CN113122210B - Deep profile control water shutoff agent capable of delaying gelling and preparation and application thereof - Google Patents
Deep profile control water shutoff agent capable of delaying gelling and preparation and application thereof Download PDFInfo
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- CN113122210B CN113122210B CN202010042076.6A CN202010042076A CN113122210B CN 113122210 B CN113122210 B CN 113122210B CN 202010042076 A CN202010042076 A CN 202010042076A CN 113122210 B CN113122210 B CN 113122210B
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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
- C09K8/5045—Compositions based on water or polar solvents containing inorganic compounds
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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
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices, or the like
- E21B33/138—Plastering the borehole wall; Injecting into the formation
Abstract
The invention relates to a depth profile control water shutoff agent for delaying gelling and application thereof. The profile control water shutoff agent comprises an oil-in-water emulsion and a water glass solution, wherein the oil-in-water emulsion comprises an initiator A, a surfactant and water, the initiator A is selected from organic weak acids insoluble in water, and the initiator A and the organic weak acids are mixed to form the profile control water shutoff agent. The profile control water shutoff agent can play roles of delayed gelling and profile control water shutoff at the deep part of an oil reservoir, can effectively enlarge swept volume of subsequent water flooding or chemical flooding, and has the characteristics of high plugging strength and long validity period.
Description
Technical Field
The invention relates to a deep profile control water shutoff agent for delaying gelling and preparation and application thereof.
Background
Due to the heterogeneity of the stratum and the high permeable layer and the water flow dominant channel generated after the subsequent water flooding or chemical flooding, water channeling or fingering phenomena are caused, so that the water flooding or chemical flooding forms ineffective fluid circulation, the swept volume cannot be enlarged, the development effect is reduced, and the oil reservoir development cost is increased. Therefore, the profile control water shutoff technology is an important measure for water control and stable production of oil fields, but the requirements on the profile control water shutoff agent are higher and higher along with the gradual increase of the water content of an oil reservoir, and particularly the profile control water shutoff can reach the deep part of the oil reservoir, so that a seepage channel is plugged in the deep part of the oil reservoir, the flow direction of a liquid flow is changed, and the swept volume of fluid displacement between layers and in the layers is increased, thereby improving the crude oil recovery rate. The present deep profile control and water shutoff technology mainly is a delayed crosslinking type profile control and water shutoff agent, such as CN1278564A, and is characterized in that organic monomers such as polyacrylamide are used as main agents, corresponding crosslinking agents are selected, and then a buffering agent, an oxygen scavenger and the like are added into a system to delay the release speed of the crosslinking agents, so that the crosslinking time is prolonged, and the effect of deep profile control and water shutoff is achieved. The system has complex composition and a plurality of influencing factors, and the expected effect is difficult to achieve under complex formation conditions. Meanwhile, the organic monomer has poor temperature resistance and salt tolerance, is easy to lose effectiveness in a short period under the action of formation temperature or formation water, and has short period of validity and weak strength.
Disclosure of Invention
The invention aims to provide a deep profile control water plugging agent for delayed gelling aiming at the technical problems.
The invention also provides a preparation method of the deep profile control water shutoff agent for delaying gelling.
The invention also provides a method for deep profile control and water shutoff.
In order to achieve the purpose, the invention provides the following technical scheme:
the deep profile control water shutoff agent comprises an oil-in-water emulsion and a water glass solution, wherein the oil-in-water emulsion comprises an initiator A, a surfactant and water, and the initiator A is selected from water-insoluble organic weak acids.
In the oil-in-water emulsion of the invention, the initiator A is preferably a water-insoluble weak organic acid which is liquid at normal temperature, can be C6-C10 monobasic acid, can be fatty acid, hydroxy acid, aromatic acid and the like, such as caproic acid, heptanoic acid, caprylic acid, benzoic acid and the like, and preferably caproic acid and heptanoic acid.
