CN104358554B - Shale gas combined sand fracturing fracture conductivity evaluation method - Google Patents
Shale gas combined sand fracturing fracture conductivity evaluation method Download PDFInfo
- Publication number
- CN104358554B CN104358554B CN201410743602.6A CN201410743602A CN104358554B CN 104358554 B CN104358554 B CN 104358554B CN 201410743602 A CN201410743602 A CN 201410743602A CN 104358554 B CN104358554 B CN 104358554B
- Authority
- CN
- China
- Prior art keywords
- proppant
- sand
- whaleback
- laid
- fracture
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
- 239000004576 sand Substances 0.000 title claims abstract description 88
- 238000011156 evaluation Methods 0.000 title claims abstract description 16
- 238000009826 distribution Methods 0.000 claims abstract description 46
- 238000000034 method Methods 0.000 claims abstract description 45
- 230000006870 function Effects 0.000 claims abstract description 30
- 238000002474 experimental method Methods 0.000 claims abstract description 25
- 230000005012 migration Effects 0.000 claims abstract description 22
- 238000013508 migration Methods 0.000 claims abstract description 22
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 18
- 230000008569 process Effects 0.000 claims abstract description 17
- 238000004088 simulation Methods 0.000 claims abstract description 10
- 238000013461 design Methods 0.000 claims abstract description 8
- 238000012417 linear regression Methods 0.000 claims abstract description 6
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N silicon dioxide Inorganic materials O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims description 65
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 33
- 239000008186 active pharmaceutical agent Substances 0.000 claims description 29
- 238000012800 visualization Methods 0.000 claims description 13
- 239000002184 metal Substances 0.000 claims description 11
- 238000012360 testing method Methods 0.000 claims description 8
- 239000010453 quartz Substances 0.000 claims description 7
- 238000001802 infusion Methods 0.000 claims description 6
- 230000035699 permeability Effects 0.000 claims description 5
- 230000009466 transformation Effects 0.000 claims description 5
- 238000005303 weighing Methods 0.000 claims description 5
- 230000008859 change Effects 0.000 claims description 4
- 238000009434 installation Methods 0.000 claims description 4
- 239000000463 material Substances 0.000 claims description 4
- 238000007790 scraping Methods 0.000 claims description 4
- 230000015572 biosynthetic process Effects 0.000 claims description 3
- 239000002552 dosage form Substances 0.000 claims description 3
- 238000000605 extraction Methods 0.000 claims description 3
- 238000003672 processing method Methods 0.000 abstract description 2
- 239000002245 particle Substances 0.000 abstract 2
- 238000011158 quantitative evaluation Methods 0.000 abstract 1
- 230000000007 visual effect Effects 0.000 abstract 1
- 208000010392 Bone Fractures Diseases 0.000 description 34
- 206010017076 Fracture Diseases 0.000 description 34
- 230000004888 barrier function Effects 0.000 description 5
- 238000005516 engineering process Methods 0.000 description 4
- 238000004519 manufacturing process Methods 0.000 description 4
- 239000004744 fabric Substances 0.000 description 3
- 230000010354 integration Effects 0.000 description 3
- 238000009738 saturating Methods 0.000 description 3
- 238000010276 construction Methods 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 239000000284 extract Substances 0.000 description 2
- 230000008520 organization Effects 0.000 description 2
- 238000011144 upstream manufacturing Methods 0.000 description 2
- 239000006004 Quartz sand Substances 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000008901 benefit Effects 0.000 description 1
- 238000007664 blowing Methods 0.000 description 1
- 239000009096 changqing Substances 0.000 description 1
- 238000010835 comparative analysis Methods 0.000 description 1
- 230000001186 cumulative effect Effects 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 239000000835 fiber Substances 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 230000000877 morphologic effect Effects 0.000 description 1
- 238000005457 optimization Methods 0.000 description 1
- 230000000704 physical effect Effects 0.000 description 1
- 238000007639 printing Methods 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 238000010998 test method Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK 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
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
- E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Road Paving Machines (AREA)
- Management, Administration, Business Operations System, And Electronic Commerce (AREA)
Abstract
The invention discloses a shale gas combined sand fracturing fracture conductivity evaluation method, which comprises the following steps: a. simulating the sand bank migration process in the shale gas slickwater combined sand adding fracturing fracture by means of a visual fracture network inside proppant flowing simulation experiment device, and acquiring a sand bank migration video of combined sand adding fracturing under different experiment conditions; b. obtaining sand bank distribution curves of the proppants with different particle sizes by utilizing a gray processing method and a point-by-point scanning method, and obtaining sand bank distribution shape functions of the proppants with different particle sizes by utilizing a linear regression method; c. according to the size specification of the API diversion chamber, a sand bank distribution shape function in the API diversion chamber is established by utilizing a geometric similarity principle, and the corresponding propping agent is laid in a shape state, so that the flow conductivity evaluation of the combined sand fracturing fracture is realized. The method can simply and accurately realize quantitative evaluation of the flow conductivity of the shale gas combined sand fracturing fracture, and provides experimental support for optimizing the combined sand fracturing design and improving the flow conductivity of the shale fracturing fracture.
Description
Technical field
The present invention relates to shale gas combination sand fracturing crack merit rating technical field.
