CA2614114C - Methods for preventing proppant carryover from fractures, and gravel-packed filter - Google Patents
Methods for preventing proppant carryover from fractures, and gravel-packed filter Download PDFInfo
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- 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
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Abstract
This invention relates to the oil and gas industry, in particular, to methods affecting the formation productivity at the oil and gas production stage.
A method for fracture propping in a subsurface layer, which ensures a reliable protection of wells from the proppant carryover from the fracture, has been proposed.
According to the proposed method, a fracturing fluid is mixed with a propping agent and granulated binding material with a length-to-width ratio of less than or equal to 10;
thereafter, a formation fracturing process is implemented. Then, the granulated binding material hardens and forms a homogenous firm mass with the propping agent, which impedes the closing of the fracture and precludes proppant carryover from the fracture.
Or, a fracturing fluid composition obtained by mixing a propping agent with a binding compound in the form of a powder whose size varies from about 1 to about 500 µm. A
gravel-packed filter is then constructed; the said filter is based on the application of the working fluid comprising a propping filler and granulated binding component with a length-to-width ratio of less than or equal to 10, or comprising a propping filler and a binding compound in the form of a powder with a size varying from about 1 to about 500 microns.
A method for fracture propping in a subsurface layer, which ensures a reliable protection of wells from the proppant carryover from the fracture, has been proposed.
According to the proposed method, a fracturing fluid is mixed with a propping agent and granulated binding material with a length-to-width ratio of less than or equal to 10;
thereafter, a formation fracturing process is implemented. Then, the granulated binding material hardens and forms a homogenous firm mass with the propping agent, which impedes the closing of the fracture and precludes proppant carryover from the fracture.
Or, a fracturing fluid composition obtained by mixing a propping agent with a binding compound in the form of a powder whose size varies from about 1 to about 500 µm. A
gravel-packed filter is then constructed; the said filter is based on the application of the working fluid comprising a propping filler and granulated binding component with a length-to-width ratio of less than or equal to 10, or comprising a propping filler and a binding compound in the form of a powder with a size varying from about 1 to about 500 microns.
Description
Methods for preventing proppant carryover from fractures, and gravel-packed filter This invention relates to the oil and gas industry, in particular, to methods affecting the formation productivity at the oil and gas production stage.
A carryover of proppant from a fracture to the well at the post-fracturing period either during the initial cleaning or sometimes even after completion of the well construction is a crucial issue for the oil production sector. As practice experience shows, up to 20% of proppant could be conveyed to the well, which, in its turn, could lead to a number of negative consequences; some of them are specified below. In marginal wells, proppant settles in a casing; thus, regular washings are required and the cost of well repair operations grows. A, premature wear and failure of electrical submersible pumps is another consequence of the carryover of unbound proppant or other solid particles of rocks. Also, oil or gas production decrease is observed due to a significant loss of the near wellbore conductivity caused as a result of a reduced fracture thickness or overlapping of a production zone.
At present, several methods allowing a significant decrease in the carryover of proppant or other propping agents from the fracture are known.
The most wide-spread approach is based on the application of proppant with a hardening resin coating (US 5218038 ), which is injected into the fracture at the end of the treatment process. However, the application of this proppant has a number of notable restrictions which are caused by casual chemical reactions of the resin coating with a layer fracturing fluid. On one hand, this interaction causes partial degradation and disintegration of the coating, thus reducing the contact strength among proppant particles and, therefore, decreasing the. proppant pack strength. On the other hand, the interaction between the resin coating components . and fracturing fluid components causes uncontrolled change in of rheological properties of the fluid, which also diminishes the fracturing process efficiency. The above-listed factors alongside with periodic cyclic loads emerged due to the well closure and construction as well as an extended well closure period could significantly reduce the proppant filler strength.
A carryover of proppant from a fracture to the well at the post-fracturing period either during the initial cleaning or sometimes even after completion of the well construction is a crucial issue for the oil production sector. As practice experience shows, up to 20% of proppant could be conveyed to the well, which, in its turn, could lead to a number of negative consequences; some of them are specified below. In marginal wells, proppant settles in a casing; thus, regular washings are required and the cost of well repair operations grows. A, premature wear and failure of electrical submersible pumps is another consequence of the carryover of unbound proppant or other solid particles of rocks. Also, oil or gas production decrease is observed due to a significant loss of the near wellbore conductivity caused as a result of a reduced fracture thickness or overlapping of a production zone.
At present, several methods allowing a significant decrease in the carryover of proppant or other propping agents from the fracture are known.
