Permeation and absorption yield increasing agent for low-permeability oil reservoir development and preparation method and application of imbibition and absorption yield increasing agent

Abstract

The invention relates to the technical field of oilfield chemistry and oil-gas field development, in particular to an imbibition yield increasing agent for low-permeability reservoir development as well as a preparation method and application of the imbibition yield increasing agent. The imbibition yield increasing agent for low-permeability reservoir development comprises a compound shown in a formula I: # imgabs0 #, R is alkyl, and X <-> is halogen anion Cl <-> or Br <->. The imbibition yield-increasing agent disclosed by the invention is good in temperature resistance and salt resistance, and meanwhile, the imbibition yield-increasing agent has relatively good compatibility with fracturing fluid and acid liquor. The imbibition yield increasing agent disclosed by the invention has super-strong capability of imbibing and replacing crude oil when a tight oil reservoir is developed, and the oil washing efficiency and the water drive recovery efficiency can be remarkably improved.

Description

Technical Field

[0001] The invention relates to the technical field of oilfield chemistry and oil and gas field development, and in particular to an imbibition and production-increasing agent for low-permeability oil reservoir development, and a preparation method and application thereof. Background Art

[0002] Low permeability oil and gas fields are of great significance in my country's oil and gas development. Low permeability oil and gas fields discovered in my country account for more than half of the newly discovered oil and gas reservoirs, and the scale of low permeability oil and gas field capacity construction accounts for more than 70% of the total scale of oil and gas field capacity construction. Low permeability oil and gas fields have become the main battlefield for oil and gas development and construction. In 2008 alone, low permeability crude oil production accounted for 37.6% of the country's total crude oil production, and low permeability natural gas production accounted for 42.1% of the country's total natural gas production. Secondly, the distribution of low permeability oil and gas resources in my country is characterized by high oil and gas content, multiple oil and gas reservoir types, wide distribution area, and "upper gas and lower oil, marine gas-based, and continental oil and gas". Among the proven reserves, the proportion of low permeability oil reservoir reserves is very high, accounting for more than 2 / 3 of the country's reserves, and the development potential is huge.

[0003] As an important development method for low-permeability tight oil reservoirs, imbibition oil recovery utilizes the strong capillary force of low-permeability reservoirs to enhance the oil-water replacement capacity between matrix and fractures, thereby effectively mobilizing the remaining oil in the matrix. This can provide a new technical means for the development of low-permeability reservoirs in Zhuangxi.

[0004] The imbibition was first implemented by the United States in the 1950s, and was first applied in the sandstone siltstone fractured oil field of the Sprague-Dawley Oilfield in Texas, USA. In the following decades, domestic and foreign scholars have conducted a lot of research on imbibition. CN107216863A discloses an imbibition agent used for imbibition oil production in low permeability reservoirs, which is mainly composed of organochlorosilane-modified nano-SiO2. Since the organochlorosilane-modified nano-SiO2 contains organic chlorine groups, if the crude oil is mixed with this substance, it may cause refining catalyst poisoning and refining equipment corrosion. CN 111303854 A discloses a sandstone reservoir phase permeation agent, phase permeation fracturing fluid and a method of using the same, wherein the sandstone reservoir phase permeation agent is made of alkyl trimethylammonium chloride, quaternary ammonium salt cationic fluorocarbon surfactant, alkyl alkoxy carboxy betaine, mannitol erythritol ester and organic alcohol as raw materials, and the components synergistically enhance the effect, and can convert the sandstone surface from oil wetting to water wetting, thereby improving the oil phase permeability. CN113717709B discloses a nanofluid absorbing agent, which is mainly composed of amphiphilic grafted modified nano silicon dioxide particles, betaine surfactant, nonionic surfactant, etc. The steric structure on the surface of the amphiphilic modified nano silicon dioxide particles can prevent them from agglomerating with each other in a high mineralization environment, so that they can be fully dispersed in a water environment and have a good mineralization resistance effect; at the same time, the betaine surfactant and the nonionic surfactant have good salt resistance, so the high-efficiency nanofluid absorbing agent has a strong salt resistance and can be applied to the fracturing fluid system prepared with high mineralization flowback fluid. However, the current absorbing agents all have the problems of poor temperature resistance and poor compatibility with fracturing fluid and acid solution. Therefore, it will be a bright prospect to study an absorbing agent with good compatibility with fracturing fluid and acid solution and excellent temperature resistance. Summary of the invention

