CN112358863B - Chemical yield increasing liquid and method for low-permeability oil layer - Google Patents
Chemical yield increasing liquid and method for low-permeability oil layer Download PDFInfo
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- CN112358863B CN112358863B CN202110034200.9A CN202110034200A CN112358863B CN 112358863 B CN112358863 B CN 112358863B CN 202110034200 A CN202110034200 A CN 202110034200A CN 112358863 B CN112358863 B CN 112358863B
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- 239000007788 liquid Substances 0.000 title claims abstract description 24
- 239000000126 substance Substances 0.000 title claims abstract description 23
- 230000001965 increasing effect Effects 0.000 title claims abstract description 21
- 238000000034 method Methods 0.000 title claims abstract description 20
- QTBSBXVTEAMEQO-UHFFFAOYSA-N Acetic acid Chemical compound CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 claims abstract description 36
- 239000003129 oil well Substances 0.000 claims abstract description 30
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 claims abstract description 26
- 230000035699 permeability Effects 0.000 claims abstract description 26
- VWDWKYIASSYTQR-UHFFFAOYSA-N sodium nitrate Chemical compound [Na+].[O-][N+]([O-])=O VWDWKYIASSYTQR-UHFFFAOYSA-N 0.000 claims abstract description 24
- -1 alkylbenzene sulfonate Chemical class 0.000 claims abstract description 23
- 238000006243 chemical reaction Methods 0.000 claims abstract description 14
- 239000003208 petroleum Substances 0.000 claims abstract description 14
- PAWQVTBBRAZDMG-UHFFFAOYSA-N 2-(3-bromo-2-fluorophenyl)acetic acid Chemical compound OC(=O)CC1=CC=CC(Br)=C1F PAWQVTBBRAZDMG-UHFFFAOYSA-N 0.000 claims abstract description 12
- DGAQECJNVWCQMB-PUAWFVPOSA-M Ilexoside XXIX Chemical compound C[C@@H]1CC[C@@]2(CC[C@@]3(C(=CC[C@H]4[C@]3(CC[C@@H]5[C@@]4(CC[C@@H](C5(C)C)OS(=O)(=O)[O-])C)C)[C@@H]2[C@]1(C)O)C)C(=O)O[C@H]6[C@@H]([C@H]([C@@H]([C@H](O6)CO)O)O)O.[Na+] DGAQECJNVWCQMB-PUAWFVPOSA-M 0.000 claims abstract description 12
- YIKSCQDJHCMVMK-UHFFFAOYSA-N Oxamide Chemical compound NC(=O)C(N)=O YIKSCQDJHCMVMK-UHFFFAOYSA-N 0.000 claims abstract description 12
- DBMJMQXJHONAFJ-UHFFFAOYSA-M Sodium laurylsulphate Chemical compound [Na+].CCCCCCCCCCCCOS([O-])(=O)=O DBMJMQXJHONAFJ-UHFFFAOYSA-M 0.000 claims abstract description 12
- XSQUKJJJFZCRTK-UHFFFAOYSA-N Urea Chemical compound NC(N)=O XSQUKJJJFZCRTK-UHFFFAOYSA-N 0.000 claims abstract description 12
- 239000004202 carbamide Substances 0.000 claims abstract description 12
- 239000011734 sodium Substances 0.000 claims abstract description 12
- 229910052708 sodium Inorganic materials 0.000 claims abstract description 12
- 239000004317 sodium nitrate Substances 0.000 claims abstract description 12
- 235000010344 sodium nitrate Nutrition 0.000 claims abstract description 12
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 claims abstract description 12
- 238000002360 preparation method Methods 0.000 claims description 63
- 238000003756 stirring Methods 0.000 claims description 42
- 230000000638 stimulation Effects 0.000 claims description 22
- 239000012530 fluid Substances 0.000 claims description 15
- 239000008139 complexing agent Substances 0.000 claims description 14
- QGZKDVFQNNGYKY-UHFFFAOYSA-N Ammonia Chemical compound N QGZKDVFQNNGYKY-UHFFFAOYSA-N 0.000 claims description 10
- 238000010276 construction Methods 0.000 claims description 9
- 229910021529 ammonia Inorganic materials 0.000 claims description 8
- 239000002245 particle Substances 0.000 claims description 8
- NZRSEGYTVSNMCK-UHFFFAOYSA-N sodium;undecyl benzenesulfonate Chemical group [Na].CCCCCCCCCCCOS(=O)(=O)C1=CC=CC=C1 NZRSEGYTVSNMCK-UHFFFAOYSA-N 0.000 claims description 7
- 239000002904 solvent Substances 0.000 claims description 7
- 150000001732 carboxylic acid derivatives Chemical class 0.000 claims description 2
- 238000000605 extraction Methods 0.000 abstract description 3
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 15
- 238000004519 manufacturing process Methods 0.000 description 10
- 238000002347 injection Methods 0.000 description 5
- 239000007924 injection Substances 0.000 description 5
- 230000035945 sensitivity Effects 0.000 description 5
- 239000000243 solution Substances 0.000 description 5
- 239000002253 acid Substances 0.000 description 3
- 230000000694 effects Effects 0.000 description 3
- 230000037452 priming Effects 0.000 description 2
- 230000008569 process Effects 0.000 description 2
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 1
- 101000932768 Conus catus Alpha-conotoxin CIC Proteins 0.000 description 1
- 239000000654 additive Substances 0.000 description 1
- 239000009096 changqing Substances 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- 238000004088 simulation Methods 0.000 description 1
