CN113025292A - High-strength gel temporary plugging agent for plugging horizontal shaft before workover of thermal recovery horizontal well and preparation method thereof - Google Patents
High-strength gel temporary plugging agent for plugging horizontal shaft before workover of thermal recovery horizontal well and preparation method thereof Download PDFInfo
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- CN113025292A CN113025292A CN202110305826.9A CN202110305826A CN113025292A CN 113025292 A CN113025292 A CN 113025292A CN 202110305826 A CN202110305826 A CN 202110305826A CN 113025292 A CN113025292 A CN 113025292A
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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
- C09K8/512—Compositions based on water or polar solvents containing organic compounds macromolecular compounds containing cross-linking agents
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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
- C09K8/516—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls characterised by their form or by the form of their components, e.g. encapsulated material
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Abstract
The invention relates to a high-strength gel temporary plugging agent for plugging a horizontal shaft before workover of a thermal recovery horizontal well and a preparation method thereof. The temporary plugging agent is prepared from hot sewage at 80 ℃, primary crosslinking can occur to the gel forming liquid at the temperature lower than 100 ℃, a weak crosslinking gel forming liquid with certain viscosity is formed, and the temporary plugging agent has pumping performance and simultaneously avoids the gel forming liquid from being filtered to the stratum and being diluted when meeting well water. The gel rubber plug can be quickly crosslinked to form a high-strength gel rubber plug sealed shaft at the temperature higher than 100 ℃, so that the overflow of stratum hot fluid is prevented, the gel rubber plug is stable for 3-5 days at the temperature of 200 ℃, and the safety of the workover operation of the thermal recovery horizontal well is ensured; after 7 days, the strength is gradually broken, the production can be recovered, and the oil extraction efficiency is not influenced.
Description
Technical Field
The invention relates to the field of oilfield chemistry, in particular to a high-strength gel temporary plugging agent which is injected into a horizontal section of a shaft before the well workover of a thermal recovery horizontal well, can plug overflow of stratum thermal fluid and creates conditions for subsequent non-drainage operation.
Background
The thick oil with the viscosity of more than 3000 mPa.s (the formation temperature or 50 ℃) in China is mainly developed by steam injection, including steam flooding, steam huff and puff and the like. In recent years, the shallow extra-thick oil in the wind city operation area of the Xinjiang oil field has better effect by adopting SAGD. A large amount of superheated steam is injected into a stratum, the viscosity of thick oil is reduced, but when a pump needs to be detected due to problems of sand production, scaling, eccentric wear and the like, measures need to be taken to prevent stratum hot fluid from gushing out of the well after a high-pressure well head is disassembled during operation. These measures include high density kill hydraulic wells, well opening drainage, injection of plugging agents, etc. High density kill fluid wells are relatively mature for treating formations with wellbore temperatures of 120 c, but when wellbore temperatures are greater than 150 c, kill fluid density decreases and kill fails due to steam invasion of the kill fluid (referred to as steam invasion). For a well to be operated, which cannot be well-killing at high temperature, long-time liquid drainage is needed to reduce the formation temperature and the formation pressure. The liquid drainage prolongs the operation period, reduces the formation capability and reduces the production efficiency of the oil field. A high-temperature temporary plugging agent is injected into a shaft, so that the stratum can be plugged temporarily in 3-5 days, smooth completion of operation can be guaranteed, and the production efficiency is improved.
Unlike temporary plugging agents, which prevent the loss of flushing fluid to the formation, the temporary plugging agents used to temporarily plug formation fluids create conditions for subsequent operations are generally not granular temporary plugging agents, but are primarily gel plugging agents, which have high elasticity. For the oil-water well of the thermal recovery oil field with a deeper target well or a deeper target well, the temporary plugging agent for auxiliary operation is required to have stronger temperature resistance in a certain time because of high temperature of formation fluid. The temporary plugging agent used for plugging wellbore fluid before operation is mainly divided into two types, one type is a system formed by high-content monomers (the mass fraction of the monomers is more than 4%), and the monomers can form high-strength cross-linked polymers in a wellbore and a near wellbore zone under the action of temperature or an initiator. Another class of polymers is gels formed by the action of a crosslinking agent. The former has high strength, but the polymerization time is difficult to control when the temperature is higher than 90 ℃; the crosslinking time of the latter is easy to control, but the formed jelly strength is lower than that of the first system.
