CN114737898B - Ultrahigh-temperature carbonate reservoir yield increasing transformation method - Google Patents

Ultrahigh-temperature carbonate reservoir yield increasing transformation method Download PDF

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CN114737898B
CN114737898B CN202210341738.9A CN202210341738A CN114737898B CN 114737898 B CN114737898 B CN 114737898B CN 202210341738 A CN202210341738 A CN 202210341738A CN 114737898 B CN114737898 B CN 114737898B
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injecting
stratum
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agent
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CN114737898A (en
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杨建�
刘平礼
熊钢
杜娟
陈伟华
陈鹏飞
刘飞
熊颖
李年银
罗志锋
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Southwest Petroleum University
Petrochina Southwest Oil and Gasfield Co
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Petrochina Southwest Oil and Gasfield Co
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    • 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
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • 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
    • C09K8/74—Eroding chemicals, e.g. acids combined with additives added for specific purposes
    • 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
    • E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
    • E21B41/02—Equipment or details not covered by groups E21B15/00 - E21B40/00 in situ inhibition of corrosion in boreholes or wells
    • 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
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures
    • 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
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures
    • E21B43/261—Separate steps of (1) cementing, plugging or consolidating and (2) fracturing or attacking the formation
    • 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
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures
    • E21B43/27—Methods for stimulating production by forming crevices or fractures by use of eroding chemicals, e.g. acids

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
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  • Mining & Mineral Resources (AREA)
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  • Environmental & Geological Engineering (AREA)
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  • Chemical & Material Sciences (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Mechanical Engineering (AREA)
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  • Organic Chemistry (AREA)
  • Cleaning And De-Greasing Of Metallic Materials By Chemical Methods (AREA)
  • Preventing Corrosion Or Incrustation Of Metals (AREA)

Abstract

The invention relates to a method for improving yield of an ultrahigh-temperature carbonate reservoir, which sequentially comprises the following steps: (1) Adopting an oil pipe injection annulus discharge or annulus injection oil pipe discharge mode to circularly clean a shaft and a pipeline; (2) injecting a fracturing fluid into the formation to fracture the formation; (3) injecting a dispersing film former into the formation; (4) Injecting retarded acid solution into the stratum, and improving the effective acting distance of the acid solution in the cracks; (5) Injecting a steering agent into the stratum, improving the acid fracturing effect and realizing the acid fracturing of the stitch net; (6) repeating the step (3); (7) Injecting closed acid into the stratum, and improving the fracture conductivity of the near well; (8) injecting a displacement fluid into the formation; (9) closing the well for 1-5h, and opening the well and returning the row. The invention utilizes the dispersion film forming agent to realize non-uniform adsorption on the crack wall surface, so that non-uniform etching is realized during acid reaction, the effective distance of acid action is increased by using the coated acid, the corrosion of the acid to the oil casing is reduced, and the invention has important significance for the yield increase and reconstruction of the high-temperature and ultra-high-temperature carbonate reservoir.

Description

Ultrahigh-temperature carbonate reservoir yield increasing transformation method
Technical Field
The invention belongs to the technical field of oil and gas field yield increase, and particularly relates to a method for improving yield of an ultrahigh-temperature carbonate reservoir.
Background
Acidizing or acid fracturing is a main measure for increasing production of carbonate reservoirs, and the method is to inject acid liquor into the stratum to dissolve rock mineral components of the reservoir and substances which cause blockage of the reservoir in the processes of drilling, well completion, well repairing and production operation, so that the permeability of the reservoir is improved and the productivity of an oil and gas well is improved. The action mechanism is that HCl enters into the reservoir to react with rock wall surface, and the mineral which mainly participates in the reaction is calcite (CaCO) 3 ) And dolomite (CaMg (CO) 3 ) 2 ) The reaction equation is:
CaCO 3 +2HCl＝CaCl 2 +CO 2 +H 2 O
CaMg(CO 3 ) 2 +4HCl＝CaCl 2 +MgCl 2 +2CO 2 +2H 2 O
in the prior art, the acid fracturing and acidizing processes of gelled acid, cross-linked acid and self-steering acid are mainly utilized for a carbonate reservoir, and the processes are to add additives into high-concentration HCl to improve the viscosity of acid liquor so as to achieve the purpose of retarding deep penetration, namely, the high-concentration hydrochloric acid is directly injected into the well, so that the acid liquor cannot reach the deep part of a crack due to severe corrosion to a tubular column and high acid-rock reaction speed in the construction process, and the purpose of deep transformation of the reservoir cannot be achieved.