Classifications
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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
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/72—Eroding chemicals, e.g. acids
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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
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/84—Compositions based on water or polar solvents
- C09K8/86—Compositions based on water or polar solvents containing organic compounds
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
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- Mining & Mineral Resources (AREA)
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- Chemical Kinetics & Catalysis (AREA)
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Abstract
The invention is suitable for the technical field of petroleum exploitation, and provides a chemical yield increasing liquid for a low-permeability oil layer and a yield increasing method. The chemical yield increasing liquid for the low-permeability oil layer comprises a component A, a component B and a component C; the component A comprises ammonium nitrate, urea and alkylbenzene sulfonate; the component B comprises sodium nitrate, oxamide and sodium dodecyl sulfate; the component C comprises hydrochloric acid, acetic acid and sodium petroleum sulfonate. According to the invention, high-temperature high-pressure gas generated by the reaction enters the reservoir gap hole from the perforation section, the high-pressure gas in the reservoir gap can effectively pass through the smaller gap at a higher temperature, an oil gas conveying route is opened, the resistance is reduced, the oil extraction yield is increased, the permeability of an oil well is finally improved, and the oil well yield is improved.
Description
Technical Field
The invention belongs to the technical field of petroleum exploitation, and particularly relates to a chemical yield increasing liquid for a low-permeability oil layer and a yield increasing method.
Background
At present, the conventional acidizing well adopts measures which aim at the acidizing and penetrating modes of medium-shallow reservoirs and medium-high reservoirs, namely, acidizing a carbonate reservoir by utilizing hydrochloric acid, and acidizing a sandstone reservoir by utilizing earth acid and compound acid, so that the purpose is to improve the productivity again. In general, the primary oil test of the middle and high permeability well layers has commercial oil flow production value, but the low permeability layer is often secondarily reformed under the condition that the primary oil test is fruitless due to insufficient natural reservoir conditions, the condition of permeability reformation is very harsh, and weak side effects can play a role in killing. For example, under medium permeability conditions, weak rapid sensitivity effects have little effect on the post-formation production value of the medium permeability reservoir, but for low permeability layers, weak rapid sensitivity may lead to momentary production shutdowns of the production well. Similarly, other types of sensitivity are also critical factors in the impediment of low permeability reservoir well production. Because of the various sensitivities of low permeability reservoirs, the engineering measures must be formulated according to reservoir properties and sensitivity characteristics, and dynamic flow simulation is preferred before implementation.
Thus, factors currently limiting the success rate of low permeability acidizing reservoirs mainly include: acid liquor and additives have poor matching with low permeability reservoirs, resulting in poor oil enhancement.
Disclosure of Invention
The embodiment of the invention aims to provide a chemical yield increasing liquid for a low-permeability oil layer and a yield increasing method, and aims to solve the problems in the prior art pointed out in the background art.
The embodiment of the invention is realized in such a way that the chemical stimulation fluid for the low-permeability oil layer comprises a component A, a component B and a component C;
the component A comprises ammonium nitrate, urea and alkylbenzene sulfonate, wherein the mass ratio of the ammonium nitrate to the urea to the alkylbenzene sulfonate is (1-1.5): (0.5 to 0.8): (0.1 to 0.2);
the component B comprises sodium nitrate, oxamide and sodium dodecyl sulfate, wherein the mass ratio of the sodium nitrate to the oxamide to the sodium dodecyl sulfate is (1-1.5): (0.5 to 0.8): (0.1 to 0.2);
the component C comprises hydrochloric acid, acetic acid and sodium petroleum sulfonate, wherein the mass ratio of the hydrochloric acid to the acetic acid to the sodium petroleum sulfonate is (4-4.3): (0.9-1): (0.9-1).