[0005] In view of the problems existing in the above-mentioned prior art, the present invention provides an imbibition production-enhancing agent for low permeability oil reservoir development, and a preparation method and application thereof. The imbibition production-enhancing agent of the present invention has good temperature and salt resistance, and has good compatibility with fracturing fluid and acid. The imbibition production-enhancing agent of the present invention has a super strong ability to imbibe and replace crude oil when developing tight oil reservoirs, and can significantly improve the oil washing efficiency and water drive recovery rate.

[0006] To achieve the above object, the present invention adopts the following technical solutions:

[0007] In a first aspect, the present invention provides an imbibition and production-enhancing agent for low permeability reservoir development, which comprises a compound represented by formula I:

[0008]

[0009] Wherein, R is an alkyl group, X - For the halogen anion Cl - or Br- .

[0010] Furthermore, R is C 12 -C 20 The alkyl group has a middle carbon chain length of 4 to 6, X - For the halogen anion Cl - or Br - .

[0011] Furthermore, the yield-increasing agent consists of the compound shown in formula I and water.

[0012] Furthermore, the mass concentration of the compound is 0.1%-1%.

[0013] In a second aspect, the present invention provides a method for preparing an imbibition production enhancing agent for low permeability reservoir development, the method comprising the following steps:

[0014] S1. Fatty amide propyl dimethyl tertiary amine is reacted with a dihalogenated alkane in a solvent, and after the solvent is evaporated, an alkylene bis fatty amide propyl dimethyl quaternary ammonium salt intermediate is prepared;

[0015] S2. The obtained alkylene bis fatty amide propyl dimethyl quaternary ammonium salt intermediate is mixed with a solvent, and sodium α-olefin sulfonate is added to react, and the resultant is separated and purified and prepared with water to a mass concentration of 0.1%-1% aqueous solution to obtain;

[0016] After separation and purification, the main components of the obtained product are as shown in Formula I:

[0017]

[0018] Where R is C 12 -C 20 The alkyl group has a middle carbon chain length of 4 to 6, X - For the halogen anion Cl - or Br - .

[0019] Furthermore, in step S1, the solvent is water or isopropanol-water solution, and the reaction is carried out at 60-90° C. for 4-6 hours. The volume ratio of isopropanol to water in the isopropanol-water is 1-3:1, and the molar ratio of the reactants fatty amide propyl dimethyl tertiary amine and dihaloalkane is 2:1.0-1.3.

[0020] Furthermore, the dihaloalkane is one of 1,4-dichlorobutane, 1,4-dibromobutane, 1,6-dichlorohexane and 1,6-dibromohexane.

[0021] Furthermore, in step S2, the solvent used is an ethanol-water solution, which is stirred at 30-50° C. for 0.5-3 hours, and then sodium α-olefin sulfonate is added and stirred for 30-60 minutes, wherein the volume ratio of ethanol to water in the ethanol-water solution is 1:4-6.

[0022] Furthermore, the mass ratio of alkylene bis fatty amide propyl dimethyl quaternary ammonium salt to sodium α-olefin sulfonate is 1-5:1.

[0023] The third aspect of the present invention provides the use of the imbibition production enhancing agent described in the first aspect and prepared by the method described in the second aspect in tight oil production.

[0024] Compared with the prior art, the present invention has the following advantages:

[0025] (1) The imbibition production enhancing agent of the present invention has a stronger imbibition ability and can automatically enter the microcracks of carbonate rocks and the micropore throats of low-permeability sandstones. At the same time, it uses its super strong crude oil stripping ability to displace the crude oil in the microcracks and micropore throats. In addition, the imbibition agent can improve the reservoir wettability to neutral weak hydrophilic wetting, which is beneficial to the discharge of crude oil and formation water in the formation, and improves the liquid production and oil production capacity of the oil well.

[0026] (2) The imbibition and production enhancement agent of the present invention has a temperature resistance of up to 200°C. After aging at 200°C for 48 hours, the performance does not change significantly, and is suitable for application in high-temperature carbonate rocks and low-permeability oil reservoirs in Shengli buried hills.