There are also many patent documents reported about blocking agents, such as: CN103160261A discloses a preparation method and a use method of an underground intelligent rubber plug, and CN104628957A relates to a high-strength gel for snubbing serving and a preparation method thereof. CN102191023A discloses a temporary plugging agent for medium-high temperature (80-100 ℃) oil-gas reservoirs. CN104449618A discloses a temperature-resistant salt-tolerant high-temperature self-crosslinking in-situ polymerized water shutoff gel, and CN109280542A discloses a high-temperature-resistant gel plugging agent, and a preparation method and application thereof. Patent CN110669484A discloses a degradable temporary plugging agent for well repair and a preparation method thereof.
However, the above prior art is directed to the polymerization of high amounts of monomers in subterranean formations to form high strength plugging agents. The temporary plugging agent has the defects that the temporary plugging agent is polymerized too fast at high temperature, and the polymerization time is difficult to control even if a retarder is added when the formation temperature is higher than 150 ℃, so that the formation glue solution can not be ensured to be smoothly injected into a target layer, and the temporary plugging agent is suitable for being used at medium and low temperature.
Another class of temporary blocking agents is built up from polymers and crosslinking agents, for example: CN104694093A relates to a high-temperature fluid slug glue solution capable of sealing oil gas and the application thereof; CN106566488A discloses polymer gel for well killing, a preparation method and application thereof. CN101135237A discloses a preparation method and a construction method of a downhole gel valve. CN107011879A discloses a high-temperature-resistant high-strength composite cross-linked gel packing agent and a preparation method thereof. CN106905940A discloses a medium-high density elastic liquid rubber plug, and CN105131921A discloses a preparation method of temperature-resistant salt-resistant jelly. But the temperature resistance of the jelly formed by crosslinking the polymer is not more than 180 ℃, and the requirement of plugging 200 ℃ steam in a shaft is difficult to meet.
In addition, CN103232839A reports a gel plugging agent prepared by using tannin extract and lignin as raw materials. The plugging agent has strong temperature resistance, and once the plugging agent is gelled, the gel is difficult to be broken by heat and a gel breaker, so the plugging agent is not suitable for being used as a temporary plugging agent. Moreover, because the molecular weight of tannin extract and alkali lignin is small, the formed jelly is brittle and lacks elasticity, the surface of the sieve tube is basically not provided with adhesive capacity, and an effective sealing layer is difficult to form in a well bore.
Disclosure of Invention
Aiming at the defects of the prior art, particularly the temperature resistance of the jelly in the prior art is insufficient, and the requirement of plugging steam at 200 ℃ is difficult to meet. The invention forms a high-strength gel plug which can resist the temperature of 200 ℃ by injecting a multi-component gel-forming liquid into a well section below a horizontal well pump, thereby preventing the steam of a shaft from overflowing and realizing the rapid well repair. The gel forming liquid contains a temperature-resistant polymer, partially hydrolyzed polyacrylamide, a phenolic cross-linking agent, a chromium cross-linking agent, an oxygen scavenger, organic acid and sodium soil.
The technical scheme of the invention is as follows:
a high-strength gel temporary plugging agent for plugging a horizontal wellbore before workover of a thermal recovery horizontal well comprises the following components in percentage by mass:
0.5 to 2.5 percent of temperature-resistant polymer, 0.1 to 0.5 percent of partially hydrolyzed polyacrylamide, 0.2 to 0.8 percent of phenolic crosslinking agent, 0.1 to 0.5 percent of chromium crosslinking agent, 0.1 to 0.5 percent of deoxidant, 0.05 to 0.3 percent of organic acid, 2 to 6 percent of sodium soil and the balance of water.
According to the invention, preferably, the high-strength gel temporary plugging agent for plugging the horizontal wellbore before the well workover of the thermal recovery horizontal well comprises the following components in percentage by mass:
1-2% of temperature-resistant polymer, 0.2-0.4% of partially hydrolyzed polyacrylamide, 0.3-0.5% of phenolic crosslinking agent, 0.2-0.4% of chromium crosslinking agent, 0.2-0.4% of oxygen scavenger, 0.08-0.15% of organic acid, 3-5% of sodium soil and the balance of water.