For high temperature, ultra high temperature reservoirs, the most interesting problem for reservoir reformation processes is how to deal with the difficulties presented by high temperatures:
(1) High temperature acid treatment can cause serious corrosion to pipelines;
(2) The chemical reaction rate is exponentially improved at high temperature, namely the acid rock reaction rate is rapidly improved;
(3) The system stability of the acid liquor system at high temperature can be deteriorated, namely gel breaking of the gel type acid liquor system and the like.
In order to achieve a reduction in corrosion of the string by the acid and a reduction in the reaction rate of the acid rock, a scholars have proposed a self-acid-generating acidification process and a self-acid (also known as in situ acid generation, latent acid) acid system that is neutral or weakly acidic when formulated at the surface and gradually releases H as the acid rock reacts after the liquid is injected into the formation + Thereby realizing slow deep penetration acidification. According to the invention patent, an autogenous acid system and application thereof (201210169268.9), ammonium salt is utilized to react with aldehydes to generate hydrochloric acid; the invention patent' a self-generated hydrochloric acid acidification method (201510751382.6) applicable to a carbonate reservoir utilizes the reaction of phenols and chloroacetic acid to generate acid.
The acid-producing source is changed to reduce the reaction speed of acid rock, so that the acid-producing source is used as a better treatment measure for a high-temperature reservoir, is beneficial to extending the effective acting distance of acid liquor and has lower corrosiveness to a tubular column. However, the biggest disadvantage in the acid treatment process of the system is that high-flow-conductivity cracks are difficult to obtain. It is generally difficult to obtain long effective working distances for high flow-directing acid solutions, while low reaction rates are difficult to obtain high flow-directing cracks.
Disclosure of Invention
The invention aims to provide a method for improving the yield of an ultrahigh temperature carbonate reservoir, which aims at developing an acid treatment process with low corrosion, high diversion and deep improvement on a high temperature and ultrahigh temperature carbonate reservoir and has great significance on improving the yield of the high temperature and ultrahigh temperature carbonate reservoir.
In order to achieve the technical purpose, the invention adopts the following technical scheme.
The ultrahigh temperature carbonate reservoir yield increasing transformation method sequentially comprises the following steps:
(1) And (3) adopting a mode of oil pipe injection and annular discharge or annular injection and oil pipe discharge, and circularly cleaning a shaft and a pipeline by using conventional well flushing liquid.
The well-flushing liquid is an acid liquid (commonly used inorganic acid or organic acid) containing a corrosion inhibitor, wherein the acid liquid is at least one of hydrochloric acid, formic acid, acetic acid, oxalic acid, citric acid and maleic acid, and the corrosion inhibitor is one or more of mercaptan, polyethylene glycol ether, sodium dodecyl sulfonate, sodium dodecyl benzene sulfonate, diethylenetriamine, hexamethylenetetramine, butynoethanol, butynediol, oleic acid imidazoline, 4-methylpyridine and 4-vinylpyridine.
(2) And injecting a fracturing fluid into the stratum under high pressure to enable the stratum to generate cracks, so that the subsequent injection of the well entering fluid and the increase of the effective acting distance of the acid solution are facilitated, and the fracturing fluid is a conventional fracturing fluid or a high-temperature-resistant fracturing fluid.
(3) And injecting a dispersing film forming agent into the stratum according to the designed fracture, so as to prepare for forming non-uniform etching by injecting acid liquor subsequently and improving the fracture conductivity.
