CN113136180B - High-temperature-resistant waterproof locking agent for drilling fluid - Google Patents
High-temperature-resistant waterproof locking agent for drilling fluid Download PDFInfo
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- CN113136180B CN113136180B CN202110542797.8A CN202110542797A CN113136180B CN 113136180 B CN113136180 B CN 113136180B CN 202110542797 A CN202110542797 A CN 202110542797A CN 113136180 B CN113136180 B CN 113136180B
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- 239000012530 fluid Substances 0.000 title claims abstract description 56
- 238000005553 drilling Methods 0.000 title claims abstract description 54
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- 229920000570 polyether Polymers 0.000 claims abstract description 54
- 150000002191 fatty alcohols Chemical class 0.000 claims abstract description 45
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 41
- -1 alkyl glycoside quaternary ammonium salt Chemical class 0.000 claims abstract description 39
- 229930182470 glycoside Natural products 0.000 claims abstract description 31
- KFZMGEQAYNKOFK-UHFFFAOYSA-N Isopropanol Chemical compound CC(C)O KFZMGEQAYNKOFK-UHFFFAOYSA-N 0.000 claims description 60
- 239000007864 aqueous solution Substances 0.000 claims description 45
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 30
- 239000008367 deionised water Substances 0.000 claims description 30
- 229910021641 deionized water Inorganic materials 0.000 claims description 30
- 238000000034 method Methods 0.000 claims description 18
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- 229910052757 nitrogen Inorganic materials 0.000 claims description 15
- LTVDFSLWFKLJDQ-UHFFFAOYSA-N α-tocopherolquinone Chemical compound CC(C)CCCC(C)CCCC(C)CCCC(C)(O)CCC1=C(C)C(=O)C(C)=C(C)C1=O LTVDFSLWFKLJDQ-UHFFFAOYSA-N 0.000 claims description 15
- 238000010438 heat treatment Methods 0.000 claims description 14
- PYIDGJJWBIBVIA-UYTYNIKBSA-N lauryl glucoside Chemical compound CCCCCCCCCCCCO[C@@H]1O[C@H](CO)[C@@H](O)[C@H](O)[C@H]1O PYIDGJJWBIBVIA-UYTYNIKBSA-N 0.000 claims description 12
- 229930182478 glucoside Natural products 0.000 claims description 10
- 125000000217 alkyl group Chemical group 0.000 claims description 9
- JDRSMPFHFNXQRB-IBEHDNSVSA-N decyl glucoside Chemical compound CCCCCCCCCCO[C@@H]1O[C@H](CO)[C@@H](O)[C@H](O)[C@H]1O JDRSMPFHFNXQRB-IBEHDNSVSA-N 0.000 claims description 2
- HEGSGKPQLMEBJL-RKQHYHRCSA-N octyl beta-D-glucopyranoside Chemical compound CCCCCCCCO[C@@H]1O[C@H](CO)[C@@H](O)[C@H](O)[C@H]1O HEGSGKPQLMEBJL-RKQHYHRCSA-N 0.000 claims description 2
- 239000000243 solution Substances 0.000 claims description 2
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- 239000004094 surface-active agent Substances 0.000 description 6
- GVNVAWHJIKLAGL-UHFFFAOYSA-N 2-(cyclohexen-1-yl)cyclohexan-1-one Chemical compound O=C1CCCCC1C1=CCCCC1 GVNVAWHJIKLAGL-UHFFFAOYSA-N 0.000 description 4
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- 239000000693 micelle Substances 0.000 description 3
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- MWKFXSUHUHTGQN-UHFFFAOYSA-N n-decyl alcohol Natural products CCCCCCCCCCO MWKFXSUHUHTGQN-UHFFFAOYSA-N 0.000 description 3
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- 239000012528 membrane Substances 0.000 description 2
- ONJQDTZCDSESIW-UHFFFAOYSA-N polidocanol Chemical compound CCCCCCCCCCCCOCCOCCOCCOCCOCCOCCOCCOCCOCCO ONJQDTZCDSESIW-UHFFFAOYSA-N 0.000 description 2
- 239000011148 porous material Substances 0.000 description 2
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- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical group [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 1
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- 230000007547 defect Effects 0.000 description 1
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- 150000008131 glucosides Chemical class 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 239000001257 hydrogen Substances 0.000 description 1
- 229910052739 hydrogen Inorganic materials 0.000 description 1
- 125000002887 hydroxy group Chemical group [H]O* 0.000 description 1
- 239000007791 liquid phase Substances 0.000 description 1
- 230000007774 longterm Effects 0.000 description 1
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- 238000012544 monitoring process Methods 0.000 description 1
- 229920000056 polyoxyethylene ether Polymers 0.000 description 1
- 229940051841 polyoxyethylene ether Drugs 0.000 description 1
- 229920000136 polysorbate Polymers 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 150000003242 quaternary ammonium salts Chemical class 0.000 description 1
- 238000005956 quaternization reaction Methods 0.000 description 1
- 239000002994 raw material Substances 0.000 description 1
- 238000005185 salting out Methods 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 238000012216 screening Methods 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 239000003079 shale oil Substances 0.000 description 1
