CN109296350B - Fracture network volume fracturing method for carbonate reservoir - Google Patents
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- 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
- E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
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Abstract
The invention relates to a fracture network volume fracturing method for a carbonate reservoir. The volume fracturing method comprises the following steps: 1) initial cracking: injecting slick water into the pretreated stratum to form a seam, and then injecting gelled acid to perform acid corrosion modification on the seam to increase the length of the seam; 2) temporary blocking in the seam: adopting slickwater to carry a temporary plugging agent to temporarily plug the microcracks formed by acid etching modification; 3) turning to acid fracturing: injecting gelled acid into the stratum subjected to temporary plugging, and after the gelled acid replaces the temporary plugging agent in place, turning to other parts for acid etching modification; 4) sliding water to form seams: injecting slick water into the stratum subjected to acid etching modification in the step 3) for seam forming; 5) and (3) expanding the gap and supporting: and (4) injecting sand-carrying liquid into the stratum subjected to the seam making in the step 4) for supporting. The method can effectively reduce the fluid loss, realize the 'near-control and far-expansion', form rich secondary cracks, improve the connectivity with the main cracks and the natural cracks and further improve the transformation effect of volume fracturing.
Description
Technical Field
The invention belongs to the field of volume fracturing modification of shale gas reservoirs, and particularly relates to a fracture network volume fracturing method of a carbonate reservoir.
Background
Shale gas reservoirs have the characteristics of low porosity and permeability, various gas occurrence states and the like, and can be developed economically and effectively generally after hydraulic fracturing reservoir modification measures are taken. The volume fracturing is to comprehensively reform the reservoir in the three-dimensional directions of length, width and height so as to achieve the purpose of increasing the seepage area and the flow conductivity of the reservoir.
Chinese patent No. CN105275446B discloses a volume fracturing modification method, which includes: and injecting low-viscosity fracturing liquid to ensure that the microcracks of the near-well stratum are saturated by the low-viscosity fracturing liquid which is filtered, and then injecting sand-mixing fracturing liquid containing small-particle-size propping agent to block the microcracks, reduce the bending friction, reduce the near-well-barrel effect and ensure that a main force fracture dominant channel is formed. Alternately injecting high-viscosity fracturing fluid and low-viscosity fracturing fluid to continuously expand and extend the generated main fracture from the near-well stratum to the middle-far well stratum, communicating with the far-field natural fracture and the weak surface fracture and reaching the expected length, and injecting sand-mixing fracturing fluid containing medium-particle-size proppant to support the main fracture; and injecting a sand fracturing fluid containing a large-particle-size proppant to complete fracture support.
The existing volume fracturing method is used for injecting different fracturing fluid systems in an alternating mode in the hydraulic fracturing process so as to achieve the purpose of enhancing swept volume of hydraulic fracturing. The method focuses on the fracturing transformation of the main crack, the formation of the secondary crack is limited, the secondary crack is not favorable for forming good communication with the main crack and the natural crack, and the volume fracturing transformation effect is still to be improved.
Disclosure of Invention
The invention aims to provide a fracture network volume fracturing method for a carbonate reservoir, so as to solve the problems of small formation amount of secondary fractures and poor volume fracturing transformation effect in the conventional method.
In order to achieve the purpose, the technical scheme adopted by the fracture network volume fracturing method of the carbonate reservoir is as follows:
a fracture network volume fracturing method for a carbonate reservoir comprises the following steps:
1) initial cracking: injecting slick water into the pretreated stratum to form a seam, and then injecting gelled acid to perform acid corrosion modification on the seam to increase the length of the seam;
2) temporary blocking in the seam: adopting slickwater to carry a temporary plugging agent to temporarily plug the microcracks formed by acid etching modification;
3) turning to acid fracturing: injecting gelled acid into the stratum subjected to temporary plugging, and after the gelled acid replaces the temporary plugging agent in place, turning to other parts for acid etching modification;
4) sliding water to form seams: injecting slick water into the stratum subjected to acid etching modification in the step 3) for seam forming;
5) and (3) expanding the gap and supporting: and (4) injecting sand-carrying liquid into the stratum subjected to the seam making in the step 4) for supporting.