The dispersing film forming agent consists of the following components in parts by weight: 30-70 parts of film forming agent, 1-5 parts of emulsifying agent and 30-70 parts of water. The film forming agent is one or more of acrylic resin emulsion, butadiene resin film forming agent, polyurethane film forming agent and nitrocellulose film forming agent. The emulsifier is one or more of nonionic paraffin wax micro-emulsifier NMP, cationic paraffin wax micro-emulsifier CMP, anionic paraffin wax emulsifier AMP, alkylphenol ethoxylate OP-10, alkylphenol ethoxylate OP-15 and fatty alcohol ethoxylate O-10.
(4) And injecting retarded acid solution into the stratum for improving the effective acting distance of the acid solution in the cracks.
The retarded acid solution comprises the following components in parts by weight: 50-80 parts of conventional fracturing fluid, 20-50 parts of wrapping acid or autogenous acid and 1-2 parts of corrosion inhibitor. The coating acid is gelatin or sodium alginate coated solid acid particles, and the solid acid is one or more of glycolic acid, sulfamic acid, solid nitric acid, solid hydrochloric acid, boric acid, oxalic acid, maleic acid, tartaric acid, citric acid, ethylenediamine tetraacetic acid, hydroxyethylidene diphosphate, diethylenetriamine pentaacetic acid and gluconic acid. The self-generated acid is hydrochloric acid generated by reacting ammonium salt with aldehydes (patent of invention "a self-generated acid system and application thereof" (201210169268.9)) or acid generated by reacting phenols with chloroacetic acid (patent of invention "a self-generated hydrochloric acid acidification method applicable to carbonate reservoirs" (201510751382.6)).
The corrosion inhibitor can be one or more of various corrosion inhibitors sold in the market, such as mercaptan, polyethylene glycol ether, sodium dodecyl sulfonate, sodium dodecyl benzene sulfonate, diethylenetriamine, hexamethylenetetramine, butynoethanol, butynediol, oleic acid imidazoline, 4-methylpyridine and 4-vinylpyridine.
(5) And a steering agent is injected into the stratum to improve acid fracturing effect and effectively realize the acid fracturing of the slotted net.
The steering agent comprises the following components in percentage by weight: 0.3-1% of gelatinizer, 0.05-0.3% of cross-linking agent, 0.1-1% of gel breaker, 0.1-1% of corrosion inhibitor, 0-10% of filtrate reducer and the balance of water.
The gelling agent may be one of an acrylamide-based binary or ternary copolymer. Can be binary or ternary copolymer of acrylamide, 2-acrylamido-2-methylpropanesulfonic acid, N-vinyl pyrrolidone, N-dodecyl acrylamide, N-methylolacrylamide and N-tertiary butyl acrylamide.
The cross-linking agent can be one or more of polyethylenimine, urotropine, N-methylene bisacrylamide, glutaraldehyde and ammonium chloride.
The gel breaker can be one of ammonium persulfate, potassium permanganate, sodium permanganate, tert-butyl hydroperoxide and potassium dichromate.
The corrosion inhibitor can be one or more of various corrosion inhibitors sold in the market, such as mercaptan, polyethylene glycol ether, sodium dodecyl sulfonate, sodium dodecyl benzene sulfonate, diethylenetriamine, hexamethylenetetramine, butynoethanol, butynediol, oleic acid imidazoline, 4-methylpyridine and 4-vinylpyridine.
The filtrate reducer can be one or more of silicon dioxide, calcium carbonate, phenolic resin, acetate fiber, polyvinyl alcohol fiber and glass fiber.
(6) Repeating the step (3).
(7) And (3) injecting closed acid into the stratum, so as to improve the fracture conductivity of the near well.