According to the invention, preferably, the high-strength gel temporary plugging agent for plugging the horizontal wellbore before the well workover of the thermal recovery horizontal well comprises the following components in percentage by mass:
1.8% of temperature-resistant polymer, 0.3% of partially hydrolyzed polyacrylamide, 0.4% of phenolic crosslinking agent, 0.3% of chromium crosslinking agent, 0.3% of oxygen scavenger, 0.1% of organic acid, 4% of sodium soil and the balance of water.
According to the invention, the temperature-resistant polymer is preferably selected from acrylamide/2-acrylamide-2-methylpropanesulfonic acid/vinyl pyrrolidone (AM-AMPS-NVP) polymer;
preferably, the relative molecular mass of the temperature-resistant polymer is 300-800 ten thousand, more preferably 400 ten thousand;
preferably, when the temperature-resistant polymer is prepared, the molar ratio of the acrylamide to the 2-acrylamide-2-methylpropanesulfonic acid to the vinyl pyrrolidone is 1: (1-2): (1-5);
preferably, the molar content of vinylpyrrolidone chain members in the temperature-resistant polymer is from 30% to 70%, more preferably 60%.
According to the present invention, preferably, the molecular weight of the partially hydrolyzed polyacrylamide is 800 to 1800 ten thousand, more preferably 1200 to 1500 ten thousand; the degree of hydrolysis is 20% to 30%, more preferably 25% to 30%.
According to the present invention, preferably, the phenolic crosslinking agent is composed of a phenolic substance and an aldehyde substance;
preferably, the phenolic substance is one or two of phenol, hydroquinone and resorcinol, and hydroquinone is more preferred; the aldehyde crosslinking agent is one or two of m-phthalaldehyde, p-phthalaldehyde and urotropine, and is more preferably m-phthalaldehyde;
preferably, the molar ratio of the phenolic substance to the aldehyde substance in the phenolic aldehyde crosslinking agent is 1: (1-1.2), more preferably 1: 1.
According to the present invention, preferably, the chromium crosslinking agent is selected from chromium acetate, chromium lactate or chromium citrate, more preferably chromium acetate.
According to the present invention, preferably, the oxygen scavenger is sodium sulfite, sodium bisulfite or thiourea, more preferably thiourea.
According to the present invention, preferably, the organic acid is acetic acid, butyric acid or valeric acid, more preferably acetic acid.
According to the invention, the effect of the components is as follows:
the acrylamide/2-acrylamide-2-methylpropanesulfonic acid/vinyl pyrrolidone polymer used in the invention is a temperature-resistant polymer, and amide groups in the polymer can be crosslinked with a phenolic crosslinking agent to form jelly. The pyrrolidone ring in the polymer does not participate in the cross-linking reaction, but has three important roles in the formed jelly: (1) the pyrrolidone ring can form a coordination bond with metal, so that the adhesion of the jelly on the surface of the metal is increased; (2) the pyrrolidone ring has stronger adsorption capacity on the surface of the sodium soil, and the strength of the jelly can be greatly increased; (3) the pyrrolidone ring is a stable hydrophilic group, so that the jelly has better water retention capacity at high temperature.
In the invention, hydroquinone and m-phthalaldehyde are used for crosslinking acrylamide/2-acrylamide-2-methylpropanesulfonic acid/vinyl pyrrolidone, mainly for controlling the crosslinking reaction speed. In order to improve the strength of the frozen rubber plug, the invention uses the polymer and the cross-linking agent with higher mass fraction, and the higher the content of the components in the gel forming liquid is, the faster the cross-linking reaction speed is; in addition, in order to reduce the viscosity of the glue-forming liquid, the invention can use hot sewage at 80 ℃ to prepare the glue-forming liquid, and the temperature is also beneficial to the crosslinking of phenol, aldehyde and amide groups. Comprehensively considering the factors, in order to control the reaction speed, the invention selects terephthalaldehyde with strong steric hindrance effect to replace formaldehyde, paraformaldehyde, urotropine and the like. The cross-linking system composed of hydroquinone and terephthalaldehyde does not react with amide groups in polymer molecules at 80 ℃, and can be quickly cross-linked with the amide groups to form jelly glue after the temperature is higher than 100 ℃. Thus, the formation of high-viscosity jelly during the transportation and injection of the high-content jelly-forming liquid is avoided, and construction accidents are avoided.
