped using constant speed and constant pressure
Return the clamper parallel bedding arrival end injection step 4 that row leads experiment test device to shale by intermediate receptacle) prepare pressure
Liquid is split, while passing through injection liquid measure corresponding to control computer record different time, each time primary every 10 minutes records
The corresponding integrated flow of node is the imbibition amount of shale at the time point, and the testing time is can be obtained the imbibition period for 3 days
Corresponding accumulative imbibition amount, is denoted as Vimb；
7) on the basis of step 6), setting returns that row pressure is poor, removes shale and returns the clamper that row leads experiment test device
Arrival end pipeline, using nitrogen cylinder to clamper outlet end inverse injection nitrogen, the reverse displacement time is taken out for 3 days
Weighing is denoted as m1；
8) shale returns row and leads calculating: according to step 6) shale imbibition stage imbibition amount versus time curve, after imbibition
Accumulative flow is imbibition amount Vimb；Row's stage is returned in shale, shale returns quality m after row1Dry rock sample matter before being tested with experiment
Measure m0Difference and fracturing fluid density ratio be in the hold-up of the experiment condition fracturing liquid in shale, by expression
(5) it calculates；The row of returning that fracturing fluid tests test under formation conditions leads, and is calculated by expression (6), may further obtain pressure break
Liquid leads E in the row of returning of shale unit pore volume, is calculated by expression formula (7)；
In formula: VfFor hold-up of the row's of returning stage fracturing fluid in shale, cm3；VimbFor imbibition stage corresponding accumulative infiltration
Pipette, cm3；m0For the weight for testing preceding dry rock sample, g；m1For the weight of rock sample after the row's of returning experiment, g；ρ is experiment fracturing fluid
Density, g/cm3；For shale porosity, % after drying；AcFor imbibition sectional area, cm2；L is rock sample length, cm；F is fracturing fluid
The row of returning of experiment test leads under formation conditions, %；E is that fracturing fluid is led in the row of returning of shale unit pore volume, 1/cm3。
Compared with prior art, the invention has the benefit that the present invention innovate propose a kind of consideration stratum three
Fracturing fluid after to the shale gas well volume fracturing under stress, formation temperature, injection pressure, back displacement pressure various factors
The experimental test procedures that the row of returning leads, can be to the row's of returning calibration quantization signifying, while laboratory sample is the true rock sample of shale gas well, real
It is reliable to test real result, row's rule is returned to shale under understanding stratum full-scale condition and shale gas well returns the optimization of row's system and has well
Directive function.
Detailed description of the invention
Fig. 1 is shale cube rock sample schematic diagram of the present invention.
Fig. 2 returns row for shale of the present invention and leads test device clamper schematic diagram.
Fig. 3 returns row for shale of the present invention and leads test device schematic diagram.
Fig. 4 is the graph of relation that shale of the present invention adds up imbibition amount and time.
Wherein, rock sample 1, clamper 2, press machine 3, insulating box 4, constant speed and constant pressure pump 5, intermediate receptacle 6, constant speed and constant pressure pump out
Mouth valve 7, fluid inlet valve 8, fluid outlet valve 9, nitrogen cylinder outlet valve 10, nitrogen cylinder 11, outlet valve 12；It is upper and lower cover plates 2-1, preceding
Cover board 2-2, back shroud 2-3, side cover plate 2-4, fluid-infusing port 2-5, fluid outlet 2-6, diversion trench 2-7, sealing rubber ring 2-8.
Specific embodiment
The present invention provides a kind of experiment test device of fracturing fluid recovery (backflow) rate after shale gas well volume fracturing, feature exists
In test device includes clamper 2, press machine 3, insulating box 4, constant speed and constant pressure pump 5, intermediate receptacle 6, constant speed and constant pressure pump discharge valve
7, fluid inlet valve 8, fluid outlet valve 9, nitrogen cylinder outlet valve 10, nitrogen cylinder 11, outlet valve 12, wherein clamper includes up and down
Cover board 2-1, front shroud 2-2, back shroud 2-3, side cover plate 2-4, wherein on front shroud 2-2 and back shroud 2-3 and rock sample contact surface
Equipped with diversion trench 2-7, cover board edge, which is equipped on sealing rubber ring 2-8, front shroud 2-2 and back shroud 2-3, is respectively equipped with fluid injection
Mouthful 2-5 and fluid outlet 2-6, rock sample is placed in insulating box 4 when experiment and using press machine 3 by clamper 2 to rock sample
Load three-dimensional stress.
Method of the invention is further illustrated below according to drawings and examples.
