CN114737898A - Ultrahigh-temperature carbonate reservoir yield-increasing transformation method - Google Patents
Ultrahigh-temperature carbonate reservoir yield-increasing transformation method Download PDFInfo
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- CN114737898A CN114737898A CN202210341738.9A CN202210341738A CN114737898A CN 114737898 A CN114737898 A CN 114737898A CN 202210341738 A CN202210341738 A CN 202210341738A CN 114737898 A CN114737898 A CN 114737898A
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- acid
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- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 title claims abstract description 26
- 238000011426 transformation method Methods 0.000 title abstract description 4
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- 239000003795 chemical substances by application Substances 0.000 claims abstract description 51
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- 238000006243 chemical reaction Methods 0.000 claims abstract description 12
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- 238000000034 method Methods 0.000 claims description 26
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- 239000003112 inhibitor Substances 0.000 claims description 19
- KRKNYBCHXYNGOX-UHFFFAOYSA-N citric acid Chemical compound OC(=O)CC(O)(C(O)=O)CC(O)=O KRKNYBCHXYNGOX-UHFFFAOYSA-N 0.000 claims description 18
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 17
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- VKYKSIONXSXAKP-UHFFFAOYSA-N hexamethylenetetramine Chemical compound C1N(C2)CN3CN1CN2C3 VKYKSIONXSXAKP-UHFFFAOYSA-N 0.000 claims description 12
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- 239000010695 polyglycol Substances 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
Classifications
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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
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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
- 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
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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
- 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
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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
- 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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- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- Geochemistry & Mineralogy (AREA)
- Chemical & Material Sciences (AREA)
- Chemical Kinetics & Catalysis (AREA)
- General Chemical & Material Sciences (AREA)
- Mechanical Engineering (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Preventing Corrosion Or Incrustation Of Metals (AREA)
- Cleaning And De-Greasing Of Metallic Materials By Chemical Methods (AREA)
Abstract
The invention relates to a yield-increasing transformation method for an ultrahigh-temperature carbonate reservoir, which sequentially comprises the following steps of: (1) circularly cleaning a shaft and a pipeline in a mode of annular discharge by oil pipe injection or annular oil pipe injection; (2) injecting a fracturing fluid into the stratum to crack the stratum; (3) injecting a dispersed film-forming agent into the formation; (4) injecting a retarding acid solution into the stratum to increase the effective acting distance of the acid solution in the cracks; (5) injecting a diverting agent into the stratum to improve the acid fracturing effect and realize the network fracture acid fracturing; (6) repeating the step (3); (7) injecting closed acid into the stratum to improve the fracture conductivity of the near well; (8) injecting a displacement fluid into the formation; (9) closing the well for 1-5h, opening the well and returning the well. The invention utilizes the dispersed film-forming agent to form non-uniform adsorption on the wall surface of the crack, realizes non-uniform etching during acid reaction, utilizes the coated acid to improve the effective distance of the acid action and reduce the corrosion of the acid to an oil casing, and has important significance for the yield-increasing transformation of high-temperature and ultrahigh-temperature carbonate reservoirs.
Description
Technical Field
The invention belongs to the technical field of yield increase of oil and gas fields, and particularly relates to a yield increase transformation method for an ultrahigh-temperature carbonate reservoir.
Background
Acidification or acid fracturing is a main yield-increasing measure of carbonate reservoirs, and the method is to inject acid liquor into a stratum, dissolve mineral components of the rock of the reservoir and substances for blocking the reservoir in the processes of drilling, well completion, well workover and production operation, improve and increase the permeability of the reservoir, and further improve the productivity of oil and gas wells. The action mechanism is that HCl enters a reservoir and then chemically reacts with the rock wall surface, and the mineral mainly participating in the reaction is calcite (CaCO)3) And dolomitic rock (CaMg (CO)3)2) The reaction equation is:
CaCO3+2HCl＝CaCl2+CO2+H2O
CaMg(CO3)2+4HCl＝CaCl2+MgCl2+2CO2+2H2O
in the prior art, a carbonate reservoir is mainly subjected to acid fracturing and acidizing processes by using gelled acid, crosslinked acid and self-diverting acid, additives are added into high-concentration HCl to improve the viscosity of acid liquor so as to achieve the purpose of slow-speed deep penetration, namely, the high-concentration hydrochloric acid is directly injected into a well, so that not only is the pipe column seriously corroded, but also the acid rock reaction speed is high in the construction process, and the acid liquor cannot reach the deep part of a crack, namely, the purpose of improving the deep part of the reservoir cannot be realized.
