CN108659806A - A kind of deep profile correction system being suitable for marine high temperature and pressure heterogeneous reservoir - Google Patents
A kind of deep profile correction system being suitable for marine high temperature and pressure heterogeneous reservoir Download PDFInfo
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- CN108659806A CN108659806A CN201810412660.9A CN201810412660A CN108659806A CN 108659806 A CN108659806 A CN 108659806A CN 201810412660 A CN201810412660 A CN 201810412660A CN 108659806 A CN108659806 A CN 108659806A
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/5083—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained by reactions only involving carbon-to-carbon unsaturated bonds
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/5086—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds
Abstract
The invention belongs to the chemicals technical fields of field use, and in particular to a kind of deep profile correction system being suitable for marine high temperature and pressure heterogeneous reservoir.Including A liquid and B liquid, A liquid includes that mass concentration is 20%NaNO2, mass concentration is 0.3% citric acid, mass concentration is 0.04% Organic Chromium, mass concentration is 0.06% phenolic resin, mass concentration is 0.3% seawater Instant HPAM, mass concentration is 1 foaming agents of 0.5%COSL, excess water 78.8%, B liquid includes that mass concentration is 15.5%NH4Cl, mass concentration is 0.3% citric acid, mass concentration is 0.04% Organic Chromium, mass concentration is 0.06% phenolic resin, mass concentration is 0.3% seawater Instant HPAM, mass concentration is 1 foaming agents of 0.5%COSL, excess water 83.3%.Advantageous effect：Streaming rate is good under the conditions of high temperature and pressure (65~85 DEG C of temperature, 8~12MPa of pressure)；Effective closure can be formed to marine high temperature and pressure heterogeneous reservoir High water cut stratum, sealing ratiod is high, improves sweep efficiency, and then improve recovery ratio.
Description
Technical field
The invention belongs to the chemicals technical fields of field use, and in particular to it is non-that one kind being suitable for marine high temperature and pressure
The deep profile correction system of Homogeneous Reservoir.
Background technology
With the extension of development time, Bohai Sea part oilfield water flooding development effectiveness is deteriorated year by year, and part well group or block are
Into high water cut rate, " water and oil control " difficulty is gradually increased, and High water cut problem has become the key for restricting and being produced on oil field and asks
Topic.The reason of causing the result mainly has at 2 points：First, offshore oilfield productive series is complicated, after waterflooding extraction for many years,
Interlayer is particularly thorny in reservoir layer, and injection water water breakthrough is serious；Second is that with the exploitation in oil field, edge and bottom water invasion is serious, edge-bottom water
Water breakthrough causes moisture content to increase severely.At this stage, injection water is inefficient or inefficient cycle phenomenon is on the rise, and difficulty of governance also gradually adds
Greatly, the long-acting exploitation in oil field is influenced.Although current oil field has carried out well profile modification work, aqueous rising is slowed down to a certain extent
Speed, but after the operation of excessive round, effect worse and worse, and from oil well carry out water blockoff work carry out at present it is less, with
The increase of oil field High water cut difficulty of governance, oilwell water shutoff work will more and more be carried out.Water shutoff in oil well can be sealed effectively
Hypertonic channel is blocked up, the purpose for slowing down aqueous rising is realized in the water breakthrough of control injection water and edge-bottom water.
That there are construction spaces is small for offshore oilfield oilwell water shutoff, water-blocking operation is of high cost, is asked with liquid water supply difficulty etc.
Topic, applicable blocking agent should meet seawater prepare, preparing process is simple, blocking time is controllable, intensity controlled, under formation conditions surely
Determine, be easy to the conditions such as injection, environmental-friendly, of low cost.
Foam composite plugging agent is a kind of efficient selective water-plugging, and the application in the Bohai Sea and South Sea bottom water oil field achieves
Preferable effect.But the limitations of offshore platform are constrained to, foam air source supplement is difficult so that composite foam water blockoff skill
Art application is limited.It is therefore proposed that block water breakthrough layer position technology on the spot, by self generating gas system and foam, polymer or frozen glue etc. its
Its closure system is mutually compound, and spontaneous reaction generates composite foam and blocks system in the earth formation, blocks injection water or edge-bottom water water breakthrough
Channel, to achieve the effect that " water and oil control ".