Background technology
Shale reservoir has low hole, hypotonic, the feature of intrinsic fracture development.At present, with extensive, huge discharge horizontal well
Multistage fracturing technology is widely used in shale reservoir, increases reservoir reconstruction volume by forming effective complex fracture network, greatly
Width lifts gas well yield.However, the uncertainty of proppant migration and fracture condudtiviy is stored up to shale in complicated seam net
Layer transformation brings tremendous influence, has had a strong impact on effective transformation of reservoir.Therefore, net inner support agent stream is stitched by indoor visualization
Dynamic analogue experiment installation observes the migration rule of proppant, and proppant flow conductivity in shale gas combination sand fracturing crack is entered
Row quantitative assessment, can strengthen stitching the understanding of net inner support agent migration rule, and shale reservoir construction parameter is optimized, and improve crack and lead
Stream ability is respectively provided with significance.
Author be Wu Shunlin, Li Xianwen, Zhang Kuangsheng, Tang Meirong, Lee to gentle up to drawing friend, it is entitled printing《Fault-blcok oil-gas field》
Periodical file on delivered phase of pieces of entitled " a kind of pulse sand fracturing new method for realizing crack high flow conductivity "
Publish the article and offer, its date issued is 01 phase in 2014, its main contents is disclosed：Ordos Basin compact oil reservoir reserves are big, point
Cloth is stablized, and is the upper product of 5 000 ten thousand tons of Changqing oilfields, the important making ＆ breaking of stable yields.Such oil reservoir is because reservoir is fine and close, physical property
Difference, early stage correctional effect is poor, and conventional fracturing technique is difficult to effectively employ, and urgent need opens up a new way carries out effectively changing for oil reservoir
Make.Ordos Basin tight sandstone reservoir unique characteristics are combined in text, elaborates that " pulsed adds sand, fiber fracturing liquid to take sand
And wait a shower hole " a kind of new fracture technology, filled by the alternating of proppant in fracturing fracture, form stable
Flow channel network, make crack possess higher flow conductivity, so as to reach improve well yield purpose.It is straight by 3 mouthfuls
The field test of well, with conventional fractured well comparative analysis has been carried out.Using the pulse Sand Fracturing Technology of high flow conductivity, after pressure
Incipient crack flow conductivity improves 14.1%, and tested production value, operation yield, unit pressure reduction cumulative oil production and production capacity index compare
Conventional fractured well is high 1.1 ~ 1.4 times, achieves preferable effect of field application.
But at present, yet there are no shale reservoir slippery water combination sand fracturing fracture support agent flow conductivity both at home and abroad is carried out
The method of indoor quantitative assessment, therefore the present invention is with certain novelty and perspective.
The content of the invention
It is contemplated that for defect and deficiency existing for above-mentioned prior art, there is provided a kind of shale gas combination plus sand pressure
Fracture condudtiviy evaluation method is split, this method can simply, accurately realize that shale gas combine sand fracturing fracture guide energy
The quantitative assessment of power, provides experiment and supports for optimum organization sand fracturing design, raising shale fracturing fracture flow conductivity.
The present invention using following technical proposals by being realized：
A kind of shale gas combine sand fracturing fracture condudtiviy evaluation method, it is characterised in that step is as follows：
A, by visualization seam net inner support agent flowing simulated experiment device, simulation shale gas slippery water combination sand fracturing
Whaleback migration process in crack, obtains the whaleback migration video that sand fracturing is combined under different experimental conditions；
B, using gray proces method and point by point scanning method, different-grain diameter proppant whaleback distribution curve is obtained, using linear
The Return Law obtains different-grain diameter proppant whaleback distribution shape function；
C, according to API diversion chamber dimensions, using geometrical similarity principle, set up whaleback distribution shape in API water conservancy diversion room
Function, and it is laid to carry out respective support dosage form state, realizes that combination sand fracturing fracture condudtiviy is evaluated.
It is described to stitch net inner support agent flowing simulated experiment device, the combination of simulation shale gas slippery water plus sand pressure by visualization
Whaleback migration process in crack, in the case where experimental temperature is room temperature, its key step is as follows：
（1）The distance between two transparent panels in adjustment man-made fracture, make fracture width be 3mm；
（2）On the basis of fluidised form, flow velocity in the seam of scene, according to similarity criterion, the infusion discharge capacity under the conditions of simulated experiment point
Not Wei 6.5 L/min, 9.18L/min, sand concentration is respectively 100Kg/m3、160Kg/m3, proppant using 100 mesh quartz sands with
The combination of 40/70 mesh haydite plus the transport conditions of sand model；
（3）Weigh respective support agent and be put into standby in sand tank；
（4）Infusion slippery water, make it is hydraulically full in crack, formation follow loop checking installation；
（5）Variable speed electric motors, particularly in proppant mulling unit is opened, the scraping blade below sand tank is adjusted, makes the sand for entering crack dense
Degree reaches design requirement；
（6）Start to matched somebody with somebody slippery water all to pump into crack from proppant to finish, whole process is remembered with picture pick-up device
The distribution mode and relevant parameter of record whaleback；
（7）Image data to obtaining is analyzed process.