For high-temperature and ultrahigh-temperature reservoirs, the most concerned problem of the reservoir modification process is how to deal with the difficulty brought by high temperature:
(1) the high-temperature acid treatment causes serious corrosion to pipelines;
(2) the chemical reaction rate can be exponentially improved at high temperature, namely, the acid rock reaction rate is rapidly improved;
(3) the system stability of the acid system at high temperature will be deteriorated, i.e. gel-type acid system breaks gel, etc.
In order to reduce the corrosion of the acid solution to the pipe column and to reduce the acid rock reaction rate, some researchers have proposed a self-acid-generating acidification process and a self-acid-generating (also called in situ-generated acid, latent acid) acid solution system which is neutral or weakly acidic when formulated at the surface and gradually releases H following the acid rock reaction after the liquid is injected into the formation+Thereby realizing the slow deep penetration acidification. For example, the invention patent "a self-generating acid system and its application" (201210169268.9), utilizes the reaction of ammonium salt and aldehydes to generate hydrochloric acid; the invention relates to a self-generated hydrochloric acid acidification method suitable for carbonate reservoirs (201510751382.6), which utilizes the reaction of phenols and chloroacetic acid to generate acid.
The acid rock reaction speed is reduced by changing the acid generation source, and the acid rock reaction speed is taken as a better treatment measure for a high-temperature reservoir, so that the effective action distance of acid liquor can be extended, and the corrosion to a pipe column is low. However, the biggest disadvantage of the acid treatment process of the system is that the crack with high flow conductivity is difficult to obtain. Usually, acid liquor with high diversion cannot obtain long effective action distance, and acid liquor with low reaction speed cannot obtain high diversion cracks.
Disclosure of Invention
The invention aims to provide a method for increasing the production of an ultrahigh-temperature carbonate reservoir, which aims at developing an acid treatment process with low corrosion, high flow guide and deep modification for the high-temperature and ultrahigh-temperature carbonate reservoir and has important significance for increasing the production of the high-temperature and ultrahigh-temperature carbonate reservoir.
In order to achieve the technical purpose, the invention adopts the following technical scheme.
A method for increasing production and improving yield of an ultrahigh-temperature carbonate reservoir sequentially comprises the following steps:
(1) the method adopts the mode of injecting oil pipe into annulus for discharge or injecting annulus into oil pipe for discharge, and uses the conventional well-flushing fluid to circularly clean the shaft and the pipeline.
The well washing liquid is an acid liquid (common inorganic acid or organic acid) containing a corrosion inhibitor, 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, polyglycol ether, sodium dodecyl sulfate, sodium dodecyl benzene sulfonate, diethylenetriamine, hexamethylenetetramine, butynol ethanol, butynediol, imidazoline oleate, 4-methylpyridine and 4-vinylpyridine.
(2) And injecting a fracturing fluid into the stratum under high pressure to crack the stratum, so that the injection of a subsequent working fluid is facilitated, and the effective action distance of an acid liquid is increased, wherein the fracturing fluid is a conventional fracturing fluid or a high-temperature-resistant fracturing fluid.
(3) And injecting a dispersion film-forming agent into the stratum according to the designed fracture, so as to prepare for the subsequent injection of acid liquor to form non-uniform etching and improve the flow conductivity of the fracture.
The dispersing film-forming agent comprises the following components in parts by weight: 30-70 parts of a film forming agent, 1-5 parts of an emulsifier and 30-70 parts of water. The film forming agent is one or more of acrylic resin emulsion, a butadiene resin film forming agent, a polyurethane film forming agent and a nitrocellulose film forming agent. The emulsifier is one or more of nonionic paraffin micro-emulsifier NMP, cationic paraffin micro-emulsifier CMP, anionic paraffin emulsifier AMP, alkylphenol polyoxyethylene OP-10, alkylphenol polyoxyethylene OP-15 and fatty alcohol polyoxyethylene ether O-10.