Invention content
In view of the deficiencies of the prior art, the present invention provides a kind of deep tune being suitable for marine high temperature and pressure heterogeneous reservoir
Displacement system, to solve the problems in marine high temperature and pressure heterogeneous reservoir water plugging and profile controlling operation, the technical solution used is as follows：
A kind of deep profile correction system being suitable for marine high temperature and pressure heterogeneous reservoir, including A liquid and B liquid, A liquid includes matter
Measure a concentration of 20%NaNO2, mass concentration is 0.3% citric acid, mass concentration is 0.04% Organic Chromium, mass concentration is
0.06% phenolic resin, mass concentration are 0.3% seawater Instant HPAM, mass concentration is 0.5%COSL-1 foaming agents, surplus
Water 78.8%, B liquid include mass concentration be 15.5%NH4Cl, mass concentration is 0.3% citric acid, mass concentration 0.04%
Organic Chromium, mass concentration are 0.06% phenolic resin, mass concentration is 0.3% seawater Instant HPAM, mass concentration 0.5%
COSL-1 foaming agents, excess water 83.3%.
A kind of preparation method of deep profile correction system suitable for marine high temperature and pressure heterogeneous reservoir includes the following steps：
(1) polyacrylamide is added while stirring into water by A liquid mass percents, persistently stirs 2~3h, until completely molten
Solution, obtains polyacrylamide solution；
(2) in the solution obtained to step (1) NaNO2, citric acid, organic is sequentially added according to the mass percent of A liquid
Chromium, phenolic resin, COSL-1 foaming agents, stirring acquired solution are the A liquid of transfer drive system；
(3) polyacrylamide is added while stirring into water by B liquid mass percents, persistently stirs 2~3h, until completely molten
Solution, obtains polyacrylamide solution；
(4) in the solution obtained to step (3) NaNO2, citric acid, organic is sequentially added according to the mass percent of B liquid
Chromium, phenolic resin, COSL-1 foaming agents, stirring acquired solution are the B liquid of transfer drive system；
(5) by the A liquid obtained by step (2) and the B liquid mixed injections stratum obtained by step (4) when constructing.
The invention has the advantages that：The streaming rate under the conditions of high temperature and pressure (65~85 DEG C of temperature, 8~12MPa of pressure)
It is good；Effective closure can be formed to marine high temperature and pressure heterogeneous reservoir High water cut stratum, sealing ratiod is high, improves sweep efficiency, into
And improve recovery ratio.
Description of the drawings
In order to more clearly explain the embodiment of the invention or the technical proposal in the existing technology, to embodiment or will show below
There is attached drawing needed in technology description to be briefly described, it should be apparent that, the accompanying drawings in the following description is only this
Some embodiments of invention without having to pay creative labor, may be used also for those of ordinary skill in the art
With obtain other attached drawings according to these attached drawings.
Fig. 1：Shut-off capacity physical simulation experiment device schematic diagram in the embodiment of the present invention 1；
Fig. 2：Separation rate is measured in the embodiment of the present invention 2 and embodiment 3 and improves recovery ratio ability physical simulation experiment dress
Set schematic diagram；
Fig. 3：The streaming rate curve that permeability grade is 2 in the embodiment of the present invention 2；
Fig. 4：The streaming rate curve that permeability grade is 4 in the embodiment of the present invention 2；
Fig. 5：The streaming rate curve that permeability grade is 7 in the embodiment of the present invention 2；
Fig. 6：The streaming rate curve that permeability grade is 10 in the embodiment of the present invention 2；
Fig. 7：Recovery ratio curve in the embodiment of the present invention 3.
Symbol description：
1, oil reservoir buffer, 2, precision pressure gauge, 3, high permeability sandpack column, 4, valve, 5, constant-flux pump, 6, intermediate hold
Device, 7, graduated cylinder, 8, back pressure control device, 9, back-pressure valve, 10, six-way valve, 11, low-permeability sandpack column.
Specific implementation mode
Following will be combined with the drawings in the embodiments of the present invention, and technical solution in the embodiment of the present invention carries out clear, complete
Site preparation describes, it is clear that described embodiments are only a part of the embodiments of the present invention, instead of all the embodiments.It is based on
Embodiment in the present invention, it is obtained by those of ordinary skill in the art without making creative efforts every other
Embodiment shall fall within the protection scope of the present invention.