As another preferable scheme of the embodiment of the invention, the preparation method of the component A comprises the following steps:
adding ammonium nitrate into a preparation tank, sequentially adding urea and alkylbenzene sulfonate in sequence, and stirring simultaneously in the preparation process;
and continuously stirring for 20-30 minutes.
As another preferable mode of the embodiment of the invention, the alkylbenzene sulfonate is sodium undecyl benzene sulfonate.
As another preferable scheme of the embodiment of the invention, the preparation method of the component B comprises the following steps:
adding sodium nitrate into a preparation tank, sequentially adding oxamide and sodium dodecyl sulfate, and stirring simultaneously in the preparation process;
and continuously stirring for 20-30 minutes.
As another preferable scheme of the embodiment of the invention, the preparation method of the component C comprises the following steps:
adding hydrochloric acid into a preparation tank, sequentially adding acetic acid and sodium petroleum sulfonate in sequence, and stirring simultaneously in the preparation process;
and continuously stirring for 20-30 minutes.
It is another object of an embodiment of the present invention to provide a stimulation method for a chemical stimulation fluid for a low permeability reservoir, comprising the steps of:
injecting the component A into the artificial bottom of the oil well to the middle of the perforation section;
injecting component B into an oil well tubular cavity;
the component A and the component B are fused for chemical reaction, high-temperature gas with the temperature of 200-300 ℃ and high pressure gas with the pressure of 18-22 MPa is generated to enter a reservoir layer, and the reaction lasts for 10-22 hours;
injecting the component C into an oil well pipe cavity, and reacting for 10-22 hours;
repeating the steps for 3-5 times.
As another preferred embodiment of the present invention, the priming solution is added before both the component A and the component B are added.
As another preferred embodiment of the present invention, after both component A and component B are filled, the post-liquid particle complexing agent is added.
As another preferable scheme of the embodiment of the invention, the pre-liquid is ammonia carboxylate, and the post-liquid particle complexing agent is ammonia carboxyl complexing agent.
As another preferable scheme of the embodiment of the invention, the component A, the component B and the component C are dissolved by adopting a solvent 8-11 hours before construction.
According to the invention, high-temperature high-pressure gas generated by the reaction enters the reservoir gap hole from the perforation section, the high-pressure gas in the reservoir gap can effectively pass through the smaller gap at a higher temperature, an oil gas conveying route is opened, the resistance is reduced, the oil extraction yield is increased, the permeability of an oil well is finally improved, and the oil well yield is improved. The method has the advantages of simple construction, no damage to the reservoir, repeated use, obvious oil increasing effect and the like.
Detailed Description
The present invention will be described in further detail with reference to the following examples in order to make the objects, technical solutions and advantages of the present invention more apparent. It should be understood that the specific embodiments described herein are for purposes of illustration only and are not intended to limit the scope of the invention.
Specific implementations of the invention are described in detail below in connection with specific embodiments.
Example 1
This example provides a chemical stimulation fluid for a low permeability reservoir comprising component a, component B and component C;
the preparation method of the component A comprises the following steps: adding 1t of ammonium nitrate into a preparation tank, sequentially adding 0.8t of urea and 0.1t of alkylbenzene sulfonate in sequence, and stirring simultaneously in the preparation process; continuously stirring for 30 minutes; the alkylbenzene sulfonate is sodium undecyl benzene sulfonate;
the preparation method of the component B comprises the following steps: adding 1t of sodium nitrate into a preparation tank, sequentially adding 0.8t of oxamide and 0.1t of sodium dodecyl sulfate in sequence, and stirring simultaneously in the preparation process; continuously stirring for 30 minutes;
the preparation method of the component C comprises the following steps: adding hydrochloric acid 4t into a preparation tank, sequentially adding acetic acid 1t and petroleum sodium sulfonate 0.9t, and stirring simultaneously in the preparation process; stirring was continued for 30 minutes.