Combination sand fracturing whaleback distribution mode record, description and whaleback distribution shape function are set up, and its method is specifically：
（1）By visualization seam net inner support agent flowing simulated experiment device, the combination of simulation shale gas slippery water plus sand pressure
Whaleback migration process in crack, and obtain the whaleback migration video that sand fracturing is combined under different experimental conditions；
（2）Using gray proces method, the picture pixels point at corresponding moment in the video of acquisition is made into gray proces, to whole
Picture carries out point by point scanning, extracts different-grain diameter proppant whaleback distribution curve；
（3）The whaleback distribution curve of extraction is utilized into linear regression method, different-grain diameter proppant whaleback distribution shape is set up
Function f1(x), f2(x),……,fnX (), concrete formula is：f1(x)=ax3+bx2+ cx+d, in formula, a, b, c, d are experimental fit
Coefficient；
（4）According to API diversion chamber dimensions, using geometrical similarity principle, whaleback distribution shape in API water conservancy diversion room is set up
Function F1(x), F2(x),……,Fn(x)；Specifically formula is：F1(x)=a1x3+b1x2+c1x+d1, in formula, a1, b1, c1, d1For several
What Similarity Transformation coefficient；
（5）Repeat step（1-4）, according to the spread change of combination sand adding sand dike, obtain different moment whalebacks in API water conservancy diversion room
Distribution shape function F1(x, t), F2(x, t),……, Fn(x, t)。
Combination sand fracturing fracture condudtiviy API test and evaluation, its method is specifically：
（1）According to the API diversion chamber difference proppant distribution shape function F for obtaining1(x, t), F2(x, t),……, Fn
(x, t), and different proppants are obtained using numerical integration（100 mesh quartz sands, 40/70 mesh haydite）Laid area A1,
A2,……, An, and different proppant shape function F are drawn on a metal plate1(x, t), F2(x, t),……, Fn(x, t)
Curve；
The computing formula of the laid area A of proppant is in API rooms：
In formula, the laid area of A-proppant, cm2；
The laid length of L-proppant, cm；
（2）According to laid area A1, A2,……, AnAnd laid thickness H, obtain laid quality W of different proppantsp1,
Wp2,……, Wpn；
Proppant quality needed for flow conductivity evaluation experimental：
In formula：Wp- proppant quality, g；
The laid area of A-proppant, cm2；
The laid thickness of H-proppant (i.e. fracture width W f ), cm；
- proppant volume density, g/cm3；
（3）The proppant for weighing up is uniform laid on the metallic plate of diversion chamber, do not assumed by the region of proppant pack
For closure seam, filling is replaced with dense material；
（4）Other piece of metal plate is placed on above laid good proppant pack, while will be with square seal ring
Upper piston be put in water conservancy diversion room, down pushed away slowly until contacting metal plate with hand；
（5）The diversion chamber for assembling is placed between two parallel-plates of hydraulic pressure framework, lower flat board is lifted by hydraulic means
Plus hydraulic pressure, until loading speed is 3500kPa/min；
（6）Experimental gas discharge capacity is adjusted by " FCTS-1 fracture acidizing fracture condudtiviy detecting and analysing systems " so as to
Stablize in 100 ~ 109mL/min；
（7）Start computer, be input into experiment parameter；
（8）Gas is allowed to pass through proppant pack under the clossing pressure of setting；
（9）Increase clossing pressure step by step, repeat（8）The step of, obtain oozing for proppant pack under different clossing pressures
Saturating rate and flow conductivity；
（10）Record instrument connection inlet pressureP AWith instrument connection outlet pressureP B；
（11）All data are delivered to computer by data collecting system, and computer recorded a secondary data per 30 seconds, most
Calculate the flow conductivity and permeability of proppant pack automatically afterwards；
The flow conductivity of proppant pack is calculated as follows：
In formula：k g The perm-plug method of-filling bed,；
q 0- gas flow, cm3/s；
p 0- standard atmospheric pressure；
μ g- test gas viscosity, mPa.s；
LDistance between-two pressure tapsL=12.7cm；
W- diversion chamber width, W=3.81cm；
P A- instrument connection inlet pressure（Upstream pressure）, kPa；
P B- instrument connection outlet pressure（Downstream pressure）, kPa；
W fThe thickness of-proppant pack, cm；
kW f- proppant pack gas surveys flow conductivity,。
Compared with prior art, what the present invention was reached has the beneficial effect that：
1st, the present invention can simply, accurately realize that shale gas combine the quantitative assessment of sand fracturing fracture condudtiviy,
Method of testing is practical.Experiment is provided to combine sand fracturing design parameter optimization, improving shale fracturing fracture flow conductivity
Support.
2nd, using the method for tri- steps of a, b, c of the present invention, have further the advantage that：
A. device, according to fluid similarity principle design, can more really simulate the combination of shale gas slippery water in visualization seam net
The migration process of sand fracturing crack inner support agent, while device visualization can realize the videograph of sand barrier distribution mode,
Obtain the dynamic migration image of proppant sand barrier；B. gray proces method and point by point scanning method can really obtain sand barrier distribution shape
State, the proppant sand barrier distribution shape function that linear regression method is obtained and actual experiment data point tolerance are only 0.5%, the same to time-division
Cloth shape function method for building up is simple, be easily programmed；C. geometrical similarity principle is applied, combination in API water conservancy diversion room can be obtained and added
The laid form of sand sand barrier, effectively realizes being measured in combination plus sand fracture condudtiviy room and evaluates.Above step is simply easily grasped
Make, data processing method is simple, accuracy is high.