The most wide-spread approach is based on the application of proppant with a hardening resin coating (US 5218038 ), which is injected into the fracture at the end of the treatment process. However, the application of this proppant has a number of notable restrictions which are caused by casual chemical reactions of the resin coating with a layer fracturing fluid. On one hand, this interaction causes partial degradation and disintegration of the coating, thus reducing the contact strength among proppant particles and, therefore, decreasing the. proppant pack strength. On the other hand, the interaction between the resin coating components . and fracturing fluid components causes uncontrolled change in of rheological properties of the fluid, which also diminishes the fracturing process efficiency. The above-listed factors alongside with periodic cyclic loads emerged due to the well closure and construction as well as an extended well closure period could significantly reduce the proppant filler strength.
In another method, a fibrous material mixed with a propping agent material is added with the aim to limit the conveyance of a proppant placed in a formation (US5330005); in this process, fibers interweave among proppant particles and thus increase the proppant strength and restricts the back-flow carryover of the proppant.
Besides, the addition of fibers enables a more effective redistribution of loads through addition of bulkheads along a vast area of the proppant filler. A fibrous structure is more flexible as compared to cured resin proppant; it allows movements of proppant-fibrous filler without the strength property deterioration.
In another method (US 5908073), fiber bundles comprising about 5 to 200 separate fibers with a length of 0.8 to 2.5 mm and diameter of 10 to 1,000 m are used for preventing proppant carryover from the well. In this process, the fiber bundle structure is fixed from one side.
A method of mixing proppant with the deformable material in the bead-shaped particles (US 6059034) is known. The said deformable particles are made of a polymeric material. Deformable polymeric particles could be differently shaped (oval, wedge-like, cubic, bar-like, cylindrical, conic, etc.); however, a maximum length-to-base ratio of equal to or less than 5 is preferable. In case of deformable materials with a cone-shaped diameter as well as for aluminum particles, the maximum length-to-base ratio should be equal to or less than 25. Deformable particles could be made as spherical plastic balls or composite particles containing a non-deformable core and a deformable coating.
Generally, the volume of the non-deformable core is about 50 to 95% (vol.) of the total volume of the particle and can be made of silica, cristobalite, graphite, gypsum or talc. In another embodiment (US 6330916), the core consists of deformable materials and could include milled or crushed materials, e.g., nutshell, seed shell, fruits kernels and processed wood.
For fixing a propping agent and restricting' its carryover, a mixture of the proppant with adhesive polymeric materials could be applied (US 5582249). Adhesive compositions enter into a mechanical contact with the propping agent particles, ensphere and cover the particles with a thin sticky layer. As a result, particles glue to each other as well as with sand or crushed fragments of the propping agent, thus completely preventing the carryover of solid particles from the fracture. The ability to maintain adhesiveness over a long period of time and at increased welibore temperatures without stitching or hardening is intrinsic feature of sticky compounds.
Sticky materials could combine with other chemical agents, which are used in the formation fracturing process, e.g., retarding agents, antimicrobial agents, polymer gel destructors, as well as antioxidant and wax-formation and corrosion retarding agents (US
6209643).
There is another known method for fracture propping with the application of sticky agents and resin proppants (US 7032667). The US patent No. 6742590 discloses a method for protecting fractures from the carryover of the propping filler, using a mixture of sticky materials with deformable particles, which are on their own are effective additives to prevent the proppant carryover.
Another variety of materials used for proppant carryover fighting is thermoplastic materials (US 5501274, EP 0735235). Thermoplastic materials when mixed with a propping agent are capable of softening being exposed to high temperatures of rocks, and thereafter they stick with the propping agent to form agglutinated aggregates which include a plural number of the proppant.
A method for using thermoplastic materials mixed with a resin proppant is known (US 5697440). In a number of methods, a thermoplastic material is mixed with the proppant in a liquid state or in the form of a solution in a suitable solvent (US 6830105 ).
In this case, an elastomer-forming compound could solidify either itself, or under the influence of special additional chemical reagents, to form thermoplastic materials.
Another known method describes the application of a fracturing fluid, which is a self-degrading cement (US patent application No. US 2006/0169448) comprising acid and main components, whose interaction causes formation of a cement material, as well as a degrading component, which could disintegrate under the fracture conditions and ensures the formation of cavities in the cement.
Another known method describes the formation fracturing process using a new type of propping particles as well as the composition of a new material for creating gravel-packed filters with the application of hydrated cement particles with an average size ranging from 5 m to 2.5 cm (US patent application No. 2006/0162926, US
2006/0166834 ).
This invention relates to the oils and gas industry, in particular, to the development of a method for preventing carryover of proppant from fractures.