Example 2
This example provides a chemical stimulation fluid for a low permeability reservoir comprising component a, component B and component C;
the preparation method of the component A comprises the following steps: adding 1.5t of ammonium nitrate into a preparation tank, sequentially adding 0.5t of urea and 0.2t of alkylbenzene sulfonate according to the sequence, and stirring simultaneously in the preparation process; continuously stirring for 20 minutes; the alkylbenzene sulfonate is sodium undecyl benzene sulfonate;
the preparation method of the component B comprises the following steps: adding 1.5t of sodium nitrate into a preparation tank, sequentially adding 0.5t of oxamide and 0.2t of sodium dodecyl sulfate in sequence, and stirring simultaneously in the preparation process; continuously stirring for 20 minutes;
the preparation method of the component C comprises the following steps: adding 4.3t of hydrochloric acid into a preparation tank, sequentially adding 0.9t of acetic acid and 1t of petroleum sodium sulfonate in sequence, and stirring simultaneously in the preparation process; stirring was continued for 20 minutes.
Example 3
This example provides a chemical stimulation fluid for a low permeability reservoir comprising component a, component B and component C;
the preparation method of the component A comprises the following steps: adding 1.1t of ammonium nitrate into a preparation tank, sequentially adding 0.6t of urea and 0.15t of alkylbenzene sulfonate in sequence, and stirring simultaneously in the preparation process; continuously stirring for 22 minutes; the alkylbenzene sulfonate is sodium undecyl benzene sulfonate;
the preparation method of the component B comprises the following steps: adding 1.2t of sodium nitrate into a preparation tank, sequentially adding 0.6t of oxamide and 0.15t of sodium dodecyl sulfate in sequence, and stirring simultaneously in the preparation process; continuously stirring for 25 minutes;
the preparation method of the component C comprises the following steps: adding 4.2t of hydrochloric acid into a preparation tank, sequentially adding 0.95t of acetic acid and 0.94t of petroleum sodium sulfonate in sequence, and stirring simultaneously in the preparation process; stirring was continued for 25 minutes.
Example 4
This example provides a chemical stimulation fluid for a low permeability reservoir comprising component a, component B and component C;
the preparation method of the component A comprises the following steps: adding 1.3t of ammonium nitrate into a preparation tank, sequentially adding 0.7t of urea and 0.16t of alkylbenzene sulfonate in sequence, and stirring simultaneously in the preparation process; continuously stirring for 24 minutes; the alkylbenzene sulfonate is sodium undecyl benzene sulfonate;
the preparation method of the component B comprises the following steps: adding 1.4t of sodium nitrate into a preparation tank, sequentially adding 0.7t of oxamide and 0.16t of sodium dodecyl sulfate in sequence, and stirring simultaneously in the preparation process; continuously stirring for 24 minutes;
the preparation method of the component C comprises the following steps: adding 4.2t of hydrochloric acid into a preparation tank, sequentially adding 0.94t of acetic acid and 0.98t of petroleum sodium sulfonate in sequence, and stirring simultaneously in the preparation process; stirring was continued for 28 minutes.
Example 5
This example provides a chemical stimulation fluid for a low permeability reservoir comprising component a, component B and component C;
the preparation method of the component A comprises the following steps: adding 1.4t of ammonium nitrate into a preparation tank, sequentially adding 0.75t of urea and 0.18t of alkylbenzene sulfonate in sequence, and stirring simultaneously in the preparation process; continuously stirring for 29 minutes; the alkylbenzene sulfonate is sodium undecyl benzene sulfonate;
the preparation method of the component B comprises the following steps: adding 1.4t of sodium nitrate into a preparation tank, sequentially adding 0.75t of oxamide and 0.13t of sodium dodecyl sulfate in sequence, and stirring simultaneously in the preparation process; continuously stirring for 21 minutes;
the preparation method of the component C comprises the following steps: adding 4.25t of hydrochloric acid into a preparation tank, sequentially adding 0.91t of acetic acid and 0.95t of petroleum sodium sulfonate in sequence, and stirring simultaneously in the preparation process; stirring was continued for 23 minutes.
Example 6
This example provides a stimulation method for a chemical stimulation fluid for a low permeability reservoir prepared in example 1, comprising the steps of:
the component A, the component B and the component C are dissolved by a solvent 8 hours before construction;
injecting the component A into the artificial bottom of the oil well to the middle of the perforation section;
injecting component B into an oil well tubular cavity;
the component A and the component B are fused to carry out chemical reaction to generate high-pressure gas (H) with high temperature of 200-300 ℃ and high pressure of 18-22 MPa 2 N 2 、CO 2 、NO 2 ) Entering a reservoir layer, and reacting for 10 hours;
injecting the component C into an oil well pipe cavity, and reacting for 10 hours;
the above steps are repeated continuously for 5 times.