The fracture network volume fracturing method of the carbonate reservoir provided by the invention realizes that after a main fracture is fractured, a temporary plugging agent is added to temporarily plug a micro-fracture, the net pressure in the fracture is improved, a complex fracture network system is formed on the basis of a natural fracture and an artificial fracture, and finally, the fracture is completely filled by using a sand carrying liquid, so that the comprehensive and effective support of the fracture network system is realized. The method can effectively reduce the fluid loss, realize the 'near-control and far-expansion', form rich secondary cracks, improve the connectivity with the main cracks and the natural cracks and further improve the transformation effect of volume fracturing.
In the step 1), the pretreatment is to inject a pre-acid into the stratum so as to reduce the friction of the hole and the fracture pressure of the near-well stratum. By adopting the means to pretreat the stratum, the friction resistance of the hole and the fracture pressure of the near-well stratum can be effectively reduced, and the subsequent steps can be conveniently carried out.
And the step of injecting the slickwater for making the cracks comprises alternately injecting the slickwater and the micro-crack plugging slug (the slug with the small particle size). The micro-crack plugging slug consists of slickwater and small-particle size propping agent, and the mass content of the small-particle size propping agent in the slug is 2-3%. The small-particle size proppant has a particle size of 70-140 meshes. The small-particle-size slug can block the micro-cracks of the reservoir stratum to reduce the filtration reduction of the fracturing fluid, and can further reduce the filtration loss by adopting a liquid nitrogen injection-following mode. By adopting the method for treatment, filtration reduction can be realized by using the micro-crack plugging slug, the wall surface of the crack is abraded, the construction friction is reduced, and the near-wellbore effect is reduced.
The acid etching transformation is carried out by adopting gelled acid, and the reaction speed of acid liquid and rock can be reduced and the acid etching seam length can be increased by matching with the pretreatment of the front-mounted slipstream.
In the step 2), the temporary plugging agent comprises a fiber temporary plugging agent and a particle temporary plugging agent, and the mass ratio of the fiber temporary plugging agent to the particle temporary plugging agent is (50-60): (100-. By adopting the temporary plugging mode, good temporary plugging effect can be obtained, for example, in the first section of an ancient DPF-203 well under a gas field of a big cattle during temporary plugging and acid fracturing construction, 50kg of fiber temporary plugging agent and 100kg of particle temporary plugging agent are added, the pressure of temporary plugging is increased by 12.6mPa, in the second section of temporary plugging and acid fracturing construction, 50kg of fiber temporary plugging agent is added, 100kg of particle temporary plugging agent is added, the pressure of temporary plugging is increased by 16.7mPa, and the temporary plugging effect is obvious.
The step mainly adopts a temporary blocking modification process in the gap, on one hand, liquid filtration loss is reduced by temporary blocking in the gap, the 'near and far control' is realized, on the other hand, the net pressure in the gap is increased, conditions can be created for subsequent steering acid fracturing, the generation of secondary cracks such as more acid-etched earthworm holes and acid-etched microcracks is promoted, the complexity of the crack is improved, and then the main crack and the natural crack are better communicated to form a communication gap network.
And 3) the process of turning to acid fracturing is mainly a turning to acid fracturing process, on the basis of temporary plugging in the step 2), the filtration loss in the turning to acid fracturing process is less, the net pressure in the seam is high, a primary complex seam net system is favorably formed, and good conditions are created for the perfection of the complex seam net system in the step 4).
