CN113187456A - Process flow for old well energizing group repeated fracturing - Google Patents
Process flow for old well energizing group repeated fracturing Download PDFInfo
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- CN113187456A CN113187456A CN202110521489.7A CN202110521489A CN113187456A CN 113187456 A CN113187456 A CN 113187456A CN 202110521489 A CN202110521489 A CN 202110521489A CN 113187456 A CN113187456 A CN 113187456A
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- well
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- plugging agent
- temporary plugging
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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 DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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 DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
Abstract
The invention discloses a process flow for repeated fracturing of an old well energized group, which comprises the following steps: collecting basic data of a target area, and selecting more than 3 compressible wells in the target area as target group fracturing wells according to the basic data; calculating the energy deficit degree of the reservoir and calculating the using amount of the energy increasing liquid; pumping an energizing liquid into each target group fracturing well for energizing and then performing group fracturing; injecting a water-soluble temporary plugging agent into each target group fracturing well to form network cracks; and injecting sand-carrying liquid and displacing liquid into each target group fracturing well to support the network cracks, stopping the pump, closing the well, and opening the well for production after bottom hole pressure is diffused. The method has the advantages of improving the volume of old well repeated fracturing modification, improving the efficiency of old well repeated fracturing, finally improving the yield of the fractured well, greatly improving the development benefit of the oil field, improving the difficult problem of poor traditional single well repeated fracturing construction effect, and providing new ideas and means for the old well repeated fracturing of the ultra-low permeability reservoir.
Description
Technical Field
The invention relates to the technical field of fracturing in oil and gas field development, in particular to a process flow for repeated fracturing of an old well energizing group.
Background
After the ultra-low permeability reservoir oil and gas well is put into operation through primary fracturing modification, various factors exist to cause that the single well modification degree is low, the whole stratum energy attenuation is fast, the stratum pressure is reduced to cause that a large amount of oil wells stop production and reduce production, the efficiency is low, but at the moment, the oil well exploitation degree is low, and a large amount of residual reserves are not exploited. It is necessary to carry out residual oil excavation on old oil fields, and the economic benefit of old wells is improved.
The repeated fracturing operation of the old well is a key technology for excavating residual oil and improving the yield. The purpose of repeated fracturing is to form a new seam network in a reservoir, increase the modification volume of the reservoir, reduce seepage resistance and further improve the oil and gas yield. However, for an energy-attenuated reservoir stratum, the problem of stratum energy failure cannot be effectively solved by repeated fracturing, and practice proves that fracturing modification is carried out on the energy-failed reservoir stratum, so that the liquid efficiency is low, and the modification effect is poor; and for the oil-gas well with stratum energy failure, the stratum energy is supplemented in a conventional water injection mode, and because the water injection efficiency is low, the discharge capacity is small, the stratum energy is supplemented slowly, and the energy increasing effect is poor.
Disclosure of Invention
Aiming at the problems, the invention aims to provide a process flow for repeated fracturing of an old well energized group.
The technical scheme of the invention is as follows:
a process flow for old well energized group repeated fracturing comprises the following steps:
collecting basic data of a target area, analyzing and evaluating the residual recoverable reserve and the residual oil distribution position of a reservoir in the target area, and selecting more than 3 compressible wells in the target area as target group fracturing wells by combining the compressibility analysis and evaluation results of each single well in the target area;
calculating the energy deficit degree of the reservoir according to the production condition of each target group fracturing well and the current reservoir pressure, and calculating the using amount of the energizer liquid according to the deficit degree;
pumping energizing liquid into each target group fracturing well according to the amount of the energizing liquid, and performing cluster fracturing after energizing of all target group fracturing wells is completed;
injecting a water-soluble temporary plugging agent into each target group fracturing well, plugging the tail end of a main crack, improving the construction net pressure and forming a network crack;
and injecting sand-carrying liquid and displacing liquid into each target group fracturing well to support the network cracks, stopping the pump, closing the well, and opening the well for production after bottom hole pressure is diffused.
Preferably, the base data includes reservoir data, production data and modification history data for a single well within the target zone.
Preferably, the target layers of the target group fracturing wells are the same reservoir layer and the vertical depth is within the same threshold range.
Preferably, the energizer fluid is a nanoemulsion containing an oil displacement agent.
Preferably, the concentration of the energizer liquid is 0.1 to 0.2 percent.