- 238000002791 soaking Methods 0.000 description 1
- 238000011895 specific detection Methods 0.000 description 1
- 208000027301 sporadic infantile bilateral striatal necrosis Diseases 0.000 description 1
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- 239000012085 test solution Substances 0.000 description 1
- HLZKNKRTKFSKGZ-UHFFFAOYSA-N tetradecan-1-ol Chemical compound CCCCCCCCCCCCCCO HLZKNKRTKFSKGZ-UHFFFAOYSA-N 0.000 description 1
- 238000011282 treatment Methods 0.000 description 1
Classifications
-
- 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
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
- Y02P20/00—Technologies relating to chemical industry
- Y02P20/141—Feedstock
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- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Polyethers (AREA)
- Emulsifying, Dispersing, Foam-Producing Or Wetting Agents (AREA)
Abstract
The invention belongs to the technical field of oil and gas drilling and discloses a high-temperature-resistant waterproof locking agent for drilling fluid. The high-temperature resistant waterproof locking agent provided by the invention has the advantages that the mutual synergistic effect of the fatty alcohol block polyether and the alkyl glycoside quaternary ammonium salt enables the obtained waterproof locking agent to effectively prevent and remove water locking damage and improve the yield of low-permeability and compact oil and gas reservoirs; meanwhile, the high temperature resistance of the waterproof locking agent provided by the invention can reach more than 150 ℃, the performance is stable after long-time high-temperature aging, the foaming rate is low, and the on-site use requirement of the working solution can be met.
Description
Technical Field
The invention belongs to the technical field of oil and gas drilling, and relates to a high-temperature-resistant waterproof locking agent for drilling fluid.
Background
In the development process of low-permeability oil and gas fields, in the processes of drilling, well completion, fracturing and the like, contact with external fluid cannot be avoided, the pore throat of a reservoir is very small, the capillary action is large, the external fluid can enter the deep part of the reservoir, the invaded fluid cannot be completely discharged by the pressure of the formation alone, the water saturation of the reservoir is increased, and the relative permeability of oil and gas is greatly reduced, so that water lock is caused. Water lock damage is a main damage factor of low-permeability oil and gas reservoirs, compact oil and gas reservoirs and shale oil and gas reservoirs, and the development efficiency of the oil and gas reservoirs is seriously influenced. Therefore, reducing the water lock effect is an important measure for protecting low-pore, low-permeability hydrocarbon reservoirs.
The water-proof locking agent for the drilling fluid is an important additive used in a drilling fluid system, and prevents the drilling fluid filtrate from invading a stratum to cause water locking by reducing the surface tension of the drilling fluid filtrate. The current water-blocking agents are generally one of the treatments developed based on surfactants, such as ABS, OP-10, ABSN, 1231, TWEEN, etc. Because the environmental temperature of the general drilling fluid is mostly higher than 120 ℃, the ambient temperature is partially even higher than 200 ℃ and the action time generally exceeds 24 hours, and the action time is dozens of days, the drilling fluid treating agent is required to resist high temperature for a long time, and simultaneously, because the drilling fluid operation has high requirement on the stability of the liquid density, the treating agent is required to be low-foamed or non-foamed.
Most of the surfactants used for the waterproof locking agent at present have the defects of poor temperature resistance effect and ineffective effect after long-term aging, and most of the surfactants have high foaming rate, and the application of the surfactants in drilling fluid is limited due to the prominent foaming property of the surfactants such as alkyl glycoside type surfactants.
Disclosure of Invention
The invention aims to solve the technical problems that the existing waterproof locking agent is high in foaming rate, poor in temperature resistance effect and incapable of meeting the field use requirements, and provides a low-foaming and high-temperature-resistant waterproof locking agent for drilling fluid.
In order to solve the technical problems, the technical scheme of the invention is as follows:
the high-temperature resistant waterproof locking agent for the drilling fluid consists of fatty alcohol block polyether and alkyl glycoside quaternary ammonium salt water solution.
