CN115199249A - Method for forming complex seam net by shale oil fracturing - Google Patents
Method for forming complex seam net by shale oil fracturing Download PDFInfo
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Images
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
- 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
-
- 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
- C09K8/66—Compositions based on water or polar solvents
- C09K8/68—Compositions based on water or polar solvents containing organic compounds
-
- 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
- C09K8/80—Compositions for reinforcing fractures, e.g. compositions of proppants used to keep the fractures open
-
- 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
- E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Chemical & Material Sciences (AREA)
- Fluid Mechanics (AREA)
- Environmental & Geological Engineering (AREA)
- Geochemistry & Mineralogy (AREA)
- Physics & Mathematics (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
Abstract
The invention provides a method for forming a complex fracture network by shale oil fracturing, which is characterized in that 3-5 sections of high-viscosity fracturing fluid slugs are pumped in a pre-fluid and initial sand-carrying fluid stage of shale oil reservoir fracturing construction to form a wider complex channel fracture network system of main joints and branch joints, so that the permeability of a reservoir is improved, the oil drainage area is effectively increased, and the fracturing effect is improved. According to the invention, in the stages of pad fluid and sand carrying fluid, high-viscosity fracturing fluid slugs are injected by a large-displacement pump for carrying sand, so that the width of the main channel crack is increased, conditions are created for subsequent high-sand ratio proppant fracturing construction, and the fracturing sand-adding construction success rate is improved; meanwhile, the invention can play a role in temporary plugging, improve the net pressure in the cracks, promote the cracks to be further complicated, form a complex crack network and improve the fracturing effect.
Description
Technical Field
The invention belongs to the technical field of hydraulic fracturing of unconventional oil and gas reservoirs, and particularly relates to a method for forming a complex fracture network by shale oil fracturing.
Background
The shale oil is oil stored in a shale stratum which is rich in organic matters and mainly has nanometer apertures and exists in an adsorption state and a free state; has the characteristics of source-storage integration, wide distribution range, large single-layer thickness, high organic carbon content, high clay mineral content and the like. The shale (compact) oil is mainly distributed in the basin of Songliao, sichuan, etc., in which the Songliao basin is a continental deep lake-half deep lake deposition basin, one section of the Qingshan group is a main force crude oil layer system, the buried depth is 1800-2500 m, permeability is 0.01-0.5 md, porosity is 4.6-8.5%, organic carbon content is 0.4-2.6%, and pyrolysis S is 1 12.5-18.45 mg/g, clay mineral content of 46.03-51.65% and oil saturation of 41.57-68.80%.
After years of exploration and development, domestic shale oil is subjected to fracturing construction by adopting various process technologies, but the effect after fracturing is not ideal. In the early stage, the conventional fracturing technology, namely the crosslinked glue solution sand-carrying technology, is adopted for reservoir reconstruction, but the technology can only form two-wing main cracks in a stratum, the formed cracks are low in complexity and poor in fracturing effect, and therefore the conventional fracturing technology is not suitable for shale oil reservoir reconstruction. In order to form complex fractures in a shale reservoir, reservoir transformation is carried out on the shale oil reservoir by referring to a shale gas fracturing technical mode, namely a slickwater sand-carrying technical mode is adopted, a preposed liquid slickwater is pumped for fracture formation, the fracture is promoted to be complicated by utilizing the good communication and fracture formation capability of the slickwater, and then the large-displacement slickwater is used for carrying sand, so that the fractures are supported to improve the formation flow conductivity; however, the technology is applied on site, and because the stratum has higher embedding degree to the propping agent, sand blocking is easy to occur in the sand adding process, and the success rate of fracturing construction is not high, the technology is not suitable for fracturing modification of shale oil reservoirs. In the fracturing mode, rocket propellant is used as fuel, the injected propellant can be ignited to generate high-energy gas, and multiple fractures can be formed in a reservoir under the instantaneous high-pressure condition; however, the high-energy gas fracturing mode has high requirements on fracturing equipment and high dangerousness, so that the high-energy gas fracturing mode is rarely applied to the site.
Disclosure of Invention
In view of the above, the invention aims to provide a method for forming a complex fracture network by shale oil fracturing, which can reduce sand blocking risk and improve fracturing construction success rate, and can realize optimal fracturing yield increase effect by optimizing parameters such as viscosity change of fracturing fluid, sand adding scale, construction discharge and the like.
The invention provides a method for forming a complex seam net by shale oil fracturing, which comprises the following steps:
pumping and injecting slick water to form branch seams and net seams;
pumping the carboxymethyl hydroxypropyl guar gum fracturing fluid into a stratum main channel crack, and pumping slickwater into a stratum net-shaped complex crack;
alternately pumping silt and a liquid slug; the granularity of the silt is 70-140 meshes;
alternately pumping the medium sand and adding a sand slug and a liquid slug; the granularity of the medium sand is 40-70 meshes.