Embodiment 1
It is described the specific embodiments of the present invention in detail below according to attached drawing and Sichuan province a well for example.Specifically such as
Under:
1., rock sample preparation: be derived from rock core under W1 well 2015~2060m Reservoir Section real well, by rock core be processed as side length at
The cube rock sample of 7cm ± 1mm, and rock sample is placed in 100 DEG C of baking ovens and is dried to constant weight, and weighs quality m0For
850.5g。
2., the test of shale physical parameter: using porosity measuring instrument using helium as working media testing procedure 1. middle institute
The porosity for stating rock sample 1 after drying is 7.31%.
3., 75 DEG C of W1 well shale reservoir temperature, formation pore pressure 42MPa, maximum horizontal well principal stress 46MPa is minimum
Horizontal principal stress 38MPa, vertical stress 44MPa, instantaneous termination of pumping bottom pressure 47MPa, effective stress coefficient is 0.5.Utilize public affairs
Formula (1)~(3) can determine experiment maximum horizontal principal effective stress 25MPa, minimum level principal effective stress 17MPa, vertical effectively
Stress is 23MPa；It can determine that experiment injection Fluid pressure is 5MPa using formula (4)；Initial stage returns row pressure after example well body is overstock
Difference is 3MPa, therefore determines that the experiment row's of returning displacement pressure is 3MPa.
4., configuration construction site fracturing fluid, mini-frac liquid density p be 1.12g/cm3, and fracturing fluid is poured into constant speed
In the intermediate receptacle of constant pressure pump.
5., by step 2. described in shale rock sample 1 after porosity test be put into shale and return the experiment test device that row leads
Clamper 2 in, according to step 3. in determine experiment loading stress using press machine to rock sample load three-dimensional stress.Before wherein
Back shroud loads minimum horizontal principal stress, and side cover plate loads maximum horizontal principal stress, and upper and lower cover plates loads vertical stress, and utilizes
Rock sample 1 is heated to the step 3. middle experimental temperature determined by insulating box 4.
6., return with pipeline connection constant speed and constant pressure pump 5, intermediate receptacle 6 and shale row and lead the clamper 2 of experiment test device and flow
Body inlet 2-5 according to the step pump injection pressure power that 3. the middle injection pressure setting constant speed and constant pressure determined pumps, and utilizes constant speed and constant pressure
Pump 5 returns the clamper fluid-infusing port 2-5 injection fracturing fluid that row leads experiment test device to shale by intermediate receptacle 6, simultaneously
By injection liquid measure corresponding to control computer record different time, primary every 10 minutes records, each timing node is corresponding
Integrated flow be the pressure imbibition amount of shale at the time point, the testing time be 3 days, such as scheme (4) shown in, imbibition can be obtained
Period corresponding accumulative imbibition amount VimbFor 24.37cm3。
7., on the basis of step 6, row pressure difference 3MPa is returned in setting, remove connection constant speed and constant pressure pump 5, intermediate receptacle 6 and
Shale returns the pipeline that row leads the 2 fluid-infusing port 2-5 of clamper of experiment test device, connects nitrogen cylinder with pipeline and shale returns row
The 2 fluid outlet 2-6 of clamper of rate experiment test device, and utilize nitrogen cylinder to 1 reverse displacement nitrogen of rock core, the row's of returning time
Removal of core and quality m is weighed for 3 days, after the row of returning1For 872.8g.
8., shale returns row and leads calculating: calculate hold-up V of the row's of returning stage fracturing fluid in shale by expression formula (5)fFor
19.9cm3, and it is 18.3% that fracturing fluid, which can be obtained, and test the row of returning tested under formation conditions to lead F in conjunction with expression formula (6), in turn
Return row in shale unit pore volume of the fracturing fluid under the shale corresponding row's of returning time obtained by expression formula (7) lead E be
0.73/cm3。
The present invention is specifically described above by embodiment, it is necessary to which indicated herein to be, the present embodiment is only this
The preferred embodiment of invention, is not intended to limit the invention in any way, and is also not limited to forms disclosed herein, and should not regard as
It is excluding other embodiments.And the change and simple change that those skilled in the art are carried out do not depart from technical thought of the invention and
Range then belongs in the protection scope of technical solution of the present invention.
Claims (4)
1. the experiment test device of fracturing fluid recovery (backflow) rate after shale gas well volume fracturing, which is characterized in that test device includes folder
Holder, press machine, insulating box, constant speed and constant pressure pump, intermediate receptacle, constant speed and constant pressure pump discharge valve, fluid inlet valve, fluid outlet
Valve, nitrogen cylinder outlet valve, nitrogen cylinder, outlet valve, wherein clamper is made of upper and lower cover plates, front shroud, back shroud, side cover plate,
Wherein front shroud and back shroud and rock sample contact surface are equipped with diversion trench, and cover board edge is equipped with sealing rubber ring, front shroud and rear cover
It is respectively equipped with fluid-infusing port and fluid outlet on plate, rock sample is placed in insulating box and passes through folder using press machine by when experiment
Holder loads three-dimensional stress to rock sample.
