CN204374032U - Sand filling model device for simulating deep profile control and flooding plugging agent effects of different oil reservoirs - Google Patents
Sand filling model device for simulating deep profile control and flooding plugging agent effects of different oil reservoirs Download PDFInfo
- Publication number
- CN204374032U CN204374032U CN201420802791.5U CN201420802791U CN204374032U CN 204374032 U CN204374032 U CN 204374032U CN 201420802791 U CN201420802791 U CN 201420802791U CN 204374032 U CN204374032 U CN 204374032U
- Authority
- CN
- China
- Prior art keywords
- tube
- sand
- oil reservoir
- straight
- sand filling
- 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.)
- Expired - Fee Related
Links
- 239000004576 sand Substances 0.000 title claims abstract description 64
- 230000000694 effects Effects 0.000 title claims abstract description 19
- 239000003795 chemical substances by application Substances 0.000 title abstract description 36
- 239000002184 metal Substances 0.000 claims abstract description 4
- 239000002981 blocking agent Substances 0.000 claims description 17
- 238000012937 correction Methods 0.000 claims description 15
- 235000013312 flour Nutrition 0.000 claims description 3
- 238000000227 grinding Methods 0.000 claims description 3
- 238000003801 milling Methods 0.000 claims description 3
- 238000004088 simulation Methods 0.000 abstract description 7
- 239000000463 material Substances 0.000 abstract description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 54
- 239000003921 oil Substances 0.000 description 49
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 48
- 238000002347 injection Methods 0.000 description 39
- 239000007924 injection Substances 0.000 description 39
- 230000035699 permeability Effects 0.000 description 35
- 238000011084 recovery Methods 0.000 description 35
- 238000000034 method Methods 0.000 description 27
- 230000008569 process Effects 0.000 description 21
- 230000008859 change Effects 0.000 description 17
- 238000002474 experimental method Methods 0.000 description 15
- 238000011160 research Methods 0.000 description 9
- 239000003129 oil well Substances 0.000 description 7
- 238000011161 development Methods 0.000 description 6
- 238000012360 testing method Methods 0.000 description 6
- 241000184339 Nemophila maculata Species 0.000 description 5
- 238000001514 detection method Methods 0.000 description 5
- 230000014759 maintenance of location Effects 0.000 description 5
- 238000013508 migration Methods 0.000 description 5
- 230000005012 migration Effects 0.000 description 5
- 230000000704 physical effect Effects 0.000 description 5
- 229920006395 saturated elastomer Polymers 0.000 description 5
- 239000002349 well water Substances 0.000 description 4
- 235000020681 well water Nutrition 0.000 description 4
- 239000012530 fluid Substances 0.000 description 3
- 239000011435 rock Substances 0.000 description 3
- 239000010779 crude oil Substances 0.000 description 2
- 238000006731 degradation reaction Methods 0.000 description 2
- 238000007789 sealing Methods 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000000903 blocking effect Effects 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000013401 experimental design Methods 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 238000005065 mining Methods 0.000 description 1
- 239000002808 molecular sieve Substances 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 238000010298 pulverizing process Methods 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 239000000377 silicon dioxide Substances 0.000 description 1
- URGAHOPLAPQHLN-UHFFFAOYSA-N sodium aluminosilicate Chemical compound [Na+].[Al+3].[O-][Si]([O-])=O.[O-][Si]([O-])=O URGAHOPLAPQHLN-UHFFFAOYSA-N 0.000 description 1
- 230000000638 stimulation Effects 0.000 description 1
- 238000003809 water extraction Methods 0.000 description 1
Landscapes
- Management, Administration, Business Operations System, And Electronic Commerce (AREA)
Abstract
The utility model provides a sand filling model device for simulating the deep profile control and flooding plugging agent effect of different oil reservoirs, which comprises a five-way pipe and four straight-tube sand filling pipes, wherein one end of each straight-tube sand filling pipe is connected with the port of the five-way pipe, and the four straight-tube sand filling pipes are positioned in the same plane; a plurality of pressure measuring holes are arranged on the pipe wall of each straight barrel sand filling pipe along the radial direction of the straight barrel sand filling pipe; in order to avoid the sand material in the model from leaking outwards, metal filter screens are arranged in the ports at the two ends of each straight barrel sand filling pipe along the radial direction. The device has the advantages of compact structure, simple and convenient operation and low use cost, and is combined with the existing physical model to realize a comprehensive solution for researching rheological property and seepage condition simulation of the profile control plugging agent in different characteristic oil reservoir types such as plane, vertical and fractured oil reservoirs.