(4) And injecting a retarding acid liquid into the stratum for increasing the effective acting distance of the acid liquid in the fracture.
The retarding acid liquid consists of the following components in parts by weight: 50-80 parts of conventional fracturing fluid, 20-50 parts of wrap acid or authigenic acid and 1-2 parts of corrosion inhibitor. The coated acid is solid acid particles coated by gelatin or sodium alginate, 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 diphosphonic acid, diethylenetriamine pentaacetic acid and gluconic acid. The authigenic acid is hydrochloric acid generated by reacting ammonium salt and aldehyde (invention patent 'an authigenic acid system and application thereof' (201210169268.9)) or acid generated by reacting phenols and chloroacetic acid (invention patent 'an authigenic hydrochloric acid acidification method applicable to carbonate reservoirs' (201510751382.6)).
The corrosion inhibitor can be various commercially available corrosion inhibitors, such as one or more of mercaptan, polyethylene glycol ether, sodium dodecyl sulfonate, sodium dodecyl benzene sulfonate, diethylenetriamine, hexamethylenetetramine, butynol ethanol, butynediol, oleic acid imidazoline, 4-methylpyridine and 4-vinylpyridine.
(5) And (3) injecting a diverting agent into the stratum for improving the acid fracturing effect and effectively realizing the network joint acid fracturing.
The diverting agent comprises the following components in percentage by weight: 0.3-1% of gelling agent, 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-vinylpyrrolidone, N-dodecylacrylamide, N-methylolacrylamide and N-tert-butylacrylamide.
The cross-linking agent can be one or more of polyethyleneimine, 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 various commercially available corrosion inhibitors, such as one or more of mercaptan, polyethylene glycol ether, sodium dodecyl sulfonate, sodium dodecyl benzene sulfonate, diethylenetriamine, hexamethylenetetramine, butynol ethanol, butynediol, imidazoline oleate, 4-methylpyridine and 4-vinylpyridine.
The fluid loss additive can be one or more of silicon dioxide, calcium carbonate, phenolic resin, acetate fiber, polyvinyl alcohol fiber and glass fiber.
(6) And (4) repeating the step (3).
(7) And injecting closed acid into the stratum to improve the fracture conductivity of the near well.
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 solution 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, butynol ethanol, butynol glycol, oleic acid imidazoline, 4-methylpyridine and 4-vinylpyridine. The iron ion stabilizer is one or more of disodium ethylene diamine tetraacetate, nitrilotriacetic acid, citric acid, tetrasodium glutamate diacetate, hydroxyethylidene diphosphonic acid, amino trimethylene phosphonic acid, ethylene diamine tetramethylene phosphonic acid, 2-hydroxyphosphonoacetic acid and hexamethylene tetramethy phosphonic acid. The mutual solvent is one or more of ethylene glycol monobutyl ether, octyl and decyl alcohol polyoxyethylene ether, diethylene glycol monobutyl ether and ethylene glycol tert-butyl ether.
(8) A displacement fluid is injected into the formation.
The displacement liquid is clear water and 1-3% of NH4Cl and 1-3% of KCl.
(9) Closing the well for 1-5h, opening the well and returning the well.
Compared with the prior art, the invention has the following beneficial effects:
aiming at the difficult problem of acid reformation of a high-temperature and ultrahigh-temperature carbonate reservoir, namely simultaneously improving the effective action distance and realizing the high flow conductivity of a crack, the invention provides a new reformation method, and non-uniform etching is realized during acid reaction by utilizing the non-uniform adsorption formed by a dispersive film-forming agent on the wall surface of the crack; the effective distance of the acid action can be effectively increased by using the wrapped acid; by using the wrapping acid, 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 high flow conductivity and long effective action distance, and has wide market application prospect.
