WO2013163504A1 - Well treatment compositions and methods utilizing nano-particles - Google Patents
Well treatment compositions and methods utilizing nano-particles Download PDFInfo
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- WO2013163504A1 WO2013163504A1 PCT/US2013/038343 US2013038343W WO2013163504A1 WO 2013163504 A1 WO2013163504 A1 WO 2013163504A1 US 2013038343 W US2013038343 W US 2013038343W WO 2013163504 A1 WO2013163504 A1 WO 2013163504A1
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- B—PERFORMING OPERATIONS; TRANSPORTING
- B82—NANOTECHNOLOGY
- B82Y—SPECIFIC USES OR APPLICATIONS OF NANOSTRUCTURES; MEASUREMENT OR ANALYSIS OF NANOSTRUCTURES; MANUFACTURE OR TREATMENT OF NANOSTRUCTURES
- B82Y30/00—Nanotechnology for materials or surface science, e.g. nanocomposites
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- C—CHEMISTRY; METALLURGY
- C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
- C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
- C04B28/00—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
- C04B28/02—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/02—Well-drilling compositions
- C09K8/03—Specific additives for general use in well-drilling compositions
- C09K8/032—Inorganic additives
-
- 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
- C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
- C09K8/46—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/502—Oil-based compositions
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/5045—Compositions based on water or polar solvents containing inorganic compounds
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/516—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls characterised by their form or by the form of their components, e.g. encapsulated material
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- C—CHEMISTRY; METALLURGY
- C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
- C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
- C04B2111/00—Mortars, concrete or artificial stone or mixtures to prepare them, characterised by specific function, property or use
- C04B2111/00008—Obtaining or using nanotechnology related materials
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/10—Nanoparticle-containing well treatment fluids
Definitions
- the present invention relates to well treatment compositions and methods utilizing nano-particles and, more particularly, in one or more embodiments, to well cement compositions and/or well completion fluids that comprise nano-particles.
- ell treatments include a wide variety of methods that may be performed in oil, gas, geotbermal and or water wells, such as drilling, completion and workover methods.
- the drilling, completion and workover methods may include, but are not limited to, drilling, fracturing, acidizing. logging, cementing, gravel packing, perforating and conformance methods.
- Many of these well treatments are designed to enhance and/or facilitate the recovery of desirable fluids from a subterranean well.
- cementing methods such as well construction and remedial cementing
- well cement compositions are commonly utilized.
- a pipe string e.g., casing and liners
- the process of cementing the pipe string in place is commonly referred to as "primary cementing.”
- primary cementing a cement composition may be pumped into an annulus between the walls of the well bore and the exterior surface of the pipe string disposed therein.
- the cement composition sets in the annular spa.ee, thereby forming an annular sheath of hardened, substantially impermeable cement that supports and positions the pipe string in the well bore and bonds the exterior surface of the pipe siring to the subterranean formation.
- the annular sheath of set cement surrounding the pipe string functions to prevent the migration of fluids in the annulus, as well as protecting the pipe string from corrosion.
- Cement compositions also may be used in remedial cementing methods, such as squeeze cementing and the placement of cement plugs.
- the annular sheath of cement formed between the well bore and the pipe string often, suffers structural failure due to pipe movements which cause shear stresses to be exerted on the set cement,
- Such stress conditions are commonly the result of relatively high fluid pressures and/or temperatures inside the cemented pipe string during testing, perforating, fluid injection or fluid production.
- stress may occur in wells subjected to steam recovery or production of hot formation fluids from high- temperature formations.
- the high-internal pipe pressure and/or temperature can result in the expansion of the pipe string, both radially and longitudinally, which places stresses on the cement sheath causing the cement bond between the exterior surfaces of the pipe or the well bore walls, or both, to fail and thus allow leakage of formation fluids and so forth.
- the cement composition utilized for cementing pipe strings iii the well bores may develop high strength after setting and to have sufficient resiliency (e.g., elasticity and ductility) to resist loss of the cement bond between the exterior surfaces of the pipe or the well bore wails, or both.
- the cement composition may be able to resist cracking and/or shattering that may result from other forces on the cement sheath.
- the cement sheath may include structural characteristics that protect its structural integrity from forces associated with formation shifting, overburden pressure, subsidence, tectonic creep, pipe movements, impacts and shocks subsequently generated by drilling and other well operations.
- the set accelerator in addition to including components that improve mechanical properties of the cement, in a number of cementing methods, it may also be desirable to include one or more set accelerators in the well cement compositions to counteract certain constituents and/or environmental characteristics that excessively slow set times.
- low temperatures and cement additives e.g., fluid loss control additives and dispersants
- Completion fluids are another type of fluid that may be used in well treatments.