[0027] (3) The imbibition and production-increasing agent of the present invention has good compatibility with fracturing fluid, acid solution, etc., does not affect the cross-linking, temperature resistance and shear resistance of the fracturing fluid, is not easy to produce acid slag with the acid solution, and the residual acid does not affect the demulsification of crude oil. It can be used for fracturing acidification pre-fluid, or directly added to the fracturing fluid and acid solution for use, and has strong adaptability. BRIEF DESCRIPTION OF THE DRAWINGS

[0028] Figure 1 This is a graph showing the changes in imbibition oil recovery after aging of the imbibition production enhancer II and the commercially available imbibition production enhancer SX-1 at different temperatures;

[0029] Figure 2 This is the fracturing fluid pick-up and hanging performance diagram after adding cross-linking agent to the imbibition and production enhancement agent IV;

[0030] Figure 3 This is the solution state diagram after the imbibition and production enhancement agent V in the pre-acid system. DETAILED DESCRIPTION

[0031] It should be noted that the following detailed descriptions are exemplary and are intended to provide further explanation of the present invention. Unless otherwise specified, all technical and scientific terms used herein have the same meanings as those commonly understood by those skilled in the art to which the present invention belongs.

[0032] It should be noted that the terms used herein are only for describing specific embodiments and are not intended to limit exemplary embodiments according to the present invention. As used herein, unless the context clearly indicates otherwise, the singular form is also intended to include the plural form. In addition, it should be understood that when the terms "comprising" and / or "including" are used in this specification, it indicates the presence of features, steps, operations and / or combinations thereof.

[0033] In order to enable those skilled in the art to more clearly understand the technical solution of the present invention, the technical solution of the present invention will be described in detail below in conjunction with specific embodiments.

[0034] Example 1

[0035] Add 60.0 g of dodecylamidopropyl dimethyl tertiary amine, 20 g of 1,4-dibromobutane and 100 ml of water into a three-necked flask, react at 90° C. for 6 hours, cool, and evaporate water under reduced pressure to obtain butanediol didodecylamidopropyl dimethyl quaternary ammonium salt.

[0036] Add 60g of butylene didodecylamidopropyl dimethyl quaternary ammonium salt to 100ml of ethanol-water (ethanol: water = 1:4 (v / v)), stir and dissolve at 40°C for 1 hour, add 30g of sodium α-olefin sulfonate and continue stirring for 30min, separate and purify, and prepare an aqueous solution with water having a mass percentage of 0.1% to obtain an imbibition production enhancer I for low permeability reservoir development.

[0037] Example 2

[0038] In a three-necked flask, add 60.0 g of tetradecylamidopropyl dimethyl tertiary amine, 18 g of 1,4-dichlorobutane, and 100 ml of isopropanol-water solution (isopropanol: water = 2:1 (v / v), react at 90° C. for 5 hours, cool, and evaporate the solvent under reduced pressure to obtain butanediyl ditetradecylamidopropyl dimethyl quaternary ammonium salt.

[0039] Add 50g of butylene ditetradecylamide propyl dimethyl quaternary ammonium salt to 100ml of ethanol-water (ethanol: water = 1:4 (v / v)), stir and dissolve at 40°C for 1 hour, add 25g of sodium α-olefin sulfonate and continue stirring for 30min, separate and purify, and prepare an aqueous solution with water having a mass percentage of 0.3%, thereby obtaining an imbibition production enhancer II for low permeability reservoir development.

[0040] Example 3

[0041] In a three-necked flask, add 63 g of dodecylamidopropyl dimethyl tertiary amine, 23.6 g of 1,6-dichlorohexane, and 100 ml of isopropanol-water solution (isopropanol: water = 2:1 (v / v), react at 90° C. for 6 hours, cool, and evaporate the solvent under reduced pressure to obtain hexyldidodecylamidopropyl dimethyl quaternary ammonium salt.

[0042] 70 g of hexyldidodecylamidopropyl dimethyl quaternary ammonium salt was added to 100 ml of ethanol-water (ethanol: water = 1:4 (v / v)), and the mixture was stirred and dissolved at 50° C. for 1 hour. 35 g of sodium α-olefin sulfonate was added and the stirring was continued for 30 min. After separation and purification, the mixture was prepared with water into an aqueous solution with a mass percentage of 0.5%, thereby obtaining an imbibition production enhancer III for low permeability reservoir development.