Detailed Description
The present invention is further illustrated below by examples to facilitate understanding of the invention by those skilled in the art. It is to be understood that the invention is not limited in scope to the specific embodiments, but is intended to cover various modifications within the spirit and scope of the invention as defined and defined by the appended claims, as would be apparent to one of ordinary skill in the art.
Example 1
The influence of the addition film agent on the crack flow conductivity is comparatively tested by adopting a flow conductivity experiment, and the experiment temperature is 180 ℃. The experimental rock plate is marble with calcium carbonate content more than 99%. Experiment one displacement sequence: 1-base solution of acid liquor; experiment two displacement sequence: dispersing film-forming agent-acid liquor 1-base liquor; experiment three-displacement sequence: 2-base solution of acid liquor; experimental four-drive replacement sequence: dispersing film-forming agent-acid liquor 2-base liquor. The acid solution 1 comprises the following components: 70 parts of fracturing fluid, 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, 38 parts of sodium alginate-coated sulfamic acid and 2 parts of oleic acid imidazoline; the dispersing film-forming agent is: 20 parts of acrylic resin emulsion, 2 parts of non-ionic paraffin micro-emulsifier NMP and 78 parts of water; the base liquid is 2% NH4And (4) Cl solution.
TABLE 1 rock plate conductivity test results
As can be seen from table 1. Under low closing pressure (5MPa and 10MPa), the experiment I is superior to the experiment II, and the experiment III is superior to the experiment IV, which shows that the use of the dispersed film forming agent reduces the reaction speed of the acid rock, and the film forming agent forms a barrier film on the wall surface of the rock. Under high closing pressure (more than 20MPa), experiment two is superior to experiment one, and experiment four is superior to experiment three, which shows that the dispersed film-forming agent has the capability of improving non-uniform etching and has the excellent function of maintaining the flow conductivity of cracks. This demonstrates that the key technology in the present invention uses a dispersing film former to help improve and stabilize fracture conductivity of high temperature reservoir acid fracturing.
Example 2
And (3) carrying out acid fracturing measure modification by using the A well engineering modification of the S gas field as an implementation object and using an ultrahigh-temperature carbonate reservoir yield-increasing modification method. The well A is a carbonate gas well, the lithology is dolomite, and the reservoir temperature is 167 ℃. And determining the modification mode to be conventional acid fracturing according to the reservoir characteristics.
The method comprises the following steps: injecting an oil pipe into the annulus to discharge a well washing liquid, wherein the well washing liquid is 5% acetic acid and 1% oleic acid imidazoline;
step two: pressing the stratum open and extending the crack under the pressure higher than the fracture pressure of the stratum, wherein the fracturing fluid is high-temperature resistant fracturing fluid;
step three: and injecting a dispersion film-forming agent A into the stratum, wherein the agent A comprises 30 parts of acrylic resin emulsion, 1 part of non-ionic paraffin micro-emulsifier NMP, 1 part of fatty alcohol-polyoxyethylene ether O-10 and 68 parts of water.
Step four: and injecting a retarding acid solution B into the stratum, wherein the B 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 injecting a diverting agent C into the stratum, wherein the component of the diverting agent C is 0.5 part of gelling agent, 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-acrylamide-2-methylpropanesulfonic acid and N-dodecyl acrylamide. The cross-linking agent is polyethyleneimine. The gel breaker is ammonium persulfate. The corrosion inhibitor is oleic acid imidazoline. The fluid loss additive is silicon dioxide.
Step six: and injecting a dispersion film-forming agent A into the stratum, wherein the agent A comprises 30 parts of acrylic resin emulsion, 1 part of non-ionic paraffin micro-emulsifier NMP, 1 part of fatty alcohol-polyoxyethylene ether O-10 and 68 parts of water.
Step seven: and injecting a closed acid D agent into the stratum, wherein the D agent comprises 10 parts of hydrochloric acid, 10 parts of acetic acid, 2 parts of oleic imidazoline, 2 parts of ethylene diamine tetraacetic acid disodium, 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% NH4And (4) Cl solution.
Step nine: and closing the well for 1.5h, opening the well and performing flowback.