- a completion fluid is typically a solids-tree liquid that is used, in part, to control well pressure while completing the well.
- the completion fluid is typically placed into the well bore after drilling, but before the start of production, to facilitate completion of the well, which typically involves preparing the bottom of the well bore to the required specifications, running in the production tubing and its associated downhole equipment, and optionally carrying out production enhancement operations, if desired.
- the completion fluid should generally be chemically compatible with the reservoir formation and fluid and should not damage the permeability of the formation or other equipment placed into the well bore, such as production screens. To avoid such damage, the completion fluid is typically filtered to a high degree to remove any solids that could be introduced into the near-well bore region or downhole equipment.
- Brines such as chlorides, bromides, and formates
- these metal brines can be expensive, corrosive, and difficult to handle.
- brines may tend to corrode and damage the downhole equipment in .many instances, especially those of a delicate nature such as production screens.
- Brines may also cause undesired precipitation reactions that can damage the permeability of the producing formation.
- disposal of the brines may be difficult and costly, especially on land where environmental regulations prdhib.it the placement of high, concentrations of chlorides and other ions into landfills.
- the present invention relates to welt treatment compositions and methods utilizing nano-particles and, more particularly, in one or more embodiments, to well cement compositions and/or well completion fluids that comprise nano-partides.
- An embodiment of the present invention provides a method of completing a well comprising: including nano-partic!es in a completion fluid; and using the completion fluid in completing the well.
- Another embodiment of the present invention provides a method of completing a well comprising: providing a completion fluid comprising nano-partie!es; and introducing the completion fluid into a well bore.
- Another embodiment of the present invention provides a method of completing a well comprising: including nano-particles having a particle size of from about I nanometer to about 100 nanometers in a completion fluid, wherein the nano-particles comprise at least one oano-parttcle selected from the group consisting of na.no-alum.ina, nano-zinc oxide, nano-boron, nano-iron oxide, nano-silica, and any combination: thereof; and using the completion fluid in completing the well.
- the present invention relates to welt treatment compositions and methods utilizing nano-partieles and, more particularly, in one or more embodiments, to well cement compositions and/or well completion fluids that comprise nano-particles.
- An exemplary embodiment of the cement compositions of the present invention comprises cement, water and particulate nano-siiica.
- the exemplary cement compositions generally should have a density suitable for a particular application.
- the cement composition may have a density in the range of from about 4 pounds per gallon ('ib/gal") to about 20 Ib/gal
- the cement compositions may have a. density in the range of from about 8 lb gal to about 57 lb/gal.
- Exemplary embodiments of the cement compositions may he foamed or unfoamed or may comprise other means to reduce their densities, such as hollow microspheres, knv-density elastic beads, or other density-reducing additives known in the art Those of ordinary skill in the art with the benefit of this disclosure, will recognize the appropriate density for a particular application.
- Exemplary embodiments of the cement compositions of the present invention comprise a cement.
- a cement Any of a variety of cements sui table for use in subterranean cementing operations may be used in accordance with exemplar embodiments of the present invention, Suitable examples include hydraulic cements that comprise calcium, aluminum, silicon, oxygen and/or sulfur, which set and harden by reaction with water.
- Such hydraulic cements include, but are not limited to, Portland cements, pozzoiana cements, gypsum cements, hsgh- alumina-eontent cements, slag cements, silica cements and combinations thereof.
- the hydraulic cement may comprise a Portland cement
- the Portland cements that may be suited for use in exemplary embodiments of the present invention are classified as Class A, C, H and G cements according to American Petroleum institute, API Specification for Materials and Testing for Well Cements f API Specification 10, Fifth Ed., July 1, 1990.
- the water used in exemplary embodiments of the cement compositions of the present invention may be freshwater or saltwater (e.g., water containing one or more salts • dissolved therein, seawater, brines, saturated saltwater, etc.).
- the water may be present in an -amount sufficient to form & pumpable slurry.
- the water may be present in the cement compositions in an amount in the range of from about 33% to about 200% by weight of the cement on a dry basis C'bwoe * ).
- the water may be present in an amount in the range of f om about 35% to about 70% bwoe.
- exemplary embodiments of the cement compositions comprise nano-silica.
- the nano-silica may be described as particulate nano-silica. That is, the nano- silica may be paniculate in nature and not, for example, a colloidal silica or a suspension of silica in solution. Indeed, in one embodiment, the particulate nano-silica may be added to the cement composition as a dry nano-silica powder.
- the particulate nano-silica may be defined as nano-silica having a panicle size of less than or equal to about 100 nra.