The suggested method for fracture propping in an underground layer ensures as reliable protection of the well from the proppant conveyance from the fracture. In this method, a formation fracturing fluid is mixed with a propping filler and a granulated binding material with a length-to-width ratio of equal to or less than 10, and thereafter, a formation fracturing process is implemented. Then, the granulated binding material is solidified to form a homogeneous firm mass with the propping agent, which obstructs the closure of the fracture and precludes the proppant carryover.
Technical result of this invention is as follows.
1. Fracturing fluid composition obtained by mixing a propping filler and a granulated binding component with a length-to-width ratio of equal to or less than 10, which could solidify under underground formation conditions.
2. Fracturing fluid composition obtained by mixing a propping filler and a granulated binding composition in the form of a powder, whose size varies from about I
m to about 500 m. In this case, powder-like particles of the binding component get into contact with the propping filler and are then solidified thus increasing the propping filler pack strength.
3. Fracturing fluid composition obtained by mixing a propping filler and a granulated or powder binding material as well as other components obstructing the proppant conveyance from the fracture, including deformable particles and adhesive and fiber-like materials.
4. Development of gravel-packed filter which is based on the application of a working fluid comprising a propping filler and a granulated binding component with a length-to-width ratio of equal to or less than 10, or comprising a propping filler and a granulated binding composition in the form of a powder, whose size varies from about 1 m to about 500 m.
At least one of the below-listed materials can be used as a propping filler:
ceramic particles and sand of a different shape, plated solidified and curable proppants and sands;
swollen expanded clay, vermiculite, and agloporite.
Proppant or polymer-coated sand can be used as a propping filler.
Granulated and powder-like binding components could be added in a fracturing fluid either in a dry state, or in the form of suspension in water, working fluid, gel or other suitable solvent, including those modified with various surfactants.
At least one of binding components of the below-listed hardening classes could be used as a granulated binding component: hydraulic, air and autoclave hardening as well as acid-proof binding materials as well as their mixture, including:
1. Binding materials on the basis of crystalline hydrates CaSO4 and anhydrite (gypsum binding materials);
2. Binding materials on the basis of CaO, CaO hydration and carbonization products (lime binding materials);
3. Binding materials on the basis of MgO and saline sealers (magnesian binding materials);
4. Lime-silica binding materials comprising a mixture of CaO or Ca(OH)2 with fine-milled silica, which solidify at increased temperatures;
Besides, the addition of fibers enables a more effective redistribution of loads through addition of bulkheads along a vast area of the proppant filler. A fibrous structure is more flexible as compared to cured resin proppant; it allows movements of proppant-fibrous filler without the strength property deterioration.
In another method (US 5908073), fiber bundles comprising about 5 to 200 separate fibers with a length of 0.8 to 2.5 mm and diameter of 10 to 1,000 m are used for preventing proppant carryover from the well. In this process, the fiber bundle structure is fixed from one side.
A method of mixing proppant with the deformable material in the bead-shaped particles (US 6059034) is known. The said deformable particles are made of a polymeric material. Deformable polymeric particles could be differently shaped (oval, wedge-like, cubic, bar-like, cylindrical, conic, etc.); however, a maximum length-to-base ratio of equal to or less than 5 is preferable. In case of deformable materials with a cone-shaped diameter as well as for aluminum particles, the maximum length-to-base ratio should be equal to or less than 25. Deformable particles could be made as spherical plastic balls or composite particles containing a non-deformable core and a deformable coating.
Generally, the volume of the non-deformable core is about 50 to 95% (vol.) of the total volume of the particle and can be made of silica, cristobalite, graphite, gypsum or talc. In another embodiment (US 6330916), the core consists of deformable materials and could include milled or crushed materials, e.g., nutshell, seed shell, fruits kernels and processed wood.
For fixing a propping agent and restricting' its carryover, a mixture of the proppant with adhesive polymeric materials could be applied (US 5582249). Adhesive compositions enter into a mechanical contact with the propping agent particles, ensphere and cover the particles with a thin sticky layer. As a result, particles glue to each other as well as with sand or crushed fragments of the propping agent, thus completely preventing the carryover of solid particles from the fracture. The ability to maintain adhesiveness over a long period of time and at increased welibore temperatures without stitching or hardening is intrinsic feature of sticky compounds.
Sticky materials could combine with other chemical agents, which are used in the formation fracturing process, e.g., retarding agents, antimicrobial agents, polymer gel destructors, as well as antioxidant and wax-formation and corrosion retarding agents (US
6209643).
There is another known method for fracture propping with the application of sticky agents and resin proppants (US 7032667). The US patent No. 6742590 discloses a method for protecting fractures from the carryover of the propping filler, using a mixture of sticky materials with deformable particles, which are on their own are effective additives to prevent the proppant carryover.