The high-temperature resistant waterproof locking agent is mainly prepared by matching fatty alcohol block polyether and alkyl glycoside quaternary ammonium salt, both have excellent biodegradability, and the waterproof locking agent prepared by compounding the fatty alcohol block polyether and the alkyl glycoside quaternary ammonium salt also has excellent biodegradability. According to the invention, the fatty alcohol block polyether and the alkyl glycoside quaternary ammonium salt are compounded, and the block polyether structure is embedded into the hydrophilic group of the alkyl glycoside quaternary ammonium salt, so that the foaming structure of the alkyl glycoside is destroyed, and the foaming effect of the alkyl glycoside quaternary ammonium salt can be effectively reduced; meanwhile, as the fatty alcohol block polyether and the alkyl glycoside quaternary ammonium salt form a mixed micelle, and the alkyl glycoside quaternary ammonium salt is inserted into an interface film of the fatty alcohol block polyether micelle, the surface charge density of the micelle is increased, and the cloud point is obviously increased; with the increase of the content of the fatty alcohol block polyether, shielding is generated between the polar heads of the alkyl glycoside quaternary ammonium salt, so that the temperature resistance effect of the quaternary ammonium salt can be further improved. Meanwhile, because the hydrogen bond function between the hydroxyl groups on the block polyether and the alkyl glycoside is enhanced, the fatty alcohol block polyether and the alkyl glycoside quaternary ammonium salt can play a good synergistic effect, and the surface tension is further reduced.
Preferably, the mass ratio of the fatty alcohol block polyether to the alkyl glycoside quaternary ammonium salt aqueous solution is 3:7-7:3, and more preferably, the mass ratio of the fatty alcohol block polyether to the alkyl glycoside quaternary ammonium salt aqueous solution is 5: 5.
Preferably, the fatty alcohol block polyether has a general structural formula:
wherein, R is C12-C16 alkyl, n is 2-4, and m is 2-4.
Preferably, the fatty alcohol block polyether is selected from, but not limited to, C14 alcohol block polyether, and more preferably the C14 alkyl block polyether includes fatty alcohol block polyether B, fatty alcohol block polyether C, fatty alcohol block polyether D, fatty alcohol block polyether E, wherein:
the structural formula of the fatty alcohol block polyether B is as follows: RO (CH) 2 CH 2 O) 3 (CH 2 CHCH 3 O) 2 H, wherein R is C14 alkyl;
the structural formula of the fatty alcohol block polyether C is as follows: RO (CH) 2 CH 2 O) 3 (CH 2 CHCH 3 O) 3 H, wherein R is C14 alkyl;
the structural formula of the fatty alcohol block polyether D is as follows: RO (CH) 2 CH 2 O) 4 (CH 2 CHCH 3 O) 2 H, wherein R is C14 alkyl;
the structural formula of the fatty alcohol block polyether E is as follows: RO (CH) 2 CH 2 O) 2 (CH 2 CHCH 3 O) 4 H, wherein R is C14 alkyl;
preferably, the alkyl chain length in the alkyl glycoside quaternary ammonium salt is 8-16, preferably C8-C12.
Preferably, the aqueous solution of the alkyl glycoside quaternary ammonium salt is prepared by the following method:
adding alkyl glucoside and 3-chloro-2-hydroxypropyl trimethyl ammonium chloride into a flask, adding isopropanol and deionized water, connecting a stirring device and a condenser tube, introducing nitrogen for replacement twice, heating to 80-85 ℃, reacting for 4 hours, vacuumizing to remove water and isopropanol, and adding deionized water to obtain the alkyl glucoside quaternary ammonium salt aqueous solution.
Preferably, the alkyl glucoside is a C8-C16 glucoside, preferably dodecyl glucoside, n-octyl glucoside, n-decyl glucoside.
Compared with the prior art, the invention has the beneficial effects that:
the high-temperature resistant waterproof locking agent provided by the invention has the advantages that the mutual synergistic effect of the fatty alcohol block polyether and the alkyl glycoside quaternary ammonium salt enables the obtained waterproof locking agent to effectively prevent and remove water locking damage and improve the yield of low-permeability and compact oil and gas reservoirs; meanwhile, the high temperature resistance of the waterproof locking agent provided by the invention can reach more than 150 ℃, the performance is stable after long-time high-temperature aging, the foaming rate is low, and the on-site use requirement of the working solution can be met.
Detailed Description
The following further describes the embodiments of the present invention. It should be noted that the description of the embodiments is provided to help understanding of the present invention, but the present invention is not limited thereto. In addition, the technical features involved in the embodiments of the present invention described below may be combined with each other as long as they do not conflict with each other.
