CN117603663A - Oil-based drilling fluid viscosity reducer and preparation and use methods thereof - Google Patents
Oil-based drilling fluid viscosity reducer and preparation and use methods thereof Download PDFInfo
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- 238000005553 drilling Methods 0.000 title claims abstract description 118
- 239000012530 fluid Substances 0.000 title claims abstract description 112
- 239000003638 chemical reducing agent Substances 0.000 title claims abstract description 92
- 238000000034 method Methods 0.000 title claims abstract description 31
- 238000002360 preparation method Methods 0.000 title claims abstract description 13
- PLIKAWJENQZMHA-UHFFFAOYSA-N 4-aminophenol Chemical compound NC1=CC=C(O)C=C1 PLIKAWJENQZMHA-UHFFFAOYSA-N 0.000 claims abstract description 70
- FPYJFEHAWHCUMM-UHFFFAOYSA-N maleic anhydride Chemical compound O=C1OC(=O)C=C1 FPYJFEHAWHCUMM-UHFFFAOYSA-N 0.000 claims abstract description 24
- 239000000376 reactant Substances 0.000 claims abstract description 20
- 239000003054 catalyst Substances 0.000 claims abstract description 16
- 238000006243 chemical reaction Methods 0.000 claims abstract description 11
- 238000003756 stirring Methods 0.000 claims abstract description 10
- 238000010438 heat treatment Methods 0.000 claims abstract description 9
- 230000008569 process Effects 0.000 claims abstract description 7
- 230000001681 protective effect Effects 0.000 claims abstract description 4
- XLOMVQKBTHCTTD-UHFFFAOYSA-N Zinc monoxide Chemical compound [Zn]=O XLOMVQKBTHCTTD-UHFFFAOYSA-N 0.000 claims description 40
- ZMXDDKWLCZADIW-UHFFFAOYSA-N N,N-Dimethylformamide Chemical group CN(C)C=O ZMXDDKWLCZADIW-UHFFFAOYSA-N 0.000 claims description 24
- 239000011787 zinc oxide Substances 0.000 claims description 20
- 239000012024 dehydrating agents Substances 0.000 claims description 17
- 239000002002 slurry Substances 0.000 claims description 12
- 230000035484 reaction time Effects 0.000 claims description 6
- QPLDLSVMHZLSFG-UHFFFAOYSA-N Copper oxide Chemical compound [Cu]=O QPLDLSVMHZLSFG-UHFFFAOYSA-N 0.000 claims description 4
- 239000002283 diesel fuel Substances 0.000 claims description 4
- 239000004615 ingredient Substances 0.000 claims description 4
- UQSXHKLRYXJYBZ-UHFFFAOYSA-N iron oxide Inorganic materials [Fe]=O UQSXHKLRYXJYBZ-UHFFFAOYSA-N 0.000 claims description 4
- 239000005751 Copper oxide Substances 0.000 claims description 3
- 229910000428 cobalt oxide Inorganic materials 0.000 claims description 3
- IVMYJDGYRUAWML-UHFFFAOYSA-N cobalt(ii) oxide Chemical compound [Co]=O IVMYJDGYRUAWML-UHFFFAOYSA-N 0.000 claims description 3
- 229910000431 copper oxide Inorganic materials 0.000 claims description 3
- 239000003292 glue Substances 0.000 claims description 3
- 229910000480 nickel oxide Inorganic materials 0.000 claims description 3
- GNRSAWUEBMWBQH-UHFFFAOYSA-N oxonickel Chemical compound [Ni]=O GNRSAWUEBMWBQH-UHFFFAOYSA-N 0.000 claims description 3
- NDLPOXTZKUMGOV-UHFFFAOYSA-N oxo(oxoferriooxy)iron hydrate Chemical compound O.O=[Fe]O[Fe]=O NDLPOXTZKUMGOV-UHFFFAOYSA-N 0.000 claims description 2
- 238000003786 synthesis reaction Methods 0.000 abstract description 8
- 230000015572 biosynthetic process Effects 0.000 abstract description 7
- WSFSSNUMVMOOMR-UHFFFAOYSA-N Formaldehyde Chemical compound O=C WSFSSNUMVMOOMR-UHFFFAOYSA-N 0.000 abstract description 6
- 239000000126 substance Substances 0.000 abstract description 3
- 230000009467 reduction Effects 0.000 description 35
- 230000032683 aging Effects 0.000 description 24
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 8
- 238000011156 evaluation Methods 0.000 description 8
- 239000000047 product Substances 0.000 description 8
- 238000005259 measurement Methods 0.000 description 6
- 239000000693 micelle Substances 0.000 description 6
- 230000000694 effects Effects 0.000 description 5
- 239000007789 gas Substances 0.000 description 5
- 229910052757 nitrogen Inorganic materials 0.000 description 5
- 230000001603 reducing effect Effects 0.000 description 5
- 238000006297 dehydration reaction Methods 0.000 description 4
- 238000010907 mechanical stirring Methods 0.000 description 4
- 238000005303 weighing Methods 0.000 description 4
- YXFVVABEGXRONW-UHFFFAOYSA-N Toluene Chemical compound CC1=CC=CC=C1 YXFVVABEGXRONW-UHFFFAOYSA-N 0.000 description 3
- 230000009286 beneficial effect Effects 0.000 description 3
- 239000006227 byproduct Substances 0.000 description 3