Preferably, the pump injection slickwater seam-making pump injects 2-3 wellbore volumes of slickwater near wellbore area seam-making.
Preferably, the step of pumping the carboxymethyl hydroxypropyl guar gum fracturing fluid into the fracture of the main formation channel is to pump the carboxymethyl hydroxypropyl guar gum fracturing fluid with the volume of 5-7 wellholes.
Preferably, the pump-injected slick water enters the stratum to form the net-shaped complex seam, and the pump-injected slick water has the volume of 0.8-1.5 mineshafts.
Preferably, the method for alternately pumping the silt, the sand slug and the liquid slug comprises the following steps:
alternately pumping three silts and sand adding slugs and liquid slugs; the sand-carrying fracturing fluid of the silt and sand slug is slickwater; the liquid of the liquid slug is slick water;
alternately pumping a fourth silt and liquid slug; the sand-carrying fracturing fluid of the silt and sand slug is carboxymethyl hydroxypropyl guar gum fracturing fluid; the liquid of the liquid slug is slick water;
alternately pumping the fifth silt and liquid slug; the sand-carrying fracturing fluid of the silt and sand slug is slickwater; the liquid of the liquid slug is slick water.
Preferably, the sand carrying liquid amount of the sand powder adding slug in the process of alternately pumping three sand powder adding slugs and liquid slugs is 1-2 shaft volumes; the liquid volume of the liquid slug is 1-2 well bores volumes.
Preferably, the sand carrying liquid amount of the sand powder adding slug in the process of alternately pumping the fourth sand powder adding slug and the liquid slug is 1-2 shaft volumes.
Preferably, the method for alternately pumping the sand plus the sand slug and the liquid slug comprises the following steps:
alternately pumping the first medium sand and adding a sand slug and a liquid slug; the sand carrying liquid of the medium sand adding slug is slick water; the liquid of the liquid slug is slick water;
alternately pumping the second medium sand and adding the sand slug and the liquid slug; the sand carrying liquid of the medium sand and sand slug is carboxymethyl hydroxypropyl guar gum fracturing liquid; the liquid of the liquid slug is slick water.
Preferably, the construction displacement of the slick water is 10-14 m 3 Min; the construction discharge capacity of the carboxymethyl hydroxypropyl guar gum fracturing fluid is 10-12 m 3 /min。
Preferably, the sand ratio of the silt and the sand slug is 3-10%; the sand ratio of the medium sand and the sand slug is 4-18%.
The shale oil reservoir has the characteristics of high clay mineral content (illite accounts for 70-80%), high embedding degree of sand fracturing propping agent, development of horizontal seams and bedding seams, large horizontal stress difference, difficulty in forming volume seam networks and the like. Aiming at the characteristics of a reservoir stratum, in order to improve the construction success rate and the fracturing effect of shale oil fracturing, the invention organically combines a large-channel fracturing technology and a temporary blocking steering fracturing technology into a whole, is suitable for unconventional reservoir stratums such as compact sandstone and shale, can realize volume transformation in a larger range of a vertical well and a horizontal well, enhances the stratum flow conductivity and improves the post-fracturing effect.
The shale oil and shale gas reservoir characteristics are different, the fluid in the reservoir is different, the reservoir should be distinguished when the reservoir is modified, and the shale oil reservoir fracturing modification mainly adopts large-channel complex fractures, so that the seepage resistance of the fluid is reduced, and the fracturing effect is improved. Compared with the traditional slug sand adding process, the method has the difference that 2-3 high-viscosity frozen glue slugs are pumped and injected in the early sand adding slug stage, the method mainly has the functions of improving the fracturing construction success rate, forming a shale oil reservoir complex fracture network, further expanding the reservoir modification volume and improving the fracturing effect (as shown in figures 1 and 2, figure 1 is a schematic diagram of the complex fracture network formed by shale oil fracturing, and figure 2 is a schematic diagram of the shale oil fracturing fracture network in the prior art).
Drawings
FIG. 1 is a schematic view of a complex network of relatively wide passages formed by shale oil fracturing in accordance with the present invention;
fig. 2 is a schematic diagram of a fracture network of a shale reservoir formed in the prior art.
Detailed Description
The technical solutions in the embodiments of the present invention will be described clearly and completely below, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments. All other examples, which may be modified or appreciated by those of ordinary skill in the art based on the examples given herein, are intended to be within the scope of the present invention. It should be understood that the embodiments of the present invention are only for illustrating the technical effects of the present invention, and are not intended to limit the scope of the present invention. In the examples, the methods used are conventional methods unless otherwise specified.