Preferably, when the water-soluble temporary plugging agent in the fracture seams is injected into each target group fracturing well, whether the water-soluble temporary plugging agent in the fracture seams needs to be injected into each target group fracturing well is judged according to the difference value of two-way main stress of each target group fracturing well:
when the difference value of the two-way main stress is larger than the stress difference threshold value, the corresponding target group fracturing well needs to be injected with the water-soluble in-seam temporary plugging agent;
and when the difference value of the two-way main stress is smaller than or equal to the stress difference threshold value, the corresponding target group fracturing well does not need to be injected with the water-soluble in-seam temporary plugging agent.
Preferably, the stress difference threshold is 10%.
Preferably, when the water-soluble intra-fracture temporary plugging agent is injected into each target group fracturing well, the amount of the water-soluble intra-fracture temporary plugging agent is calculated by the following formula:
M＝V1×ρ1×56％×V2+V2×ρ2 (1)
V1＝πH(d×Δd+Δd2) (2)
in the formula: m is the mass of the temporary plugging agent; v1The volume of the crack to be blocked; rho1The apparent density of the temporary plugging agent is; v2The volume of the perforation; rho2Is the volume density of the temporary plugging agent; h is the height of the supporting seam; d is the outer diameter of the sleeve; Δ d is the cake thickness.
Preferably, the water-soluble temporary plugging agent in the gap consists of a temporary plugging agent I and a temporary plugging agent II, wherein the size of the temporary plugging agent I is 20-100 meshes, and the size of the temporary plugging agent II is 1-5 mm.
The invention has the beneficial effects that:
according to the invention, the energizing liquid is adopted for energizing before the repeated fracturing, so that the reservoir pressure can be recovered to or close to the original reservoir pressure state, and reservoir energy guarantee is provided for the post-fracturing production; meanwhile, in the fracturing process, the generation of a microcrack network can be maximized by adopting a group fracturing technology and an intra-fracture temporary plugging technology; therefore, the method has the advantages of improving the volume of old well repeated fracturing modification, improving the efficiency of old well repeated fracturing, finally improving the yield of the fractured well, greatly improving the benefit of oil field development, improving the difficult problem of poor traditional single well repeated fracturing construction effect, and providing new ideas and means for the old well repeated fracturing of the ultra-low permeability reservoir.
In addition, the process flow of the invention also has the advantages of simplicity, reliability, convenient operation and the like; the water-soluble temporary plugging agent in the joint can be completely degraded and returns to the ground along with the flowback liquid, so that the pollution to a reservoir stratum can not be caused.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings used in the description of the embodiments or the prior art will be briefly described below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and for those skilled in the art, other drawings can be obtained according to these drawings without creative efforts.
FIG. 1 is a schematic diagram of well log data for each target group of fractured wells according to one embodiment of the present invention;
FIG. 2 is a schematic view of stress disturbance at the end of a crack;
FIG. 3 is a schematic diagram of a microseism monitoring result of mutual interference and expansion of fractures of a target group fractured well;
fig. 4 is a schematic diagram of simulation results of reservoir energization.
Detailed Description
The invention is further illustrated with reference to the following figures and examples. It should be noted that, in the present application, the embodiments and the technical features of the embodiments may be combined with each other without conflict. It is noted that, unless otherwise indicated, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this application belongs. The use of the terms "comprising" or "including" and the like in the present disclosure is intended to mean that the elements or items listed before the term cover the elements or items listed after the term and their equivalents, but not to exclude other elements or items.
A process flow for old well energized group repeated fracturing comprises the following steps:
s1: collecting reservoir data, production data and transformation historical data of single wells in a target area, analyzing and evaluating the residual recoverable reserve and the residual oil distribution position of the reservoir in the target area, and selecting more than 3 compressible wells in the target area as target group fracturing wells according to the compressibility analysis and evaluation result of each single well in the target area, wherein the target layer of each target group fracturing well is the same reservoir and the vertical depth of each target group fracturing well is in the same threshold range.
In one embodiment, the log data of each target interval fractured well is shown in fig. 1, and it can be seen from fig. 1 that several selected target intervals fractured wells are in the same reservoir and have similar depths.
S2: and calculating the energy deficit degree of the reservoir according to the production condition of each target group fracturing well and the current reservoir pressure, and calculating the using amount of the energy-increasing liquid according to the deficit degree.