Example 7
This example provides a stimulation method for a chemical stimulation fluid for a low permeability reservoir prepared in example 2, comprising the steps of:
the component A, the component B and the component C are dissolved by a solvent 10 hours before construction;
injecting the component A into the artificial bottom of the oil well to the middle of the perforation section;
injecting component B into an oil well tubular cavity;
the component A and the component B are fused to carry out chemical reaction to generate high-pressure gas (H) with high temperature of 200-300 ℃ and high pressure of 18-22 MPa 2 N 2 、CO 2 、NO 2 ) Entering a reservoir layer, and reacting for 20 hours;
injecting the component C into an oil well pipe cavity, and reacting for 20 hours;
the above steps are repeated continuously for 3 times.
Example 8
This example provides a stimulation method for a chemical stimulation fluid for a low permeability reservoir prepared in example 3, comprising the steps of:
the component A, the component B and the component C are dissolved by a solvent 11 hours before construction;
injecting the component A into the artificial bottom of the oil well to the middle of the perforation section;
injecting component B into an oil well tubular cavity;
the component A and the component B are fused to carry out chemical reaction to generate high-pressure gas (H) with high temperature of 200-300 ℃ and high pressure of 18-22 MPa 2 N 2 、CO 2 、NO 2 ) Entering a reservoir layer, and reacting for 22 hours;
injecting the component C into an oil well pipe cavity, and reacting for 22 hours;
the above steps are repeated continuously for 3 times.
Example 9
This example provides a stimulation method for a chemical stimulation fluid for a low permeability reservoir prepared in example 4, comprising the steps of:
the component A, the component B and the component C are dissolved by a solvent 9 hours before construction;
injecting the component A into the artificial bottom of the oil well to the middle of the perforation section;
injecting component B into an oil well tubular cavity;
the component A and the component B are fused to carry out chemical reaction to generate high-pressure gas (H) with high temperature of 200-300 ℃ and high pressure of 18-22 MPa 2 N 2 、CO 2 、NO 2 ) Entering a reservoir, and reacting for 18 hours;
injecting the component C into an oil well pipe cavity, and reacting for 18 hours;
the above steps are repeated continuously for 3 times.
Example 10
This example provides a stimulation method for a chemical stimulation fluid for a low permeability reservoir prepared in example 5, comprising the steps of:
the component A, the component B and the component C are dissolved by a solvent 10 hours before construction;
injecting the component A into the artificial bottom of the oil well to the middle of the perforation section;
injecting component B into an oil well tubular cavity;
the component A and the component B are fused to carry out chemical reaction to generate high-pressure gas (H) with high temperature of 200-300 ℃ and high pressure of 18-22 MPa 2 N 2 、CO 2 、NO 2 ) Entering a reservoir layer, and reacting for 12 hours;
injecting the component C into an oil well pipe cavity, and reacting for 12 hours;
the above steps are repeated continuously for 5 times.
Example 11
This example provides the specific stimulation method of the chemical stimulation fluid for low permeability reservoirs of example 1, comprising the steps of:
1. the first procedure is completed within two days:
adding 0.05t of pre-liquid carboxylic acid ammonia;
filling component a0.55t;
adding 0.05t of post-liquid particle complexing agent (aminocarboxylic complexing agent);
injecting field water 4t by using a high-pressure water injection pump, keeping the pressure of an oil well within a pressure range defined by each well, and performing casing reverse drainage 4t while injecting water into an oil pipe;
adding a pre-solution (ammonia carboxylate) 0.05t;
filling component B0.55 t;
adding 0.05t of post-liquid particle complexing agent (aminocarboxylic complexing agent);
injecting field water 4t by using a high-pressure water injection pump, keeping the pressure of an oil well within a pressure range defined by each well, and performing casing reverse drainage 4t while injecting water into an oil pipe, and performing well closing reaction for 20 hours;
filling the component C1.1 t, and closing the well and reacting for 20 hours;
2. the first pass process is continued for 2 times.