Another variety of materials used for proppant carryover fighting is thermoplastic materials (US 5501274, EP 0735235). Thermoplastic materials when mixed with a propping agent are capable of softening being exposed to high temperatures of rocks, and thereafter they stick with the propping agent to form agglutinated aggregates which include a plural number of the proppant.
A method for using thermoplastic materials mixed with a resin proppant is known (US 5697440). In a number of methods, a thermoplastic material is mixed with the proppant in a liquid state or in the form of a solution in a suitable solvent (US 6830105 ).
In this case, an elastomer-forming compound could solidify either itself, or under the influence of special additional chemical reagents, to form thermoplastic materials.
Another known method describes the application of a fracturing fluid, which is a self-degrading cement (US patent application No. US 2006/0169448) comprising acid and main components, whose interaction causes formation of a cement material, as well as a degrading component, which could disintegrate under the fracture conditions and ensures the formation of cavities in the cement.
Another known method describes the formation fracturing process using a new type of propping particles as well as the composition of a new material for creating gravel-packed filters with the application of hydrated cement particles with an average size ranging from 5 m to 2.5 cm (US patent application No. 2006/0162926, US
2006/0166834 ).
This invention relates to the oils and gas industry, in particular, to the development of a method for preventing carryover of proppant from fractures.
The suggested method for fracture propping in an underground layer ensures as reliable protection of the well from the proppant conveyance from the fracture. In this method, a formation fracturing fluid is mixed with a propping filler and a granulated binding material with a length-to-width ratio of equal to or less than 10, and thereafter, a formation fracturing process is implemented. Then, the granulated binding material is solidified to form a homogeneous firm mass with the propping agent, which obstructs the closure of the fracture and precludes the proppant carryover.
Technical result of this invention is as follows.
1. Fracturing fluid composition obtained by mixing a propping filler and a granulated binding component with a length-to-width ratio of equal to or less than 10, which could solidify under underground formation conditions.
2. Fracturing fluid composition obtained by mixing a propping filler and a granulated binding composition in the form of a powder, whose size varies from about I
m to about 500 m. In this case, powder-like particles of the binding component get into contact with the propping filler and are then solidified thus increasing the propping filler pack strength.
3. Fracturing fluid composition obtained by mixing a propping filler and a granulated or powder binding material as well as other components obstructing the proppant conveyance from the fracture, including deformable particles and adhesive and fiber-like materials.
4. Development of gravel-packed filter which is based on the application of a working fluid comprising a propping filler and a granulated binding component with a length-to-width ratio of equal to or less than 10, or comprising a propping filler and a granulated binding composition in the form of a powder, whose size varies from about 1 m to about 500 m.
At least one of the below-listed materials can be used as a propping filler:
ceramic particles and sand of a different shape, plated solidified and curable proppants and sands;
swollen expanded clay, vermiculite, and agloporite.
Proppant or polymer-coated sand can be used as a propping filler.
Granulated and powder-like binding components could be added in a fracturing fluid either in a dry state, or in the form of suspension in water, working fluid, gel or other suitable solvent, including those modified with various surfactants.
At least one of binding components of the below-listed hardening classes could be used as a granulated binding component: hydraulic, air and autoclave hardening as well as acid-proof binding materials as well as their mixture, including:
1. Binding materials on the basis of crystalline hydrates CaSO4 and anhydrite (gypsum binding materials);
2. Binding materials on the basis of CaO, CaO hydration and carbonization products (lime binding materials);
3. Binding materials on the basis of MgO and saline sealers (magnesian binding materials);
4. Lime-silica binding materials comprising a mixture of CaO or Ca(OH)2 with fine-milled silica, which solidify at increased temperatures;
5. Lime-pozzolanic and lime-cindery binding materials comprising a lime-containing component and a reactive silicic acid in the form of amorphous silica or silicate glass, whose hardening occurs due to the interaction of a lime with an active silicon oxide or glass with the formation of calcium hydrosilicates;
6. Slag-alkali binding materials, which include a component comprising caustic alkali and slag, preferably, in a vitreous state, whose hardening is connected with the formation of alcaline aluminum silicate;
7. Cements (binding) on the basis of high-basic calcium silicates (portland cement clinker, natural cement, calcareous cement, hydraulic lime), whose binding properties are essentially predefined by hydration of tricalcium (Ca3SiO5) and dicalcium (Ca2SiO4) silicates, including slag-portland cement;
8. Cements on the basis of low-basic calcium aluminates (CaA, CA2, C12A7) as well as on the basis of their derivatives, e.g. calcium sulfoaluminates, calcium fluoroaluminates (aluminate cement, high-alumina cement, sulfoaluminate cement); high iron oxide cements and sulfur high iron oxide cements;
9. Cements on the basis of calcium ferrites and their derivatives - calcium sulfoferrites;
10. Phosphatic binding materials (cement and binding materials), which harden due to phosphate formation;
11. Watersoluble silicate - based binding materials including alkali metal silicates (soluble glasses) and organic base silicates;
12. Polymer-cement and polymer-silicate binding compositions which include organic compositions as modifying components and inorganic binding materials (cement, soluble glass) as the base;
13. Hydroxy salts of aluminum, chrome, zirconium, colloidal solution of silica and aluminum oxide, partially dehydrated crystalline hydrates of aluminum sulfates and calcium aluminates.