The invention provides a method for forming a complex seam net by shale oil fracturing, which comprises the following steps:
pumping and pouring slick water to form seams;
pumping the carboxymethyl hydroxypropyl guar gum fracturing fluid into a stratum main channel crack and expanding the crack width, and pumping slickwater into a stratum net-shaped complex crack;
alternately pumping silt and sand adding slugs and liquid isolating and replacing the slugs; the granularity of the silt is 70 to 140 meshes, and the particle size is phi 212 to 106 mu m.
Alternately pumping medium sand and adding a sand slug and liquid isolating and replacing the slug; the granularity of the medium sand is 40-70 meshes, and the grain diameter is phi 425-212 mu m.
In the present invention, it is preferable to perform the pumping construction by using a ground high-pressure pumping equipment.
In the invention, the slickwater with 2-3 shaft volumes is preferably pumped to inject as the pad fluid to make a seam near the well zone; preferably 2 slugs are pumped.
In the invention, the carboxymethyl hydroxypropyl guar gum fracturing fluid is pumped to enter a stratum main channel crack and simultaneously expand the crack width, and then slick water is pumped to replace the carboxymethyl hydroxypropyl guar gum fracturing fluid to enter the stratum and enter the stratum to form a reticular complex crack.
In the present invention, the volume of the carboxymethyl hydroxypropyl guar fracturing fluid pumped is preferably 5 to 7 well volumes, more preferably 6 well volumes.
In the invention, the volume of the slickwater pumped in the process of manufacturing the net-shaped complex seam is preferably 0.8-1.5 shaft volumes, and more preferably 1-1.2 shaft volumes.
The invention adopts slick water and carboxymethyl hydroxypropyl guar gum fracturing fluid as a fracturing fluid system.
In the present invention, the ingredients of the slick water are preferably:
0.05-0.09 wt% of resistance reducing agent;
0.08 to 0.12 weight percent of cleanup additive;
0.1-0.3 wt% of an anti-swelling agent;
0.03-0.07 wt% of demulsifier;
the balance being water.
In the present invention, the mass content of the resistance reducing agent is preferably 0.06 to 0.08%, and more preferably 0.07%. In the present invention, the resistance reducing agent is preferably a polyacrylamide substance. In the present invention, the mass content of the drainage aid (drainage aid in the slipstream) is preferably 0.09 to 0.11%, more preferably 0.1%; the cleanup additive (in slick water) is preferably a combination of polyoxyethylene amine ethers and fluorocarbon surfactants.
In the present invention, the mass content of the anti-swelling agent (anti-swelling agent in the slick water) is preferably 0.15 to 0.25%, more preferably 0.18 to 0.22%, and most preferably 0.2%; the antiswelling agent (antiswelling agent in slick water) is preferably a composite antiswelling agent, and more preferably a poly N-hydroxymethyl acrylamide substance.
In the invention, the mass content of the demulsifier (demulsifier in the slick water) is preferably 0.04-0.06%, and more preferably 0.05%; the demulsifier (demulsifier in slick water) is preferably one or both of alkyl phosphate and alkoxy carboxylate.
In the present invention, the water is preferably clear water.
In the present invention, the density of the slickwater is preferably 0.8 to 1.2g/cm 3 More preferably 0.9 to 1.1g/cm 3 Most preferably 1g/cm 3 (ii) a The apparent viscosity (25 ℃) of the slickwater is preferably 1-3mPa.s, more preferably 1.5-2.5mPa.s, and most preferably 2mPa.s; the pH value of the slickwater is preferably 6-8, and more preferably 7; the anti-swelling rate of the slickwater is preferably more than or equal to 70 percent, more preferably 72 to 76 percent and most preferably 75 percent; the drag reduction ratio of the slickwater is preferably 70 to 75%, more preferably 71 to 74%, more preferably 72 to 73%, and most preferably 72.3%.
In the present invention, the carboxymethyl hydroxypropyl guar fracturing fluid preferably comprises the following components:
0.2-0.4 wt% of a thickening agent;
0.4-0.6 wt% of an anti-swelling agent;
0.03-0.007 wt% of demulsifier;
0.08 to 0.12 weight percent of cleanup additive;
0.08-0.12 wt% of a bactericide;
0.4 to 0.6 weight percent of cross-linking agent;
0.008 to 0.012wt% of gel breaker;
the balance being water.