Example 12
For old wells (the bearing pressure of the casing is less than or equal to 12 MPa), the specific yield increasing method of the chemical yield increasing liquid for the low-permeability oil layer comprises the following steps of:
1. the first procedure is completed within one day:
early 7:00-8:00 priming:
adding a pre-solution (ammonia carboxylate) 0.05t;
filling component A3.3 t;
adding 0.05t of post-liquid particle complexing agent (ammonia carboxyl complexing agent),
injecting field water 4t by using a high-pressure water injection pump, keeping the pressure of an oil well within a pressure range defined by each well, and performing casing reverse drainage 4t while injecting water into an oil pipe;
adding a pre-solution (ammonia carboxylate) 0.05t;
filling component B0.33 t;
adding 0.05t of post-liquid particle complexing agent (aminocarboxylic complexing agent);
injecting field water 3t by using a high-pressure water injection pump, keeping the pressure of an oil well within a pressure range defined by each well, and performing casing reverse drainage 3t while injecting water into an oil pipe, and performing well closing reaction for 10 hours;
6 pm: 00-7:00 filling:
filling component C0.66 t;
injecting field water 2t by using a high-pressure water injection pump, keeping the pressure of an oil well within a pressure range defined by each well, and performing casing reverse drainage 2t while injecting water into an oil pipe, and performing well closing reaction for 10 hours;
2. the first pass process is repeated 5 times.
Experimental example
The petrochemical yield increasing liquid prepared in the embodiment 1 and the yield increasing method in the embodiment 6 are applied to 12 Yang 65-52 well groups in eight-factory edge fixing operation area science of oil extraction in Changqing oil fields.
Checking production records after construction:
before the yield increasing operation: 3.5t of daily oil production liquid and 1.5t of daily oil production liquid.
After the yield increasing operation: average daily production liquid for 5t in the first 5 months and daily production oil for 2.5t.
It can be seen that the oil increasing effect of the 65-52 well group is obvious.
The foregoing description of the preferred embodiments of the invention is not intended to be limiting, but rather is intended to cover all modifications, equivalents, and alternatives falling within the spirit and principles of the invention.
Claims (2)
1. A chemical stimulation fluid for a low permeability reservoir, comprising a component a, a component B and a component C;
the component A comprises ammonium nitrate, urea and alkylbenzene sulfonate, wherein the mass ratio of the ammonium nitrate to the urea to the alkylbenzene sulfonate is (1-1.5): (0.5 to 0.8): (0.1 to 0.2);
the component B comprises sodium nitrate, oxamide and sodium dodecyl sulfate, wherein the mass ratio of the sodium nitrate to the oxamide to the sodium dodecyl sulfate is (1-1.5): (0.5 to 0.8): (0.1 to 0.2);
the component C comprises hydrochloric acid, acetic acid and sodium petroleum sulfonate, wherein the mass ratio of the hydrochloric acid to the acetic acid to the sodium petroleum sulfonate is (4-4.3): (0.9-1): (0.9-1);
the preparation method of the component A comprises the following steps: adding ammonium nitrate into a preparation tank, sequentially adding urea and alkylbenzene sulfonate in sequence, and stirring simultaneously in the preparation process; continuously and fully stirring for 20-30 minutes;
the preparation method of the component B comprises the following steps: adding sodium nitrate into a preparation tank, sequentially adding oxamide and sodium dodecyl sulfate, and stirring simultaneously in the preparation process; continuously and fully stirring for 20-30 minutes;
the preparation method of the component C comprises the following steps: adding hydrochloric acid into a preparation tank, sequentially adding acetic acid and sodium petroleum sulfonate in sequence, and stirring simultaneously in the preparation process; continuously and fully stirring for 20-30 minutes;
the alkylbenzene sulfonate is sodium undecyl benzene sulfonate;
the yield increasing method of the chemical yield increasing liquid for the low-permeability oil layer comprises the following steps of:
injecting the component A into the artificial bottom of the oil well to the middle of the perforation section;
injecting component B into an oil well tubular cavity;
the component A and the component B are fused for chemical reaction, high-temperature gas with the temperature of 200-300 ℃ and high pressure gas with the pressure of 18-22 MPa is generated to enter a reservoir layer, and the reaction lasts for 10-22 hours;
injecting the component C into an oil well pipe cavity, and reacting for 10-22 hours;
repeating the steps for 3-5 times continuously;
before the component A and the component B are filled, the pre-liquid is filled;
after the component A and the component B are added, adding post-liquid particle complexing agent;
the pre-liquid is carboxylic acid ammonia, and the post-liquid particle complexing agent is an ammonia-carboxyl complexing agent.
2. The chemical stimulation fluid for low permeability oil layers according to claim 1, wherein component a, component B and component C are dissolved with a solvent 8-11 hours before construction.
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Citations (7)
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