A granulated binding component could comprise either one component, or have a multi-component composition. In addition to binding components, the A
granulated binding component could include components which ensure required strength properties (e.g., polymers) and density (e.g., particles of barite, red iron ore, glass beads, porous particles).
A granulated binding component could be differently shaped: spherical, cylindrical, sparry, cubic, oval, flaked, scaly, irregular shape, or a mixture of the above-mentioned shapes, but with a length-to-width ratio to be equal to or less than 10.
The content of granulated binding filler in the total volume of propping and granulated fillers varies in the range from 0.1 to 99.9% by weight.
Actual density of granulated binding agent could vary in the range from 0.3 to g/cm.
At least one of binding components of the below-listed hardening classes could be used as a powder binding component: hydraulic, air and autoclave hardening as well as acid-proof binding materials as well as their mixture, including:
1. Binding materials on the basis of crystalline hydrates CaSO4 and anhydrite (gypsum binding materials);
2. Binding materials on the basis of CaO, CaO hydration and carbonization products (lime binding materials);
3. Binding materials on the basis of MgO and saline sealers (magnesian binding materials);
4. Lime-silica binding materials comprising a mixture of CaO or Ca(OH)2 with fine-milled silica, which solidify at increased temperatures;
5. Lime-pozzolanic and lime-cindery binding materials comprising a lime-containing component and a reactive silicic acid in the form of amorphous silica or silicate glass, whose hardening occurs due to the interaction of a lime with an active silicon oxide or glass with the formation of calcium hydrosilicates;
6. Slag-alkali binding materials, which include a component comprising caustic alkali and slag, preferably, in a vitreous state, whose hardening is connected with the formation of alcaline aluminum silicate;
7. Cements (binding) on the basis of high-basic calcium silicates (portland cement clinker, natural cement, calcareous cement, hydraulic lime), whose binding properties are essentially predefined by hydration of tricalcium (Ca3SiO5) and dicalcium (Ca2SiO4) silicates, including slag-portland cement;
8. Cements on the basis of low-basic calcium aluminates (CaA, CA2, C12A7) as well as on the basis of their derivatives, e.g. calcium sulfoaluminates, calcium fluoroaluminates (aluminate cement, high-alumina cement, sulfoaluminate cement); high iron oxide cements and sulfur high iron oxide cements;
9. Cements on the basis of calcium ferrites and their derivatives - calcium sulfoferrites;
10. Phosphatic binding materials (cement and binding materials), which harden due to phosphate formation;
11. Watersoluble silicate - based binding materials including alkali metal silicates (soluble glasses) and organic base silicates;
12. Polymer-cement and polymer-silicate binding compositions which include organic compositions as modifying components and inorganic binding materials (cement, soluble glass) as the base;
13. Hydroxy salts of aluminum, chrome, zirconium, colloidal solution of silica and aluminum oxide, partially dehydrated crystalline hydrates of aluminum sulfates and calcium aluminates.
The size of the powder-like binding materials varies from about 0.5 to 500 m.
The content of powder-like binding materials in the propping filler varies from 0.1 to 99.9% by weight.
The density of the powder-like binding materials could vary from about 0.5 to about 5 g/cm3.
Granulated or powder-like binding materials will be used in the mixture with a propping agent whose concentration in the mixture could vary in the range of 0.1 to 99.9%.
Granulated or powder-like binding materials could be added to the propping fluid either in a dry state or in the form of suspension in water, working fluid, gel or other suitable solution including those modified by various surfactants.
A granulated binding component could comprise either one component, or have a multi-component composition. In addition to binding components, the A
granulated binding component could include components which ensure required strength properties (e.g., polymers) and density (e.g., particles of barite, red iron ore, glass beads, porous particles).