In the present invention, the mass content of the thickener is preferably 0.25 to 0.35%, and more preferably 0.3%; the thickening agent is preferably carboxymethyl hydroxypropyl guanidine gum; in the present invention, the mass content of the anti-swelling agent (anti-swelling agent in the fracturing fluid) is preferably 0.45 to 0.55%, more preferably 0.5%; the swelling prevention agent (swelling prevention agent in the fracturing fluid) is preferably a poly N-methylolacrylamide substance. In the invention, the mass content of the demulsifier (the demulsifier in the fracturing fluid) is preferably 0.04-0.06%, and more preferably 0.05%; the demulsifier (in the fracturing fluid) is preferably one or both of alkyl phosphate and alkoxy carboxylate. In the invention, the mass content of the cleanup additive (cleanup additive in the fracturing fluid) is preferably 0.09-0.11%, and more preferably 0.1%; the cleanup additive (cleanup additive in the fracturing fluid) is preferably a combination of polyoxyethylene amine ethers and fluorocarbon surfactants. In the present invention, the mass content of the bactericide is preferably 0.09 to 0.11%, more preferably 0.1%; the bactericide is preferably one or more of formaldehyde, glutaraldehyde and quaternary ammonium salt. In the present invention, the mass content of the crosslinking agent is preferably 0.45 to 0.55%, more preferably 0.5%; the cross-linking agent is preferably selected from the group consisting of organic zirconium salts. In the present invention, the mass content of the gel breaker is preferably 0.009 to 0.011%, more preferably 0.01%; the breaker is preferably an ammonium persulfate species.
In the invention, the density of the carboxymethyl hydroxypropyl guar gum fracturing fluid is preferably 1 to 1.04g/cm 3 More preferably 1.01 to 1.03g/cm 3 Most preferably 1.02g/cm 3 (ii) a The viscosity (3 wt% aqueous solution concentration) is preferably 23 to 27mPa.s, more preferably 24 to 26mPa.s, most preferably 25mPa.s; the pH value is preferably 4 to 6, more preferably 5; the temperature resistance and the shear resistance (90 ℃,90 min) are preferably more than or equal to 100mPa.s, more preferably between 100mPa.s and 120mPa.s, and most preferably 115mPa.s; the residue content is preferably 140 to 150mg/L, more preferably 142 to 148mg/L, and still more preferably 144 to 146mg/L, most preferably 145mg/L.
Aiming at shale reservoir transformation, the hydroxypropyl guar fracturing fluid system has the characteristics of high viscosity, high temperature resistance and high shearing resistance, has high crack forming and sand carrying capacities, can only be crosslinked under an alkaline condition, and has incomplete gel breaking and high residue content in a flowback stage; the carboxymethyl hydroxypropyl guar gum fracturing fluid adopted by the invention has high elasticity, high sand suspension property, low using concentration of a thickening agent, low base fluid viscosity, low damage and low friction resistance, and has the performance of 'two high four low' performance, can effectively inhibit clay mineral expansion and migration caused by electronegativity of the clay surface, and plays a role in stabilizing the clay; effectively reduces the damage of the fracturing fluid to the reservoir and achieves the purpose of fully reforming the reservoir.
In the invention, the pump-injected silt and sand adding slug can fill micro cracks, polish seams, reduce filtration loss and reduce construction. In the invention, the granularity of the silt in the silt and sand adding slug is preferably 70 to 140 meshes, more preferably 80 to 130 meshes, more preferably 90 to 120 meshes, and most preferably 100 to 110 meshes. In the present invention, the particle size of the silt is preferably 212 to 106 μm, more preferably 120 to 180 μm, more preferably 140 to 160 μm, and most preferably 150 μm; the volume density is preferably 1.5 to 1.6g/cm 3 More preferably 1.52 to 1.55g/cm 3 Most preferably 1.53g/cm 3 (ii) a The breaking rate is preferably less than or equal to 10 percent (86 MPa), more preferably 8 to 10 percent, and most preferably 8 percent; the sphericity is preferably 0.8 to 1, more preferably 0.9; the circularity is preferably 0.8 to 1, more preferably 0.9.
In the present invention, the method for alternately pumping the sand adding slug and the liquid isolating and replacing slug comprises the following steps:
alternately pumping three silt sand adding slugs and liquid isolating slugs; the sand-carrying fracturing fluid of the silt and sand slug is slickwater; the liquid of the liquid slug is slick water;
alternately pumping a fourth silt sand adding slug and a liquid isolating slug; the sand-carrying fracturing fluid of the silt and sand slug is carboxymethyl hydroxypropyl guar gum fracturing fluid; the liquid of the liquid slug is slick water;
alternately pumping a fifth silt sand adding slug and a liquid isolating slug; the sand-carrying fracturing fluid of the silt and sand slug is slickwater; the liquid of the liquid slug is slick water.