Example 3
And (3) carrying out acid fracturing measure modification by using the B well engineering modification of the S gas field as an implementation object and using an 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 to be conventional acid fracturing according to the reservoir characteristics.
The method comprises the following steps: injecting an oil pipe into the annulus to discharge a well washing liquid, wherein the well washing liquid is 5% acetic acid and 1% oleic acid imidazoline;
step two: pressing the stratum open and extending the crack under the pressure higher than the fracture pressure of the stratum, wherein the fracturing fluid is high-temperature resistant;
step three: injecting dispersed film forming agent A into stratum*Agent, A*The agent comprises 20 parts of acrylic resin emulsion, 10 parts of polyurethane film forming agent, 1 part of non-ionic paraffin micro-emulsifier NMP, 1 part of fatty alcohol-polyoxyethylene ether O-10 and 68 parts of water.
Step four: injecting a retarding acid liquid B into the stratum*Agent, B*The agent comprises 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 diverting agent C into the formation*Agent, C*The composition of the agent is 0.5 part of gelling agent, 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-acrylamide-2-methylpropanesulfonic acid and N-dodecyl acrylamide. The cross-linking agent is polyethyleneimine. The gel breaker is ammonium persulfate. The corrosion inhibitor is oleic acid imidazoline. Fluid loss additive silica.
Step six: injecting dispersed film forming agent A into stratum*Agent, A*The agent comprises 20 parts of acrylic resin emulsion, 10 parts of polyurethane film forming agent and 1 part of non-acrylic resinIonic paraffin micro-emulsifier NMP +1 portion fatty alcohol-polyoxyethylene ether O-10+68 portions water.
Step seven: injection of closed acid D into the formation*Agent, D*The agent consists of 10 parts of hydrochloric acid, 10 parts of acetic acid, 2 parts of oleic acid imidazoline, 2 parts of ethylene diamine tetraacetic acid, 5 parts of ethylene glycol monobutyl ether and 71 parts of water.
Step eight: injection of a displacing liquid E into the formation*The preparation E is 2% KCl solution.
Step nine: and closing the well for 2h, opening the well and returning the well.
And (3) analysis of acidification effect:
the daily natural gas production of the well is 13.25 multiplied by 10 before the operation of the well A4m365.68 multiplied by 10 of natural gas produced in the day after operation4m3Increase production 52.43X 104m3。
The daily natural gas production of the well is 19.35 multiplied by 10 before the operation of the well B4m371.29X 10 natural gas produced in the day after operation4m3Increasing yield 51.94X 104m3。
Adopting conventional acid fracturing measures from 16.37 multiplied by 10 for M wells and N wells adjacent to the well4m3Increased to 49.38X 104m3From 21.68X 104m3Increased to 56.49X 104m3The production increases are 33.01 multiplied by 10 respectively4m3、34.81×104m3。
Compared with the prior acidification reconstruction measures, the new technology provided by the invention increases the yield by about 70 percent in the same operation block. This shows that the measures proposed by the invention can be more beneficial to maintaining the high conductivity of the crack.
Claims (9)
1. A method for increasing production and improving yield of an ultrahigh-temperature carbonate reservoir sequentially comprises the following steps:
(1) circularly cleaning a shaft and a pipeline by using conventional flushing fluid in a mode of injecting annular fluid into an oil pipe for discharging or injecting annular fluid into the oil pipe for discharging;
(2) injecting a fracturing fluid into the stratum to crack the stratum;
(3) injecting a dispersed film former into the formation;
(4) injecting a retarded acid solution into the stratum to increase the effective acting distance of the acid solution in the cracks;
(5) injecting a diverting agent into the stratum to improve the acid fracturing effect and realize the network joint acid fracturing;
(6) repeating the step (3);
(7) injecting closed acid into the stratum to improve the fracture conductivity of the near well;
(8) injecting a displacement fluid into the formation;
(9) closing the well for 1-5h, opening the well and returning the well.
2. The method of increasing production of an ultrahigh-temperature carbonate reservoir according to claim 1, wherein the well-flushing fluid is an acid solution containing a corrosion inhibitor, and the acid solution is at least one of hydrochloric acid, formic acid, acetic acid, oxalic acid, citric acid and maleic acid.