[0043] Example 4

[0044] Add 65 g of hexadecylamidopropyl dimethyl tertiary amine, 22.3 g of 1,6-dibromobutane, and 100 ml of isopropanol-water solution (isopropanol: water = 2:1 (v / v)) into a three-necked flask, react at 80°C for 4 hours, cool, and evaporate the solvent under reduced pressure to obtain butane dihexadecylamidopropyl dimethyl quaternary ammonium salt.

[0045] 58 g of butylene dihexadecylamidopropyl dimethyl quaternary ammonium salt was added to 100 ml of ethanol-water (ethanol: water = 1:4 (v / v)), and the mixture was stirred and dissolved at 50°C for 1 hour. 29 g of sodium α-olefin sulfonate was added and the stirring was continued for 30 minutes. After separation and purification, the mixture was prepared with water into an aqueous solution with a mass percentage of 1%, thereby obtaining an imbibition production enhancer IV for low permeability reservoir development.

[0046] Example 5

[0047] Add 57.3 g of octadecylamidopropyl dimethyl tertiary amine, 18.6 g of 1,6-dibromobutane, and 100 ml of isopropanol-water solution (isopropanol: water = 2:1 (v / v)) into a three-necked flask, react at 70° C. for 6 hours, cool, and evaporate the solvent under reduced pressure to obtain butane dioctadecylamidopropyl dimethyl quaternary ammonium salt.

[0048] 56 g of butylene dioctadecylamidopropyl dimethyl quaternary ammonium salt was added to 100 ml of ethanol-water (ethanol: water = 1:4 (v / v)), and the mixture was stirred and dissolved at 50° C. for 1 hour. 28 g of sodium α-olefin sulfonate was added and stirring was continued for 30 min. After separation and purification, the mixture was prepared with water into an aqueous solution with a mass percentage of 0.8%, thereby obtaining an imbibition production enhancer V for low permeability reservoir development.

[0049] Example 6

[0050] Add 60.2 g of arachidyl amidopropyl dimethyl tertiary amine, 23.2 g of 1,6-dibromohexane, and 100 ml of isopropanol-water solution (isopropanol: water = 2:1 (v / v)) into a three-necked flask, react at 90° C. for 6 hours, cool, and evaporate the solvent under reduced pressure to obtain hexyl diarachidyl amidopropyl dimethyl quaternary ammonium salt.

[0051] 50 g of hexylene diaramidopropyl dimethyl quaternary ammonium salt was added to 100 ml of ethanol-water (ethanol: water = 1:4 (v / v)), and the mixture was stirred and dissolved at 50° C. for 1 hour. 25 g of sodium α-olefin sulfonate was added and the stirring was continued for 30 min. After separation and purification, the mixture was prepared with water into an aqueous solution with a mass percentage of 0.3%, thereby obtaining an imbibition production enhancer VI for low permeability reservoir development.

[0052] Experimental Example 1

[0053] The imbibition yield enhancer II obtained in Example 2 and the commercially available imbibition yield enhancer SX-1 (0.3% by mass aqueous solution) were aged at different temperatures for 48 hours and then taken out to test their imbibition oil recovery rates. The results are as follows: Figure 1 As shown:

[0054] The temperature resistance of imbibition production enhancer II can reach 200℃. After aging at 200℃ for 48h, the imbibition oil recovery rate can still reach more than 20%, which is slightly different from that at 60℃. However, SX-1 has an obvious downward trend at 150℃, indicating that imbibition production enhancer II has excellent temperature resistance.

[0055] Different concentrations of imbibition enhancer II and SX-1 were prepared with distilled water, and then the core pieces were placed in the imbibition enhancer aqueous solution at 90°C for 24 hours. The contact angles were measured and the results are shown in Table 1:

[0056]

[0057]

[0058] As shown in Table 1, the imbibition and production enhancement agent II has a good effect on improving reservoir wettability, which can change the reservoir from hydrophilic to neutral and weak hydrophilic, which is conducive to the outflow of formation fluids and improves the production capacity of oil wells. However, SX-1 basically has no ability to improve reservoir wettability.