The closed acid consists of the following components in percentage by weight: 20-50% of acid liquor, 0.5-2% of corrosion inhibitor, 1-2% of iron ion stabilizer, 5-10% of mutual solvent and the balance of water. The acid liquid is one or more of hydrochloric acid, formic acid and acetic acid. The corrosion inhibitor is one or more of mercaptan, polyethylene glycol ether, sodium dodecyl sulfonate, sodium dodecyl benzene sulfonate, diethylenetriamine, hexamethylenetetramine, butynoethanol, butynediol, oleic acid imidazoline, 4-methylpyridine and 4-vinylpyridine. The iron ion stabilizer is one or more of disodium ethylenediamine tetraacetate, nitrilotriacetic acid, citric acid, disodium glutamate diacetate, hydroxyethylidene diphosphonic acid, aminotrimethylene phosphonic acid, ethylenediamine tetramethylene phosphonic acid, 2-hydroxyphosphonoacetic acid and hexamethylene diamine tetramethylene phosphonic acid. The mutual solvent is one or more of ethylene glycol monobutyl ether, xin Guichun polyoxyethylene ether, diethylene glycol butyl ether and ethylene glycol tertiary butyl ether.
(8) And injecting displacement fluid into the stratum.
The displacement liquid is clear water and 1-3% NH 4 Cl, 1-3% KCl.
(9) Closing the well for 1-5h, opening the well and returning the row.
Compared with the prior art, the invention has the following beneficial effects:
aiming at the difficult problem of acid modification of a high-temperature and ultra-high-temperature carbonate reservoir, namely, the effective acting distance is increased and the high flow conductivity of a crack is realized, the invention provides a novel modification method, and the dispersed film forming agent is utilized to form non-uniform adsorption on the wall surface of the crack, so that non-uniform etching is realized during acid reaction; the wrapping acid can effectively improve the effective distance of the acid action; the acid is coated, so that the corrosion of the acid to the oil casing can be effectively reduced. Compared with the conventional acid treatment measures, the method can effectively give consideration to both high flow conductivity and long effective acting distance, and has wide market application prospect.
Detailed Description
The invention is further illustrated below by way of example to facilitate an understanding of the invention by those skilled in the art. It should be understood that the invention is not limited to the precise embodiments, and that various changes may be effected therein by one of ordinary skill in the art without departing from the spirit or scope of the invention as defined and determined by the appended claims.
Example 1
The influence of the film forming agent on the crack flow conductivity is tested by adopting a flow guiding experiment, and the experimental temperature is 180 ℃. The experimental rock plate is marble with the calcium carbonate content of more than 99 percent. Experiment one displacement sequence: acid liquor 1-base liquor; experimental two-displacement sequence: dispersing a film forming agent, namely acid liquor 1-base liquor; experimental three-drive sequence: 2-base acid liquor; experimental four-drive sequence: dispersing film forming agent-acid liquor 2-base liquor. The acid liquor 1 comprises the following components: 70 parts of fracturing fluid and 28 parts of sodium alginate coated solid hydrochloric acid and 2 parts of oleic acid imidazoline; the acid liquor 2 comprises the following components: 60 parts of fracturing fluid and 38 parts of sodium alginate coated sulfamic acid and 2 parts of oleic acid imidazoline; the dispersing film forming agent comprises the following components: 20 parts of acrylic resin emulsion, 2 parts of non-ionic paraffin wax micro-emulsifier NMP and 78 parts of water; the base solution is 2% NH 4 Cl solution.
Table 1 results of the flow conductivity experiments of the rock plates
As can be seen from table 1. Under low closing pressure (5 MPa, 10 MPa), experiment one is better than experiment two, experiment three is better than experiment four, which shows that the use of the dispersed film forming agent reduces the reaction speed of acid rock, mainly because the film forming agent forms a barrier film on the rock wall surface. Under high closing pressure (more than 20 MPa), experiment two is better than experiment one, experiment four is better than experiment three, which shows that the dispersed film forming agent has the capability of improving non-uniform etching and has excellent effect of maintaining crack flow conductivity. This illustrates that the key technology in the present invention uses a dispersed film former to help enhance and stabilize fracture conductivity of high temperature reservoir acid fracturing.