- 230000018044 dehydration Effects 0.000 description 3
- 230000002349 favourable effect Effects 0.000 description 3
- 238000011049 filling Methods 0.000 description 3
- 238000004064 recycling Methods 0.000 description 3
- 239000010913 used oil Substances 0.000 description 3
- 239000003795 chemical substances by application Substances 0.000 description 2
- 239000000203 mixture Substances 0.000 description 2
- 230000001105 regulatory effect Effects 0.000 description 2
- 239000007790 solid phase Substances 0.000 description 2
- 239000002904 solvent Substances 0.000 description 2
- 239000004094 surface-active agent Substances 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 description 1
- 238000009833 condensation Methods 0.000 description 1
- 230000005494 condensation Effects 0.000 description 1
- 230000001276 controlling effect Effects 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 235000014113 dietary fatty acids Nutrition 0.000 description 1
- 238000004090 dissolution Methods 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 229930195729 fatty acid Natural products 0.000 description 1
- 239000000194 fatty acid Substances 0.000 description 1
- 150000004665 fatty acids Chemical class 0.000 description 1
- 230000005764 inhibitory process Effects 0.000 description 1
- XEEYBQQBJWHFJM-UHFFFAOYSA-N iron Substances [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 238000002156 mixing Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 239000001301 oxygen Substances 0.000 description 1
- 229910052760 oxygen Inorganic materials 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 239000012071 phase Substances 0.000 description 1
- 239000002994 raw material Substances 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 238000007086 side reaction Methods 0.000 description 1
- 239000003381 stabilizer Substances 0.000 description 1
- 239000008399 tap water Substances 0.000 description 1
- 235000020679 tap water Nutrition 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
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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
- C09K8/02—Well-drilling compositions
- C09K8/03—Specific additives for general use in well-drilling compositions
- C09K8/035—Organic additives
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- C—CHEMISTRY; METALLURGY
- C07—ORGANIC CHEMISTRY
- C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
- C07C231/00—Preparation of carboxylic acid amides
- C07C231/02—Preparation of carboxylic acid amides from carboxylic acids or from esters, anhydrides, or halides thereof by reaction with ammonia or amines
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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
- C09K8/02—Well-drilling compositions
- C09K8/32—Non-aqueous well-drilling compositions, e.g. oil-based
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- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
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- Oil, Petroleum & Natural Gas (AREA)
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Abstract
The invention provides an oil-based drilling fluid viscosity reducer and a preparation and use method thereof, wherein the preparation method comprises the following steps: dissolving para-aminophenol into a first catalyst to form a para-aminophenol solution; heating maleic anhydride to 70-150 ℃, adding a second catalyst and introducing protective gas to form maleic anhydride reactant; the reaction was carried out by dropping a stream of para-aminophenol solution into the reactants under stirring and condensing conditions until a brown viscous product formed. The invention is particularly suitable for repeatedly using the oil-based drilling fluid for a plurality of times, and reduces the viscosity of the oil-based drilling fluid so as to meet the requirement of new drilling; in the synthesis process, harmful substances such as formaldehyde and the like are not used, and the synthesis process is safer and more environment-friendly.
Description
Technical Field
The invention relates to the field of oil-based drilling working fluids in drilling engineering, in particular to the field of recycling of old slurry of oil-based drilling fluids with high solid phase content and high viscosity, and particularly relates to an oil-based drilling fluid viscosity reducer and a preparation and use method thereof.