It should be noted that the injection amount of the stimulation fluid is equal to 80% of the cumulative total production amount of the oil well. Through numerical simulation calculation, when the accumulated deficit amount is pumped into the fracturing unit by 80%, the formation energy can be effectively recovered by more than 85%, and the fracturing construction and post-fracturing production at the later stage are facilitated.
S3: and pumping the energizing liquid into each target group fracturing well according to the using amount of the energizing liquid, performing cluster fracturing after the energizing of all the target group fracturing wells is completed, and performing fracturing construction on each target group fracturing well simultaneously when the groups are fractured, wherein the distance of a shaft of each target group fracturing well is within 350m, and the connecting line of each well is the same as the direction of the maximum main stress of a reservoir layer, so that the end parts of a plurality of artificial fractures which are simultaneously fractured are close to each other and generate interference, and the stress interference of the end parts of the fractures is shown in figure 2. In a specific embodiment, the results of microseismic monitoring of the propagation of target group fractured well fractures interfering with each other are shown in FIG. 3.
In a specific embodiment, the energizer liquid is prepared from GPT nano emulsion and an efficient viscosity reducer, and the concentration of the energizer liquid is 0.1-0.2%. The results of the simulation of the reservoir stimulation with the stimulation fluid are shown in fig. 4, and it can be seen from fig. 4 that after the stimulation fluid is injected, the energy around the wellbore has been restored to substantially the same extent as the remote reservoir. It should be noted that, besides the energizer fluid adopted in this embodiment, the energizer fluid of the present invention may also adopt other nano-emulsions containing an oil-displacing agent, and the oil-displacing agent may be any oil-displacing agent in the prior art.
S4: and injecting a water-soluble temporary plugging agent into each target group fracturing well to plug the tail end of the main fracture, improve the construction net pressure and form a network fracture.
In a specific embodiment, when the water-soluble intra-fracture temporary plugging agent is injected into each target group fracturing well, whether the water-soluble intra-fracture temporary plugging agent needs to be injected into each target group fracturing well is judged according to the difference value of the two-way main stresses of each target group fracturing well: when the difference value of the two-way main stress is larger than the stress difference threshold value, the corresponding target group fracturing well needs to be injected with the water-soluble in-seam temporary plugging agent; and when the difference value of the two-way main stress is smaller than or equal to the stress difference threshold value, the corresponding target group fracturing well does not need to be injected with the water-soluble in-seam temporary plugging agent. In a specific embodiment, the stress difference threshold is 10%.
The amount of the water-soluble intra-seam temporary plugging agent is calculated by the following formula:
M＝V1×ρ1×56％×V2+V2×ρ2 (1)
V1＝πH(d×Δd+Δd2) (2)
in the formula: m is the mass of the temporary plugging agent; v1The volume of the crack to be blocked; rho1The apparent density of the temporary plugging agent is; v2The volume of the perforation; rho2Is the volume density of the temporary plugging agent; h is the height of the supporting seam; d is the outer diameter of the sleeve; Δ d is the cake thickness.
In a specific embodiment, the water-soluble intra-seam temporary plugging agent consists of a temporary plugging agent I and a temporary plugging agent II, wherein the size of the temporary plugging agent I is 20-100 meshes, and the size of the temporary plugging agent II is 1-5 mm. Optionally, the water-soluble temporary plugging agent in the gap is a polymer which can bear pressure of more than 40MPa and takes acrylamide and sulfonate as main components. Optionally, the water-soluble intra-seam temporary plugging agent is the water-soluble intra-seam temporary plugging agent disclosed in CN 108300439A. It should be noted that, in addition to the water-soluble intra-seam temporary plugging agent in the above-described embodiment, other water-soluble intra-seam temporary plugging agents in the prior art may be used in the present invention.
When the water-soluble temporary plugging agent is injected, a bypass can be arranged on a high-pressure manifold for presetting, and the water-soluble temporary plugging agent is added in the construction process; the fracturing truck with a modified fracturing pump head can also be used and directly added into a stirring tank of the sand mixer.
S5: and injecting sand-carrying liquid and displacing liquid into each target group fracturing well to support the network cracks, stopping the pump, closing the well, and opening the well for production after bottom hole pressure is diffused.
In practical application, the invention can also carry out the hole patching on the secondary dessert area which is not perforated in the early stage of the reservoir stratum on the basis of revising and analyzing the logging result aiming at different well conditions to form a new perforation cluster, and the temporary plugging agent is pumped to block the old perforation hole, carry out the fracturing operation on the new perforation cluster and excavate the unused reserves.