In the step 4), injecting slickwater for making the crack comprises alternately injecting slickwater and micro-crack plugging slugs. The step 4) has the main function that on the basis of the primary seam net system formed in the step 3), slickwater is matched with slug injection, so that the length of a crack can be effectively increased, the seam making effect is perfected, and a complex seam net system is finally formed.
In the step 5), the step of injecting the sand carrying liquid comprises the steps of injecting the sand carrying liquid containing the medium-particle-size propping agent to support the seam net main body, and tracing the sand carrying liquid containing the large-particle-size propping agent to support the seam opening in the later period. The medium particle size can be 40-70 meshes, and the large particle size can be 30-50 meshes. After the seam expanding support, the seam net system can be kept stable, and the flow guide capability of the seam net system is optimized. And (4) after the sand-carrying liquid is injected, using slickwater to replace the sand-carrying liquid in place.
Preferably, after the step 5) of expanding the seam and supporting, completing the fracturing transformation of the perforation section; and further comprising a step of temporarily blocking the gap, wherein the step of temporarily blocking the gap is to put a temporarily blocking ball into the perforation section which is subjected to fracturing transformation, and then sequentially repeat the steps 1) -5) to perform fracturing transformation on another perforation section on the same fracturing section. And the temporary blocking in the seams and the temporary blocking between the seams are combined, so that the fracture can be driven to turn, and a grid fracture system is constructed. The practical application effect shows that the fracturing transformation is carried out on each perforation section of the horizontal well by combining the intra-fracture temporary plugging and the inter-fracture temporary plugging, so that natural fractures and artificial fractures around a shaft can be staggered and branched to form an artificial fracture three-dimensional network, the maximization of the swept volume of the fractured fractures in a reservoir is realized, and the seepage volume of a fractured well is multiplied, thereby achieving the purpose of increasing the yield of an oil and gas field.
The temporary blocking in the crack is to block the end part of the crack, stop the extension of the crack, increase the net pressure in the crack and open the natural crack; the temporary blocking among the seams is to use a temporary blocking ball to block a seam opening of the seam and then fracture the other perforation hole, the temporary blocking among the seams realizes the reconstruction of multiple seams in the section, and the effectiveness of the reconstruction of the perforation section can be effectively improved.
In the volume fracturing process, the initial fracturing step adopts large-displacement injection, the temporary plugging step in the seam adopts small-displacement injection, the turning acid fracturing step adopts medium-displacement injection, and the slickwater seam making step and the seam expanding supporting step both adopt large-displacement injection. The large discharge injection is generally 8-10m3Permin, medium displacement injection typically 5-8m3Min, low volume injection typically 1-4m3And/min. The injection mode has the advantages that the large-discharge injection of slickwater for crack formation and crack expansion support facilitates the improvement of the length of the crack and the improvement of the crack formation effect, so that a complex crack network is formed, and the maximization of the crack propagation volume in the reservoir is realized; the injection of the diverting acid with medium displacement is convenient for forming a primary complex seam net system, the pore volume of the acid-etched fracture is increased, and the seepage area is increased; the temporary plugging agent injected into the crack with small discharge capacity is convenient for transporting the temporary plugging agent carried by slickwater to a specified position, thereby temporarily plugging the microcracks formed by acid etching modification.
Closing the well for 30min after volume fracturing to ensure the formation of higher acid-etched fracture conductivity, starting blowout 30min after construction, and shortening the well closing time to fully utilize acid-rock reaction to form CO2The self energy of the utility model is beneficial to the flowback.
Drawings
FIG. 1 is a flow chart of the operation of an embodiment of a method of fracture network volume fracturing of a carbonate reservoir of the present invention;
FIG. 2 is a graph of a simulation of the propagation of a fracture formed by conventional acid fracturing of the prior art;
FIG. 3 is a simulation of the propagation of a crack formed by the method of the present invention.
Detailed Description
The following examples are provided to further illustrate the practice of the invention. The injection liquid in the examples will be briefly described below. The percentage of each component in the injected liquid is weight percentage.