In the invention, in the process of alternately pumping three silt sand adding slugs and liquid isolating slugs, the sand ratio of the silt sand adding slugs is preferably 3-6%, and more preferably 4-5%; the liquid amount of the sand-carrying fracturing fluid is preferably 1-2 well volumes, and more preferably 1.5 well volumes; the liquid volume of the liquid slug is preferably 1 to 2 well bore volumes, more preferably 1.5 well bore volumes.
In the invention, in the process of alternately pumping the fourth silt plus sand slug and the liquid slug, the sand ratio of the silt plus sand slug is preferably 6-8%, and more preferably 7%; the liquid amount of the sand-carrying fracturing fluid is preferably 1-2 well volumes, and more preferably 1.5 well volumes; the liquid volume of the liquid slug is preferably 1.0 to 1.5 well bore volumes, more preferably 1.2 to 1.3 well bore volumes.
In the invention, in the process of alternately pumping the fifth sand powder and sand adding slug and the liquid isolating slug, the sand ratio of the sand powder and sand adding slug is preferably 8-10%, and more preferably 9%; the liquid amount of the sand-carrying fracturing fluid is preferably 1.0-2.0 wellbore volumes, and more preferably 1.5 wellbore volumes; the liquid volume of the liquid slug is preferably 1 to 1.5 wellbore volumes, more preferably 1.2 to 1.3 wellbore volumes.
In the present invention, the method for alternately pumping the silt and the liquid isolating slug more preferably comprises:
pumping a (70-40 mesh) silt and sand slug, wherein the sand-carrying fracturing fluid is slickwater, and the fluid volume is about 1.5 well bores; after the sand slug is filled with silt by the pump, a liquid is filled by the pump to replace the slug, the liquid amount is about 1-2 shaft volumes, and the sand slug carried in the shaft is replaced to enter the stratum;
repeating the above process to complete the subsequent 2 sand powder adding slugs and liquid slugs alternately pumped, wherein the sand-carrying fracturing fluid and the displacing liquid are slickwater;
pumping a fourth silt sand-adding slug and a liquid isolation slug, replacing the sand-carrying fracturing fluid with a carboxymethyl hydroxypropyl guar gum fracturing fluid, introducing a certain amount of sand ratio sand-adding slug into the stratum by the carboxymethyl hydroxypropyl guar gum fracturing fluid with the volume of 1-2 mineshafts, and taking the displacement liquid as slick water, wherein the displacement liquid is used for further expanding the seam width, creating conditions for subsequent sand addition, playing a role of temporary plugging, promoting further complication of artificial cracks, increasing the effective reconstruction volume, and simultaneously observing the pressure change condition of a wellhead, and whether to improve the sand ratio sand-adding slug of the next stage or repeat the sand ratio sand-adding slug of the previous stage according to the design;
and pumping the fifth and subsequent silts, sand adding slugs and displacement liquid slugs, wherein the fracturing fluid is slickwater.
In the invention, the granularity of the medium sand in the medium sand adding slug is preferably 40 to 70 meshes, more preferably 50 to 60 meshes, and most preferably 55 meshes. In the present invention, the medium sand preferably has a particle size of 425 to 212 μm, more preferably 250 to 400 μm, and most preferably 300 to 350 μm; the volume density of the medium sand is preferably 1.5-1.6 g/cm 3 More preferably 1.56 to 1.58g/cm 3 Most preferably 1.57g/cm 3 (ii) a The degree of breakage is preferably 10% or less (52 MPa, more preferably 8 to 10%, most preferably 8%; the sphericity is more than or equal to 0.8, preferably 0.9-1.1, and more preferably 1.0; the roundness is not less than 0.8, preferably 1.0.
In the present invention, the method for alternately pumping sand and liquid slugs preferably comprises:
alternately pumping the first medium sand and adding a sand slug and a liquid slug; the sand carrying liquid of the medium sand and sand slug is slickwater; the liquid of the liquid slug is slick water;
alternately pumping the second medium sand and adding a sand slug and a liquid slug; the sand carrying liquid of the medium sand and sand slug is carboxymethyl hydroxypropyl guar gum fracturing liquid; the liquid of the liquid slug is slick water.
In the invention, in the process of alternately pumping the first sand adding slug and the liquid slug, the sand ratio of the sand adding slug is preferably 4-6%, and more preferably 5%; the liquid amount of the sand-carrying fracturing fluid is preferably 1.0-2.0 wellbore volumes, and more preferably 1.5 wellbore volumes; the liquid volume of the liquid slug is preferably 1.5 to 2.0 wellbore volumes.
In the invention, in the process of alternately pumping the second middling sand adding slug and the liquid slug, the sand ratio of the middling sand adding slug is preferably 6-8%, and more preferably 7%; the liquid amount of the sand-carrying fracturing fluid is preferably 1.0-2.0 wellbore volumes, and more preferably 1.5 wellbore volumes; the liquid volume of the liquid slug is preferably 1.5 to 2.0 wellbore volumes.