Example 1
The high-temperature-resistant waterproof locking agent for the drilling fluid consists of fatty alcohol block polyether C, APG-A1 aqueous solution according to the mass ratio of 7:3, wherein APG-A1 is prepared by the following method: 0.55mol of n-decanol glucoside (176.24g) and 0.5mol of 3-chloro-2-hydroxypropyl trimethylammonium chloride (94.5g) are added into a 1000ml three-neck flask, 90ml of isopropanol and 90ml of deionized water are added, a stirring device and a condensation tube are connected, nitrogen is introduced for replacement twice, the temperature is increased to 80-85 ℃, reaction is carried out for 4 hours, then, vacuum pumping is carried out to remove water and isopropanol, and 254.27 deionized water is added to prepare a 50% aqueous solution.
Example 2
The high-temperature resistant waterproof locking agent for the drilling fluid is prepared from a fatty alcohol block polyether C, APG-A1 aqueous solution according to a mass ratio of 5:5, wherein the APG-A1 is prepared by the following method: 0.55mol of n-decyl alcohol glucoside (176.24g) and 0.5mol of 3-chloro-2-hydroxypropyl trimethyl ammonium chloride (94.5g) are added into a 1000ml three-neck flask, 90ml of isopropanol and 90ml of deionized water are added, a stirring device and a condensing tube are connected, nitrogen is introduced for replacement twice, the temperature is increased to 80-85 ℃, the reaction is carried out for 4 hours, then, vacuum pumping is carried out to remove water and isopropanol, and 254.27 deionized water is added to prepare a 50% aqueous solution.
Example 3
A high-temperature resistant waterproof locking agent for drilling fluid is prepared from an aliphatic alcohol block polyether C, APG-A1 aqueous solution in a mass ratio of 3:7, wherein the APG-A1 aqueous solution is prepared by the following method: adding 0.55mol of n-decyl alcohol glucoside and 0.5mol of 3-chloro-2-hydroxypropyl trimethyl ammonium chloride into a 1000ml three-neck flask, adding 90ml of isopropanol and 90ml of deionized water, connecting a stirring device and a condenser tube, introducing nitrogen for replacement twice, heating to 80-85 ℃, reacting for 4 hours, vacuumizing to remove water and isopropanol, and adding 254.27 deionized water to prepare a 50% aqueous solution.
Example 4
A high-temperature resistant waterproof locking agent for drilling fluid is prepared from an aliphatic alcohol block polyether C, APG-A2 aqueous solution in a mass ratio of 7:3, wherein the APG-A2 aqueous solution is prepared by the following method: adding 0.55mol of dodecyl glucoside and 0.5mol of 3-chloro-2-hydroxypropyl trimethyl ammonium chloride into a 1000ml three-neck flask, adding 100ml of isopropanol and 100ml of deionized water, connecting a stirring device and a condenser tube, introducing nitrogen for replacement twice, heating to 80-85 ℃, reacting for 4 hours, vacuumizing to remove water and isopropanol, and adding 268.3g of deionized water to prepare a 50% aqueous solution.
Example 5
A high-temperature resistant waterproof locking agent for drilling fluid is prepared from an aliphatic alcohol block polyether C, APG-A2 aqueous solution in a mass ratio of 5:5, wherein the APG-A2 aqueous solution is prepared by the following method: adding 0.55mol of dodecyl glucoside and 0.5mol of 3-chloro-2-hydroxypropyl trimethyl ammonium chloride into a 1000ml three-neck flask, adding 100ml of isopropanol and 100ml of deionized water, connecting a stirring device and a condenser tube, introducing nitrogen for replacement twice, heating to 80-85 ℃, reacting for 4 hours, vacuumizing to remove water and isopropanol, and adding 268.3g of deionized water to prepare a 50% aqueous solution.
Example 6
The high-temperature resistant waterproof locking agent for the drilling fluid is prepared from a fatty alcohol block polyether C, APG-A2 aqueous solution in a mass ratio of (3): 7, wherein the APG-A2 aqueous solution is prepared by the following method: adding 0.55mol of dodecyl glucoside and 0.5mol of 3-chloro-2-hydroxypropyl trimethyl ammonium chloride into a 1000ml three-neck flask, adding 100ml of isopropanol and 100ml of deionized water, connecting a stirring device and a condenser tube, introducing nitrogen for replacement twice, heating to 80-85 ℃, reacting for 4 hours, vacuumizing to remove water and isopropanol, and adding 268.3g of deionized water to prepare a 50% aqueous solution.
Example 7
A high-temperature resistant waterproof locking agent for drilling fluid is prepared from an aliphatic alcohol block polyether B, APG-A2 aqueous solution in a mass ratio of 5:5, wherein the APG-A2 aqueous solution is prepared by the following method: adding 0.55mol of dodecyl glucoside and 0.5mol of 3-chloro-2-hydroxypropyl trimethyl ammonium chloride into a 1000ml three-neck flask, adding 100ml of isopropanol and 100ml of deionized water, connecting a stirring device and a condenser tube, introducing nitrogen for replacement twice, heating to 80-85 ℃, reacting for 4 hours, vacuumizing to remove water and isopropanol, and adding 268.3g of deionized water to prepare a 50% aqueous solution.