Description
Technical field
The utility model belongs to field of petroleum exploitation, is specifically related to a kind of sand-packed model device of simulating the deep profile correction blocking agent effect of different oil reservoir.
Background technology
In the process of oil-field development, after oil reservoir primary energy starts reduction, need to stratum after-teeming energy, namely to oil-bearing stratum flooding, to improve oil recovery factor.But, after oil-field development enters middle and advanced stage, well water problem will be run into, bring serious impact to oil well production.Due to well water, oil reservoir energy is declined, causes pipeline and equipment scaling, concurrent corrosion, increase dewatering system load, reduce the ultimate recovery factor of oil reservoir.Therefore, in the process of oil-field development, must notice that well water is dynamic in time, study and take effective measures, reducing well water, to improve oil recovery factor.Due to the nonuniformity of oil reservoir or because mining type is improper, injection water and limit water are advanced unevenly along most permeable zone and high permeability zones, form individual layer in the vertical to advance by leaps and bounds, form tonguing in the horizontal, cause before injecting water extraction and break through, cause oil well to cross early leaving, until water logging, and low permeability layer is not yet had an effect, reduce the recovery ratio of crude oil.Therefore, steady oil control water is an important subject in oilfield development process.For preventing oil well from crossing early leaving, people do a lot of work in development plan and exploitation measure.In development plan, have employed reasonable pattern shape; In exploitation measure, have employed the method for zonal injection.But, due to the nonuniformity on stratum, inject water and still can not avoid along the uneven propelling of most permeable zone; In the process of mechanical dispensing, because separation scraper occurs to separate not tight situation, or because of reasons such as cementing qualities, oil well still can be caused to cross the phenomenon of early leaving.Therefore, the method for oilwell water shutoff or Profile Control in Injection Well must be adopted to administer water damage.For the oil field of most waterflooding, due to the nonuniformity of oil reservoir, injection water is advanced by leaps and bounds be the main cause of waterflood along most permeable zone band.To water producer Ex post, although can reduce water cut, the term of validity is short, and only individual well is benefited, and certainly will increase construction cost, and success ratio is not high, the stratum that particularly nonuniformity is serious.For this reason, solve the problem of the too early water logging of oil well, also must set about from water injection well.On water injection well, adopt zonal injection and separate zone stimulation low permeability layer to be the important measures that waterline can more evenly be advanced, but be not can deal with problems better in all cases.Therefore, the method of water injection well being carried out to selectively blocking off most permeable zone macropore adjusts and improves intake profile, i.e. Profile Control in Injection Well, that waterline is advanced more equably, prevent the too early water logging of oil well, reduce crude oil water containing, increase the area of water displacing oil, reduce region of bypassed oil, improve reservoir recovery better method.
Profile control and water plugging is the important measures that oil reservoir improving ecology improves that block integral injects effect, carrying out in profile control and water plugging research process, the foundation of physical simulating method and device is the pith of experimental design, current research process mainly adopts single tube and two-tube parallel model to carry out the sealing characteristics research of profile control agent, the degradation process of immediate vicinity of wellbore to profile control agent cannot be simulated, also cannot the change of close-ups rock core content displacement process, and Physical Modeling is single, there is certain distance with the flow event of oil reservoir complexity.
Utility model content
The purpose of this utility model is that the existing profile control blocking agent sand-packed model of solution is single, cannot simulate the degradation process of immediate vicinity of wellbore to profile control agent, there is the problem of certain distance with the flow event of oil reservoir complexity.
For this reason, the utility model provides a kind of sand-packed model device of simulating the deep profile correction blocking agent effect of different oil reservoir, comprise a Five-way tube and four straight tube fill out sand tube, one end of every root straight tube fill out sand tube is connected with the port of Five-way tube, and four straight tube fill out sand tube are in same plane;
The tube wall of every root straight tube fill out sand tube is radially provided with multiple pressure tap;
Radially metal screen is provided with in the port at the two ends of every root straight tube fill out sand tube.
Described straight tube fill out sand tube comprises straight length, is positioned at top connection and the lower sub at straight length two ends, and the port of described top connection and Five-way tube is threaded connection.