In the present invention, the method for alternately pumping sand and liquid slug preferably further comprises:
alternately pumping the third medium sand and adding a sand slug and a liquid slug; the sand carrying liquid of the third medium sand adding slug is slick water; the liquid of the liquid slug is slick water.
In the invention, in the process of alternately pumping the third sand adding slug and the liquid slug, the sand ratio of the sand adding slug is preferably 6-10%, more preferably 8-10%, and most preferably 9%; the liquid amount of the sand-carrying fracturing fluid is preferably 1.0-2.0 wellbore volumes, and more preferably 1.5 wellbore volumes; the liquid volume of the liquid slug is preferably 1 to 2.0 wellbore volumes, more preferably 1.5 wellbore volumes.
In the present invention, the method for alternately pumping sand and adding a sand slug and a liquid slug in sand more preferably comprises:
after the sand powder and sand slug filling stage is completed, the sand slug filling stage of the first middling (40-70 meshes) is started to be filled, after the sand slug filling stage of the first middling is completed, a displacement liquid slug is filled by a pump, and the sand-carrying fracturing fluid is slickwater;
pumping a second medium sand (40-70 meshes) with a sand slug, replacing the sand-carrying fracturing fluid with carboxymethyl hydroxypropyl guar gum, and pumping a replacement fluid slug after the second medium sand (40-70 meshes) with the sand slug is pumped, wherein the replacement fluid is slickwater;
and finishing the sand adding amount in the subsequent medium sand stage, and finishing the design of the whole sand adding amount according to the design.
Compared with the prior art, the slug sanding process has the main difference that 2-3 high-viscosity frozen glue slugs are pumped and injected in the early stage of sanding the slug, and the functions of the slug are mainly to improve the success rate of fracturing construction, form a shale oil reservoir complex seam net, further enlarge the reconstruction volume of the reservoir and improve the fracturing effect.
In the invention, the construction displacement of the slickwater in the process of pumping the slickwater is preferably 10-14 m 3 Min, more preferably 11 to 13m 3 Min, most preferably 12m 3 Min; the construction discharge capacity of the carboxymethyl hydroxypropyl guar gum fracturing fluid in the process of pumping the carboxymethyl hydroxypropyl guar gum fracturing fluid is preferably 12 to 13m 3 /min。
In the present invention, after the sand adding and liquid slugs in the alternate pump injection are completed, the method preferably further comprises:
and (4) pumping the slick water to complete the whole fracturing construction task.
The shale oil reservoir has the characteristics of high clay mineral content (70-80% of illite), high embedding degree of the sand fracturing propping agent, development of horizontal seams and bedding seams, large horizontal stress difference, difficulty in forming a volume seam network and the like. Aiming at the characteristics of a reservoir stratum, in order to improve the construction success rate and the fracturing effect of shale oil fracturing, the invention organically combines a large-channel fracturing technology and a temporary plugging steering fracturing technology into a whole, is suitable for unconventional reservoir stratums such as compact sandstone and shale, can realize volume transformation in a larger range of a vertical well and a horizontal well, enhances the stratum flow conductivity and improves the post-fracturing effect.
The slippery water adopted in the following examples of the invention comprises the following components: 0.07wt% of drag reducer (polyacrylamide substance), 0.1wt% of cleanup additive (polyoxyethylene amine ether and fluorocarbon surfactant compound), 0.2wt% of composite anti-swelling agent (poly N-hydroxymethyl acrylamide substance), 0.05wt% of demulsifier (alkyl phosphate and alkoxy carboxylate), and the balance of clear water; the adopted drag reducer, cleanup additive, composite anti-swelling agent and demulsifier are provided by Beijing BFC company. The adopted carboxymethyl hydroxypropyl guar gum fracturing fluid comprises the following components: 0.3wt% of thickening agent (carboxymethyl hydroxypropyl guar gum), 0.5wt% of anti-swelling agent (poly N-hydroxymethyl acrylamide substance), 0.05wt% of demulsifier (alkyl phosphate and alkoxy carboxylic ester), 0.1wt% of cleanup additive (polyoxyethylene amine ether and fluorocarbon surfactant complex), 0.1wt% of bactericide (formaldehyde), 0.5wt% of crosslinking agent (organic zirconium salt substance), 0.01wt% of gel breaker (ammonium persulfate substance) and the balance of clear water; the adopted thickening agent, anti-swelling agent, demulsifier, cleanup additive, bactericide, cross-linking agent and gel breaker are provided by Beijing BFC company. The proppants (silt and medium sand) with different particle sizes are provided by Yangquan Changnie oil fracturing proppants, inc.