Example 2
Taking the engineering transformation of the A well of the S gas field as an implementation object, and carrying out acid fracturing measure transformation by using the ultrahigh temperature carbonate reservoir yield increasing transformation method. The A well is a carbonate gas well, the lithology is dolomite, and the reservoir temperature is 167 ℃. And determining the modification mode as conventional acid fracturing according to the reservoir characteristics.
Step one: injecting oil pipe into annulus to drain flushing well, wherein the flushing liquid is 5% acetic acid and 1% oleic acid imidazoline;
step two: the method comprises the steps of fracturing the ground layer and prolonging cracks under the condition that the fracturing pressure of the ground layer is higher than the fracturing pressure of the ground layer, wherein the fracturing fluid is high-temperature-resistant fracturing fluid;
step three: and injecting a dispersed film forming agent A into the stratum, wherein the composition of the agent A is 30 parts of acrylic resin emulsion, 1 part of nonionic paraffin wax microemulsion NMP, 1 part of fatty alcohol polyoxyethylene ether O-10 and 68 parts of water.
Step four: and (3) injecting a retarder acid liquid B agent into the stratum, wherein the B agent comprises 68 parts of conventional fracturing fluid, 30 parts of sodium alginate coated sulfamic acid and 2 parts of oleic acid imidazoline.
Step five: and (3) injecting a steering agent C agent into the stratum, wherein the composition of the agent C is 0.5 part of a gelling agent, 0.1 part of a cross-linking agent, 1 part of a gel breaker, 1 part of a corrosion inhibitor, 1 part of a filtrate reducer and 96.4 parts of water. The gelatinizer is terpolymer of acrylamide, 2-acrylamido-2-methylpropanesulfonic acid and N-dodecyl acrylamide. The cross-linking agent is polyethyleneimine. The breaker is ammonium persulfate. The corrosion inhibitor is oleic acid imidazoline. The filtrate reducer is silicon dioxide.
Step six: and injecting a dispersed film forming agent A into the stratum, wherein the composition of the agent A is 30 parts of acrylic resin emulsion, 1 part of nonionic paraffin wax microemulsion NMP, 1 part of fatty alcohol polyoxyethylene ether O-10 and 68 parts of water.
Step seven: and injecting a closed acid agent D into the stratum, wherein the composition of the closed acid agent D is 10 parts of hydrochloric acid, 10 parts of acetic acid, 2 parts of oleic acid imidazoline, 2 parts of disodium ethylenediamine tetraacetate, 5 parts of ethylene glycol monobutyl ether and 71 parts of water.
Step eight: injecting a displacing liquid E agent into the stratum, wherein the E agent is 2% NH 4 Cl solution.
Step nine: closing the well for 1.5 hours, opening the well and returning the row.
Example 3
The B well engineering of the S gas field is used as an implementation object, and the acid fracturing measure is modified by using the ultrahigh temperature carbonate reservoir yield increasing modification method. The well B is a carbonate gas well, the lithology is dolomite, and the reservoir temperature is 169 ℃. And determining the modification mode as conventional acid fracturing according to the reservoir characteristics.
Step one: injecting oil pipe into annulus to drain flushing well, wherein the flushing liquid is 5% acetic acid and 1% oleic acid imidazoline;
step two: fracturing the ground layer at a pressure higher than the fracture pressure of the stratum, and prolonging the fracture, wherein the fracturing fluid is resistant to high-temperature fracturing fluid;
step three: injecting dispersed film former A into stratum * Agent A * The agent comprises 20 parts of acrylic resin emulsion, 10 parts of polyurethane film forming agent, 1 part of nonionic paraffin wax microemulsion NMP, 1 part of fatty alcohol polyoxyethylene ether O-10 and 68 parts of water.
Step four: injecting retarded acid liquor B into stratum * Agent B * The agent composition is 58 parts of conventional fracturing fluid, 20 parts of sodium alginate coated sulfamic acid, 20 parts of sodium alginate coated maleic acid and 2 parts of oleic acid imidazoline.