3rd, it is excellent to instruct this invention address that carrying out quantitative assessment to shale gas combination sand fracturing fracture condudtiviy
Change shale reservoir hydrfracturing construction parameter and add sand model, and then improve the gentle well production of reservoir reconstruction volume.
Description of the drawings
Below in conjunction with specification drawings and specific embodiments, the present invention is described in further detail, wherein：
Combination plus sand proppant distribution map in Tu1Shi API diversion chamber；
Fig. 2 is API proppants diversion chamber experimental provision schematic diagram；
Fig. 3 is proppant flow conductivity quantitative assessment experiment flow figure.
Specific embodiment
Embodiment 1
As better embodiment of the present invention, referring to Fig. 1, Fig. 2, Fig. 3.
Proppant quality needed for test：
Wherein：W p1--- 40/70 mesh haydite quality；
W p2--- 100 mesh quartz sand quality；
W p3--- 20/40 mesh haydite quality；
A kind of shale gas combine sand fracturing fracture condudtiviy evaluation method, comprise the following steps successively：
（1）According to the API diversion chamber different-grain diameter proppant distribution shape function F for obtaining1(x, t), F2(x, t), one
The line of demarcation of different proppants is drawn on piece metallic plate 5；
（2）Different proppants are obtained using geometric integration（100 mesh quartz sands, 40/70 mesh haydite and 20/40 mesh haydite）
Laid area A1, A2, A3, further according to laid thickness H, proppant density quality W of respective support agent is obtainedp1, Wp2, Wp3；
（3）The proppant for weighing respective quality is standby；
（4）Bottom piston 7 with square seal ring 6 is put in water conservancy diversion room, and drafting is had into marginal metallic plate 5
It is placed on above bottom piston（Should ensure that metallic plate is very smooth）；
（5）By the proppant for weighing up according to uniform laid on the metallic plate 5 of diversion chamber 8 shown in Fig. 1, do not filled by proppant
The region filled out replaces filling with dense material equivalent to closure seam；
（6）The proppant pack 4 of experiment is struck off with an instrument for scraping plate shape；
（7）Other piece of metal plate 3 is placed on above the proppant pack 4 for blowing flat（The step is careful, no
The form of proppant pack can be destroyed）, while the upper piston 1 with square seal ring 2 is put in diversion chamber 8 and 9, use hand
Down push away slowly until contacting metal plate 3.
（8）Mounted diversion chamber 12 is placed between the upper parallel-plate 13 of hydraulic pressure framework and lower flat board 14, hydraulic means
15 lift lower flat board 14 by force (forcing) pump 16 adds hydraulic pressure for it, until loading speed is 3500kPa/min；
（9）Experimental gas discharge capacity is adjusted by " FCTS-1 fracture acidizing fracture condudtiviies detecting and analysing system 17 ", is made
It is stable in 100 ~ 109mL/min；
（10）Start computer 18, be input into experiment parameter；
（11）Experimental gas 19 are allowed to pass through proppant pack under certain clossing pressure（It is on sample plus sufficiently long
Clossing pressure makes proppant pack reach half stable state）；
（12）Increase clossing pressure, repeat step step by step（11）, obtain oozing for proppant pack under different clossing pressures
Saturating rate and flow conductivity.
（13）System records instrument connection inlet pressure 10 and instrument connection outlet pressure 11 automatically；
（14）All data are delivered to computer 18 by data collecting system, and computer recorded a secondary data per 30 seconds,
The last flow conductivity and permeability for calculating proppant pack automatically.
Embodiment 2
As the preferred forms of the present invention, the invention mainly comprises：Whaleback exhibition in combination sand fracturing visualization seam
Cloth morphologic description is set up from record, different proppant whaleback distribution shape functions and seam Inner guide capacity experimental is measured and is evaluated etc.
Three parts.It is concretely comprised the following steps：
A, by visualization seam net inner support agent flowing simulated experiment device, simulation shale gas slippery water combination sand fracturing
Whaleback migration process in crack, obtains the whaleback migration video that sand fracturing is combined under different experimental conditions；
B, using gray proces method and point by point scanning method, different-grain diameter proppant whaleback distribution curve is obtained, using linear
The Return Law obtains different-grain diameter proppant whaleback distribution shape function；
C, according to API diversion chamber dimensions, using geometrical similarity principle, set up whaleback distribution shape in API water conservancy diversion room
Function, and it is laid to carry out respective support dosage form state, realizes that combination sand fracturing fracture condudtiviy is evaluated.
It is described to stitch net inner support agent flowing simulated experiment device, the combination of simulation shale gas slippery water plus sand pressure by visualization
Whaleback migration process in crack, in the case where experimental temperature is room temperature, its key step is as follows：
（1）The distance between two transparent panels in adjustment man-made fracture, make fracture width be 3mm；
（2）On the basis of fluidised form, flow velocity in the seam of scene, according to similarity criterion, the infusion discharge capacity under the conditions of simulated experiment point
Not Wei 6.5 L/min, 9.18L/min, sand concentration is respectively 100Kg/m3、160Kg/m3, proppant using 100 mesh quartz sands with
The combination of 40/70 mesh haydite plus the transport conditions of sand model；
（3）Weigh respective support agent and be put into standby in sand tank；
（4）Infusion slippery water, make it is hydraulically full in crack, formation follow loop checking installation；
（5）Variable speed electric motors, particularly in proppant mulling unit is opened, the scraping blade below sand tank is adjusted, makes the sand for entering crack dense
Degree reaches design requirement；
（6）Start to matched somebody with somebody slippery water all to pump into crack from proppant to finish, whole process is remembered with picture pick-up device
The distribution mode and relevant parameter of record whaleback；
（7）Image data to obtaining is analyzed process.