Background
The oil-based drilling fluid has simple formula, stable performance and easy maintenance, and is far superior to other drilling fluid systems in the aspects of the stability of the well wall of the shale stratum and the stability of high temperature resistance. The oil-based drilling fluid has the advantages that: the oil-based drilling fluid has the advantages of good rheological property control under high temperature, high recovery value of permeability, small damage to an oil layer, high solid phase capacity limit, wide density application range, good well wall stability, shale inhibition and the like, can greatly reduce underground complex conditions in the drilling process of complex stratum, can be recycled and reused, and can well control the cost of the drilling fluid and the comprehensive drilling cost, so that the oil-based drilling fluid is greatly developed.
The viscosity of the recovered and repeatedly used oil-based drilling fluid is relatively high, so that the viscosity is difficult to meet the field engineering requirements, and the viscosity reducer is required to be added to adjust the rheological property of the oil-based drilling fluid. Patent CN115926763A discloses an oil-based drilling fluid viscosity reducer and a preparation method thereof, wherein the viscosity reducer is prepared from the following raw materials in parts by weight: 100-120 parts of fatty acid, 100-120 parts of N, N-dimethyl alkyl diamine, 140-180 parts of oil phase solvent and 20-35 parts of surfactant. Patent CN112358857A discloses an oil-based drilling fluid viscosity reducer, which comprises the following components in parts by weight: 50-100 parts of solvent oil, 5-50 parts of surfactant, 1-20 parts of penetrating agent and 1-10 parts of stabilizer.
The prior art has reduced viscosity for both recovered and reused oil-based drilling fluids. However, according to the prior invention, the viscosity reducer contains harmful substances such as toluene and the like in the preparation process, and the synthesis process is relatively complex.
Therefore, it is of great importance to research an oil-based drilling fluid viscosity reducer with high safety and/or simple preparation process.
Disclosure of Invention
The present invention aims to address at least one of the above-mentioned deficiencies of the prior art. For example, one of the purposes of the invention is to reduce the viscosity of the old slurry of the oil-based drilling fluid for repeated use, which is beneficial to recycling; the second purpose of the invention is to provide a viscosity reducer suitable for recycling the old slurry of the oil-based drilling fluid.
In order to achieve the above object, the present invention provides a method for preparing an oil-based drilling fluid viscosity reducer, the method comprising the following steps:
dissolving para-aminophenol into a first catalyst to form a para-aminophenol solution;
heating maleic anhydride to 70-150 ℃, then adding a second catalyst and introducing protective gas to form maleic anhydride reactant;
the reaction was carried out by dropping a stream of para-aminophenol solution into the reactants under stirring and condensing conditions until a brown viscous product formed.
Optionally, the first catalyst is an organic dehydrating agent, and the second catalyst is an inorganic dehydrating agent.
Optionally, the organic dehydrating agent is dimethylformamide, and the addition amount is 15-35% of the total weight of the oil-based drilling fluid viscosity reducer ingredients.
Optionally, the inorganic dehydrating agent comprises one or more of ferric oxide, cobalt oxide, nickel oxide, copper oxide and zinc oxide, and the addition amount of the inorganic dehydrating agent is 1-5% of the total weight of the oil-based drilling fluid viscosity reducer.
Alternatively, the maleic anhydride heating temperature is 100-120 ℃.
Alternatively, the reaction time of the para-aminophenol solution and the reactant is 3 to 7 hours.
Optionally, the inorganic dehydrating agent is zinc oxide ZnO, and the addition amount is 1-5% of the total weight of the oil-based drilling fluid viscosity reducer preparation ingredients.
Alternatively, the molar ratio of maleic anhydride to para-aminophenol is 1:0.5 to 2.
The invention further provides an oil-based drilling fluid viscosity reducer, which is prepared by the method.
In still another aspect, the present invention provides a method for using an oil-based drilling fluid viscosity reducer, where the viscosity reducer is prepared by the above method, and the method includes: and directly adding the viscosity reducer into the old slurry of the oil-based drilling fluid.
Optionally, the using method further comprises: firstly, dissolving the viscosity reducer into white oil or diesel oil, and adding the viscosity reducer into the old slurry of the oil-based drilling fluid in a conventional drilling fluid glue solution mode.
Compared with the prior art, the invention has the beneficial effects that at least one of the following contents is included:
1) The viscosity reducer can reduce the viscosity of old slurry of oil-based drilling fluid used for multiple times, thereby being applicable to the requirement of new drilling.