Term " first ", " second " in description and claims of this specification and above-mentioned attached drawing, etc. be to be used for area
Not similar object, without being used to describe specific sequence or precedence.It should be appreciated that the data used in this way are appropriate
In the case of can be interchanged, so that the embodiment of the present invention described herein for example can be with that in addition to illustrating or describing herein
Sequence other than a little is implemented.In addition, term " comprising " and " having " and their any deformation, it is intended that covering is non-exclusive
Include to be not necessarily limited to clearly arrange for example, containing the process of series of steps or unit, method, system, product or equipment
Those of go out step or unit, but may include not listing clearly or solid for these processes, method, product or equipment
The other steps or unit having.
The invention will be further described with example below in conjunction with the accompanying drawings：
In following embodiment, water used is high salinity, high hardness water：Total salinity 2.5 × 105mg/L..Oil reservoir used
Pressure is 8MPa, 65 DEG C of reservoir temperature.
Embodiment 1
A kind of deep profile correction system being suitable for marine high temperature and pressure heterogeneous reservoir, including A liquid and B liquid, A liquid include matter
Measure a concentration of 20%NaNO2, mass concentration is 0.3% citric acid, mass concentration is 0.04% Organic Chromium, mass concentration is
0.06% phenolic resin, mass concentration are 0.3% seawater Instant HPAM, mass concentration is 0.5%COSL-1 foaming agents, surplus
Water 78.8%, B liquid include mass concentration be 15.5%NH4Cl, mass concentration is 0.3% citric acid, mass concentration 0.04%
Organic Chromium, mass concentration are 0.06% phenolic resin, mass concentration is 0.3% seawater Instant HPAM, mass concentration 0.5%
COSL-1 foaming agents, excess water 83.3%.Each component quality is：
A liquid：NaNO2 20g；Citric acid 0.3g；Organic Chromium 0.04g；Phenolic resin 0.06g；HPAM0.3g；
COSL-1 foaming agents 0.5g；Water 78.8g.
B liquid：NH4Cl 15.5g；Citric acid 03g；Organic Chromium 0.04g；Phenolic resin 0.06g；HPAM0.3g；
COSL-1 foaming agents 0.5g；Water 83.3g.
A kind of preparation method of deep profile correction system suitable for marine high temperature and pressure heterogeneous reservoir includes the following steps：
(1) polyacrylamide is added in the water for taking 78.8g while stirring, persistently stirs 2~3h and is gathered until being completely dissolved
Acrylamide solution；
(2) it is slowly added to NaNO2 20g, citric acid 0.3g, Organic Chromium while stirring in the solution obtained to step (1)
0.04g, phenolic resin 0.06g, HPAM0.3g, COSL-1 foaming agent 0.5g, stirring acquired solution are the A liquid of transfer drive system；
(3) polyacrylamide is added in the water for taking 83.3g while stirring, persistently stirs 2~3h and is gathered until being completely dissolved
Acrylamide solution；
(4) it is slowly added to NH4Cl 15.5g, citric acid 03g, Organic Chromium while stirring in the solution obtained to step (3)
0.04g, phenolic resin 0.06g, HPAM0.3g, COSL-1 foaming agent 0.5g, water 83.3g, stirring acquired solution is transfer drive body
The B liquid of system；
It is very poor that this transfer drive system different permeabilities under high-temperature and high-pressure conditions are investigated using the transfer drive system of above-mentioned preparation
Sealing ratiod, Experimental equipment is as shown in Figure 1, experimental procedure is as follows：
(1) fill out sand tube of long 100cm, internal diameter 2.5cm is filled into gravel, simulates oil reservoir high permeability zone, and by fill out sand tube
It vacuumizes, is saturated water flooding；
(2) it uses water flooding water drive to pressure stability after constant temperature 10h under 65 DEG C of reservoir temperature, back pressure 8MPa, measures back-up sand
The original permeability of pipe (is denoted as K1)；
(3) by the alternately inverted injection fill out sand tube of transfer drive system A liquid and B liquid of preparation, injection rate is fill out sand tube pore volume,
Then replaced with water flooding.