Combination sand fracturing whaleback distribution mode record, description and whaleback distribution shape function are set up, and its method is specifically：
（1）By visualization seam net inner support agent flowing simulated experiment device, the combination of simulation shale gas slippery water plus sand pressure
Whaleback migration process in crack, and obtain the whaleback migration video that sand fracturing is combined under different experimental conditions；
（2）Using gray proces method, the picture pixels point at corresponding moment in the video of acquisition is made into gray proces, to whole
Picture carries out point by point scanning, extracts different-grain diameter proppant whaleback distribution curve；
（3）The whaleback distribution curve of extraction is utilized into linear regression method, different-grain diameter proppant whaleback distribution shape is set up
Function f1(x), f2(x),……,fnX (), concrete formula is：f1(x)=ax3+bx2+ cx+d, in formula, a, b, c, d are experimental fit
Coefficient；
（4）According to API diversion chamber dimensions, using geometrical similarity principle, whaleback distribution shape in API water conservancy diversion room is set up
Function F1(x), F2(x),……,Fn(x)；Specifically formula is：F1(x)=a1x3+b1x2+c1x+d1, in formula, a1, b1, c1, d1For several
What Similarity Transformation coefficient；
（5）Repeat step（1-4）, according to the spread change of combination sand adding sand dike, obtain different moment whalebacks in API water conservancy diversion room
Distribution shape function F1(x, t), F2(x, t),……, Fn(x, t)。
Combination sand fracturing fracture condudtiviy API test and evaluation, its method is specifically：
（1）According to the API diversion chamber difference proppant distribution shape function F for obtaining1(x, t), F2(x, t),……, Fn
(x, t), and different proppants are obtained using numerical integration（100 mesh quartz sands, 40/70 mesh haydite）Laid area A1,
A2,……, An, and different proppant shape function F are drawn on a metal plate1(x, t), F2(x, t),……, Fn(x, t)
Curve；
The computing formula of the laid area A of proppant is in API rooms：
In formula, the laid area of A-proppant, cm2；
The laid length of L-proppant, cm；
（2）According to laid area A1, A2,……, AnAnd laid thickness H, obtain laid quality W of different proppantsp1,
Wp2,……, Wpn；
Proppant quality needed for flow conductivity evaluation experimental：
In formula：W p- proppant quality, g；
The laid area of A-proppant, cm2；
The laid thickness of H-proppant (i.e. fracture width W f ), cm；
- proppant volume density, g/cm3；
（3）The proppant for weighing up is uniform laid on the metallic plate of diversion chamber, do not assumed by the region of proppant pack
For closure seam, filling is replaced with dense material；
（4）Other piece of metal plate is placed on above laid good proppant pack, while will be with square seal ring
Upper piston be put in water conservancy diversion room, down pushed away slowly until contacting metal plate with hand；
（5）The diversion chamber for assembling is placed between two parallel-plates of hydraulic pressure framework, lower flat board is lifted by hydraulic means
Plus hydraulic pressure, until loading speed is 3500kPa/min；
（6）Experimental gas discharge capacity is adjusted by " FCTS-1 fracture acidizing fracture condudtiviy detecting and analysing systems " so as to
Stablize in 100 ~ 109mL/min；
（7）Start computer, be input into experiment parameter；
（8）Gas is allowed to pass through proppant pack under the clossing pressure of setting；
（9）Increase clossing pressure step by step, repeat（8）The step of, obtain oozing for proppant pack under different clossing pressures
Saturating rate and flow conductivity；
（10）Record instrument connection inlet pressureP AWith instrument connection outlet pressureP B；
（11）All data are delivered to computer by data collecting system, and computer recorded a secondary data per 30 seconds, most
Calculate the flow conductivity and permeability of proppant pack automatically afterwards；
The flow conductivity of proppant pack is calculated as follows：
In formula：k g The perm-plug method of-filling bed,；
q 0- gas flow, cm3/s；
p 0- standard atmospheric pressure；
μ g- test gas viscosity, mPa.s；
LDistance between-two pressure tapsL=12.7cm；
W- diversion chamber width, W=3.81cm；
P A- instrument connection inlet pressure（Upstream pressure）, kPa；
P B- instrument connection outlet pressure（Downstream pressure）, kPa；
W fThe thickness of-proppant pack, cm；
kW f- proppant pack gas surveys flow conductivity,。
The present invention can simply, accurately realize that shale gas combine the quantitative assessment of sand fracturing fracture condudtiviy, be
Optimum organization sand fracturing design, raising shale fracturing fracture flow conductivity provide experiment and support.