A granulated binding component could be differently shaped: spherical, cylindrical, sparry, cubic, oval, flaked, scaly, irregular shape, or a mixture of the above-mentioned shapes, but with a length-to-width ratio to be equal to or less than 10.
The content of granulated binding filler in the total volume of propping and granulated fillers varies in the range from 0.1 to 99.9% by weight.
Actual density of granulated binding agent could vary in the range from 0.3 to g/cm.
At least one of binding components of the below-listed hardening classes could be used as a powder binding component: hydraulic, air and autoclave hardening as well as acid-proof binding materials as well as their mixture, including:
1. Binding materials on the basis of crystalline hydrates CaSO4 and anhydrite (gypsum binding materials);
2. Binding materials on the basis of CaO, CaO hydration and carbonization products (lime binding materials);
3. Binding materials on the basis of MgO and saline sealers (magnesian binding materials);
4. Lime-silica binding materials comprising a mixture of CaO or Ca(OH)2 with fine-milled silica, which solidify at increased temperatures;
5. Lime-pozzolanic and lime-cindery binding materials comprising a lime-containing component and a reactive silicic acid in the form of amorphous silica or silicate glass, whose hardening occurs due to the interaction of a lime with an active silicon oxide or glass with the formation of calcium hydrosilicates;
6. Slag-alkali binding materials, which include a component comprising caustic alkali and slag, preferably, in a vitreous state, whose hardening is connected with the formation of alcaline aluminum silicate;
7. Cements (binding) on the basis of high-basic calcium silicates (portland cement clinker, natural cement, calcareous cement, hydraulic lime), whose binding properties are essentially predefined by hydration of tricalcium (Ca3SiO5) and dicalcium (Ca2SiO4) silicates, including slag-portland cement;
8. Cements on the basis of low-basic calcium aluminates (CaA, CA2, C12A7) as well as on the basis of their derivatives, e.g. calcium sulfoaluminates, calcium fluoroaluminates (aluminate cement, high-alumina cement, sulfoaluminate cement); high iron oxide cements and sulfur high iron oxide cements;
9. Cements on the basis of calcium ferrites and their derivatives - calcium sulfoferrites;
10. Phosphatic binding materials (cement and binding materials), which harden due to phosphate formation;
11. Watersoluble silicate - based binding materials including alkali metal silicates (soluble glasses) and organic base silicates;
12. Polymer-cement and polymer-silicate binding compositions which include organic compositions as modifying components and inorganic binding materials (cement, soluble glass) as the base;
13. Hydroxy salts of aluminum, chrome, zirconium, colloidal solution of silica and aluminum oxide, partially dehydrated crystalline hydrates of aluminum sulfates and calcium aluminates.
The size of the powder-like binding materials varies from about 0.5 to 500 m.
The content of powder-like binding materials in the propping filler varies from 0.1 to 99.9% by weight.
The density of the powder-like binding materials could vary from about 0.5 to about 5 g/cm3.
Granulated or powder-like binding materials will be used in the mixture with a propping agent whose concentration in the mixture could vary in the range of 0.1 to 99.9%.
Granulated or powder-like binding materials could be added to the propping fluid either in a dry state or in the form of suspension in water, working fluid, gel or other suitable solution including those modified by various surfactants.
Claims (25)
1. A method for preventing proppant carryover from a fracture, according to which a fluid used in the formation fracturing process is mixed with a filler component comprising at least one propping agent and at least one granulated binding component having a length-to-width ratio of less than or equal to 10, which fluid solidifies under subsurface formation conditions.
2. The method of claim 1, wherein the granulated binder component is present in the filler component in an amount of from 0.1% to 99.9%.
3. The method of claim 1 or 2, wherein the filler component comprises at least one material selected from the group consisting of particulates having been hardened by a hydraulic hardening, air hardening or autoclave hardening, acid-proof binding materials and mixtures thereof.
4. The method of claim 1 or 2, in which the filler component comprises gypsum binding materials.
5. The method of claim 4 wherein the filler component comprises CaSO4 crystalline hydrates and anhydrites.
6. The method of claim 1 or 2, wherein the filler component comprises lime binding materials.
7. The method of claim 6, wherein the filler component comprises materials selected from calcium oxides and CaO hydration and carbonization products.
8. The method of claim 1 or 2, wherein the filler component comprises magnesium binding materials.
9. The method of claim 8, wherein the filler component comprises magnesium oxide or a saline sealer.
10. The method of claim 1 or 2, wherein the filler component comprises a lime-silica material comprising a mixture of CaO or Ca(OH)2 with fine-milled silica which hardens at subterranean formation temperatures.