In addition, during fracturing construction, according to the well logging data of the fracturing well, combining rock mechanics, calculating the minimum principal stress difference value of the reservoir, and using the minimum principal stress difference value as the basis for single-well segmental transformation of the fracturing well of each target group, and injecting a temporary plugging agent into the fractured stratum in the construction process to plug the end part of a crack; continuously injecting fracturing fluid and proppant to form a new fracture network in the stratum; and completing fracturing of all intervals in sequence.
Although the present invention has been described with reference to a preferred embodiment, it should be understood that various changes, substitutions and alterations can be made herein without departing from the spirit and scope of the invention as defined by the appended claims.
Claims (9)
1. A process flow for repeated fracturing of an old well energized group is characterized by comprising the following steps:
collecting basic data of a target area, analyzing and evaluating the residual recoverable reserve and the residual oil distribution position of a reservoir in the target area, and selecting more than 3 compressible wells in the target area as target group fracturing wells by combining the compressibility analysis and evaluation results of each single well in the target area;
calculating the energy deficit degree of the reservoir according to the production condition of each target group fracturing well and the current reservoir pressure, and calculating the using amount of the energizer liquid according to the deficit degree;
pumping energizing liquid into each target group fracturing well according to the amount of the energizing liquid, and performing cluster fracturing after energizing of all target group fracturing wells is completed;
injecting a water-soluble temporary plugging agent into each target group fracturing well, plugging the tail end of a main crack, improving the construction net pressure and forming a network crack;
and injecting sand-carrying liquid and displacing liquid into each target group fracturing well to support the network cracks, stopping the pump, closing the well, and opening the well for production after bottom hole pressure is diffused.
2. The process flow for old well energized group repeated fracturing as claimed in claim 1, wherein said base data includes reservoir data, production data and reconstruction history data for a single well within said target zone.
3. The process flow for old well energized group repeated fracturing of claim 1 wherein the target zone of each target group fracturing well is the same reservoir and the vertical depth is within the same threshold range.
4. The process flow for old well energized group repeated fracturing as claimed in claim 1, wherein said energizing fluid is a nano emulsion containing oil displacing agent.
5. The process flow for old well energized group repeated fracturing as claimed in claim 4, wherein the concentration of the energizing liquid is 0.1-0.2%.
6. The process flow for old well energized group repeated fracturing as claimed in claim 1, wherein when injecting water soluble in-fracture plugging agent into each target group fracturing well, judging whether each target group fracturing well needs to inject the water soluble in-fracture plugging agent according to the difference of two-way principal stress of each target group fracturing well:
when the difference value of the two-way main stress is larger than the stress difference threshold value, the corresponding target group fracturing well needs to be injected with the water-soluble in-seam temporary plugging agent;
and when the difference value of the two-way main stress is smaller than or equal to the stress difference threshold value, the corresponding target group fracturing well does not need to be injected with the water-soluble in-seam temporary plugging agent.
7. The process flow for old well energized group repeated fracturing of claim 6 wherein the stress difference threshold is 10%.
8. The process flow for old well energized group repeated fracturing as claimed in claim 1, wherein when injecting water soluble intra-fracture temporary plugging agent into each target group fracturing well, the amount of said water soluble intra-fracture temporary plugging agent is calculated by the following formula:
M＝V1×ρ1×56％×V2+V2×ρ2 (1)
V1＝πH(d×Δd+Δd2) (2)
in the formula: m is the mass of the temporary plugging agent; v1The volume of the crack to be blocked; rho1The apparent density of the temporary plugging agent is; v2The volume of the perforation; rho2Is the volume density of the temporary plugging agent; h is the height of the supporting seam; d is the outer diameter of the sleeve; Δ d is the cake thickness.
9. The process flow for old well energized group repeated fracturing according to any one of claims 1 to 8, wherein the water-soluble temporary plugging agent in the seam consists of a temporary plugging agent I and a temporary plugging agent II, the size of the temporary plugging agent I is 20-100 meshes, and the size of the temporary plugging agent II is 1-5 mm.
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| CN115163020A (en) * | 2022-07-01 | 2022-10-11 | 中国石油化工股份有限公司 | Shale oil energy storage, oil displacement, pressure control and crack formation fracturing process |
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