Described pressure tap is 2.
The internal diameter of described straight tube fill out sand tube is 15.4mm ~ 35.4mm, and length is 100mm ~ 300mm.
The internal diameter of described straight tube fill out sand tube is 25.4mm, and length is 200mm.
The internal diameter of described Five-way tube is 15.4mm ~ 35.4mm.
The internal diameter of described Five-way tube is 25.4mm.
The inwall of described Five-way tube and four straight tube fill out sand tube is the flour milling of grinding homogeneity.
The beneficial effects of the utility model: the utility model provides a kind of sand-packed model device of simulating the deep profile correction blocking agent effect of different oil reservoir, compact conformation, easy and simple to handle, use cost is low, is combined the total solution achieving and study profile control blocking agent and simulate in the different characteristic Oil Reservoir Types process streams sex change such as plane, vertical and fractured reservoir and seepage flow situation with existing physical model.
Below with reference to accompanying drawing, the utility model is described in further details.
Accompanying drawing explanation
Fig. 1 is the structural representation of the sand-packed model device of the deep profile correction blocking agent effect simulating different oil reservoir.
Fig. 2 is the structural representation of straight tube fill out sand tube.
Description of reference numerals: 1, Five-way tube; 2, straight tube fill out sand tube; 3, pressure tap; 4, straight length; 5, top connection; 6, lower sub.
Embodiment
Further the sand-packed model device of the deep profile correction blocking agent effect of the different oil reservoir of this simulation is described in detail below with reference to accompanying drawing.
embodiment 1:
As shown in Figure 1, the utility model provides a kind of sand-packed model device of simulating the deep profile correction blocking agent effect of different oil reservoir, comprise a Five-way tube 1 and four straight tube fill out sand tube 2, one end of every root straight tube fill out sand tube 2 is connected with the port of Five-way tube 1, and four straight tube fill out sand tube 2 are in same plane; The tube wall of every root straight tube fill out sand tube 2 is radially provided with multiple pressure tap 3; In model, sand material leaks outside, and is radially provided with metal screen in the port at the two ends of every root straight tube fill out sand tube 2.
First every root straight tube fill out sand tube 2 carries out rock core pulverizing according to research block reservoir characteristics and non-average, with molecular sieve sorting different-grain diameter rock particles, or select different-grain diameter silica sand to carry out back-up sand, back-up sand process carries out compacting according to filled out permeability, factor of porosity requirement.Back-up sand process completes.Experimentally scheme carries out the test of perm-plug method and factor of porosity, in back-up sand process, according to oil reservoir basic condition, the back-up sand of different permeability can be carried out, ensure plane heterogeneity and vertical heterogeneity, it is to be noted, four straight tube fill out sand tube 2, wherein one end of every root straight tube fill out sand tube 2 is connected with the port of Five-way tube 1, and one end is as fluid egress point in addition, and one end that namely port at Five-way tube 1 center is not connected with straight tube fill out sand tube 2 is as fluid intake.
Concrete, research block oil reservoir situation is as follows: lithology Dark grey feldspathic quartzose sandstone granularity: based on thin-middle sandstone, oil reservoir average effective factor of porosity 15.0%, average effective permeability 16.58mD, reservoir heterogeneity is strong, and permeability maximal value is 100.7mD, minimum value is 2mD, permeability grade 50.35, the coefficient of variation 0.91, well pattern form is five-spot network.Carry out back-up sand according to this data, back-up sand result test permeability maximal value is 98.6mD, and minimum value is 1.5mD, average out to 50.1mD, and integral plane nonuniformity is 0.86, and therefore, this physical model is similar to oil reservoir basic physical properties.
Experimentation: the saturated local water of reservoir temperature drag, sets up irreducible water, carries out water drive, and water drive is to moisture 98%, and injection profile agent, profile control agent injection rate IR is 0.05PV, carries out sequent water flooding after constant temperature 48h.