11. The method of claim 1 or 2, wherein the filler component comprises lime-pozzolanic and lime-slag materials.
12. The method of claim 1 or 2, wherein the filler component comprises lime-containing components and reactive silicic acid in the form of amorphous silica or silicate glass, whose hardening is caused by the interaction of lime with active silica or glass with the formation of calcium hydrosilicates.
13. The method of claim 1 or 2, wherein the filler component comprises slag-alkali binders comprising a constituent that includes a caustic alkali and slag, in a vitreous state, and whose hardening proceeds with the formation of alkaline aluminum silicates.
14. The method of claim 1 or 2, wherein the filler component comprises cement based on high-basic calcium silicates.
15. The method of claim 1 or 2, wherein the filler component comprises at least cement based on calcium aluminate, calcium sulfoaluminates or calcium fluoroaluminates.
16. The method of claim 15, wherein the calcium aluminate is CaAl, CaAl2 or C12AI7.
17. The method of claim 15, wherein the filler component comprises a calcium aluminate cement, a high-alumina cement, or a sulfoaluminate cement.
18. The method of claim 1 or 2, wherein the filler component comprises an iron or sulfur-iron cement.
19. The method of claim 1 or 2, wherein the filler component comprises calcium ferrites or calcium sulfur ferrite cements, portland cement, roman cement, calcareous lime or mixtures thereof.
20. The method of claim 1 or 2, wherein the particulate binding component comprises phosphates.
21. The method of claim 1 or 2, wherein the filler component comprises watersoluble silicates.
22. The method of claim 1 or 2, wherein the filler component comprises polymer-cement or polymer-silicate compositions comprising organic compounds as modifying agents and inorganic compounds as the base.
23. The method of claim 1, wherein the filler component comprises at least one compound selected from the group consisting of hydroxy salts of alumina, chrome, zirconium, colloidal silica solutions, partly dehydrated crystalline hydrates of aluminum sulfates and calcium aluminates.
24. The method of any one of claims 1 to 23, wherein at least one of the fluid or the filler component further comprises at least one as additive selected from the group consisting of polymers, barite particles, red iron ore, glass beads, porous particles, sand with polymeric coating, ceramic particles, sand, cured or curable proppants and sands, swollen expanded clay, vermiculite, agloporite, deformable particles, adhesive materials and fibrous materials.
25. Method for preventing proppant carryover from fractures, in which a formation fracturing liquid is mixed with a propping agent, granulated binding component as well as with components precluding proppant carryover from fractures, including deformable particles, adhesive and fibrous materials.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA2763680A CA2763680C (en) | 2006-12-28 | 2007-12-10 | Methods for preventing proppant carryover from fractures, and gravel-packed filter |
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| RU2006146962 | 2006-12-28 | ||
| RU2006146962/03A RU2006146962A (en) | 2006-12-28 | 2006-12-28 | METHOD FOR PREVENTING THE DISPOSAL OF PROPANTA FROM CRACK AND GRAVEL FILTER |
Related Child Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2763680A Division CA2763680C (en) | 2006-12-28 | 2007-12-10 | Methods for preventing proppant carryover from fractures, and gravel-packed filter |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2614114A1 CA2614114A1 (en) | 2008-06-28 |
| CA2614114C true CA2614114C (en) | 2012-03-13 |
Family
ID=39551485
Family Applications (2)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2614114A Expired - Fee Related CA2614114C (en) | 2006-12-28 | 2007-12-10 | Methods for preventing proppant carryover from fractures, and gravel-packed filter |
| CA2763680A Expired - Fee Related CA2763680C (en) | 2006-12-28 | 2007-12-10 | Methods for preventing proppant carryover from fractures, and gravel-packed filter |
Family Applications After (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2763680A Expired - Fee Related CA2763680C (en) | 2006-12-28 | 2007-12-10 | Methods for preventing proppant carryover from fractures, and gravel-packed filter |
Country Status (4)
| Country | Link |
|---|---|
| US (1) | US20080156489A1 (en) |
| CA (2) | CA2614114C (en) |
| MX (1) | MX2007015830A (en) |