Example 8
A high-temperature resistant waterproof locking agent for drilling fluid is prepared from an aliphatic alcohol block polyether D, APG-A2 aqueous solution in a mass ratio of 5:5, wherein the APG-A2 aqueous solution is prepared by the following method: adding 0.55mol of dodecyl glucoside and 0.5mol of 3-chloro-2-hydroxypropyl trimethyl ammonium chloride into a 1000ml three-neck flask, adding 100ml of isopropanol and 100ml of deionized water, connecting a stirring device and a condenser tube, introducing nitrogen for replacement twice, heating to 80-85 ℃, reacting for 4 hours, vacuumizing to remove water and isopropanol, and adding 268.3g of deionized water to prepare a 50% aqueous solution.
Example 9
A high-temperature resistant waterproof locking agent for drilling fluid is prepared from an aliphatic alcohol block polyether E, APG-A2 aqueous solution in a mass ratio of 5:5, wherein the APG-A2 aqueous solution is prepared by the following method: adding 0.55mol of dodecyl glucoside and 0.5mol of 3-chloro-2-hydroxypropyl trimethyl ammonium chloride into a 1000ml three-neck flask, adding 100ml of isopropanol and 100ml of deionized water, connecting a stirring device and a condenser tube, introducing nitrogen for replacement twice, heating to 80-85 ℃, reacting for 4 hours, vacuumizing to remove water and isopropanol, and adding 268.3g of deionized water to prepare a 50% aqueous solution.
Comparative example 1
A waterproof locking agent for drilling fluid is prepared from AEO-3 and APG-A2 aqueous solutions according to a mass ratio of 5:5, wherein the APG-A2 aqueous solution is prepared by the following method: adding 0.55mol of dodecyl glucoside and 0.5mol of 3-chloro-2-hydroxypropyl trimethyl ammonium chloride into a 1000ml three-neck flask, adding 100ml of isopropanol and 100ml of deionized water, connecting a stirring device and a condenser tube, introducing nitrogen for replacement twice, heating to 80-85 ℃, reacting for 4 hours, vacuumizing to remove water and isopropanol, and adding 268.3g of deionized water to prepare a 50% aqueous solution.
Comparative example 2
A waterproof locking agent for drilling fluid is prepared from AEO-5 and APG-A2 aqueous solutions in a mass ratio of 5:5, wherein the APG-A2 aqueous solution is prepared by the following method: adding 0.55mol of dodecyl glucoside and 0.5mol of 3-chloro-2-hydroxypropyl trimethyl ammonium chloride into a 1000ml three-neck flask, adding 100ml of isopropanol and 100ml of deionized water, connecting a stirring device and a condenser tube, introducing nitrogen for replacement twice, heating to 80-85 ℃, reacting for 4 hours, vacuumizing to remove water and isopropanol, and adding 268.3g of deionized water to prepare a 50% aqueous solution.
Comparative example 3
A waterproof locking agent for drilling fluid is prepared from AEO-7 and APG-A2 aqueous solutions in a mass ratio of 5:5, wherein the APG-A2 aqueous solution is prepared by the following method: adding 0.55mol of dodecyl glucoside and 0.5mol of 3-chloro-2-hydroxypropyl trimethyl ammonium chloride into a 1000ml three-neck flask, adding 100ml of isopropanol and 100ml of deionized water, connecting a stirring device and a condenser tube, introducing nitrogen for replacement twice, heating to 80-85 ℃, reacting for 4 hours, vacuumizing to remove water and isopropanol, and adding 268.3g of deionized water to prepare a 50% aqueous solution.
Comparative example 4
A waterproof locking agent for drilling fluid is prepared from AEO-9 and APG-A2 aqueous solutions in a mass ratio of 5:5, wherein the APG-A2 aqueous solution is prepared by the following method: adding 0.55mol of dodecyl glucoside and 0.5mol of 3-chloro-2-hydroxypropyl trimethyl ammonium chloride into a 1000ml three-neck flask, adding 100ml of isopropanol and 100ml of deionized water, connecting a stirring device and a condenser tube, introducing nitrogen for replacement twice, heating to 80-85 ℃, reacting for 4 hours, vacuumizing to remove water and isopropanol, and adding 268.3g of deionized water to prepare a 50% aqueous solution.