2. the experimental test procedures of fracturing fluid recovery (backflow) rate after shale gas well volume fracturing, comprising the following steps:
1) prepared by rock sample: cube rock sample is made in the underground rock core of shale reservoir section or same layer position outcropping rock, and places 100
Dried in DEG C baking oven to constant weight, and weigh it is dry after rock sample quality be denoted as m0；
2) shale physical parameter test: using porosity measuring instrument using helium as working media testing procedure 1) described in dry
The porosity of rock sample afterwards；
3) experiment parameter determines: experiment loading environment is determined according to reservoir stress, formation temperature, hydraulic fracturing construction parameter,
Middle experiment load three-dimensional effective stress is determined that experimental temperature is the corresponding temperature of depth of reservoirs where rock sample by expression formula (1)~(3)
Degree, Experimental Flowing Object injection pressure are determined that experiment is returned row pressure difference and determined by the practical row pressure difference of returning of mining site well by expression formula (4)；
σ'z=σz-αPp (1)
σ'H=σH-αPp (2)
σ'h=σh-αPp (3)
Pinj=PISI-Pp (4)
In formula: σ 'zFor vertical effective stress, MPa；σ'HFor maximum horizontal principal effective stress, MPa；σ'hIt is effectively main for minimum level
Stress, MPa；σzFor vertical stress, MPa；σHFor maximum horizontal principal stress, MPa；σhFor minimum horizontal principal stress, MPa；α is to have
Effect force coefficient, decimal；PinjTo test injection pressure, MPa；PISIFor instant shut-in bottom pressure, MPa after hydraulic fracturing；PP
For formation pore pressure, MPa；
4) according to the fracturing fluid recipe configuration fracturing fluid of construction site, mini-frac liquid density, and fracturing fluid is poured into constant speed perseverance
In the intermediate receptacle of press pump；
5) shale rock sample after the test of porosity described in step 2) is put into shale and returns the clamper that row leads experiment test device
In, three-dimensional stress is loaded to rock sample using press machine according to the experiment loading stress determined in step 3), and rock sample is heated to
The experimental temperature determined in step 3)；
6) the pump injection pressure power pumped according to the injection pressure setting constant speed and constant pressure determined in step 3), and passed through using constant speed and constant pressure pump
Intermediate receptacle returns the clamper parallel bedding arrival end injection step 4 that row leads experiment test device to shale) prepare fracturing fluid,
It is primary every 10 minutes records simultaneously by injection liquid measure corresponding to control computer record different time, each timing node
Corresponding integrated flow is the imbibition amount of shale at the time point, and the testing time is 3 days, and it is corresponding tired that the imbibition period can be obtained
The imbibition amount of meter, is denoted as Vimb；
7) on the basis of step 6), setting returns that row pressure is poor, removes shale and returns the clamper entrance that row leads experiment test device
End pipe line using nitrogen cylinder to clamper outlet end inverse injection nitrogen, reverse displacement certain time, and takes out weighing and is denoted as
m1；
8) shale returns row and leads calculating: according to step 6) shale imbibition stage imbibition amount versus time curve, adding up after imbibition
Flow be imbibition amount Vimb；Row's stage is returned in shale, shale returns quality m after row1Dry rock sample quality m before being tested with experiment0
Difference and the ratio of fracturing fluid density be to be counted by expression (5) in the hold-up of the experiment condition fracturing liquid in shale
It calculates；The row of returning that fracturing fluid tests test under formation conditions leads, and is calculated by expression (6), may further obtain fracturing fluid and exist
The row of returning of shale unit pore volume leads E, is calculated by expression formula (7)；
In formula: VfFor hold-up of the row's of returning stage fracturing fluid in shale, cm3；VimbFor imbibition stage corresponding accumulative imbibition amount,
cm3；m0For the weight for testing preceding dry rock sample, g；m1For the weight of rock sample after the row's of returning experiment, g；ρ is the density for testing fracturing fluid,
g/cm3；For shale porosity, % after drying；AcFor imbibition sectional area, cm2；L is rock sample length, cm；F is fracturing fluid on ground
The row of returning of experiment test leads under the conditions of layer, %；E is that fracturing fluid is led in the row of returning of shale unit pore volume, 1/cm3。
3. the experimental test procedures of fracturing fluid recovery (backflow) rate after shale gas well volume fracturing as claimed in claim 2, wherein cube
Body rock sample side length is 7cm ± 1mm.
4. the experimental test procedures of fracturing fluid recovery (backflow) rate after shale gas well volume fracturing as claimed in claim 2, wherein reversely
The displacement time is 3 days.
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