The slick water consists of 0.06 percent of resistance reducing agent, 0.3 percent of anti-swelling agent, 0.1 percent of cleanup additive and the balance of water, and has the characteristic of low viscosity.
The slug consists of slick water and 70/140-mesh powder pottery, and the mass percentage of the powder pottery is 2-3%.
The preposed acid consists of 25 percent of HCl, 1.5 percent of corrosion inhibitor, 0.15 percent of iron ion stabilizer, 1.0 percent of cleanup additive, 0.5 percent of foaming agent and the balance of water.
Gelled acid consisting of 25% HCl, 1.5% corrosion inhibitor, 0.15% iron ion stabilizer, 1.0% drainage aid, 0.5% foaming agent, 0.5% thickener and the balance water.
The sand carrying liquid consists of 0.3 percent of thickening agent, 0.3 percent of anti-swelling agent, 0.1 percent of discharge aiding agent and the balance of water.
In the injected liquid, slickwater, slug, front acid, gelled acid and sand carrying liquid are all in the prior art, can be replaced by the similar products in the prior art, or are prepared according to the components, wherein the related assistants such as the resistance reducing agent, the anti-swelling agent, the cleanup additive and the like are all conventional commercial products. Temporary plugging agents such as a fiber temporary plugging agent, a particle temporary plugging agent, a temporary plugging ball and the like are respectively used in the fracturing, and the particle temporary plugging agent is YX-ZDJ-S90 water-soluble temporary plugging powder purchased from West Security and friendship energy science and technology Limited; the performance indexes of the particle temporary plugging agent, the fiber temporary plugging agent and the temporary plugging ball are shown in tables 1, 2 and 3.
TABLE 1 Performance index of particulate temporary plugging agent
TABLE 2 Performance index of fiber temporary plugging agent
| Serial number | Measurement items | Technical index |
| 1 | Appearance of the product | White or |
| 2 | Length, mm | 6±1 |
| 3 | Dispersibility | After stirring for 15s, the mixture was uniformly dispersed |
| 4 | Bearing strength, MPa | ≥50 |
| 5 | Solubility Property (90 ℃ C.) | 16h (dissolution rate is more than or equal to 80%) |
TABLE 3 temporary plugging ball Performance index
| Serial number | Measurement items | Technical index |
| 1 | Appearance of the product | Grey or |
| 2 | Density, g/cm3 | 1.20±0.10 |
| 3 | Diameter of | 11mm，13mm |
| 4 | Bearing strength, MPa | ≥50 |
| 5 | Solubility Property (90 ℃ C.) | 7d (dissolution rate is more than or equal to 80%) |
The embodiment of the fracture network volume fracturing method of the carbonate reservoir disclosed by the invention is illustrated by taking a carbonate reservoir in a big-ox gas field as an example, the fracture of the carbonate reservoir in the area develops and has higher brittleness, the quartz content of the reservoir is lower and only accounts for 0.6-1.1% of the total mineral content, but the content of calcite accounts for more than 98%, the calcite has better brittleness, the reservoir rich in brittle minerals is favorable for generating a complex fracture network, and a working flow chart of a specific fracturing modification process is shown in figure 1 and adopts the following steps:
1) a pretreatment stage: at 1m3The displacement of/min injected 1/3 times the wellbore volume of pad acid to clean the wellbore and reduce the hole friction and near-well formation fracture pressure. Then at 4m3And injecting slickwater at the discharge capacity of/min, and replacing the preposed acid to the position of the perforation hole, so that the preposed acid fully soaks the perforation hole and the near wellbore zone.
2) Initial crack initiation stage: after the preposed acid completely enters the stratum, the large discharge capacity (10 m) is adopted3Min) alternately injecting slickwater and slug, wherein the slug plugs the reservoir microfractures when the slickwater makes fractures, simultaneously abrades the fracture wall surface, has the functions of filtration reduction and construction friction resistance reduction, and enables the near-well stratum to saturate part of slickwater in the microfractures formed in the initial fracture initiation stage in advance, thereby reducing the near-well barrel effect.