3. The method for increasing production and improving the yield of the ultrahigh-temperature carbonate reservoir of claim 1, wherein the dispersing film-forming agent comprises the following components in parts by weight: 30-70 parts of a film forming agent, 1-5 parts of an emulsifier and 30-70 parts of water; the film forming agent is one or more of acrylic resin emulsion, a butadiene resin film forming agent, a polyurethane film forming agent and a nitrocellulose film forming agent; the emulsifier is one or more of nonionic paraffin micro-emulsifier NMP, cationic paraffin micro-emulsifier CMP, anionic paraffin emulsifier AMP, alkylphenol polyoxyethylene OP-10, alkylphenol polyoxyethylene OP-15 and fatty alcohol polyoxyethylene ether O-10.
4. The method for increasing production and improving yield of the ultrahigh-temperature carbonate reservoir of claim 1, wherein the retarded acid solution comprises the following components in parts by weight: 50-80 parts of conventional fracturing fluid, 20-50 parts of wrap acid or authigenic acid and 1-2 parts of corrosion inhibitor; the coated acid is solid acid particles coated by gelatin or sodium alginate, 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 diphosphonic acid, diethylenetriamine pentaacetic acid and gluconic acid; the self-generated acid is hydrochloric acid generated by the reaction of ammonium salt and aldehyde or acid generated by the reaction of phenols and chloroacetic acid.
5. The method for stimulation modification of an ultrahigh-temperature carbonate reservoir according to claim 1, wherein the diversion agent comprises the following components in percentage by weight: 0.3-1% of gelling agent, 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.
6. The method for stimulation of an ultrahigh-temperature carbonate reservoir according to claim 5, wherein the gelling agent is a binary or ternary copolymer of acrylamide, 2-acrylamido-2-methylpropanesulfonic acid, N-vinylpyrrolidone, N-dodecylacrylamide, N-methylolacrylamide, N-tert-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 fluid loss additive is one or more of silicon dioxide, calcium carbonate, phenolic resin, acetate fiber, polyvinyl alcohol fiber and glass fiber.
7. The method for stimulation modification of an ultrahigh-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 solution is one or more of hydrochloric acid, formic acid and acetic acid; the iron ion stabilizer is one or more of disodium ethylene diamine tetraacetate, nitrilotriacetic acid, citric acid, tetrasodium glutamate diacetate, hydroxyethylidene diphosphonic acid, amino trimethylene phosphonic acid, ethylene diamine tetramethylene phosphonic acid, 2-hydroxyphosphonoacetic acid and hexamethylene tetramethy phosphonic acid; the mutual solvent is one or more of ethylene glycol monobutyl ether, octyl and decyl alcohol polyoxyethylene ether, diethylene glycol monobutyl ether and ethylene glycol tert-butyl ether.
8. The method for stimulation modification of an ultrahigh-temperature carbonate reservoir of claim 1, wherein the displacement fluid is clear water and 1-3% NH4Cl and 1-3% of KCl.
9. The method for increasing production of an ultrahigh-temperature carbonate reservoir according to claim 2, 4, 5 or 7, wherein the corrosion inhibitor is one or more of mercaptan, polyethylene glycol ether, sodium dodecyl sulfate, sodium dodecyl benzene sulfonate, diethylenetriamine, hexamethylenetetramine, butyneethanol, butynediol, oleic acid imidazoline, 4-methylpyridine and 4-vinylpyridine.
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| CN117965155B (en) * | 2024-03-29 | 2024-06-07 | 新疆中海科技有限公司 | Acidizing, yield increasing and injection increasing agent for oil field |
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| Publication number | Priority date | Publication date | Assignee | Title |
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| CN117965155A (en) * | 2024-03-29 | 2024-05-03 | 新疆中海科技有限公司 | Acidizing, yield increasing and injection increasing agent for oil field |
| CN117965155B (en) * | 2024-03-29 | 2024-06-07 | 新疆中海科技有限公司 | Acidizing, yield increasing and injection increasing agent for oil field |
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| CN114737898B (en) | 2024-03-19 |
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