Claims (3)
1. a kind of shale gas combine sand fracturing fracture condudtiviy evaluation method, it is characterised in that step is as follows：
A, by visualization seam net inner support agent flowing simulated experiment device, simulation shale gas slippery water combination sand fracturing crack
Interior whaleback migration process, obtains the whaleback migration video that sand fracturing is combined under different experimental conditions；
B, using gray proces method and point by point scanning method, different-grain diameter proppant whaleback distribution curve is obtained, using linear regression
Method obtains different-grain diameter proppant whaleback distribution shape function；
C, according to API diversion chamber dimensions, using geometrical similarity principle, set up whaleback distribution shape function in API water conservancy diversion room,
And it is laid to carry out respective support dosage form state, realize that combination sand fracturing fracture condudtiviy is evaluated；
Described to stitch net inner support agent flowing simulated experiment device by visualization, the slippery water combination sand fracturing of simulation shale gas is split
Whaleback migration process in seam, in the case where experimental temperature is room temperature, its key step is as follows：
（1）The distance between two transparent panels in adjustment man-made fracture, make fracture width be 3mm；
（2）On the basis of fluidised form, flow velocity in the seam of scene, according to similarity criterion, the infusion discharge capacity under the conditions of simulated experiment is respectively
6.5 L/min, 9.18L/min, sand concentration is respectively 100Kg/m3、160Kg/m3, proppant adopt 100 mesh quartz sands and 40/70
The combination of mesh haydite plus the transport conditions of sand model；
（3）Weigh respective support agent and be put into standby in sand tank；
（4）Infusion slippery water, make it is hydraulically full in crack, formation follow loop checking installation；
（5）Variable speed electric motors, particularly in proppant mulling unit is opened, the scraping blade below sand tank is adjusted, the sand concentration for entering crack is reached
To design requirement；
（6）Start to matched somebody with somebody slippery water all to pump into crack from proppant to finish, whole process records sand with picture pick-up device
The distribution mode and relevant parameter of dike；
（7）Image data to obtaining is analyzed process.
2. shale gas according to claim 1 combine sand fracturing fracture condudtiviy evaluation method, it is characterised in that：Group
Close sand fracturing whaleback distribution mode record, description and whaleback distribution shape function to set up, its method is specifically：
（1）By visualization seam net inner support agent flowing simulated experiment device, the slippery water combination sand fracturing of simulation shale gas is split
Whaleback migration process in seam, and obtain the whaleback migration video that sand fracturing is combined under different experimental conditions；
（2）Using gray proces method, the picture pixels point at corresponding moment in the video of acquisition is made into gray proces, to whole picture
Point by point scanning is carried out, different-grain diameter proppant whaleback distribution curve is extracted；
（3）The whaleback distribution curve of extraction is utilized into linear regression method, different-grain diameter proppant whaleback distribution shape function f is set up1
(x), f2(x),……,fnX (), concrete formula is：f1(x)=ax3+bx2+ cx+d, in formula, a, b, c, d are experimental fit coefficient；
（4）According to API diversion chamber dimensions, using geometrical similarity principle, whaleback distribution shape function in API water conservancy diversion room is set up
F1(x), F2(x),……,Fn(x)；Specifically formula is：F1(x)=a1x3+b1x2+c1x+d1, in formula, a1, b1, c1, d1For geometry phase
Like transformation ratio；
（5）Repeat step（1-4）, according to the spread change of combination sand adding sand dike, obtain different moment whaleback distributions in API water conservancy diversion room
Shape function F1(x, t), F2(x, t),……, Fn(x, t)。
3. shale gas according to claim 1 combine sand fracturing fracture condudtiviy evaluation method, it is characterised in that：Group
Sand fracturing fracture condudtiviy API test and evaluation is closed, its method is specifically：
（1）According to different moment whaleback distribution shape function F in the API water conservancy diversion room for obtaining1(x, t), F2(x, t),……, Fn
(x, t), and the laid area A of different proppants is obtained using numerical integration1, A2,……, An, the different proppants refer to
100 mesh quartz sands or 40/70 mesh haydite, and different moment whaleback distribution shape functions in API water conservancy diversion room are drawn on a metal plate
F1(x, t), F2(x, t),……, Fn(x, t) curve；
The computing formula of the laid area A of proppant is in API rooms：
In formula, the laid area of A-proppant, cm2；
The laid length of L-proppant, cm；
（2）According to laid area A1, A2,……, AnAnd laid thickness H, obtain laid quality W of different proppantsp1,
Wp2,……, Wpn；
Proppant quality needed for flow conductivity evaluation experimental：
In formula：Wp- proppant quality, g；
The laid area of A-proppant, cm2；
The laid thickness of H-proppant is fracture width W f , cm；
- proppant volume density, g/cm3；
（3）The proppant for weighing up is uniform laid on the metallic plate of diversion chamber, it is not assumed to be by the region of proppant pack and is closed
Joint close, filling is replaced with dense material；