Example 1
The specific implementation steps of the fracturing pump injection procedure of a certain shale oil well are as follows:
(1) Pumping 60m by ground high-pressure pumping equipment 3 The pre-liquid amount of the slickwater is pumped to 120m 3 Freezing glue solution;
(2) Pump 30m 3 A slickwater liquid slug;
(3) The first sand adding slug (70-140 meshes) is pumped, and the sand carrying liquid is 40m 3 The sand ratio of the slickwater is 3 percent;
(4) Pump 30m 3 The slickwater isolating fluid slug replaces the sand-carrying fluid slug in the shaft to enter the stratum;
(5) Repeating the steps (3) and (4) to finish the subsequent 2 sand powder adding slugs, wherein the sand carrying liquid is slickwater;
(6) Pumping the fourth sand powder and adding a sand slug, and switching the sand-carrying liquid to 50m 3 The sand ratio of the high-viscosity glue solution (jelly glue solution) is 8 percent, and then 35m is pumped and injected 3 A slug of slickwater spacer fluid;
(7) Repeating the steps (3) and (4) to complete the subsequent addition of the sand slug and the sand amount of the silt;
(8) After the sand amount of the silt stage is injected by a pump, firstly, injecting first medium sand (40-70 meshes) and adding a sand slug by using a slickwater (the liquid amount is 2 shaft volumes) pump, wherein the sand ratio is 4%, and then, injecting a (slickwater) isolating liquid slug with 1.0-1.5 shaft volumes by a pump;
(9) The second medium sand slug is started to be pumped, the sand-carrying liquid is changed into a frozen glue liquid (the liquid amount is 1.5 shaft volumes), the sand ratio is 6 percent, and after the second medium sand adding sand ratio slug is pumped, the slick water isolating liquid slug with 1.0-2.0 shaft volumes is pumped;
(10) Pumping a third medium sand slug, replacing the jelly liquid with slickwater (the liquid amount is 1.5 shaft volumes), the sand ratio is 8 percent, the liquid amount of the slickwater is 1.0-2.0 shaft volumes, and pumping slickwater isolation liquid with 1.0-2.0 shaft volumes after the third medium sand slug is pumped;
(11) And (5) repeating the step (10) according to different designed sand ratios to complete the subsequent sand adding workload, and finally replacing the slickwater liquid with the volume of 1.2-1.8 mineshafts to complete the whole fracturing construction task.
The well is a shale oil parameter well sunken in the north of the Songliao basin, the fracturing construction is carried out on site by applying the process method (complex fracture network fracturing technology) in the embodiment 1 of the invention, not only the design sand adding task is smoothly completed, and all index parameters meet the design requirements, but also industrial oil flow is obtained during oil testing, the daily oil yield is 3.5 tons, the breakthrough of the shale oil yield in the area is realized, and a good fracturing transformation effect is obtained.
Example 2
The specific implementation steps of the fracturing pump injection procedure of a certain shale oil well are as follows:
(1) Pumping 60m by ground high pressure pumping equipment 3 The pre-liquid amount of the slickwater is pumped to 120m 3 Freezing glue solution;
(2) Pump injection 40m 3 A slickwater liquid slug;
(3) The first (70-140 meshes) silt slug is pumped, and the sand carrying liquid is 40m 3 The sand ratio of the slickwater is 3 percent;
(4) Pump 30m 3 The slick water spacer fluid slug replaces the sand-carrying fluid slug in the shaft to enter the stratum;
(5) Repeating the steps (3) and (4) to finish the subsequent 2 sand powder adding slugs, wherein the sand carrying liquid is slick water;
(6) Pumping the fourth sand powder and adding sand slug, and switching the sand-carrying liquid to 40m 3 The sand ratio of the high-viscosity glue solution (jelly glue solution) is 8 percent, and then the high-viscosity glue solution is pumped for 30m 3 A slug of slickwater spacer fluid;
(7) Repeating the steps (3) and (4) to complete the subsequent addition of the sand slug and the sand amount of the silt, and increasing the sand ratio to 10%;
(8) After the sand amount of the silt stage is filled by the pump, the sand adding stage is started, first medium sand (40-70 meshes) is filled by the pump, a sand slug is added, the sand ratio is 4%, and then a (slick water) isolating liquid slug with the volume of 1.5 mineshafts is filled by the pump;
(9) The second medium sand slug begins to be pumped, the sand-carrying liquid is changed into a frozen glue liquid (the liquid amount is 2 shaft volumes), the sand ratio is 6 percent, and after the second medium sand adding sand ratio slug is pumped, the slickwater isolating liquid slug with the volume of 1.5 shafts is pumped;
(10) Pumping a third medium sand slug, replacing the jelly liquid with slickwater, wherein the sand ratio is 6 percent, the liquid amount of the slickwater is 1.5 shaft volumes, and pumping slickwater isolation liquid with 1.5 shaft volumes after the third medium sand slug is pumped;
(11) Repeating the step (10) according to different design sand ratios to complete subsequent sand adding workload;
(12) And finally, replacing the slickwater liquid with 2 shaft volumes to complete the whole fracturing construction task.