3) Acid injection stage: at a large displacement (10 m)3Min) injecting gelled acid to etch the micro cracks of the slick water communication in the step 2) and increase the acid etching crack length.
4) And (3) temporarily blocking slickwater: with small displacement (2-4 m)3Min) temporarily blocking the acid-etched micro cracks formed in the step 3) by using the slickwater carrying the fiber temporary blocking agent, so that net pressure in the cracks deflects to form secondary cracks, communicate the natural cracks and improve the connectivity of the main cracks, the natural cracks and the secondary cracks. The adding proportion of the fiber temporary plugging agent in the slick water is 5 percent.
5) Turning to an acid injection stage: at medium displacement (5 m)3Min) to realize diverting acid pressure, so that other parts after temporary plugging are subjected to acid etching treatment, the effective action distance of the acid liquid is increased, and complex acid etching cracks are formed.
6) Alternate injection of slick water and slugs: at a large displacement (10 m)3Min) alternately injecting slick water and a slug to reform the acid-etched crack to obtain the reformed acid-etched crack.
7) And (3) fracturing and joint expanding supporting stage: injecting a sand-carrying liquid to support the modified acid-etched fracture formed in the step 6), and during injection, firstly injecting a large amount of 40/70-mesh and 52-MPa-pressure-resistant medium-particle-size high-strength propping agent, and later tracing a 30/50-mesh and 52-MPa-pressure-resistant large-particle-size high-strength propping agent, so that the fracture conductivity of the near-well acid-etched seal is improved; and finally, injecting slick water with the volume not less than one time of the shaft for replacement to finish the fracturing reformation of the perforation section.
8) Temporary blocking among the gaps: and (3) putting into a temporary plugging ball between cracks to plug the perforation section of the fracturing modification completed in the step 7), and repeating the steps 1) to 7) to perform the fracturing modification of another perforation section on the same fracturing section.
The method of the embodiment is utilized to realize fracture network volume fracturing transformation of the DPF-205 well, and the method adopts 'segmented multi-cluster' perforation, wherein the length of each segment (fracturing segment) is 150m, a plurality of clusters of fractures are contained on the segment, the span of each cluster of fractures is 0.45-0.77m, and the interval between two adjacent clusters of fractures is 20-30 m. The single-cluster cracks are blocked in the cracks, the cracks in the sections are blocked between the cracks, and the staged fracturing reformation is completed in sequence, and the specific pump injection process is shown in table 4.
TABLE 4 concrete acid fracturing construction pump-injection process of DPF-205 well
Table 5 illustrates the construction effect comparison of 2 wells (DPF-203 well and DPF-205 well) after the cattle land gas field partial horizontal well is modified by adopting conventional acid fracturing modification and the slotted mesh volume fracturing modification method of the embodiment.
TABLE 5 comparison of conventional acid fracturing and fracture network volume fracturing effects of horizontal well
As can be seen from Table 5, after the DPF-203 well and the DPF-205 well are subjected to volume fracture network fracturing modification, the fracture conductivity is increased, and the yield is increased obviously.
FIGS. 2 and 3 show simulated extension patterns of a conventional fracture on a DP-2 well and a fracture on a DPF-203 well, respectively. It can be seen that after the seam network volume fracturing method of the embodiment is adopted for reconstruction, the length and the height of the fracture are obviously improved compared with those of the conventional acid fracturing method, and the reconstruction effect is obvious.
The well-pressure-free flow rate of the DPF-203 is 8.2 ten thousand square/day, the well-pressure-free flow rate of the DPT-112 well at the same adjacent position is 6 ten thousand square/day, the same-specific yield is increased by 26%, the well-pressure-free flow rate of the DPF-205 well is 7.8 ten thousand square/day, the well-pressure-free flow rate of the DP88S well at the adjacent well is 0.545 ten thousand square/day, the well-pressure-free flow rate of the DP107T well is 4.298 ten thousand square/day, and the well-pressure-free flow rate is obviously improved.