Another polymer useful in the present invention is partially Hydrolyzed Polyacrylamide (HPAM) having a degree of hydrolysis of 20% to 30%. The partially hydrolyzed polyacrylamide and the chromium acetate with low mass fraction are added into the gelling liquid, so that the gelling liquid can quickly form a net structure with certain viscosity. The design has two functions, one is that the gel forming liquid is prevented from being diluted by water in a shaft in the process of injecting the gel forming liquid into the stratum, and the strength of the frozen rubber plug is reduced; and after the gel liquid forms primary cross-linking, the gel liquid can have certain pressure bearing capacity in the slotted screen pipe, so that the fluid loss to the stratum under the pressure of a liquid column is avoided. The polymer can be rapidly crosslinked with chromium acetate.
The purpose of adding the organic acid in the invention is to keep the colloid-forming liquid weakly acidic, prevent hydroquinone from being oxidized in the process of preparing and transporting the colloid-forming liquid and reduce the colloid-forming performance of the hydroquinone.
The oxygen scavenger can reduce the oxygen content of the gel-forming liquid and prevent the oxidative degradation of the polymer.
The sodium soil, also called bentonite, in the invention is dispersed in water to form a lamellar structure with the thickness of nanometer level. The lamellar structure has stronger hydration capability, and can form hydrogen bonds with amide groups and pyrrolidone rings of the temperature-resistant polymer, so that the grid density of a crosslinking system is increased. The above effects increase the stability of the jelly and improve the strength of the jelly.
The invention also provides a preparation method of the high-strength gel temporary plugging agent for plugging the horizontal shaft before workover of the thermal recovery horizontal well, which comprises the following steps:
adding sodium soil into water under the condition of stirring, adding a phenolic cross-linking agent, an oxygen scavenger and an organic acid after uniformly stirring, slowly adding a temperature-resistant polymer and partially hydrolyzed polyacrylamide under the condition of stirring after uniformly stirring, finally adding a chromium cross-linking agent, and uniformly stirring to obtain the catalyst.
The invention has the following beneficial effects:
1. the gel plugging agent can resist temperature of more than 200 ℃, and can meet the requirement of plugging steam at 200 ℃.
2. The jelly plugging agent has higher strength, and the elastic modulus of the jelly after heat treatment for 4 days at 200 ℃ still reaches more than 481 Pa.
3. The gel plugging agent of the invention forms gel at a temperature above 80 ℃. Thus, the transportation and the storage are convenient, and the formation of high-viscosity gel in the transportation and injection processes of the high-content gel-forming liquid is avoided, so that construction accidents are avoided.
4. The gel forming liquid prepared by the invention is weak gel due to the crosslinking action of HPAM and chromium acetate, and can not be dispersed when meeting water, so that the gel forming liquid can not be diluted by the water in the shaft after being injected into the shaft.
5. The gel plugging agent can be prepared from hot sewage at the temperature of 80 ℃, so that the water cost is saved. At the temperature lower than 100 ℃, the gelling liquid can generate primary crosslinking to form weak crosslinking gelling liquid with certain viscosity, and the gelling liquid has pumping performance and can be prevented from being filtered out of the stratum and diluted when meeting well water. The gel rubber plug can be quickly crosslinked to form a high-strength gel rubber plug sealed shaft at the temperature higher than 100 ℃, so that the overflow of stratum hot fluid is prevented, the gel rubber plug is stable for 3-5 days at the temperature of 200 ℃, and the safety of the workover operation of the thermal recovery horizontal well is ensured; after 7 days, the strength is gradually broken, the production can be recovered, and the oil extraction efficiency is not influenced.
Detailed Description
The invention is further illustrated, but not limited, by the following specific examples.
The raw materials used in the examples are conventional raw materials.
The acrylamide/2-acrylamido-2-methylpropanesulfonic acid/vinylpyrrolidone polymers described in the examples were prepared in a molar ratio of acrylamide, 2-acrylamido-2-methylpropanesulfonic acid, vinylpyrrolidone of 1: (1-2): (1-5); the molar content of the vinylpyrrolidone chain units in the temperature-resistant polymer is 60%.