The well is a shale oil horizontal well in the north of the Songliao basin, the complex fracture technology provided by the embodiment 2 of the invention is adopted on site to complete the fracturing construction of the well, the oil testing stage after fracturing is self-blown, the daily oil yield is 11.4 tons, and the fracturing reconstruction effect is good.
The embodiment shows that the shale oil reservoir has the characteristics of high clay mineral content (70-80% of illite), high proppant embedding degree, development of horizontal seams and bedding seams, large horizontal stress difference, difficulty in forming a volume seam network and the like. Aiming at the characteristics of a reservoir stratum, in order to improve the construction success rate and the fracturing effect of shale oil fracturing, the invention organically combines a large-channel complex fracture network fracturing technology and a temporary blocking steering fracturing technology into a whole, is suitable for unconventional reservoir stratums such as compact sandstone and shale, can realize volume transformation in a larger range of a straight well and a horizontal well, enhances the stratum flow conductivity and improves the post-fracturing effect.
While only the preferred embodiments of the present invention have been shown and described, it will be understood by those skilled in the art that various changes in form and details may be made therein without departing from the spirit and scope of the invention.
Claims (10)
1. A method of shale oil fracturing to form a complex fracture network, comprising:
pumping and pouring slick water to form seams;
pumping the carboxymethyl hydroxypropyl guar gum fracturing fluid into a stratum main channel crack, and pumping slickwater into a bottom layer to form a net-shaped complex crack;
alternately pumping silt and a liquid slug; the granularity of the silt is 70-140 meshes;
alternately pumping the medium sand and adding a sand slug and a liquid slug; the granularity of the medium sand is 40-70 meshes.
2. The method of claim 1, wherein the pump-pumped slickwater cementing is pump-pumped slickwater near wellbore area cementing from 2 to 3 wellbore volumes.
3. The method of claim 1, wherein pumping the carboxymethyl hydroxypropyl guar fracturing fluid into the primary channel fracture of the formation is pumping 5 to 7 wellbore volumes of carboxymethyl hydroxypropyl guar fracturing fluid.
4. The method of claim 1, wherein the pumping of slickwater into the subterranean formation creates a reticulated complex seam that pumps slickwater from 0.8 to 1.5 wellbore volumes.
5. The method of claim 1, wherein the method of alternately pumping the silt plus sand slug and the liquid slug comprises:
alternately pumping three silts and sand adding slugs and liquid slugs; the sand-carrying fracturing fluid of the silt and sand slug is slickwater; the liquid of the liquid slug is slick water;
alternately pumping the fourth silt and adding the sand slug and the liquid slug; the sand-carrying fracturing fluid of the silt and sand slug is carboxymethyl hydroxypropyl guar gum fracturing fluid; the liquid of the liquid slug is slick water;
alternately pumping the fifth silt and liquid slug; the sand-carrying fracturing fluid of the silt and sand slug is slickwater; the liquid of the liquid slug is slick water.
6. The method according to claim 5, wherein the sand carrying amount of the silt plus sand slug in the process of alternately pumping three silt plus sand slugs and liquid slugs is 1-2 well bore volumes; the liquid volume of the liquid slug is 1-2 shaft volumes.
7. The method of claim 5, wherein the sand-carrying fluid volume of the sand-in-silt slug during the alternate pumping of the fourth sand-in-silt slug and the liquid slug is 1-2 wellbore volumes.
8. The method of claim 1, wherein the method of alternately pumping sand plus sand slugs and liquid slugs comprises:
alternately pumping the first medium sand and adding a sand slug and a liquid slug; the sand carrying liquid of the medium sand and sand slug is slickwater; the liquid of the liquid slug is slick water;
alternately pumping the second medium sand and adding a sand slug and a liquid slug; the sand carrying liquid of the medium sand and sand slug is carboxymethyl hydroxypropyl guar gum fracturing liquid; the liquid of the liquid slug is slick water.
9. The method of claim 1, wherein the slickwater is constructed with a displacement of 10-14 m 3 Min; the construction discharge capacity of the carboxymethyl hydroxypropyl guar gum fracturing fluid is 10-12 m 3 /min。
10. The method according to claim 1, characterized in that the sand ratio of the silt and the sand slug is 3-10%; the sand ratio of the medium sand and the sand slug is 4-18%.
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