（4）Other piece of metal plate is placed on above laid good proppant pack, while will be upper with square seal ring
Piston is put in water conservancy diversion room, is down pushed away slowly until contacting the other piece of metal plate with hand；
（5）The diversion chamber for assembling is placed between two parallel-plates of hydraulic pressure framework, two parallel-plates are lifted by hydraulic means
Lower flat board adds hydraulic pressure, until loading speed is 3500kPa/min；
（6）Experimental gas discharge capacity is adjusted by " FCTS-1 fracture acidizing fracture condudtiviy detecting and analysing systems " so as to stable
In 100 ~ 109mL/min；
（7）Start computer, be input into experiment parameter；
（8）Experimental gas are allowed to pass through proppant pack under the clossing pressure of setting；
（9）Increase clossing pressure step by step, repeat（8）The step of, obtain the permeability of proppant pack under different clossing pressures
And flow conductivity；
（10）Record instrument connection inlet pressureP AWith instrument connection outlet pressureP B；
（11）All data are delivered to computer by data collecting system, and computer recorded a secondary data per 30 seconds, certainly finally
The dynamic flow conductivity and permeability for calculating proppant pack；
The flow conductivity of proppant pack is calculated as follows：
In formula：k g The perm-plug method of-filling bed,；
q 0- experimental gas flow, cm3/s；
p 0- standard atmospheric pressure；
μ g- test experiments gas viscosity, mPa.s；
LDistance between-two pressure tapsL=12.7cm；
W- diversion chamber width, W=3.81cm；
P A- instrument connection inlet pressure, kPa；
P B- instrument connection outlet pressure, kPa；
W fThe thickness of-proppant pack, cm；
kg.Wf- proppant pack gas surveys flow conductivity,。
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201410743602.6A CN104358554B (en) | 2014-12-09 | 2014-12-09 | Shale gas combined sand fracturing fracture conductivity evaluation method |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201410743602.6A CN104358554B (en) | 2014-12-09 | 2014-12-09 | Shale gas combined sand fracturing fracture conductivity evaluation method |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN104358554A CN104358554A (en) | 2015-02-18 |
| CN104358554B true CN104358554B (en) | 2017-05-10 |
Family
ID=52525851
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201410743602.6A Active CN104358554B (en) | 2014-12-09 | 2014-12-09 | Shale gas combined sand fracturing fracture conductivity evaluation method |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN104358554B (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN110952970A (en) * | 2019-12-03 | 2020-04-03 | 西南石油大学 | Combined proppant flow conductivity prediction method |
Families Citing this family (21)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN105298488A (en) * | 2015-12-03 | 2016-02-03 | 中国石油集团川庆钻探工程有限公司 | Method for testing flow conductivity in discontinuous filling mode |
| CN105574283B (en) * | 2015-12-24 | 2019-04-19 | 中国石油化工股份有限公司 | Blowout oil nozzle method for determining dimension after a kind of pressure break |
| CN107558979B (en) * | 2016-06-30 | 2019-05-14 | 中国石油化工股份有限公司 | A kind of method of shale volume pressure break |
| CN106337677B (en) * | 2016-10-17 | 2019-03-26 | 长江大学 | Shale gas pressure-break net air water two-phase flow conductivity test macro and test method |
| CN108005630A (en) * | 2016-10-31 | 2018-05-08 | 中国石油天然气股份有限公司 | Method and device for acquiring channel fracturing fracture flow guide information |
| CN108152184A (en) * | 2016-12-02 | 2018-06-12 | 中国石油天然气股份有限公司 | Proppant flow conductivity test method based on in-seam flow law |
| CN109426689B (en) * | 2017-08-31 | 2021-10-29 | 中国石油化工股份有限公司 | Evaluation method and system for horizontal well fracturing fracture |
| CN109751035B (en) * | 2017-11-01 | 2021-06-22 | 中国石油化工股份有限公司 | Fracturing sand adding method for oil and gas reservoir |
| CN107701164B (en) * | 2017-11-16 | 2023-11-03 | 中国石油集团川庆钻探工程有限公司 | Shale bedding internal propping agent migration simulation device and evaluation method |
| CN109944585A (en) * | 2017-12-21 | 2019-06-28 | 中国石油化工股份有限公司 | Load fluid flow analogue system and method in a kind of large flat |
| CN108416160B (en) * | 2018-03-22 | 2020-12-11 | 西南石油大学 | Method for optimizing pulse fiber sand fracturing parameters |
| CN112228033B (en) * | 2019-07-15 | 2022-09-27 | 中国石油化工股份有限公司 | Method and system for quantitatively analyzing effectiveness of fractured fractures |
| CN111622730B (en) * | 2020-05-29 | 2022-04-01 | 中国石油大学(华东) | Fracturing sand adding design method based on large-scale parallel plate proppant migration and placement model experiment |
| CN111795915B (en) * | 2020-06-29 | 2022-03-22 | 中国石油大学(北京) | Method, device and equipment for determining proppant parameters in rough hydraulic fracture |
| CN112302607B (en) * | 2020-07-07 | 2021-09-24 | 西南石油大学 | Method for explaining artificial fracture parameters of tight gas reservoir fractured horizontal well |
| CN114482971B (en) * | 2020-11-13 | 2024-05-28 | 中国石油天然气股份有限公司 | Unconventional reservoir fracturing modification propping agent optimization method and application |
| CN113218770B (en) * | 2021-03-12 | 2022-07-01 | 西南石油大学 | Multi-lithologic fracturing crack test method |
| CN114113497B (en) * | 2022-01-21 | 2022-06-24 | 中国石油大学(华东) | Experimental device and test method for evaluating fracturing performance of liquid phase-change propping agent |
| CN114526046B (en) * | 2022-03-04 | 2023-08-15 | 西南石油大学 | Construction method of complex fracture network system under simulated stratum condition |