The surfactant may be an anionic, cationic or non-ionic surfactant, preferably an anionic surfactant such as dodecylbenzene sulphonate, heavy alkylbenzene sulphonate and the like.
The water-insoluble organic weak acid is contained in an amount of 2 to 25%, preferably 5 to 20%, the surfactant is contained in an amount of 2 to 40%, preferably 5 to 20%, and the water is contained in an amount of 40 to 96%, preferably 60 to 85%, based on 100% by weight of the oil-in-water emulsion.
Wherein the mass concentration of the water glass in the water glass solution is 10-50%, preferably 20-40%. The water glass modulus may be from 2.8 to 3.5, preferably from 3.1 to 3.4.
The mass mixing ratio of the oil-in-water emulsion to the water glass solution is 1:0.5 to 1:5, preferably 1:1 to 1:3.
preferably, the water glass solution also contains an initiator B, wherein the initiator B is selected from water-soluble organic weak acids, preferably C2-C6 polybasic acids, such as oxalic acid, succinic acid, citric acid, tartaric acid, malic acid and the like, and the mass concentration of the initiator B in the water glass solution is 0.5-3%, preferably 1-2%.
The invention relates to a preparation method of a deep profile control water shutoff agent for delayed gelling, which comprises the following steps:
1) Preparing an emulsion: stirring, mixing and emulsifying the organic weak acid which is insoluble in water, the surfactant and water to form a stable oil-in-water emulsion;
2) Preparing a water glass solution: adding water glass into water, stirring and mixing to form water glass solution.
3) Before use, the water glass solution is added into the oil-in-water emulsion to form the profile control water shutoff agent.
The water-insoluble organic weak acid is 2-25%, preferably 5-20%, the surfactant is 2-40%, preferably 5-20%, and the water is 40-96%, preferably 60-85%, based on 100% of the oil-in-water emulsion.
Wherein the mass concentration of the water glass solution is 10-50%, preferably 20-40%. The water glass modulus may be from 2.8 to 3.5, preferably from 3.1 to 3.4.
Preferably, the water glass solution also contains an initiator B, wherein the initiator B is selected from water-soluble organic weak acids, such as oxalic acid, succinic acid, citric acid, tartaric acid, malic acid and the like, and the mass concentration of the initiator B in the water glass solution is 0.5-3%, preferably 1-2%.
The invention also provides a deep profile control water shutoff method for delayed gelling, which comprises the steps of respectively preparing the oil-in-water emulsion and the water glass solution, and uniformly injecting the mixture into a stratum after mixing the oil-in-water emulsion and the water glass solution in proportion. When mixing, the water glass solution is preferably added to the oil-in-water emulsion.
The mass mixing ratio of the oil-in-water emulsion to the water glass solution is 1:0.5 to 1:5, preferably 1:1 to 1:3.
the invention is characterized in that:
1) The water glass inorganic polymerization monomer is adopted, the reaction product is inorganic and is not influenced by the formation temperature and the formation water mineralization, and the plugging strength, the flushing resistance and the plugging validity period of the water glass inorganic polymerization monomer are superior to those of the organic monomer.
2) The emulsion is adopted to coat the initiator, the delay of the reaction is achieved by utilizing the stability of the emulsion and the concentration control required by the initiation reaction, the delayed gelling is realized, the profile control water plugging agent can achieve the effect of profile control water plugging after reaching the deep part of the stratum, the plugging between layers and in the stratum is realized, the seepage dominant channel is plugged, and the swept volume is effectively enlarged.
3) Under the preferable condition, the initiator B is added into the water glass solution, the reaction time is easier to adjust, and the reaction product has better temperature resistance and salt tolerance, higher strength and longer effective period.
Detailed Description
Hereinafter, specific embodiments of the present invention will be described in detail. It should be understood that the detailed description and specific examples, while indicating the present invention, are given by way of illustration and explanation only, not limitation.