2) In the synthesis process, harmful substances such as formaldehyde and the like are not used, and the synthesis process is safer and more environment-friendly.
Detailed Description
Hereinafter, the oil-based drilling fluid viscosity reducer and the method of preparing and using the same of the present invention will be described in detail with reference to exemplary embodiments.
Example embodiment 1
The exemplary embodiment provides a preparation method of an oil-based drilling fluid viscosity reducer, which comprises the following steps:
s10: the para-aminophenol is dissolved into a first catalyst to form a para-aminophenol solution.
In this embodiment, p-aminophenol is dissolved in a first catalyst to form a p-aminophenol solution for use, where the first catalyst may be an organic dehydrating agent, including dimethylformamide; the addition amount of the viscosity reducer can be 15% -35% of the total weight of the oil-based drilling fluid viscosity reducer, such as 16%, 20% or 34%.
S20: and (3) heating maleic anhydride to 70-150 ℃, adding a second catalyst and introducing protective gas to form maleic anhydride reactant.
In this example, a certain amount of maleic anhydride was added to a three-necked flask equipped with a mechanical stirring device, a condenser tube and a constant pressure dropping funnel, heated to 70 to 150 ℃, and then a second catalyst was added to introduce a shielding gas to form maleic anhydride reactant. The shielding gas can be nitrogen, etc., and the purpose of introducing the shielding gas is to remove oxygen and isolate air. The heating temperature can be 71 ℃, 80 ℃, 100 ℃, 130 ℃ or 149 ℃ and the like, and the temperature range is favorable for dissolving maleic anhydride; the second catalyst may be an inorganic dehydrating agent comprising iron oxide Fe 2 O 3 A mixture of one or more of cobalt oxide CoO, nickel oxide NiO, copper oxide CuO, and zinc oxide ZnO. Among them, zinc oxide ZnO is preferred because ZnO has a relatively high dehydration rate.
In this embodiment, the maleic anhydride may be heated at a temperature of 100 to 120 ℃, such as 101 ℃, 110 ℃, 119 ℃ or the like, which may boil water to facilitate water removal.
S30: the para-aminophenol solution was trickled into the reactants under stirring and condensing conditions to react until a brown viscous product formed.
In the embodiment, the para-aminophenol solution is filled into a constant pressure dropping funnel, and is added into the reactant in a trickling mode under the conditions of low-speed stirring of 200-500 rpm and tap water condensation for reacting for a period of time until a brown viscous product is obtained, wherein the brown viscous product is the viscosity reducer of the oil-based drilling fluid. The reaction time may be 3 to 7 hours, for example 4 hours, 5 hours or 6 hours, etc., and the above reaction time is set to be advantageous in reducing the production of reaction by-products. When the reaction time is 5 to 6 hours, the amount of reaction by-products produced is less, and preferably, the trickle reaction time may be 5 to 6 hours.
In this example, the molar ratio of maleic anhydride to para-aminophenol added may be 1:0.5 to 2, for example 1:0.6, 1:0.9, 1:1.5 or 1:1.9, etc., the reaction proportion is favorable for generating the target viscosity reducer, and the yield is higher. Preferably, the molar ratio of maleic anhydride to para-aminophenol added may be 1:1 to 1.5, the conversion rate of the proportional reaction is higher, which is beneficial to more reactants to generate the viscosity reducer.
In this example, the molar ratio of para-aminophenol and dimethylformamide added may be 1:0.3 to 1.5, for example 1:0.4, 1:0.7, 1:0.9 or 1:1.3, etc., the reaction ratio has the best dehydration effect and higher dehydration rate. Preferably, the molar ratio of para-aminophenol to dimethylformamide added may be 1: and 0.7 to 0.9, the dehydration reaction is thoroughly carried out in the proportion, so that the reaction between reactants is more sufficient. In addition, the mixing ratio between maleic anhydride and zinc oxide has a certain influence on the synthesis reaction, and in this embodiment, the molar ratio of maleic anhydride to zinc oxide added may be 1:0.05 to 0.5, for example 1:0.08, 1:0.1, 1:0.2 or 1:0.4, etc., which is favorable for the main reaction and can improve the synthesis yield of the viscosity reducer. Preferably, the molar ratio of maleic anhydride and zinc oxide added may be 1:0.1 to 0.3, the proportion can avoid the progress of side reaction, reduce the yield of byproducts, and further improve the synthesis rate of target products.