(4) subsequent waterflooding is carried out to pressure stability, and permeability (is denoted as K after measuring back-up sand pipe plug2), according to formula E=(K1-
K2)/K1, sealing ratiod is calculated, the results are shown in Table 1.
Table 1：The shut-off capacity of transfer drive system of the present invention
| Permeability (K before stifled1) | Permeability (K after stifled2) | Sealing ratiod (E/%) |
| 3.5 | 0.04 | 98.8 |
The result shows that transfer drive system provided by the invention has very strong shut-off capacity under high-temperature and high-pressure conditions, in height
High permeability zone or macropore can effectively be blocked in warm high pressure reservoir construction.
Embodiment 2
A kind of deep profile correction system being suitable for marine high temperature and pressure heterogeneous reservoir, including A liquid and B liquid, A liquid include matter
Measure a concentration of 20%NaNO2, mass concentration is 0.3% citric acid, mass concentration is 0.04% Organic Chromium, mass concentration is
0.06% phenolic resin, mass concentration are 0.3% seawater Instant HPAM, mass concentration is 0.5%COSL-1 foaming agents, surplus
Water 78.8%, B liquid include mass concentration be 15.5%NH4Cl, mass concentration is 0.3% citric acid, mass concentration 0.04%
Organic Chromium, mass concentration are 0.06% phenolic resin, mass concentration is 0.3% seawater Instant HPAM, mass concentration 0.5%
COSL-1 foaming agents, excess water 83.3%.Each component quality is：
A liquid：NaNO2 20g；Citric acid 0.3g；Organic Chromium 0.04g；Phenolic resin 0.06g；HPAM0.3g；
COSL-1 foaming agents 0.5g；Water 78.8g.
B liquid：NH4Cl 15.5g；Citric acid 03g；Organic Chromium 0.04g；Phenolic resin 0.06g；HPAM0.3g；
COSL-1 foaming agents 0.5g；Water 83.3g.
A kind of preparation method of deep profile correction system suitable for marine high temperature and pressure heterogeneous reservoir includes the following steps：
(1) polyacrylamide is added in the water for taking 78.8g while stirring, persistently stirs 2~3h and is gathered until being completely dissolved
Acrylamide solution；
(2) it is slowly added to NaNO2 20g, citric acid 0.3g, Organic Chromium while stirring in the solution obtained to step (1)
0.04g, phenolic resin 0.06g, HPAM0.3g, COSL-1 foaming agent 0.5g, stirring acquired solution are the A liquid of transfer drive system；
(3) polyacrylamide is added in the water for taking 83.3g while stirring, persistently stirs 2~3h and is gathered until being completely dissolved
Acrylamide solution；
(4) it is slowly added to NH4Cl 15.5g, citric acid 03g, Organic Chromium while stirring in the solution obtained to step (3)
0.04g, phenolic resin 0.06g, HPAM0.3g, COSL-1 foaming agent 0.5g, water 83.3g, stirring acquired solution is transfer drive body
The B liquid of system；
It is very poor that this transfer drive system different permeabilities under high-temperature and high-pressure conditions are investigated using the transfer drive system of above-mentioned preparation
Streaming rate, Experimental equipment is as shown in Fig. 2, experimental procedure is as follows：
(1) different-grain diameter quartz sand is selected to fill and present two-tube sandpack column according to practical Reservoir Permeability and non-homogeneous degree
(planning permeability grade 2,4,7 and 10), vacuumizes and is saturated water flooding, determine porosity；
(2) back pressure is set as reservoir pressure, and water drive sandpack column measures the permeability of fill out sand tube；
(3) experimental provision is connected, sandpack column is placed under reservoir temperature constant temperature for 24 hours；
(4) from fill out sand tube outlet end note people, just prepared deep profile correction system transfer drive system A liquid and B liquid alternately inject
After 0.3PV, fill out sand tube both ends valve is closed, boils in a covered pot over a slow fire well 10h under reservoir temperature；
(5) it opens fill out sand tube both ends valve and subsequent waterflooding is carried out from injection end with the speed of 1ml/min, record two pipe streams
Amount, and the streaming rate of high seepage pipe and hypotonic pipe is calculated, as a result see Fig. 3, Fig. 4, Fig. 5, Fig. 6.