Example 1
1000g of deoiled hot sewage at 80 ℃ is taken from the united station, and 40g of bentonite is added while stirring is carried out. Stirring at high speed for 4h, adding isophthalaldehyde 4g, hydroquinone 4g, thiourea 3g and acetic acid 3g, and stirring for 10 min. Then 18 g of AM-AMPS-NVP copolymer with a relative molecular mass of 400 ten thousand and HPAM3g with a molecular weight of 1300 ten thousand and a degree of hydrolysis of 27% were slowly added with stirring and stirred for 2 h. And finally, adding 1g of chromium acetate, and uniformly stirring to obtain the high-strength gel temporary plugging agent for plugging the horizontal shaft before the well workover of the thermal recovery horizontal well.
Example 2
1000g of deoiled hot sewage at 80 ℃ is taken from the united station, and 30g of bentonite is added while stirring is carried out. After stirring at a high speed for 4 hours, adding 3g of terephthalaldehyde, 3g of phenol, 2g of sodium sulfite and 2g of butyric acid, and stirring for 10 min. Then, 10 g of AM-AMPS-NVP copolymer with a relative molecular mass of 300 ten thousand and HPAM2g with a molecular weight of 900 ten thousand and a hydrolysis degree of 22% are slowly added under stirring, and stirred for 2 hours. And finally, adding 2g of chromium citrate, and uniformly stirring to obtain the high-strength gel temporary plugging agent for plugging the horizontal shaft before the well workover of the thermal recovery horizontal well.
Example 3
1000g of deoiled hot sewage at 80 ℃ is taken from the united station, and 50g of bentonite is added while stirring is carried out. After stirring at high speed for 4h, 4g of urotropin, 3g of resorcinol, 4g of sodium bisulfite and 2g of valeric acid are added and stirred for 10 min. Then, 20 g of AM-AMPS-NVP copolymer with a relative molecular mass of 700 ten thousand and HPAM4g with a molecular weight of 1500 ten thousand and a hydrolysis degree of 30% are slowly added under stirring, and stirred for 2 hours. And finally, adding 3g of chromium lactate, and uniformly stirring to obtain the high-strength gel temporary plugging agent for plugging the horizontal shaft before the well workover of the thermal recovery horizontal well.
Comparative example 1
1000g of deoiled hot sewage at 80 ℃ is taken from the united station, and 40g of bentonite is added while stirring is carried out. Stirring at high speed for 4h, adding 4g of urotropine, 4g of hydroquinone, 3g of thiourea and 3g of acetic acid, and stirring for 10 min. Then 18 g of AM-NVP-AMPS copolymer and 3g of HPAM polymer were added slowly with stirring and stirred for 2 h. Finally, 1g of chromium acetate was added thereto, followed by stirring.
Comparative example 2
1000g of deoiled hot sewage at 80 ℃ is taken from the united station, and 40g of bentonite is added while stirring is carried out. Stirring at high speed for 4h, adding isophthalaldehyde 4g, hydroquinone 4g, thiourea 3g and acetic acid 3g, and stirring for 10 min. Then 18 g of AM-AMPS copolymer and 3g of HPAM polymer were added slowly with stirring and stirred for 2 h. Finally, 1g of chromium acetate was added thereto, followed by stirring.
Comparative example 3
1000g of deoiled hot sewage at 80 ℃ is taken from the united station, and 40g of bentonite is added while stirring is carried out. Stirring at high speed for 4h, adding m-phthalaldehyde 4g, hydroquinone 4g and thiourea 3g, and stirring for 10 min. Then 18 g of AM-AMPS-NVP copolymer and 3g of HPAM polymer were added slowly with stirring and stirred for 2 h. Finally, 1g of chromium acetate was added thereto, followed by stirring.
Comparative example 4
1000g of deoiled hot sewage at 80 ℃ is taken from a combined station, and 40g of silica sol (the median particle size is 15nm) is added while stirring. Stirring at high speed for 4h, adding isophthalaldehyde 4g, hydroquinone 4g, thiourea 3g and acetic acid 3g, and stirring for 10 min. Then 18 g of AM-AMPS-NVP copolymer particles and 3g of HPAM polymer particles were slowly added with stirring, and stirred for 2 hours. Finally, 1g of chromium acetate is added and stirred for 30 min.