Example embodiment 2
The present exemplary embodiment provides a viscosity reducer for oil-based drilling fluids, which is the viscosity reducer prepared by the method described in exemplary embodiment 1.
Example embodiment 3
The present exemplary embodiment provides a method of using the viscosity reducer for oil-based drilling fluids described in exemplary embodiment 2, the method comprising: the viscosity reducer is directly added into the oil-based drilling fluid slurry or is firstly dissolved into white oil or diesel oil and is added into the oil-based drilling fluid slurry in a conventional drilling fluid glue solution mode. The addition amount of the viscosity reducer is not more than 5% of the amount of the oil-based drilling fluid old slurry, and the addition amount of the white oil or the diesel oil is not more than 20% of the amount of the oil-based drilling fluid old slurry.
For a better understanding of the above-described exemplary embodiments of the present invention, they are further described below in conjunction with specific examples.
Example 1
Dissolving 109g of para-aminophenol into 54.5ml of dimethylformamide to form a para-aminophenol solution for later use; adding 98g of maleic anhydride into a three-neck flask provided with a mechanical stirring, a condensing tube and a constant pressure dropping funnel, heating to 100 ℃, adding 10.35g of inorganic dehydrating agent zinc oxide ZnO, and introducing nitrogen to protect to form a reactant; and (3) filling the p-aminophenol solution into a constant-pressure dropping funnel, adding the p-aminophenol solution into the reactant in a trickling mode under stirring and condensing conditions, and reacting for 5 hours to obtain a brown viscous product which is the oil-based drilling fluid 1# viscosity reducer.
Example 2
120g of para-aminophenol is dissolved in 60ml of dimethylformamide to form a para-aminophenol solution for standby; adding 90g of maleic anhydride into a three-neck flask provided with a mechanical stirring, a condensing tube and a constant pressure dropping funnel, heating to 110 ℃, adding 10.5g of inorganic dehydrating agent zinc oxide ZnO, and introducing nitrogen to protect to form a reactant; and (3) filling the p-aminophenol solution into a constant-pressure dropping funnel, adding the p-aminophenol solution into the reactant in a trickling mode under stirring and condensing conditions, and reacting for 6 hours to obtain a brown viscous product which is the oil-based drilling fluid 2# viscosity reducer.
Example 3
130g of para-aminophenol is dissolved in 65ml of dimethylformamide to form a para-aminophenol solution for standby; adding 90g of maleic anhydride into a three-neck flask provided with a mechanical stirring, a condensing tube and a constant pressure dropping funnel, heating to 120 ℃, adding 11g of inorganic dehydrating agent zinc oxide ZnO, and introducing nitrogen to protect to form a reactant; and (3) filling the p-aminophenol solution into a constant-pressure dropping funnel, adding the p-aminophenol solution into the reactant in a trickling mode under stirring and condensing conditions, and reacting for 6 hours to obtain a brown viscous product which is the oil-based drilling fluid 3# viscosity reducer.
Experimental example
Viscosity reduction performance evaluation method 1
350mL of oil-based drilling fluid which is used repeatedly is measured, 1% of viscosity reducer is added, the mixture is stirred for 20min at high speed under the condition of 10000 revolutions per minute, and the apparent viscosity AV is measured by adopting a six-speed viscometer 1 And dynamic shear force YP 1 Apparent viscosity AV of oil-based drilling fluid which is used for multiple times without viscosity reducer 0 And dynamic shear force YP 0 The performance was compared. After aging for 16 hours at a certain temperature, the apparent viscosity AV of the oil-based drilling fluid which is repeatedly used after the viscosity reducer is added is measured again 3 And dynamic shear force YP 3 And the apparent viscosity AV of the oil-based drilling fluid which is used for multiple times without adding viscosity reducer after aging 2 And dynamic shear force YP 2 By contrast, the apparent viscosity and the reduction rate R of the dynamic shear force were calculated according to the formulas (1), (2), (3) and (4), respectively, and the higher the reduction rate, the better the effect.