The gelling time evaluation is carried out according to the following method:
and (3) placing the profile control water shutoff agent in a test tube, observing the change condition of the profile control water shutoff agent according to the reaction time, and observing the gelling condition of the profile control water shutoff agent by inclining the test tube, wherein the gelling time is the final gelling time when the test tube is completely inverted and the system does not flow any more.
The evaluation of the volume retention was carried out according to the following method:
and (3) placing the profile control water shutoff agent in a test tube, finally gelling, placing the test tube in an oven at the temperature of the stratum, observing the residual volume of the colloid, and calculating the volume retention rate of the gel by dividing the residual volume by the initial volume.
Example 1
Preparing an emulsion: 20 percent of initiator A caproic acid, 15 percent of surfactant dodecyl benzene sulfonate and 65 percent of water by weight percentage are stirred, mixed and emulsified to form stable oil-in-water emulsion.
Preparing a water glass solution: stirring and mixing 40 weight percent of water glass, 1 weight percent of initiator B oxalic acid and 59 weight percent of water to form a solution.
The water glass solution was then mixed as 3: the proportion of 1 is slowly added into the emulsion to form the profile control water shutoff agent, the gelling time is 24h, and the volume retention rate is 98%.
Example 2
Preparing an emulsion: 20 percent of initiator A caproic acid, 15 percent of surfactant dodecyl benzene sulfonate and 65 percent of water are stirred, mixed and emulsified to form stable oil-in-water emulsion.
Preparing a water glass solution: water with the weight percentage of 40 percent and water glass with the weight percentage of 60 percent are stirred and mixed to form a solution.
The water glass solution was then mixed as 3:1 to form the profile control water shutoff agent, wherein the gelling time is 56 hours, and the volume retention rate is 75%.
Example 3
Preparing an emulsion: stirring, mixing and emulsifying 20 wt% of initiator A octanoic acid, 15 wt% of surfactant heavy alkylbenzene sulfonate and 65 wt% of water to form stable oil-in-water emulsion.
Preparing a water glass solution: stirring and mixing 40 weight percent of water glass, 1 weight percent of initiator B oxalic acid and 59 weight percent of water to form a solution.
The water glass solution was then mixed as 3: the proportion of 1 is slowly added into the emulsion to form the profile control water shutoff agent, the gelling time is 28h, and the volume retention rate is 90%.
Example 4
Preparing an emulsion: 20 percent of initiator A caproic acid, 15 percent of surfactant dodecyl benzene sulfonate and 65 percent of water by weight percentage are stirred, mixed and emulsified to form stable oil-in-water emulsion.
Preparing a water glass solution: stirring and mixing 40 wt% of water glass, 1 wt% of initiator B citric acid and 59 wt% of water to form a solution.
The water glass solution was then mixed as 3:1 to form the profile control water plugging agent, wherein the gelling time is 20h, and the volume retention rate is 92%.
Example 5
Preparing an emulsion: 5 percent of initiator A caproic acid, 5 percent of surfactant dodecyl benzene sulfonate and 90 percent of water are stirred, mixed and emulsified to form stable oil-in-water emulsion.
Preparing a water glass solution: 10 percent by weight of water glass, 0.5 percent by weight of initiator B oxalic acid and 89.5 percent by weight of water are stirred and mixed to form a solution.
Then the water glass solution is mixed according to the proportion of 1:1 is slowly added into the emulsion to form the profile control water shutoff agent, the gelling time is 36h, and the volume retention rate is 60%.
Example 6
Preparing an emulsion: stirring, mixing and emulsifying an initiator A heptanoic acid with the weight percentage of 10%, a surfactant dodecyl benzene sulfonate with the weight percentage of 8% and water with the weight percentage of 82% to form a stable oil-in-water emulsion.
Preparing a water glass solution: 20 percent of water glass, 0.5 percent of initiator B succinic acid and 79.5 percent of water are stirred and mixed to form solution.