Comparative example 5
A waterproof locking agent for drilling fluid is prepared from fatty alcohol block polyether C, APG0810 (solid content is 50%) in a mass ratio of 5:5, the components are mixed.
Comparative example 6
A waterproof locking agent for drilling fluid is prepared from fatty alcohol block polyether C, APG1214 (solid content 50%) in a mass ratio of 5:5 composition
Comparative example 7
A waterproof locking agent for drilling fluid is prepared from AEO-3 and APG0810 (with a solid content of 50%) in a mass ratio of 5: 5.
Analysis of experiments
1 surface tension and foaming Properties test
1.1 test specimens
Dividing the detection sample into a blank control group, an experimental example group and a comparative example group, wherein the blank control group is a raw material group, APG0810, APG1214, APG-A1, APG-A2, AEO-3, AEO-5, AEO-7, AEO-9, fatty alcohol block polyether B, fatty alcohol block polyether C, fatty alcohol block polyether D and fatty alcohol block polyether E; the example groups are the high temperature resistant water-proof locking agents prepared in examples 1-9 respectively; the comparative example groups are the water-blocking agents prepared in comparative examples 1 to 7, respectively.
1.2 test methods
Respectively detecting the samples, wherein the detection comprises the steps of testing the surface tension of the samples before and after aging, and the surface tension is detected by adopting a standard SY/T5370-2018; and (3) detecting the foaming performance of the aged sample, wherein the foaming performance is detected by stirring the sample at a high speed of 1000rpm for 10min and observing the foam height.
1.3 test results
The specific results are shown in table 1, and the data in table 1 show that the foaming performance of the alkyl glycoside quaternary ammonium salt selected by the invention is lower than that of the common alkyl glycoside, the selected fatty alcohol block polyether does not foam, and the fatty alcohol polyoxyethylene ether AEO series products commonly used in the field have certain foaming performance; after the alkyl glycoside quaternary ammonium salt with foaming performance and the fatty alcohol block polyether are compounded, the compounded product does not foam, has a foam inhibition effect and is beneficial to popularization and application of the product in drilling fluid; meanwhile, the data in the table show that although the surface tension of the alkyl glycoside quaternary ammonium salt prepared by the invention is larger and the temperature resistance effect is reduced after quaternization modification compared with that of alkyl glycoside with the same carbon chain, the surface tension of a compound system is reduced and the temperature resistance effect is obviously improved after the alkyl glycoside quaternary ammonium salt is compounded with the fatty alcohol block polyether, which shows that the alkyl glycoside quaternary ammonium salt and the fatty alcohol block polyether have good synergistic interaction.
TABLE 1 surface tension and blistering behavior of samples before and after aging
2 Rolling recovery test
1.1 test specimens
Samples prepared in example 5, comparative example 1, comparative example 5 and comparative example 7 are selected to respectively test the rolling recovery rate in clean water and drilling fluid, wherein the proportion of the samples in the clean water and the drilling fluid is 1 percent, and the formula of the drilling fluid is as follows:
4% soil (diluted with 10% hydrated soil slurry) + 1.0% PAC-LV + 5% SMP (liquid) + 3.0% RSTF + 2.0% SPNH + 3.0% bitumen + 5% KCl + barite (weighted to 1.80 g/cm) 3 )。
1.2 test methods
1) Test solutions were prepared as in table 2.
2) Weighing 50g (accurate to 0.01g) of rock debris which passes through a 2-3.35mm sieve and recording as m 1 Put into an aging tank (with a built-in lining) containing 320mL of test solutionBarrel), tightly covering.
3) And (3) putting the aging tank filled with the sample into a roller heating furnace, and rolling for 16h at 150 ℃.
4) Taking out the aging tank, and cooling to room temperature. And (3) pouring all the liquid and the rock debris in the tank onto a sample separating sieve with the side length of the hole of 0.425mm, and screening for 1min by using tap water.
5) Putting the screened rock debris into a constant-temperature oven at 105 ℃ to be dried for 4h, taking out the rock debris, cooling the rock debris in a drier for 30min, weighing the rock debris (the accuracy is 0.01g), and recording the weight as m 2 And calculating the rock debris rolling recovery rate according to the following formula:
N＝(m 1 -m 2 )/m 1
wherein: n-rock debris rolling recovery rate,%;
m 1 -the mass of rock cuttings before hot rolling, g;
m 2 the mass of the rock debris after the rock debris is dried and has constant weight after hot rolling is finished, g;
1.3 test results
The specific results are shown in table 2, and data in the table show that after the waterproof locking agent product prepared by the invention is added, the rolling recovery rate of rock debris in clear water is greatly improved to 82.32% after the waterproof locking agent product is subjected to hot rolling at 150 ℃, and the rolling recovery rate in drilling fluid is improved to 94.55%, which shows that the formula product of the invention has excellent temperature resistance effect and shale inhibition effect.