Viscosity reduction performance evaluation method 2
Weighing 1% of viscosity reducer according to the mass of 350mL of the repeatedly used oil-based drilling fluid, dissolving the viscosity reducer into 50mL of white oil, adding the white oil with the viscosity reducer dissolved into 350mL of the repeatedly used oil-based drilling fluid, and performing speed conditions of 10000 revolutions per minuteStirring at high speed for 20min, and measuring apparent viscosity AV with six-speed viscometer 5 And dynamic shear force YP 5 And with apparent viscosity AV of a multi-use oil-based drilling fluid with white oil only 4 And dynamic shear force YP 4 The performance was compared. After aging for 16 hours at a certain temperature, the apparent viscosity AV of the multi-use oil-based drilling fluid of the white oil added with the dissolution viscosity reducer is measured again 6 And dynamic shear force YP 6 And the apparent viscosity AV of the oil-based drilling fluid which is used for multiple times by adding only 50ml of white oil after aging 7 And dynamic shear force YP 7 By contrast, the apparent viscosity and the dynamic shear force reduction rate R were calculated according to the formulas (5), (6), (7) and (8), respectively, and the higher the reduction rate, the better the effect.
Experimental example 1
350ml of repeatedly used No. 1 oil-based drilling fluid is added with 3.5g of the No. 1 viscosity reducer prepared in the example 1, stirred at a high speed for 20min under the condition of 10000 revolutions per minute, and the apparent viscosity AV is measured by a six-speed viscometer 1 And dynamic shear force YP 1 Apparent viscosity AV of No. 1 oil-based drilling fluid which is used for multiple times without adding No. 1 viscosity reducer 0 And dynamic shear force YP 0 The performance was compared.
After aging for 16 hours at 120 ℃ respectively, the apparent viscosity AV of the oil-based drilling fluid 1 added with the viscosity reducer for multiple use is measured again 3 And dynamic shear force YP 3 And reducing viscosity with no 1 #)Apparent viscosity AV of No. 1 oil-based drilling fluid with multiple agent use 2 And dynamic shear force YP 2 For comparison, the apparent viscosity and the viscosity reduction rate R of the dynamic shear force were calculated, and the measurement results are shown in Table 1.
Table 1 evaluation of viscosity reduction properties of oil-based drilling fluids
The rheological parameters of the No. 1 oil-based drilling fluid before and after the No. 1 viscosity reducer is added are compared as shown in the table 1, so that the apparent viscosity and the dynamic shear force reduction rate of the No. 1 oil-based drilling fluid are more than 50% when the oil-based drilling fluid is not aged; after aging at 120 ℃, the apparent viscosity and the dynamic shear force reduction rate are slightly increased to more than 60% compared with that of the unaged viscosity reducer, which shows that the synthesized viscosity reducer has certain viscosity reducing effect and temperature resistance.
Weighing 3.5g of the No. 1 viscosity reducer in example 1, dissolving the No. 1 viscosity reducer into 50mL of white oil, adding the white oil with the No. 1 viscosity reducer dissolved into 350mL of multi-use No. 1 oil-based drilling fluid, stirring at high speed for 20min at 10000 revolutions per minute, and measuring apparent viscosity AV by adopting a six-speed viscometer 5 And dynamic shear force YP 5 And the apparent viscosity AV of the oil-based drilling fluid which is used for multiple times by only adding white oil 4 And dynamic shear force YP 4 The performance was compared.
After aging for 16 hours at 120 ℃ respectively, the apparent viscosity AV of the multi-use No. 1 oil-based drilling fluid added with the white oil dissolved with the viscosity reducer is measured again 6 And dynamic shear force YP 6 And the apparent viscosity AV of the oil-based drilling fluid 1 which is used for multiple times and is added with the white oil with the quantity of only 50ml 7 And dynamic shear force YP 7 For comparison, the apparent viscosity and the viscosity reduction rate R of the dynamic shear force were calculated, and the measurement results are shown in Table 2.
Table 2 evaluation of viscosity reduction properties of oil-based drilling fluids
In the experiment, the No. 1 viscosity reducer is dissolved in white oil and added into the No. 1 oil-based drilling fluid in a micelle mode, and as can be seen from Table 2, the reduction rate of the dynamic shear force of the oil-based drilling fluid before aging is 57 percent slightly higher than that of the viscosity reducer which is directly added into the drilling fluid; the reduction rate of apparent viscosity after high-temperature aging is close to 70%, and the fact that the viscosity reducer is added in a micelle form can generate a better viscosity reducing effect is proved.
Experimental example 2
350ml of a multi-use No. 2 oil-based drilling fluid is added with 3.5g of the No. 2 viscosity reducer prepared in the example 2, stirred at a high speed for 20min under the condition of 10000 revolutions per minute, and the apparent viscosity AV is measured by a six-speed viscometer 1 And dynamic shear force YP 1 Apparent viscosity AV of No. 2 oil-based drilling fluid which is used for multiple times without adding No. 2 viscosity reducer 0 And dynamic shear force YP 0 The performance was compared.