The water glass solution was then mixed as follows 2:1 to form the profile control water shutoff agent, the gelling time is 26h, and the volume retention rate is 90%.
Example 7
Preparing an emulsion: stirring, mixing and emulsifying an initiator A heptanoic acid with the weight percentage of 10%, a surfactant dodecyl benzene sulfonate with the weight percentage of 8% and water with the weight percentage of 82% to form a stable oil-in-water emulsion.
Preparing a water glass solution: stirring and mixing 20 wt% of water glass and 80 wt% of water to form a solution.
The water glass solution was then mixed as follows 2:1 to form the profile control water shutoff agent, the gelling time is 60 hours, and the volume retention rate is 55%.
Comparative example 1
Stirring and mixing 20 wt% of initiator A caproic acid, 20 wt% of water glass and 60 wt% of water, standing, and layering to obtain a solution, wherein a gel cannot be formed.
Comparative example 2
20 percent of water glass, 0.5 percent of initiator B oxalic acid and 79.5 percent of water are stirred and mixed to form a solution. At rest, no gel was formed.
Comparative example 3
Stirring and mixing 20 weight percent of water glass, 0.5 weight percent of 1mol/L hydrochloric acid solution and 79.5 weight percent of water, and immediately gelling.
Example 8
Indoor tubular model performance evaluation:
filling the sand filling pipe with the specification of phi 25mm multiplied by 30mm with quartz sand, and weighing the dry weight; then, vacuumizing by using a vacuum pump, weighing the wet weight of the core after saturating formation water for 120min, and calculating the porosity of the core; the saturated sand-filled rock core model is connected into a displacement device, the water phase permeability before plugging is measured, then the saturated sand-filled rock core model is placed into a constant temperature box, and the temperature of the stratum is kept constant for 120min; injecting the profile control water plugging agent 1PV of the embodiment 1-6 at the speed of 1ml/min, and keeping the temperature and standing for reaction for 48 hours; the subsequent water drive is carried out, and the injection speed is 1ml/min; and measuring the water phase permeability of the plugging liquid after plugging.
The results of the plugging performance evaluation of examples 1-7 in an indoor tubular model are given in table 1 below.
TABLE 1
| Examples | Porosity (%) | Water phase permeability (um) before plugging 2 ) | Water phase permeability (um) after plugging 2 ) | Clogging Rate (%) |
| 1 | 45.4 | 20.02 | 0.20 | 99 |
| 2 | 43.2 | 19.34 | 8.71 | 55 |
| 3 | 48.1 | 19.64 | 0.39 | 98 |
| 4 | 39.9 | 12.85 | 0.39 | 97 |
| 5 | 40.6 | 17.89 | 10.73 | 40 |
| 6 | 40.5 | 19.33 | 0.58 | 95 |
| 7 | 41.3 | 19.26 | 11.56 | 40 |
It can be seen from examples 1 to 7 that, although a gel can be formed in an emulsified state if a water-insoluble organic acid is used alone, the gel strength is relatively small, and the volume retention rate and the blocking rate are low. If water-soluble organic acid with proper proportion is added, the volume retention rate and the plugging rate can be obviously improved, and the technical goals of delayed gelling and high-strength plugging are achieved.
As can be seen from the comparative example, the caproic acid which is insoluble in water is used alone and is not prepared into emulsion, the caproic acid and the water glass are difficult to mix together, the caproic acid and the water glass are layered once the two are stopped stirring, the contact probability of the caproic acid and the water glass is reduced, and the caproic acid can not activate the water glass to form a gel system; weak acids such as oxalic acid with low concentration are independently used, and water glass cannot be activated to form a gel system due to the low concentration; the activation of the water glass can be instantly initiated by singly using the strong inorganic acid, and the gelling time is short.