Experimental result: water drive is to moisture 98%, recovery ratio is 23.5%, after injection profile agent, recovery ratio improves 3.56%, sequent water flooding recovery ratio is increased to 45.6%, resistance coefficient is 12.5, residual resistance factor is 5.6, and wherein hyposmosis sand-packed model improves recovery ratio 35.2%, and it is 2.3% that higher permeability model improves recovery ratio.Record pressure change in experimentation to find, profile control agent is the change of different pressure tap pressure gradient in injection process, detects viscosity retention ratio by pressure tap 3, calculates to determine profile control agent and to migrate in oil reservoir the degree of depth.After experiment terminates, open the connection of thread of Five-way tube 1 and straight tube fill out sand tube 2, by qualitative detection, Microscopic observation, profile control agent is in the different migration process in permeability direction and the change of viscosity.
Experiment conclusion: by carrying out this physical simulation experiment, determines profile control system and is adapted to such oil reservoir, effectively can improve the recovery ratio of such reservoir.Carry out profile control experiment for scene and determine injection parameter and injection rate IR.
embodiment 2:
On the basis of embodiment 1, further, as shown in Figure 2, described straight tube fill out sand tube 2 comprises straight length 4, is positioned at top connection 5 and the lower sub 6 at straight length 4 two ends, described top connection 5 is threaded connection with the port of Five-way tube 1, and described pressure tap 3 is 2, and lower sub 6 is as fluid egress point.
Concrete, research block oil reservoir situation is as follows: lithology Dark grey feldspathic quartzose sandstone granularity: based on thin-middle sandstone, oil reservoir average effective factor of porosity 15.0%, average effective permeability 16.58mD, reservoir heterogeneity is strong, and permeability maximal value is 100.7mD, minimum value is 2mD, permeability grade 50.35, the coefficient of variation 0.91, well pattern form is five-spot network.Carry out back-up sand according to this data, back-up sand result test permeability maximal value is 98.6mD, and minimum value is 1.5mD, average out to 50.1mD, and integral plane nonuniformity is 0.86, and therefore, this physical model is similar to oil reservoir basic physical properties.
Experimentation: the saturated local water of reservoir temperature drag, sets up irreducible water, carries out water drive, and water drive is to moisture 98%, and injection profile agent, profile control agent injection rate IR is 0.05PV, carries out sequent water flooding after constant temperature 48h.
Experimental result: water drive is to moisture 98%, recovery ratio is 23.5%, after injection profile agent, recovery ratio improves 3.56%, sequent water flooding recovery ratio is increased to 45.6%, resistance coefficient is 12.5, residual resistance factor is 5.6, and wherein hyposmosis sand-packed model improves recovery ratio 35.2%, and it is 2.3% that higher permeability model improves recovery ratio.Record pressure change in experimentation to find, profile control agent is the change of different pressure tap pressure gradient in injection process, detects viscosity retention ratio by pressure tap 3, calculates to determine profile control agent and to migrate in oil reservoir the degree of depth.After experiment terminates, open the connection of thread of Five-way tube 1 and straight tube fill out sand tube 2, by qualitative detection, Microscopic observation, profile control agent is in the different migration process in permeability direction and the change of viscosity.
Experiment conclusion: by carrying out this physical simulation experiment, determines profile control system and is adapted to such oil reservoir, effectively can improve the recovery ratio of such reservoir.Carry out profile control experiment for scene and determine injection parameter and injection rate IR.
embodiment 3:
On the basis of embodiment 1, it should be noted that, the internal diameter of described straight tube fill out sand tube 2 is 15.4mm ~ 35.4mm, and length is 100mm ~ 300mm.The internal diameter of described Five-way tube 1 is 15.4mm ~ 35.4mm.
Research block oil reservoir situation is as follows: lithology Dark grey feldspathic quartzose sandstone granularity: based on thin-middle sandstone, oil reservoir average effective factor of porosity 15.0%, average effective permeability 16.58mD, reservoir heterogeneity is strong, permeability maximal value is 100.7mD, and minimum value is 2mD, permeability grade 50.35, the coefficient of variation 0.91, well pattern form is five-spot network.Carry out back-up sand according to this data, back-up sand result test permeability maximal value is 98.6mD, and minimum value is 1.5mD, average out to 50.1mD, and integral plane nonuniformity is 0.86, and therefore, this physical model is similar to oil reservoir basic physical properties.
Experimentation: the saturated local water of reservoir temperature drag, sets up irreducible water, carries out water drive, and water drive is to moisture 98%, and injection profile agent, profile control agent injection rate IR is 0.05PV, carries out sequent water flooding after constant temperature 48h.