[0059] Experimental Example 2

[0060] The guar gum fracturing fluid base fluid was prepared by 0.6% guar gum + 0.5% microemulsion drainage agent + 0.5% clay stabilizer + 0.5% demulsifier + 0.5% imbibition production enhancer IV prepared in Example 4. The appearance of the base fluid was observed to have no floccules or precipitation, and it had no effect on the viscosity of the base fluid. After adding the cross-linking agent at a cross-linking ratio of 100:0.4, the fracturing fluid can be hung (attached Figure 2 ), does not affect the cross-linking properties of the fracturing fluid. -1 At a shear rate of , the viscosity of the fracturing fluid after shearing for 2 hours is still 65mPa.s (the blank as a control is 63mPa.s), which does not affect the temperature and shear resistance of the fracturing fluid. It can be seen that the imbibition agent of the present invention has good compatibility with the fracturing fluid.

[0061] Experimental Example 3

[0062] 0.5% of the imbibition enhancer V prepared in Example 5 was added to the pre-acid system for acidification, and the acid solution became clear and transparent (attached Figure 3 ), no flocs or precipitation were produced, indicating that the imbibition and production-enhancing agent had good compatibility with the acid system.

[0063] The above embodiments are preferred implementation modes of the present invention, but the implementation modes of the present invention are not limited to the above embodiments. Any other changes, modifications, substitutions, combinations, and simplifications that do not deviate from the spirit and principles of the present invention should be equivalent replacement methods and are included in the protection scope of the present invention.

Claims

1. An imbibition and production-increasing agent for low permeability reservoir development, characterized in that: Including compounds shown in formula I: Wherein, R is an alkyl group, X - For the halogen anion Cl - or Br - .

2. The imbibition and production-increasing agent for low permeability reservoir development according to claim 1, characterized in that: R is C 12 -C 20 The alkyl group has a middle carbon chain length of 4 to 6, X - For the halogen anion Cl - or Br - .

3. The imbibition and production-increasing agent for low permeability reservoir development according to claim 1 or 2, characterized in that: The yield-increasing agent consists of the compound shown in formula I and water.

4. The imbibition and production-increasing agent for low permeability reservoir development according to claim 3, characterized in that: The mass concentration of the compound is 0.1%-1%.

5. A method for preparing an imbibition production enhancing agent for low permeability reservoir development, characterized in that: The following steps are involved: S1. Fatty amide propyl dimethyl tertiary amine is reacted with a dihalogenated alkane in a solvent, and after the solvent is evaporated, an alkylene bis fatty amide propyl dimethyl quaternary ammonium salt intermediate is prepared; S2. The obtained alkylene bis fatty amide propyl dimethyl quaternary ammonium salt intermediate is mixed with a solvent, and sodium α-olefin sulfonate is added to react, and the resultant is separated and purified and prepared with water to a mass concentration of 0.1%-1% aqueous solution to obtain; After separation and purification, the main components of the obtained product are as shown in Formula I: Where R is C 12 -C 20 The alkyl group has a middle carbon chain length of 4 to 6, X - For the halogen anion Cl - or Br - .

6. The preparation method according to claim 5, characterized in that: In step S1, the solvent is water or isopropanol-water solution, and the reaction is carried out at 60-90° C. for 4-6 hours. The volume ratio of isopropanol to water in the isopropanol-water is 1-3:1, and the molar ratio of the reactants fatty amide propyl dimethyl tertiary amine and dihaloalkane is 2:1.0-1.

3.

7. The preparation method according to claim 5 or 6, characterized in that: The dihaloalkane is one of 1,4-dichlorobutane, 1,4-dibromobutane, 1,6-dichlorohexane and 1,6-dibromohexane.

8. The preparation method according to claim 5, characterized in that: In step S2, the solvent is ethanol-water solution, stirred at 30-50° C. for 0.5-3 hours, then sodium α-olefin sulfonate is added and stirred for 30-60 minutes, wherein the volume ratio of ethanol to water in the ethanol-water solution is 1:4-6.

9. The preparation method according to claim 5, characterized in that: The mass ratio of alkylene bis fatty amide propyl dimethyl quaternary ammonium salt to sodium α-olefin sulfonate is 1-5:

1.

10. Use of the imbibition and production-enhancing agent according to any one of claims 1 to 4, or the imbibition and production-enhancing agent prepared by the method according to any one of claims 5 to 9 in tight oil production.

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