Claims (9)
1. A deep profile control water shutoff agent capable of forming gel in a delayed manner comprises an oil-in-water emulsion and a water glass solution, wherein the oil-in-water emulsion comprises an initiator A, a surfactant and water, the initiator A is selected from C6-C10 water-insoluble unitary organic weak acids, and the content of the water-insoluble organic weak acids is 10-20%, the content of the surfactant is 2-40% and the water content is 40-85% based on 100% of the mass of the oil-in-water emulsion; the mass concentration of the water glass solution is 20-40%, the water glass solution contains an initiator B, the initiator B is selected from C2-C6 polybasic acid, and the mass concentration of the initiator B in the water glass solution is 0.5-3%; the mass mixing ratio of the oil-in-water emulsion to the water glass solution is 1:1 to 1:3.
2. the water shutoff agent according to claim 1, wherein in the oil-in-water emulsion, the initiator A is selected from one or more of caproic acid, heptanoic acid, caprylic acid and benzoic acid.
3. The water shutoff agent of claim 1, said surfactant being selected from the group consisting of dodecylbenzene sulfonate, heavy alkylbenzene sulfonate.
4. The water shutoff agent according to claim 1, wherein the surfactant content is 5-20% and the water content is 60-85% based on 100% by mass of the oil-in-water emulsion.
5. The water shutoff agent according to claim 1, wherein in the water glass solution, the water glass modulus is 2.8 to 3.5.
6. The water shutoff agent according to claim 1, wherein the initiator B is at least one selected from oxalic acid, succinic acid, citric acid, tartaric acid and malic acid.
7. The water shutoff agent according to claim 1, wherein the mass concentration of the initiator B in the water glass solution is 1-2%.
8. A method for preparing the deep profile control water shutoff agent for delayed gel formation according to any one of claims 1 to 7, which comprises the following steps:
1) Stirring, mixing and emulsifying the organic weak acid which is insoluble in water, the surfactant and water to form a stable oil-in-water emulsion;
2) Adding water glass into water, stirring and mixing to form a water glass solution, and adding an initiator B into the water glass solution, wherein the initiator B is selected from C2-C6 polybasic acid;
3) Before use, the water glass solution is added into the oil-in-water emulsion to form the profile control water shutoff agent.
9. A deep profile control water shutoff method for delayed gelling, which comprises the steps of preparing an oil-in-water emulsion and a water glass solution according to the water shutoff agent of any one of claims 1 to 7, mixing the oil-in-water emulsion and the water glass solution in proportion, and injecting the mixture into a stratum after the mixture is uniform.
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Citations (3)
| Publication number | Priority date | Publication date | Assignee | Title |
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| CN104387530A (en) * | 2014-11-21 | 2015-03-04 | 天津科技大学 | Preparation method of high-content calcium bentonite water shutoff agent |
| CN104762068A (en) * | 2015-03-25 | 2015-07-08 | 新疆贝肯能源工程股份有限公司 | Emulsion type fluid loss agent for drilling liquid and preparation method of emulsion type fluid loss agent |
| CN108300439A (en) * | 2017-12-13 | 2018-07-20 | 北京捷贝通石油技术有限公司 | A kind of temporary stall of well fracturing is to water-soluble diverting agent and preparation method thereof |
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| Publication number | Priority date | Publication date | Assignee | Title |
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| WO2016081458A1 (en) * | 2014-11-19 | 2016-05-26 | Saudi Arabian Oil Company | Compositions of and methods for using hydraulic fracturing fluid for petroleum production |
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Patent Citations (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN104387530A (en) * | 2014-11-21 | 2015-03-04 | 天津科技大学 | Preparation method of high-content calcium bentonite water shutoff agent |
| CN104762068A (en) * | 2015-03-25 | 2015-07-08 | 新疆贝肯能源工程股份有限公司 | Emulsion type fluid loss agent for drilling liquid and preparation method of emulsion type fluid loss agent |
| CN108300439A (en) * | 2017-12-13 | 2018-07-20 | 北京捷贝通石油技术有限公司 | A kind of temporary stall of well fracturing is to water-soluble diverting agent and preparation method thereof |
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