| RU (1) | RU2006146962A (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN103773355A (en) * | 2014-01-15 | 2014-05-07 | 成都新柯力化工科技有限公司 | Fracturing propping agent for shale gas mining and preparation method thereof |
Families Citing this family (12)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US8012582B2 (en) * | 2008-09-25 | 2011-09-06 | Halliburton Energy Services, Inc. | Sintered proppant made with a raw material containing alkaline earth equivalent |
| US8307897B2 (en) | 2008-10-10 | 2012-11-13 | Halliburton Energy Services, Inc. | Geochemical control of fracturing fluids |
| US20110315384A1 (en) * | 2010-06-25 | 2011-12-29 | Emilio Miquilena | Gelled foam compositions and methods |
| US8668019B2 (en) * | 2010-12-29 | 2014-03-11 | Baker Hughes Incorporated | Dissolvable barrier for downhole use and method thereof |
| WO2012174118A1 (en) | 2011-06-15 | 2012-12-20 | MAR Systems, Inc. | Proppants for removal of contaminants from fluid streams and methods of using same |
| US8424784B1 (en) | 2012-07-27 | 2013-04-23 | MBJ Water Partners | Fracture water treatment method and system |
| US9896918B2 (en) | 2012-07-27 | 2018-02-20 | Mbl Water Partners, Llc | Use of ionized water in hydraulic fracturing |
| CN105041287B (en) * | 2015-07-23 | 2017-07-07 | 中国石油天然气股份有限公司 | A kind of temporary stall of fiber for improving Low permeability and competent sand Oil ＆ Gas Productivity is to fracturing process |
| CN105331355B (en) * | 2015-12-01 | 2018-05-15 | 陕西省能源化工研究院 | A kind of petroleum fracturing propping agent prepared using oil shale waste slag and preparation method thereof |
| CN112080272B (en) * | 2020-09-24 | 2022-09-02 | 河南建筑材料研究设计院有限责任公司 | Petroleum fracturing propping agent and preparation method thereof |
| CN112521928B (en) * | 2020-12-04 | 2023-01-06 | 新疆瑞克沃新材料有限公司 | Fracturing propping agent taking power plant waste solids as raw materials and preparation method thereof |
| CN113969160A (en) * | 2021-11-26 | 2022-01-25 | 泾阳中昊建材有限责任公司 | High-strength ceramsite proppant produced by using mine tailings and preparation method thereof |
Family Cites Families (8)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US2959223A (en) * | 1955-03-25 | 1960-11-08 | Dow Chemical Co | Method of facilitating production of oil or gas from a well penetrating a petroleum-bearing stratum contiguous to a water-bearing zone |
| US3625892A (en) * | 1966-03-25 | 1971-12-07 | Union Oil Co | Hydraulic fracturing of tilted subterranean formations |
| HU177046B (en) * | 1979-02-14 | 1981-06-28 | Tatabanyai Szenbanyak | Method for caving thick coal bed carried out at least in two layers |
| US4632876A (en) * | 1985-06-12 | 1986-12-30 | Minnesota Mining And Manufacturing Company | Ceramic spheroids having low density and high crush resistance |
| US5368102A (en) * | 1993-09-09 | 1994-11-29 | Halliburton Company | Consolidatable particulate material and well treatment method |
| US6648962B2 (en) * | 2001-09-06 | 2003-11-18 | W. R. Grace & Co.-Conn. | Micro-granulose particulates |
| US7044224B2 (en) * | 2003-06-27 | 2006-05-16 | Halliburton Energy Services, Inc. | Permeable cement and methods of fracturing utilizing permeable cement in subterranean well bores |
| US7341104B2 (en) * | 2004-02-10 | 2008-03-11 | Halliburton Energy Services, Inc. | Methods of using substantially hydrated cement particulates in subterranean applications |
-
2006
- 2006-12-28 RU RU2006146962/03A patent/RU2006146962A/en not_active Application Discontinuation
-
2007
- 2007-12-10 CA CA2614114A patent/CA2614114C/en not_active Expired - Fee Related
- 2007-12-10 CA CA2763680A patent/CA2763680C/en not_active Expired - Fee Related
- 2007-12-13 MX MX2007015830A patent/MX2007015830A/en active IP Right Grant
- 2007-12-18 US US11/959,128 patent/US20080156489A1/en not_active Abandoned
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN103773355A (en) * | 2014-01-15 | 2014-05-07 | 成都新柯力化工科技有限公司 | Fracturing propping agent for shale gas mining and preparation method thereof |
| CN103773355B (en) * | 2014-01-15 | 2017-05-24 | 成都新柯力化工科技有限公司 | Fracturing propping agent for shale gas mining and preparation method thereof |
Also Published As
| Publication number | Publication date |
|---|---|
| US20080156489A1 (en) | 2008-07-03 |
| CA2614114A1 (en) | 2008-06-28 |
| CA2763680C (en) | 2015-08-25 |
| MX2007015830A (en) | 2008-10-28 |
| RU2006146962A (en) | 2008-07-10 |
| CA2763680A1 (en) | 2008-06-28 |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| EEER | Examination request | ||
| MKLA | Lapsed |
Effective date: 20181210 |