Experimental result: water drive is to moisture 98%, recovery ratio is 23.5%, after injection profile agent, recovery ratio improves 3.56%, sequent water flooding recovery ratio is increased to 45.6%, resistance coefficient is 12.5, residual resistance factor is 5.6, and wherein hyposmosis sand-packed model improves recovery ratio 35.2%, and it is 2.3% that higher permeability model improves recovery ratio.Record pressure change in experimentation to find, profile control agent is the change of different pressure tap pressure gradient in injection process, detects viscosity retention ratio by pressure tap 3, calculates to determine profile control agent and to migrate in oil reservoir the degree of depth.After experiment terminates, open the connection of thread of Five-way tube 1 and straight tube fill out sand tube 2, by qualitative detection, Microscopic observation, profile control agent is in the different migration process in permeability direction and the change of viscosity.
Experiment conclusion: by carrying out this physical simulation experiment, determines profile control system and is adapted to such oil reservoir, effectively can improve the recovery ratio of such reservoir.Carry out profile control experiment for scene and determine injection parameter and injection rate IR.
embodiment 4:
On the basis of embodiment 3, in order to ensure sealing effectiveness, this physical model adopts being threaded of identical caliber, concrete, and the internal diameter of described straight tube fill out sand tube 2 is 25.4mm, and length is 200mm.The internal diameter of described Five-way tube 1 is 25.4mm.
Research block oil reservoir situation is as follows: lithology Dark grey feldspathic quartzose sandstone granularity: based on thin-middle sandstone, oil reservoir average effective factor of porosity 15.0%, average effective permeability 16.58mD, reservoir heterogeneity is strong, permeability maximal value is 100.7mD, and minimum value is 2mD, permeability grade 50.35, the coefficient of variation 0.91, well pattern form is five-spot network.Carry out back-up sand according to this data, back-up sand result test permeability maximal value is 98.6mD, and minimum value is 1.5mD, average out to 50.1mD, and integral plane nonuniformity is 0.86, and therefore, this physical model is similar to oil reservoir basic physical properties.
Experimentation: the saturated local water of reservoir temperature drag, sets up irreducible water, carries out water drive, and water drive is to moisture 98%, and injection profile agent, profile control agent injection rate IR is 0.05PV, carries out sequent water flooding after constant temperature 48h.
Experimental result: water drive is to moisture 98%, recovery ratio is 23.5%, after injection profile agent, recovery ratio improves 3.56%, sequent water flooding recovery ratio is increased to 45.6%, resistance coefficient is 12.5, residual resistance factor is 5.6, and wherein hyposmosis sand-packed model improves recovery ratio 35.2%, and it is 2.3% that higher permeability model improves recovery ratio.Record pressure change in experimentation to find, profile control agent is the change of different pressure tap pressure gradient in injection process, detects viscosity retention ratio by pressure tap 3, calculates to determine profile control agent and to migrate in oil reservoir the degree of depth.After experiment terminates, open the connection of thread of Five-way tube 1 and straight tube fill out sand tube 2, by qualitative detection, Microscopic observation, profile control agent is in the different migration process in permeability direction and the change of viscosity.
Experiment conclusion: by carrying out this physical simulation experiment, determines profile control system and is adapted to such oil reservoir, effectively can improve the recovery ratio of such reservoir.Carry out profile control experiment for scene and determine injection parameter and injection rate IR.
embodiment 5:
On the basis of embodiment 1, the inwall of described Five-way tube 1 and four straight tube fill out sand tube 2 is the flour milling of grinding homogeneity.By inwall hacking, be to prevent edge of model channelling.
Operation concrete is further, research block oil reservoir situation is as follows: lithology Dark grey feldspathic quartzose sandstone granularity: based on thin-middle sandstone, oil reservoir average effective factor of porosity 15.0%, average effective permeability 16.58mD, reservoir heterogeneity is strong, and permeability maximal value is 100.7mD, minimum value is 2mD, permeability grade 50.35, the coefficient of variation 0.91, well pattern form is five-spot network.Carry out back-up sand according to this data, back-up sand result test permeability maximal value is 98.6mD, and minimum value is 1.5mD, average out to 50.1mD, and integral plane nonuniformity is 0.86, and therefore, this physical model is similar to oil reservoir basic physical properties.