After aging for 16 hours at 120 ℃, the apparent viscosity AV of the oil-based drilling fluid No. 2 added with the viscosity reducer for multiple use is measured again 3 And dynamic shear force YP 3 Apparent viscosity AV of No. 2 oil-based drilling fluid which is used for multiple times without adding No. 2 viscosity reducer 2 And dynamic shear force YP 2 For comparison, the apparent viscosity and the viscosity reduction rate R of the dynamic shear force were calculated, and the measurement results are shown in Table 3.
Table 3 evaluation of viscosity reduction properties of oil-based drilling fluids
As can be seen from table 3, the rheological parameters of the drilling fluid system were improved by adding the # 2 viscosity reducer to the # 2 oil-based drilling fluid. Before aging, the apparent viscosity reduction rate of the oil-based drilling fluid is 53% and the dynamic shear force reduction rate is 55% before and after the viscosity reducer is added; after aging, the apparent viscosity reduction rate of the oil-based drilling fluid is 60%, and the dynamic shear force reduction rate is 63%. The viscosity reduction performance after aging is more pronounced than before aging.
Weighing 3.5g of No. 2 viscosity reducer, dissolving the No. 2 viscosity reducer into 50mL of white oil, and adding the white oil dissolved with the No. 2 viscosity reducer into 350mL of multi-use No. 2 oil-based drilling fluidStirring at 10000 rpm for 20min, and measuring apparent viscosity AV with six-speed viscometer 5 And dynamic shear force YP 5 And the apparent viscosity AV of the oil-based drilling fluid which is used for multiple times by only adding white oil 4 And dynamic shear force YP 4 The performance was compared.
After aging at 120 ℃ for 16 hours, the apparent viscosity AV of the multi-use No. 2 oil-based drilling fluid added with the white oil dissolved with the viscosity reducer is measured again 6 And dynamic shear force YP 6 And the apparent viscosity AV of the No. 2 oil-based drilling fluid which is used for a plurality of times by adding 50ml of white oil 7 And dynamic shear force YP 7 For comparison, the apparent viscosity and the viscosity reduction rate R of the dynamic shear force were calculated, and the measurement results are shown in Table 4.
Table 4 evaluation of viscosity reduction properties of oil-based drilling fluids
And 50mL of white oil is added into the No. 2 oil-based drilling fluid, and compared with the No. 2 oil-based drilling fluid without the white oil, the apparent viscosity and the dynamic shear force are obviously reduced before and after aging, and the performance of the drilling fluid system is primarily regulated. In addition, the addition mode of the viscosity reducer is changed from direct addition to micelle addition dissolved in white oil, and as can be seen from Table 4, after the viscosity reducer is added, the dynamic shear force reduction rate of the oil-based drilling fluid before aging is close to 60%; after the temperature is 120 ℃, the apparent viscosity reduction rate is close to 70%, which shows that the viscosity reducer is added in a micelle mode to have better effect.
Experimental example 3
350ml of repeatedly used No. 3 oil-based drilling fluid is added with 3.5g of the No. 3 viscosity reducer prepared in the example 3, stirred at high speed for 20min under the condition of 10000 revolutions per minute, and the apparent viscosity AV is measured by adopting a six-speed viscometer 1 And dynamic shear force YP 1 Apparent viscosity AV of No. 3 oil-based drilling fluid which is used for multiple times without adding No. 3 viscosity reducer 0 And dynamic shear force YP 0 The performance was compared.
After aging for 16 hours at 120 ℃, the apparent viscosity of the No. 3 oil-based drilling fluid added with the viscosity reducer for multiple use is measured againAV 3 And dynamic shear force YP 3 Apparent viscosity AV of No. 3 oil-based drilling fluid which is used for multiple times without adding No. 3 viscosity reducer 2 And dynamic shear force YP 2 For comparison, the apparent viscosity and the viscosity reduction rate R of the dynamic shear force were calculated, and the measurement results are shown in Table 5.