TABLE 2 Rolling recovery of different samples at 150 deg.C
| The contents of the formula | Rolling recovery at 150 ℃/%) | |
| Clean water | 32.65 | |
| Clear water + 1% formula 1 | Fatty alcohol block polyether C: APG-a2 ═ 5:5 | 82.32 |
| Clear water + 1% formula 2 | AEO-3：APG-A2＝5:5 | 78.53 |
| Clear water + 1% formula 3 | Fatty alcohol block polyether C: APG0810 ═ 5:5 | 44.26 |
| Clean water + 1% formula 4 | AEO-3:APG0810＝5:5 | 42.16 |
| Drilling fluid | 75.09 | |
| Drilling fluid + 1% formulation 1 | Fatty alcohol block polyether C: APG-a2 ═ 5:5 | 94.55 |
| Drilling fluid + 1% formula 2 | AEO-3：APG-A2＝5:5 | 91.21 |
| Drilling fluid + 1% formula 3 | Fatty alcohol block polyether C: AP (Access Point)G0810＝5:5 | 80.27 |
| Drilling fluid + 1% formula 4 | AEO-3:APG0810＝5:5 | 80.34 |
3 permeability recovery value data test
1.1 test specimens
The samples prepared in example 5, comparative example 1, comparative example 5 and comparative example 7 are used as experimental examples, a commercially available product (a waterproof locking agent manufactured by a certain company, a product code of FSS-1) is used as a blank example, and the permeability recovery value of the samples in the drilling fluid is tested, wherein the proportion of the samples in clear water and the drilling fluid is 1%, and the formula of the drilling fluid is as follows: 4% soil (diluted with 10% hydrated soil slurry) + 1.0% PAC-LV + 5% SMP (liquid) + 3.0% RSTF + 2.0% SPNH + 3.0% bitumen + 5% KCl + barite (weighted to 1.80 g/cm) 3 )。
1.2 test methods
1) Selecting a rock core and establishing an initial water saturation Swi;
2) determination of the reference permeability:
and (4) sealing the rock core with the Swi, and storing the rock core in a shade place for 24 hours to ensure that the established saturation is uniformly distributed in the rock core. Filling the rock core with evenly distributed saturation into a holder, setting the confining pressure to be 7MPa, the pressure gradient to be 0.3MPa/cm, and measuring the reference permeability before water phase trapping damage under the back pressure of 1 MPa;
3) capillary spontaneous imbibition experiment:
after the reference permeability is measured, starting to develop a capillary spontaneous imbibition experiment of the rock core, and dividing the capillary spontaneous imbibition experiment under the near balance and a forced imbibition experiment under the positive pressure difference of 3.5MPa according to the liquid inlet pressure difference, wherein the forced imbibition experiment under the positive pressure difference of 3.5MPa is completed in a holder, an experiment fluid is pumped into the rock core through a constant pressure pump, the confining pressure is set to be 7MPa, and the capillary spontaneous imbibition experiment comprises the following steps:
firstly, selecting a rock sample and measuring basic parameters of the rock sample, preparing experimental fluid, connecting a device, turning on an electronic balance power supply, correcting and resetting the balance, turning on a spontaneous imbibition regulation program to check the spontaneous imbibition program, and inputting correct parameters;
suspending the rock sample under a balance, and recording the weight of the rock sample before water absorption;
thirdly, adjusting the height of the base plate, injecting spontaneous seepage liquid into the base plate, soaking the outlet end of the rock sample in the spontaneous seepage liquid for 2-3 mm, and starting to acquire data;
fourthly, after spontaneous imbibition is carried out for about 16 hours, ending the experiment, exiting the spontaneous imbibition procedure, processing the experiment data, and properly storing the rock sample. (spontaneous imbibition 16h, probably because of the evaporation of free water, cause the salt water absorbed into the core to produce the supersaturation phenomenon, thus produce salting-out (scaling) and stop up and stack on the water phase circle block plug during the back flooding. therefore, need to seal the membrane for imbibition experiment, the core after the imbibition experiment should be sealed with the membrane too);
4) liquid phase flow back experiment
Carrying out a gas drive water phase flowback experiment on the self-absorbed experimental rock sample, monitoring pressure and flow by using a computer, keeping pressure setting consistent with a reference permeability test, carrying out flowback time of about 7-24 h, taking out and weighing every 20min within 2h before flowback, taking out and weighing every 1h after 2h, measuring the weight of the experimental rock sample after flowback is finished, and measuring the permeability recovery rate of the flowback rock core.