Experimentation: the saturated local water of reservoir temperature drag, sets up irreducible water, carries out water drive, and water drive is to moisture 98%, and injection profile agent, profile control agent injection rate IR is 0.05PV, carries out sequent water flooding after constant temperature 48h.
Experimental result: water drive is to moisture 98%, recovery ratio is 23.5%, after injection profile agent, recovery ratio improves 3.56%, sequent water flooding recovery ratio is increased to 45.6%, resistance coefficient is 12.5, residual resistance factor is 5.6, and wherein hyposmosis sand-packed model improves recovery ratio 35.2%, and it is 2.3% that higher permeability model improves recovery ratio.Record pressure change in experimentation to find, profile control agent is the change of different pressure tap pressure gradient in injection process, detects viscosity retention ratio by pressure tap 3, calculates to determine profile control agent and to migrate in oil reservoir the degree of depth.After experiment terminates, open the connection of thread of Five-way tube 1 and straight tube fill out sand tube 2, by qualitative detection, Microscopic observation, profile control agent is in the different migration process in permeability direction and the change of viscosity.
Experiment conclusion: by carrying out this physical simulation experiment, determines profile control system and is adapted to such oil reservoir, effectively can improve the recovery ratio of such reservoir.Carry out profile control experiment for scene and determine injection parameter and injection rate IR.
More than exemplifying is only illustrate of the present utility model, does not form the restriction to protection domain of the present utility model, everyly all belongs within protection scope of the present invention with the same or analogous design of the utility model.
Claims (8)
1. simulate the sand-packed model device of the deep profile correction blocking agent effect of different oil reservoir for one kind, it is characterized in that: comprise a Five-way tube (1) and four straight tube fill out sand tube (2), one end of every root straight tube fill out sand tube (2) is connected with the port of Five-way tube (1), and four straight tube fill out sand tube (2) are in same plane;
The tube wall of every root straight tube fill out sand tube (2) is radially provided with multiple pressure tap (3);
Radially metal screen is provided with in the port at the two ends of every root straight tube fill out sand tube (2).
2. a kind of sand-packed model device of simulating the deep profile correction blocking agent effect of different oil reservoir as claimed in claim 1, it is characterized in that: described straight tube fill out sand tube (2) comprises straight length (4), is positioned at the top connection (5) at straight length (4) two ends and lower sub (6), described top connection (5) is threaded connection with the port of Five-way tube (1).
3. a kind of sand-packed model device of simulating the deep profile correction blocking agent effect of different oil reservoir as claimed in claim 1, is characterized in that: described pressure tap (3) is 2.
4. a kind of sand-packed model device of simulating the deep profile correction blocking agent effect of different oil reservoir as claimed in claim 2, is characterized in that: the internal diameter of described straight tube fill out sand tube (2) is 15.4mm ~ 35.4mm, and length is 100mm ~ 300mm.
5. a kind of sand-packed model device of simulating the deep profile correction blocking agent effect of different oil reservoir as claimed in claim 4, is characterized in that: the internal diameter of described straight tube fill out sand tube (2) is 25.4mm, and length is 200mm.
6. a kind of sand-packed model device of simulating the deep profile correction blocking agent effect of different oil reservoir as claimed in claim 1, is characterized in that: the internal diameter of described Five-way tube (1) is 15.4mm ~ 35.4mm.
7. a kind of sand-packed model device of simulating the deep profile correction blocking agent effect of different oil reservoir as claimed in claim 6, is characterized in that: the internal diameter of described Five-way tube (1) is 25.4mm.