The experimental results showed that：Permeability grade is respectively 2,4,7 and 10, and from outlet end, injection authigenous gas foaming fluid carries out
Water blockoff and when carrying out subsequent waterflooding, the streaming rate of high seepage pipe and hypotonic pipe is closer to.And the shunting equilibrium state can maintain compared with
For a long time, illustrate that the transfer drive system of research has preferable water plugging effect.
Embodiment 3
A kind of deep profile correction system being suitable for marine high temperature and pressure heterogeneous reservoir, including A liquid and B liquid, A liquid include matter
Measure a concentration of 20%NaNO2, mass concentration is 0.3% citric acid, mass concentration is 0.04% Organic Chromium, mass concentration is
0.06% phenolic resin, mass concentration are 0.3% seawater Instant HPAM, mass concentration is 0.5%COSL-1 foaming agents, surplus
Water 78.8%, B liquid include mass concentration be 15.5%NH4Cl, mass concentration is 0.3% citric acid, mass concentration 0.04%
Organic Chromium, mass concentration are 0.06% phenolic resin, mass concentration is 0.3% seawater Instant HPAM, mass concentration 0.5%
COSL-1 foaming agents, excess water 83.3%.Each component quality is：
A liquid：NaNO2 20g；Citric acid 0.3g；Organic Chromium 0.04g；Phenolic resin 0.06g；HPAM0.3g；
COSL-1 foaming agents 0.5g；Water 78.8g.
B liquid：NH4Cl 15.5g；Citric acid 03g；Organic Chromium 0.04g；Phenolic resin 0.06g；HPAM0.3g；
COSL-1 foaming agents 0.5g；Water 83.3g.
A kind of preparation method of deep profile correction system suitable for marine high temperature and pressure heterogeneous reservoir includes the following steps：
(1) polyacrylamide is added in the water for taking 78.8g while stirring, persistently stirs 2~3h and is gathered until being completely dissolved
Acrylamide solution；
(2) it is slowly added to NaNO2 20g, citric acid 0.3g, Organic Chromium while stirring in the solution obtained to step (1)
0.04g, phenolic resin 0.06g, HPAM0.3g, COSL-1 foaming agent 0.5g.Stirring acquired solution is the A liquid of transfer drive system；
(3) polyacrylamide is added in the water for taking 83.3g while stirring, persistently stirs 2~3h and is gathered until being completely dissolved
Acrylamide solution；
(4) it is slowly added to NH4Cl 15.5g while stirring in the solution obtained to step (3)；Citric acid 03g；Organic Chromium
0.04g；Phenolic resin 0.06g；HPAM0.3g；COSL-1 foaming agent 0.5g, water 83.3g.It is transfer drive body to stir acquired solution
The B liquid of system；
It is very poor that this transfer drive system different permeabilities under high-temperature and high-pressure conditions are investigated using the transfer drive system of above-mentioned preparation
Recovery ratio ability is improved, Experimental equipment is as shown in Fig. 2, experimental procedure is as follows：
(1) by the fill out sand tube of long 100cm, internal diameter 2.5cm, use respectively low mesh number (60~80 mesh) and high mesh number (100~
120 mesh) gravel fill out sand tube, oil reservoir high-permeability reservoir and low permeability formation are simulated respectively, and fill out sand tube is vacuumized, satisfy
And water flooding.
(2) use stratum water drive for fill out sand tube to steady pressure, measurement is high and low to ooze fill out sand tube permeability；
(3) it is saturated crude oil：Fill out sand tube is saturated crude oil, until outlet section production fluid be all crude oil (injection rate by
0.5min/L gradually rises to 1min/L).Record saturation crude oil volume, calculates oil saturation；
(4) water drive oozes fill out sand tube, record production fluid volume, output crude oil body with the high and low of 1min/L speed water drive parallel connection
Product and output water volume calculate water drive oil recovery factor until production fluid moisture content is 98%；
(5) inverse injection transfer drive system liquid transfer drive system A liquid and B liquid alternately inject under reservoir temperature, inject total volume
For 0.3PV (high permeability fill out sand tube pore volume), then 0.1PV water floodings is used to replace；
(6) subsequent waterflooding：High and low with the water drive parallel connection of 1min/L speed oozes fill out sand tube, and record production fluid volume, output are former
Oil volume and output water volume, until production fluid moisture content reaches 98% again, the increment of calculated for subsequent water drive oil recovery factor.