Step five: injection of diverter C into a formation * Agent C * The composition of the agent is 0.5 part of gelatinizer, 0.1 part of cross-linking agent, 1 part of gel breaker, 1 part of corrosion inhibitor, 1 part of filtrate reducer and 96.4 parts of water. The gelatinizer is terpolymer of acrylamide, 2-acrylamido-2-methylpropanesulfonic acid and N-dodecyl acrylamide. The cross-linking agent is polyethyleneimine. The breaker is ammonium persulfate. The corrosion inhibitor is oleic acid imidazoline. Filtrate reducer silica.
Step six: injecting dispersed film former A into stratum * Agent A * The agent comprises 20 parts of acrylic resin emulsion, 10 parts of polyurethane film forming agent, 1 part of nonionic paraffin wax microemulsion NMP, 1 part of fatty alcohol polyoxyethylene ether O-10 and 68 parts of water.
Step seven: injection of closed acid D into a formation * Agent D * The composition of the agent is 10 parts of hydrochloric acid, 10 parts of acetic acid, 2 parts of oleic acid imidazoline, 2 parts of disodium ethylenediamine tetraacetate, 5 parts of ethylene glycol monobutyl ether and 71 parts of water.
Step eight: injection of displacement fluid E into a formation * Agent E is 2% KCl solution.
Step nine: closing the well for 2h, opening the well and returning.
And (3) acidizing effect analysis:
well A produces 13.25X10 of natural gas daily before well A operates 4 m 3 Natural gas 65.68X10 g produced daily after operation 4 m 3 Yield increase 52.43 ×10 4 m 3 。
19.35×10 natural gas produced by well day before operation of well B 4 m 3 71.29 ×10 natural gas produced daily after operation 4 m 3 Yield increase 51.94 ×10 4 m 3 。
The conventional acid fracturing measures are adopted for the M well and the N well of the temporary well, and the pressure is respectively 16.37 multiplied by 10 4 m 3 To 49.38X10 4 m 3 From 21.68 ×10 4 m 3 To 56.49X 10 4 m 3 Yield increase is 33.01 ×10 respectively 4 m 3 、34.81×10 4 m 3 。
Compared with the prior acidification reconstruction measure, the novel technology provided by the invention increases the yield by about 70% in the same operation block. This demonstrates that the proposed measures of the present invention can be more beneficial to maintaining high conductivity of the fracture.

Claims (7)

1. The ultrahigh temperature carbonate reservoir yield increasing transformation method sequentially comprises the following steps:
(1) Adopting an oil pipe injection annulus discharging or annulus injection oil pipe discharging mode, and circularly cleaning a shaft and a pipeline by using conventional well flushing liquid;
(2) Injecting a fracturing fluid into the stratum to cause cracks in the stratum;
(3) Injecting a dispersed film forming agent into a stratum, wherein the dispersed film forming agent comprises the following components in parts by weight: 30-70 parts of film forming agent, 1-5 parts of emulsifying agent and 30-70 parts of water; the film forming agent is one or more of acrylic resin emulsion, butadiene resin film forming agent, polyurethane film forming agent and nitrocellulose film forming agent; the emulsifier is one or more of nonionic paraffin wax micro-emulsifier NMP, cationic paraffin wax micro-emulsifier CMP, anionic paraffin wax emulsifier AMP, alkylphenol ethoxylate OP-10, alkylphenol ethoxylate OP-15 and fatty alcohol ethoxylate O-10;
(4) Injecting retarded acid liquid into the stratum to improve the effective acting distance of the acid liquid in the crack, wherein the retarded acid liquid comprises the following components in parts by weight: 50-80 parts of conventional fracturing fluid, 20-50 parts of wrapping acid or autogenous acid and 1-2 parts of corrosion inhibitor; the coating acid is gelatin or sodium alginate coated solid acid particles, and the solid acid is one or more of glycolic acid, sulfamic acid, solid nitric acid, solid hydrochloric acid, boric acid, oxalic acid, maleic acid, tartaric acid, citric acid, ethylenediamine tetraacetic acid, hydroxyethylidene diphosphate, diethylenetriamine pentaacetic acid and gluconic acid; the self-generated acid is hydrochloric acid generated by reacting ammonium salt with aldehydes or acid generated by reacting phenols with chloroacetic acid;
(5) Injecting a steering agent into the stratum, improving the acid fracturing effect and realizing the acid fracturing of the stitch net;
(6) Repeating step (3);
(7) Injecting closed acid into the stratum, and improving the fracture conductivity of the near well;
(8) Injecting displacement fluid into the stratum;
(9) Closing the well for 1-5h, opening the well and returning the row.