8. a kind of sand-packed model device of simulating the deep profile correction blocking agent effect of different oil reservoir as claimed in claim 1, is characterized in that: the inwall of described Five-way tube (1) and four straight tube fill out sand tube (2) is the flour milling of grinding homogeneity.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201420802791.5U CN204374032U (en) | 2014-12-18 | 2014-12-18 | Sand filling model device for simulating deep profile control and flooding plugging agent effects of different oil reservoirs |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201420802791.5U CN204374032U (en) | 2014-12-18 | 2014-12-18 | Sand filling model device for simulating deep profile control and flooding plugging agent effects of different oil reservoirs |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN204374032U true CN204374032U (en) | 2015-06-03 |
Family
ID=53330242
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201420802791.5U Expired - Fee Related CN204374032U (en) | 2014-12-18 | 2014-12-18 | Sand filling model device for simulating deep profile control and flooding plugging agent effects of different oil reservoirs |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN204374032U (en) |
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN106896041A (en) * | 2015-12-17 | 2017-06-27 | 中国石油天然气股份有限公司 | Water plugging performance evaluation device of particle water plugging agent |
| CN110805426A (en) * | 2019-06-27 | 2020-02-18 | 大港油田集团有限责任公司 | Pipe wall channeling prevention sand filling pipe for profile control agent sealing channeling simulation experiment |
-
2014
- 2014-12-18 CN CN201420802791.5U patent/CN204374032U/en not_active Expired - Fee Related
Cited By (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN106896041A (en) * | 2015-12-17 | 2017-06-27 | 中国石油天然气股份有限公司 | Water plugging performance evaluation device of particle water plugging agent |
| CN106896041B (en) * | 2015-12-17 | 2023-09-26 | 中国石油天然气股份有限公司 | Water shutoff performance evaluation device of particle water shutoff agent |
| CN110805426A (en) * | 2019-06-27 | 2020-02-18 | 大港油田集团有限责任公司 | Pipe wall channeling prevention sand filling pipe for profile control agent sealing channeling simulation experiment |
| CN110805426B (en) * | 2019-06-27 | 2022-11-25 | 大港油田集团有限责任公司 | Pipe wall channeling prevention sand filling pipe for profile control agent sealing channeling simulation experiment |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| Seright et al. | Water shutoff and conformance improvement: an introduction | |
| CN102562012B (en) | Method for improving recovery ratio of water-flooding developed common heavy oil reservoir | |
| CN103306659B (en) | A kind of fracturing technology of realizing superelevation flow conductivity | |
| WO2020155861A1 (en) | Method for filling oil-gas well of fractured oil-gas reservoir with isolation particles to reduce water and increase oil production | |
| CN110359897A (en) | A kind of fracture-type reservoir cracks seam with boring leak-proof leak-stopping method in advance | |
| CN103244071A (en) | Old well plugging method for underground gas storage | |
| CN110359898A (en) | A kind of fracture-type reservoir cracks seam plugging material selection method in advance | |
| CN102865060A (en) | Determining method of amount of shale oil deposit hydrofracture propping agent | |
| CN102146789B (en) | Deep profile controlling method | |
| CN105756651A (en) | Positive-pressure-drilling water plugging and staged-fracturing production increasing process method for adjustment well | |
| CN105089600A (en) | Method for assisting horizontal well in dragging type hydraulic jet reconstruction through temporary blocking steering material | |
| CN107218024A (en) | Method for adjusting rhombus inverted nine-point well pattern in high water-cut period of multilayer low-permeability sandstone oil reservoir | |
| CN103087699A (en) | Sand-carrying profile control agent composition of fracture-cave type oil deposit and profile control method of profile control agent | |
| CN102052067A (en) | In-depth profile control step by step method employing equipressure drop gradient | |
| RU2478164C1 (en) | Development method of oil deposit located above gas deposit and separated from it with non-permeable interlayer | |
| Dong et al. | Discussion on the sweep efficiency of hybrid steam− chemical process in heavy oil reservoirs: an experimental study | |
| CN204374032U (en) | Sand filling model device for simulating deep profile control and flooding plugging agent effects of different oil reservoirs | |
| WO2022183898A1 (en) | Method for operating water injection well, and water injection well | |
| CN106958437A (en) | A kind of wellfracturing improves recovery ratio new method | |
| Ma et al. | Nitrogen foam flooding test for controlling water cut and enhance oil recovery in conventional oil reservoirs of China offshore oilfield | |
| Yuzhang et al. | Physical modeling of in-depth fluid diversion by “gel dam” placed with a horizontal well | |
| CN103046916A (en) | Selective injection method of refracturing plugging agent for double parallel connection rock core | |
| CN103048252A (en) | Testing method of plugging rate of repeated fracturing plugging agent | |
| CN105019873A (en) | Method for selective profile control of low-permeable fracture-type oil reservoir | |
| Yang et al. | Technique of water control and oil recovery based on water plugging combined with fracturing in low permeability and high water cut oilfield |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| C14 | Grant of patent or utility model | ||
| GR01 | Patent grant | ||
| CF01 | Termination of patent right due to non-payment of annual fee | ||
| CF01 | Termination of patent right due to non-payment of annual fee |
Granted publication date: 20150603 |