Experimental result is shown in Fig. 7, the results showed that after injection transfer drive system liquid, when edge water drive early period, high seepage pipe recovery ratio reaches
47.81%, hypotonic pipe recovery ratio is only 17.65%；Injection carries out subsequent waterflooding after being blocked from angry strengthening foam, and high seepage pipe is adopted
Yield rises to 66.7%, and hypotonic pipe recovery ratio rises to 54.64%.It is hypertonic to illustrate that the gel plugging agent of the present invention can be blocked effectively
Water predominant pathway is appeared, improves sweep efficiency, and then effectively improve recovery ratio.
Finally it should be noted that：The above embodiments are only used to illustrate the technical solution of the present invention., rather than its limitations；To the greatest extent
Present invention has been described in detail with reference to the aforementioned embodiments for pipe, it will be understood by those of ordinary skill in the art that：Its according to
So can with technical scheme described in the above embodiments is modified, either to which part or all technical features into
Row equivalent replacement；And these modifications or replacements, various embodiments of the present invention technology that it does not separate the essence of the corresponding technical solution
The range of scheme.
Claims (2)
1. a kind of deep profile correction system being suitable for marine high temperature and pressure heterogeneous reservoir, it is characterised in that：Including A liquid and B liquid,
A liquid include mass concentration be 20%NaNO2, mass concentration is 0.3% citric acid, mass concentration is 0.04% Organic Chromium, quality
A concentration of 0.06% phenolic resin, mass concentration are 0.3% seawater Instant HPAM, mass concentration is 0.5%COSL-1 blisterings
Agent, excess water 78.8%, B liquid include mass concentration be 15.5%NH4Cl, mass concentration is 0.3% citric acid, mass concentration is
0.04% Organic Chromium, mass concentration are 0.06% phenolic resin, mass concentration is 0.3% seawater Instant HPAM, mass concentration
For 0.5%COSL-1 foaming agents, excess water 83.3%.
2. a kind of preparation method for the deep profile correction system being suitable for marine high temperature and pressure heterogeneous reservoir, it is characterised in that including
Following steps：
(1) polyacrylamide is added while stirring into water by A liquid mass percents, persistently stirs 2~3h, until be completely dissolved,
Obtain polyacrylamide solution；
(2) NaNO2, citric acid, Organic Chromium, phenol are sequentially added according to the mass percent of A liquid in the solution obtained to step (1)
Urea formaldehyde, COSL-1 foaming agents, stirring acquired solution are the A liquid of transfer drive system；
(3) polyacrylamide is added while stirring into water by B liquid mass percents, persistently stirs 2~3h, until be completely dissolved,
Obtain polyacrylamide solution；
(4) NaNO2, citric acid, Organic Chromium, phenol are sequentially added according to the mass percent of B liquid in the solution obtained to step (3)
Urea formaldehyde, COSL-1 foaming agents, stirring acquired solution are the B liquid of transfer drive system；
(5) by the A liquid obtained by step (2) and the B liquid mixed injections stratum obtained by step (4) when constructing.
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| Application Number | Priority Date | Filing Date | Title |
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| CN201810412660.9A CN108659806A (en) | 2018-05-03 | 2018-05-03 | A kind of deep profile correction system being suitable for marine high temperature and pressure heterogeneous reservoir |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201810412660.9A CN108659806A (en) | 2018-05-03 | 2018-05-03 | A kind of deep profile correction system being suitable for marine high temperature and pressure heterogeneous reservoir |
Publications (1)
| Publication Number | Publication Date |
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| CN108659806A true CN108659806A (en) | 2018-10-16 |
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ID=63780553
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Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US11299663B2 (en) | 2020-06-04 | 2022-04-12 | Saudi Arabian Oil Company | Method for modifying well injection profile and enhanced oil recovery |
-
2018
- 2018-05-03 CN CN201810412660.9A patent/CN108659806A/en active Pending
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US11299663B2 (en) | 2020-06-04 | 2022-04-12 | Saudi Arabian Oil Company | Method for modifying well injection profile and enhanced oil recovery |
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Application publication date: 20181016 |