1.3 test results
The specific detection results are shown in table 3, and the data in table 3 show that the permeability recovery rate of the preferable formula product reaches 92.32%, and the preferable formula product is obviously superior to the commercially available product, so that the formula product has good reservoir protection characteristics, has an obvious waterproof lock effect, and achieves the purpose of reservoir protection.
TABLE 3 Permeability recovery in drilling fluids for different formulations
| The contents of the formula | Permeability recovery/% | |
| Drilling fluid + 1% example 5 | Fatty alcohol block polyether C: APG-a2 ═ 5:5 | 92.32 |
| Drilling fluid + 1% comparative example 1 | AEO-3：APG-A2＝5:5 | 84.75 |
| Drilling fluid + 1% comparative example 5 | Fatty alcohol block polyether C: APG0810 ═ 5:5 | 76.24 |
| Drilling fluid + 1% comparative example 7 | AEO-3:APG0810＝5:5 | 70.25 |
| Drilling fluid + 1% of commercial product | Commercially available product | 90.01 |
The foregoing is considered as illustrative of the preferred embodiments of the invention, and is provided solely for the purpose of facilitating an understanding of the principles of the embodiments; meanwhile, for a person skilled in the art, according to the present embodiment, there may be a change in the specific implementation and application scope, and in summary, the present disclosure should not be construed as a limitation to the present invention.
Claims (2)
1. The high-temperature-resistant waterproof locking agent for the drilling fluid is characterized by comprising the following components in parts by weight: the high-temperature resistant waterproof locking agent consists of fatty alcohol block polyether and alkyl glycoside quaternary ammonium salt aqueous solution;
the mass ratio of the fatty alcohol block polyether to the alkyl glycoside quaternary ammonium salt water solution is 3:7-7: 3;
the general structural formula of the fatty alcohol block polyether is as follows:
wherein R is C14 alkyl, n =2-4, m = 2-4;
the mass concentration of the alkyl glycoside quaternary ammonium salt aqueous solution is 50%;
the chain length of the alkyl group in the alkyl glycoside quaternary ammonium salt is 8-16;
the alkyl glycoside quaternary ammonium salt aqueous solution is prepared by the following method: adding alkyl glucoside and 3-chloro-2-hydroxypropyl trimethyl ammonium chloride into a flask, adding isopropanol and deionized water, connecting a stirring device and a condenser tube, introducing nitrogen for replacement twice, heating to 80-85 ℃, reacting for 4 hours, vacuumizing to remove water and isopropanol, and adding deionized water to obtain the alkyl glucoside quaternary ammonium salt aqueous solution.
2. The high-temperature-resistant waterproof locking agent for drilling fluid, according to claim 1, is characterized in that: the alkyl glucoside is any one of dodecyl glucoside, n-octyl glucoside and n-decyl glucoside.
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Citations (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| EP0702073A1 (en) * | 1994-09-19 | 1996-03-20 | Baker Hughes Incorporated | Shale stabilising drilling fluid employing saccharide derivatives |
| CN104232035A (en) * | 2013-06-20 | 2014-12-24 | 中国石油化工股份有限公司 | Drilling fluid suitable for low-permeability oil/gas reservoir and preparation method of drilling fluid |
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| US3756949A (en) * | 1971-08-30 | 1973-09-04 | Universal Oil Prod Co | Shaped particles |
| WO1990015809A1 (en) * | 1989-06-16 | 1990-12-27 | Henkel Kommanditgesellschaft Auf Aktien (Henkel Kgaa) | Cationic substituted glycosides |
| CN102786561A (en) * | 2012-08-02 | 2012-11-21 | 中国石油化工股份有限公司 | Method of preparing CAPG for drilling fluid |
| CN106350038A (en) * | 2015-07-17 | 2017-01-25 | 中石化石油工程技术服务有限公司 | Cationic alkyl glycoside drilling fluid and preparation method thereof |
| CN106563385B (en) * | 2016-11-10 | 2018-10-26 | 山东德胜精细化工研究院有限公司 | A kind of preparation method and application of alkyl glucoside quaternary ammonium surfactant |
| CN111154473B (en) * | 2020-01-14 | 2022-04-08 | 北京勃兴石油科技有限公司 | Blockage removal oil displacement agent and preparation method and application thereof |
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| EP0702073A1 (en) * | 1994-09-19 | 1996-03-20 | Baker Hughes Incorporated | Shale stabilising drilling fluid employing saccharide derivatives |
| CN104232035A (en) * | 2013-06-20 | 2014-12-24 | 中国石油化工股份有限公司 | Drilling fluid suitable for low-permeability oil/gas reservoir and preparation method of drilling fluid |
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