Table 5 evaluation of viscosity reduction properties of oil-based drilling fluids
As can be seen from table 5, the rheological properties are significantly improved after the addition of the # 3 viscosity reducer to the No. 3 oil-based drilling fluid. Testing under the unaged condition, the apparent viscosity reduction rate is 55%, and the dynamic shear force reduction rate is 52%; after aging for 16 hours at 120 ℃, the apparent viscosity and the dynamic shear reduction rate are both over 60 percent. The synthetic 3# viscosity reducer has viscosity reducing capability and temperature resistance, and has the property of regulating and controlling rheological parameters of oil-based drilling fluid.
Weighing 3.5g of 3# viscosity reducer, dissolving into 50mL of white oil, adding the white oil dissolved with the 3# viscosity reducer into 350mL of repeatedly used 3# oil-based drilling fluid, stirring at 10000 revolutions per minute for 20min at high speed, and measuring apparent viscosity AV by adopting a six-speed viscometer 5 And dynamic shear force YP 5 And the apparent viscosity AV of the oil-based drilling fluid which is used for multiple times by only adding white oil 4 And dynamic shear force YP 4 The performance was compared.
After aging at 120℃for 16h, the apparent viscosity AV was determined again 6 And dynamic shear force YP 6 And the apparent viscosity AV of the No. 3 oil-based drilling fluid which is used for a plurality of times by adding 50ml of white oil 7 And dynamic shear force YP 7 For comparison, the apparent viscosity and the viscosity reduction rate R of the dynamic shear force were calculated, and the measurement results are shown in Table 6.
Table 6 evaluation of viscosity reduction properties of oil-based drilling fluids
From Table 6, the rheological property of the No. 3 oil-based drilling fluid added with the white oil is better, the No. 3 viscosity reducer is dissolved in the white oil and added into the drilling fluid in a micelle mode, the rheological property of the system is obviously changed, the apparent viscosity reduction rate of the drilling fluid is close to 60% before aging, and the dynamic shear force reduction rate is 56%; after high-temperature aging, the apparent viscosity was reduced by 62% and the dynamic shear force was reduced by 58%. Compared with the prior and subsequent aging, the reduction effect after aging is slightly improved, and the apparent viscosity and the dynamic shear force value of the drilling fluid system after the addition of the micelle are most reasonable.
Although the invention has been described above in connection with exemplary embodiments, it will be apparent to those of ordinary skill in the art that various modifications can be made to the above-described embodiments without departing from the spirit and scope of the claims.
Claims (10)
1. A method for preparing an oil-based drilling fluid viscosity reducer, which is characterized by comprising the following steps:
dissolving para-aminophenol into a first catalyst to form a para-aminophenol solution;
heating maleic anhydride to 70-150 ℃, then adding a second catalyst and introducing protective gas to form maleic anhydride reactant;
the reaction was carried out by dropping a stream of para-aminophenol solution into the reactants under stirring and condensing conditions until a brown viscous product formed.
2. The method according to claim 1, wherein the first catalyst is an organic dehydrating agent and the second catalyst is an inorganic dehydrating agent.
3. The preparation method of claim 2, wherein the organic dehydrating agent is dimethylformamide, and the addition amount is 15% -35% of the total weight of the oil-based drilling fluid viscosity reducer ingredients;
the inorganic dehydrating agent comprises one or more of ferric oxide, cobalt oxide, nickel oxide, copper oxide and zinc oxide, and the addition amount of the inorganic dehydrating agent is 1-5% of the total weight of the oil-based drilling fluid viscosity reducer ingredients.
4. The process according to claim 1, wherein the maleic anhydride is heated at a temperature of 100 to 120 ℃.
5. The method of claim 1, wherein the reaction time of the para-aminophenol solution with the reactants is 3 to 7 hours.
6. The preparation method of claim 2, wherein the inorganic dehydrating agent is zinc oxide ZnO, and the addition amount is 1% -5% of the total weight of the oil-based drilling fluid viscosity reducer preparation.
7. The method according to claim 1, wherein the molar ratio of maleic anhydride to p-aminophenol is 1:0.5 to 2.
8. An oil-based drilling fluid viscosity reducer, characterized in that the viscosity reducer is prepared by the method of any one of claims 1-7.
9. A method of using an oil-based drilling fluid viscosity reducer, wherein the viscosity reducer is prepared by the method of any one of claims 1-7, the method comprising: and directly adding the viscosity reducer into the old slurry of the oil-based drilling fluid.
10. The method of use of claim 9, further comprising: firstly, dissolving the viscosity reducer into white oil or diesel oil, and adding the viscosity reducer into the old slurry of the oil-based drilling fluid in a conventional drilling fluid glue solution mode.
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