Comparative example 5
1000g of deoiled hot sewage at 80 ℃ is taken from the united station, and 40g of bentonite is added while stirring is carried out. Stirring at high speed for 4h, adding isophthalaldehyde 4g, hydroquinone 4g, thiourea 3g and acetic acid 3g, and stirring for 10 min. Then 18 g of AM-AMPS-NVP copolymer is slowly added under stirring, and the mixture is stirred for 2 h.
Test example 1
The jelly properties obtained in example 1 and comparative examples 1 to 5 were tested as shown in table 1.
TABLE 1 measurement of the Properties of the gels formed by the different components
As can be seen from table 1, in comparative example 1, urotropine was used instead of isophthalaldehyde, and although the formed jelly had good strength for three days at 200 ℃, the jelly time was fast at high temperature, and it was difficult to ensure smooth injection of the plugging agent into a long horizontal well bore. In comparative example 2, AM-AMPS copolymer is used to replace AM-NVP-AMPS copolymer, the formed jelly stability is obviously reduced, and the jelly strength is greatly reduced after heat treatment at 200 ℃ for 2 days. Comparative example 3 no acetic acid was added and the strength and stability of the resulting jelly was also significantly reduced. Comparative example 4 silica sol replaces sodium soil to be used as a stabilizer, the formed jelly strength and stability are also reduced, and the jelly strength can not meet the use requirement after heat treatment for 3 days at 200 ℃. Comparative example 5 no HPAM and chromium acetate were added to the gelling solution, which, although the strength and stability of the formation were similar to those of the examples, was unable to form a network structure due to the lack of rapid cross-linking of chromium in the gelling solution, which was dispersed when poured into water; the gel forming liquid prepared in the embodiment shows weak gel due to the cross-linking effect of HPAM and chromium acetate, and can not be dispersed when meeting water, so that the gel forming liquid can not be diluted by the water in the shaft after being injected into the shaft.
Claims (10)
1. The high-strength gel temporary plugging agent for plugging a horizontal wellbore before workover of a thermal recovery horizontal well is characterized by comprising the following components in percentage by mass:
0.5 to 2.5 percent of temperature-resistant polymer, 0.1 to 0.5 percent of partially hydrolyzed polyacrylamide, 0.2 to 0.8 percent of phenolic crosslinking agent, 0.1 to 0.5 percent of chromium crosslinking agent, 0.1 to 0.5 percent of deoxidant, 0.05 to 0.3 percent of organic acid, 2 to 6 percent of sodium soil and the balance of water.
2. The high-strength gel temporary plugging agent for the horizontal wellbore before the workover of the thermal recovery horizontal well, according to claim 1, is characterized by comprising the following components in percentage by mass:
1-2% of temperature-resistant polymer, 0.2-0.4% of partially hydrolyzed polyacrylamide, 0.3-0.5% of phenolic crosslinking agent, 0.2-0.4% of chromium crosslinking agent, 0.2-0.4% of oxygen scavenger, 0.08-0.15% of organic acid, 3-5% of sodium soil and the balance of water.
3. The high-strength gel temporary plugging agent for plugging a horizontal wellbore before workover of a thermal recovery horizontal well according to claim 1, wherein the temperature-resistant polymer is acrylamide/2-acrylamide-2-methylpropanesulfonic acid/vinyl pyrrolidone (AM-AMPS-NVP) polymer;
preferably, the relative molecular mass of the temperature-resistant polymer is 300-800 ten thousand.
4. The high-strength gel temporary plugging agent for plugging the horizontal wellbore before workover of the thermal recovery horizontal well according to claim 3, wherein when the temperature-resistant polymer is prepared, the molar ratio of acrylamide, 2-acrylamide-2-methylpropanesulfonic acid and vinyl pyrrolidone is 1: (1-2): (1-5);
preferably, the molar content of the vinyl pyrrolidone chain link in the temperature-resistant polymer is 30-70%.