2. The method for improving yield of an ultra-high temperature carbonate reservoir according to claim 1, wherein the well-flushing fluid is an acid fluid containing a corrosion inhibitor, and the acid fluid is at least one of hydrochloric acid, formic acid, acetic acid, oxalic acid, citric acid and maleic acid.
3. The ultra-high temperature carbonate reservoir yield increasing modification method of claim 1, wherein the steering agent comprises the following components in percentage by weight: 0.3-1% of gelatinizer, 0.05-0.3% of cross-linking agent, 0.1-1% of gel breaker, 0.1-1% of corrosion inhibitor, 0-10% of filtrate reducer and the balance of water.
4. A method of stimulation enhancement of ultra-high temperature carbonate reservoirs as in claim 3, wherein the gelling agent is a binary or ternary copolymer of acrylamide, 2-acrylamido-2-methylpropanesulfonic acid, N-vinylpyrrolidone, N-dodecylacrylamide, N-methylolacrylamide, N-t-butylacrylamide; the cross-linking agent is one or more of polyethyleneimine, urotropine, N-methylene bisacrylamide, glutaraldehyde and ammonium chloride; the gel breaker is one of ammonium persulfate, potassium permanganate, sodium permanganate, tert-butyl hydroperoxide and potassium dichromate; the filtrate reducer is one or more of silicon dioxide, calcium carbonate, phenolic resin, acetate fiber, polyvinyl alcohol fiber and glass fiber.
5. The method for improving the yield of the ultra-high temperature carbonate reservoir according to claim 1, wherein the closed acid comprises the following components in percentage by weight: 20-50% of acid liquor, 0.5-2% of corrosion inhibitor, 1-2% of iron ion stabilizer, 5-10% of mutual solvent and the balance of water; the acid liquor is one or more of hydrochloric acid, formic acid and acetic acid; the iron ion stabilizer is one or more of disodium ethylenediamine tetraacetate, nitrilotriacetic acid, citric acid, disodium glutamate diacetate, hydroxyethylidene diphosphonic acid, aminotrimethylene phosphonic acid, ethylenediamine tetramethylene phosphonic acid, 2-hydroxyphosphonoacetic acid and hexamethylene diamine tetramethylene phosphonic acid; the mutual solvent is one or more of ethylene glycol monobutyl ether, xin Guichun polyoxyethylene ether, diethylene glycol butyl ether and ethylene glycol tertiary butyl ether.
6. The ultra-high temperature carbonate reservoir stimulation modification method of claim 1, wherein the displacement fluid is clear water, 1-3% nh 4 Cl, 1-3% KCl.
7. The method for stimulation of ultra-high temperature carbonate reservoirs of claim 2, 3 or 5, wherein the corrosion inhibitor is one or more of mercaptan, polyethylene glycol ether, sodium dodecyl sulfonate, sodium dodecyl benzene sulfonate, diethylenetriamine, hexamethylenetetramine, butynoethanol, butynediol, oleic acid imidazoline, 4-methylpyridine, 4-vinylpyridine.
CN202210341738.9A 2022-03-29 2022-03-29 Ultrahigh-temperature carbonate reservoir yield increasing transformation method Active CN114737898B (en)

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