Claims (4)
1. A fracture network volume fracturing method for a carbonate reservoir is characterized by comprising the following steps:
1) initial cracking: injecting slick water into the pretreated stratum to form a seam, and then injecting gelled acid to perform acid corrosion modification on the seam to increase the length of the seam; injecting slick water for making cracks comprises alternately injecting slick water and micro-crack plugging slugs;
2) temporary blocking in the seam: adopting slickwater to carry a temporary plugging agent to temporarily plug the microcracks formed by acid etching modification;
3) turning to acid fracturing: injecting gelled acid into the stratum subjected to temporary plugging, and after the gelled acid replaces the temporary plugging agent in place, turning to other parts for acid etching modification;
4) sliding water to form seams: injecting slick water into the stratum subjected to acid etching modification in the step 3) for seam forming; injecting slick water for making cracks comprises alternately injecting slick water and micro-crack plugging slugs;
5) and (3) expanding the gap and supporting: injecting sand-carrying liquid into the stratum subjected to the seam making in the step 4) for supporting;
step 5), completing fracturing transformation of the perforating section in the steps 1) to 5) after expanding the seam and supporting; the method also comprises a step of temporary plugging among the cracks, wherein the step of temporary plugging among the cracks is to put a temporary plugging ball into the perforation section which is subjected to fracturing transformation, and then sequentially repeat the steps 1) -5) to perform fracturing transformation on another perforation section on the same fracturing section;
the micro-crack plugging slug consists of slickwater and small-particle size propping agent, wherein the mass content of the small-particle size propping agent in the slug is 2-3%, and the particle size of the small-particle size propping agent is 70-140 meshes;
the initial crack initiation step adopts large-displacement injection, the temporary blocking step in the crack adopts small-displacement injection, the turning acid fracturing step adopts medium-displacement injection, and the slick water crack formation step and the crack expansion supporting step both adopt large-displacement injection.
2. The method for fracture network volume of carbonate reservoir according to claim 1, wherein in step 1) the pretreatment is injection of a pre-acid into the formation to reduce the perforation friction and the fracture pressure of the near-well formation.
3. The method for fracturing the fracture network volume of the carbonate reservoir in the step 2), wherein the temporary plugging agent comprises a fiber temporary plugging agent and a particle temporary plugging agent, and the mass ratio of the fiber temporary plugging agent to the particle temporary plugging agent is (50-60): (100-150).
4. The method for fracturing the fracture network volume of the carbonate reservoir according to claim 1, wherein in the step 5), the step of injecting the sand-carrying fluid comprises the steps of injecting the sand-carrying fluid containing the medium-particle-size proppant to support the fracture network body, and then, chasing the sand-carrying fluid containing the large-particle-size proppant to support the fracture openings.
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| CN105275446B (en) * | 2014-06-30 | 2018-03-30 | 中国石油化工股份有限公司 | A kind of volume fracturing remodeling method |
| US9771784B2 (en) * | 2015-10-23 | 2017-09-26 | Ely And Associates Corp. | Method for re-stimulating wells with hydraulic fractures |
| CN106907137B (en) * | 2015-12-23 | 2019-01-01 | 中国石油化工股份有限公司 | A kind of method of the effective water conservancy diversion in shale oil reservoir volume fracturing crack |
| CN106917619B (en) * | 2017-03-21 | 2019-06-11 | 中国石油天然气股份有限公司 | The temporary stall of slit formation carbonate reservoir to fracture support integration remodeling method |
| CN107387053B (en) * | 2017-06-13 | 2020-05-22 | 北京大学 | Method for collaborative fracturing of main cracks and complex crack network of large channel |
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