5. The high-strength gel temporary plugging agent for plugging the horizontal wellbore before workover of the thermal recovery horizontal well according to claim 1, wherein the molecular weight of the partially hydrolyzed polyacrylamide is 800-1800 ten thousand, and the hydrolysis degree is 20-30%.
6. The high-strength gel temporary plugging agent for plugging the horizontal wellbore before workover of the thermal recovery horizontal well according to claim 1, wherein the phenolic crosslinking agent is composed of phenolic substances and aldehyde substances;
preferably, the phenolic substance is one or two of phenol, hydroquinone and resorcinol, and the aldehyde crosslinking agent is one or two of m-phthalaldehyde, p-phthalaldehyde and urotropine;
preferably, the molar ratio of the phenolic substance to the aldehyde substance in the phenolic aldehyde crosslinking agent is 1: (1-1.2).
7. The high-strength gel temporary plugging agent for plugging the horizontal wellbore before workover of the thermal recovery horizontal well according to claim 1, wherein the chromium crosslinking agent is chromium acetate, chromium lactate or chromium citrate.
8. The high-strength gel temporary plugging agent for plugging a horizontal wellbore before workover of a thermal recovery horizontal well according to claim 1, wherein the oxygen scavenger is sodium sulfite, sodium bisulfite or thiourea.
9. The high-strength jelly temporary plugging agent for the horizontal wellbore plugging before the well workover of the thermal recovery horizontal well according to claim 1, wherein the organic acid is acetic acid, butyric acid or valeric acid.
10. The preparation method of the high-strength gel temporary plugging agent for plugging the horizontal wellbore before workover of the thermal recovery horizontal well, which is disclosed by claim 1, comprises the following steps:
adding sodium soil into water under the condition of stirring, adding a phenolic cross-linking agent, an oxygen scavenger and an organic acid after uniformly stirring, slowly adding a temperature-resistant polymer and partially hydrolyzed polyacrylamide under the condition of stirring after uniformly stirring, finally adding a chromium cross-linking agent, and uniformly stirring to obtain the catalyst.
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| CN114875520A (en) * | 2022-06-10 | 2022-08-09 | 余昭军 | Water-soluble temporary plugging agent for fracturing and preparation method thereof |
| CN115704287A (en) * | 2021-08-13 | 2023-02-17 | 中国石油天然气股份有限公司 | Chemical temporary plugging and shielding workover method for heavy oil thermal recovery wells |
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| CN115704287A (en) * | 2021-08-13 | 2023-02-17 | 中国石油天然气股份有限公司 | Chemical temporary plugging and shielding workover method for heavy oil thermal recovery wells |
| CN115704287B (en) * | 2021-08-13 | 2024-08-13 | 中国石油天然气股份有限公司 | Chemical temporary plugging and shielding workover method for heavy oil thermal recovery wells |
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| CN115746808B (en) * | 2021-09-06 | 2024-04-30 | 中国石油天然气股份有限公司 | Plugging agent and its application |
| CN115746808A (en) * | 2021-09-06 | 2023-03-07 | 中国石油天然气股份有限公司 | Plugging agent and its application |
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| CN114875520B (en) * | 2022-06-10 | 2023-11-17 | 山东省科原石油科技有限责任公司 | Water-soluble temporary plugging agent for fracturing and preparation method thereof |
| CN114875520A (en) * | 2022-06-10 | 2022-08-09 | 余昭军 | Water-soluble temporary plugging agent for fracturing and preparation method thereof |
| CN117757450A (en) * | 2022-09-23 | 2024-03-26 | 中国石油天然气股份有限公司 | A high-strength thixotropic composite gel temporary plugging agent for super heavy oil SAGD well groups and its application |
| WO2024131572A1 (en) * | 2022-12-23 | 2024-06-27 | 中国石油天然气股份有限公司 | Temporary plugging agent composition, temporary plugging agent, preparation method therefor, and use thereof |
| CN116285921A (en) * | 2023-03-07 | 2023-06-23 | 郭伟 | Chemical plugging composition for offshore oil field and preparation method and application thereof |
| CN120137624A (en) * | 2023-12-12 | 2025-06-13 | 中国石油化工股份有限公司 | A kind of sheet nano material reinforced temperature-resistant and environmentally friendly jelly and its preparation method |
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