| CN114922604B (en) * | 2022-06-22 | 2023-05-30 | 西南石油大学 | Prediction method for stacking and laying morphology of propping agent in fracture |
| CN116451300B (en) * | 2022-12-13 | 2023-11-24 | 成都理工大学 | Crack diversion capacity prediction method based on different sand filling parameters |
Family Cites Families (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US6431278B1 (en) * | 2000-10-05 | 2002-08-13 | Schlumberger Technology Corporation | Reducing sand production from a well formation |
| US7210342B1 (en) * | 2001-06-02 | 2007-05-01 | Fluid Inclusion Technologies, Inc. | Method and apparatus for determining gas content of subsurface fluids for oil and gas exploration |
| FR2853071B1 (en) * | 2003-03-26 | 2005-05-06 | Inst Francais Du Petrole | METHOD AND DEVICE FOR EVALUATING PHYSICAL PARAMETERS OF A UNDERGROUND DEPOSIT FROM ROCK DEBRIS WHICH ARE TAKEN THEREFROM |
| CN102174883B (en) * | 2011-01-13 | 2013-05-29 | 东北石油大学 | Method for testing flow conductivity of clear water fracturing self-supported crack |
| CN102436656A (en) * | 2011-09-05 | 2012-05-02 | 同济大学 | Animal-diversity monitoring method based on computer vision |
| CN102720486B (en) * | 2012-06-28 | 2015-07-15 | 中国石油大学(华东) | Device for testing shale gas fracture network diversion capacity and working method of device |
-
2014
- 2014-12-09 CN CN201410743602.6A patent/CN104358554B/en active Active
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN110952970A (en) * | 2019-12-03 | 2020-04-03 | 西南石油大学 | Combined proppant flow conductivity prediction method |
Also Published As
| Publication number | Publication date |
|---|---|
| CN104358554A (en) | 2015-02-18 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN104358554B (en) | Shale gas combined sand fracturing fracture conductivity evaluation method | |
| RU2723769C1 (en) | Method of calculating volume of reverse flow of fluid for hydraulic fracturing of formation during hydraulic fracturing in horizontal wells in gas deposits of fractured sandstones | |
| Ribeiro et al. | Use of a CO2-hybrid fracturing design to enhance production from unpropped-fracture networks | |
| Liu et al. | Study on the effect of cemented natural fractures on hydraulic fracture propagation in volcanic reservoirs | |
| Wang et al. | Optimization design of hydraulic parameters for supercritical CO2 fracturing in unconventional gas reservoir | |
| Wang et al. | Experimental investigations of hydraulic fracture growth complexity in slickwater fracturing treatments | |
| CN106874544A (en) | A kind of geology characterizing method of shale reservoir reconstruction volume | |
| CN109408859A (en) | Method for establishing two-dimensional triple medium numerical model of shale gas reservoir fractured horizontal well | |
| Hu et al. | Shape factor of the flake-like particle in thermal spallation and its effects on settling and transport behavior in drilling annulus | |
| CN204086078U (en) | A kind of parallel board slit simulation apparatus of fracturing fluid leak | |
| CN106295095A (en) | New method based on Conventional Logs prediction low permeability sandstone reservoir production capacity | |
| Xu et al. | Optimization of hydraulically fractured well configuration in anisotropic coal-bed methane reservoirs | |
| Zhang | Theoretical conductivity analysis of surface modification agent treated proppant | |
| Luo et al. | Integrated simulation for hydraulic fracturing, productivity prediction, and optimization in tight conglomerate reservoirs | |
| CN116128083A (en) | Quantitative characterization method for volume of shale oil horizontal well volume fracturing crack | |
| Yang et al. | Numerical simulation of in situ exploitation of oil shale by injecting high-temperature steam. | |
| Wang et al. | Large-scale physical simulation experiment research for hydraulic fracturing in shale | |
| El Sgher et al. | The Stress Shadowing Impact on the Production Performance of Marcellus Shale | |
| Cao et al. | A dynamic fracture model combining with Laplace transform and synchronous iteration method for transient behavior analysis of a four-zone system | |
| Gao et al. | Effect of pressure pulse stimulation on imbibition displacement within a tight sandstone reservoir with local variations in porosity | |
| Liu et al. | Working fluid-induced formation damage evaluation for commingled production of multi-layer natural gas reservoirs with flow rate method | |
| Tian et al. | Quantifying micro-proppants crushing rate and evaluating propped micro-fractures | |
| CN108678723B (en) | Fracturing modification method for shale oil reservoir of closed lake basin | |
| Yang et al. | Migration of variable density proppant particles in hydraulic fracture in coal-bed methane reservoir | |
| Liang et al. | Experimental study on fracture conductivity in high temperature and high pressure tight gas formation: A case of Tarim basin in China |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| C06 | Publication | ||
| PB01 | Publication | ||
| C10 | Entry into substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant | ||
| TR01 | Transfer of patent right |
Effective date of registration: 20200914 Address after: 100007 Beijing, Dongzhimen, North Street, No. 9, No. Co-patentee after: CNPC Chuanqing Drilling Engineering Co.,Ltd. Patentee after: CHINA NATIONAL PETROLEUM Corp. Address before: The 1 section of No. 3 company Chuanqing Drilling Technology Information Office Chenghua District Green Road 610051 Chengdu City, Sichuan Province Patentee before: CNPC Chuanqing Drilling Engineering Co.,Ltd. |
|
| TR01 | Transfer of patent right |