- the particulate nano-silica may have a particle size in the range of from about 1 nm to about 100 sun (about
- the particulate nano-silica may have a particle size of less than or equal to about 50 ran,
- the particulate nano-silica may have a particle size in the range of from about 5 nm to about 50 nm.
- the particulate nano-silica may have a particle size of less than or equal to about. 30 nm.
- the particulate nano-silica may have a particle size in the range of from about S nm to about 30 nm.
- the particulate nano-silica may be utilized in combination with differently sized silica particles in accordance with present embodiments.
- a number of silica particles with particle sizes greater than 100 nm may be included in a cement composition in accordance with present embodiments.
- the particulate nano-silica utilized with present embodiments may have an impact on certain physical characteristics of resulting cements.
- inclusion of particulate nano-silica in the cement slurry may provide improved mechanical properties, such as compressive strength, tensile strength. Young's modulus and Poisson's ratio.
- the particulate nano-silica also may be included in the cement composition as a set accelerator to accelerate the set time of the resultant cement composition.
- a cement composition in accordance with present embodiments may comprise a sufficient amount of particulate nano-silica to provide the desired characteristics in a resulting cement.
- the particulate nano-silica may be present in. the cement composition in an amount in the ra ge of from about .1% to about 25% bwoe. In exemplary embodiments, the particulate nano-silica may be present in the cement, composition in an amount in the range of from about 5% to about 15% bwoe.
- additives suitable for use in subterranean cementing operations also may be added to exemplary embodiments of the cement compositions.
- additives include, su3 ⁇ 4ngth ⁇ retrogression additives, set accelerators, weighting agents, weight-reducing additives, heavyweight additives, lost-circulation materials, .filtration- control additives, dispe.rsa.nts, defbaming agents, foaming agents, and combinations thereof.
- Specific examples of these, and other, additive include crystalline silica, amorphous silica, salts, fibers, hydratabie e!ays, vitrified shale, microspheres, fly ash, lime, latex, thixoiropie additives, combinations thereof and the like.
- exemplary embodiments of the cement compositions of the present invention may be used in a variety of subterranean applications, including primary and remedial cementing.
- Exemplary embodiments of the cement compositions may be introduced into a subterranean formation and allowed to set therein.
- Exemplary embodiments of the cement compositions may comprise cement, water and the particulate nano-silica,
- a cement composition may be introduced into a space between a subterranean formation and a pipe string located i the subterranean formation.
- the cement composition may be allowed to set to form a hardened mass in the space between the subterranean formation and the pipe string, .
- a cement compositio may he used, for example, in squeeze- cementing operations or in the placement of cement plugs.
- One or more hydrocarbons e.g., oil, gas, etc.
- nano-particles include nano-atumina, nano-zinc oxide, nano-boron, rsano- iron oxide and combinations thereof
- the nano-particles may be particulate in nature and not, for example, a. colloidal nano-particle or a. suspension, of the nano-particle in solution.
- the present technique also encompasses the use of nano-particles in any of a variety of different subterranean treatments.
- the iiano-partiel.es may be included in any of a number of well treatment fluids that may be used in subterranean treatments, including drilling iluids, completion fluids, stimulation fluids and well c!ean-up fluids.
- the nano-particles may be included as proppant in a well treatment fluid.
- a well treatment fluid containing the nano- particles may be introduced into a subterranean formation at or above a pressure sufficient to create or enhance or more fractures hi the subterranean formation.
- Enhancing a fracture includes enlarging a pre-existing fracture in the formation. At least a portion of the nano- particles may be deposited in the one or more fractures such that the fractures are prevented from fully closing upon the release of pressure, forming conductive channels through which fluids may -flow to (or from) the well bore.
- embodiments of the present invention may include encapsulation of the nano-particles to facilitate transportation and incorporation of the nano-particles in well treatment fluids (e.g., cement compositions).
- encapsulation of the nano-particles in accordance with present embodiments may include enclosing the nano-particles within an outer coating or container in particulate form.
- Exemplary methods of encapsulation are set forth in U.S. Patent Nos. 5,373,901 * 6,444316; 6,527,051; 6554,071 : 7, 156,174; and 7,204,312, the relevant disclosures of which are incorporated herein by reference.
- the nano-particles e.g., the particulate nano-si!ica
- the nano-particles may be encapsulated within a bag, capsule, layer, coating or the like.
- the materia! utilized to encapsulate the nano-particles may be selected, to facilitate transportation and or incorporation of the nano-particles into a we ' ll treatment fluid.
- the encapsulation material may be degradabie.
- the encapsulating materia! may be designed to degrade at a certain rate when in contact with certain materials (e.g., water) so that the nano-particles are released into the well treatment fluid at a desired time.
- certain materials e.g., water
- the cement compositions of the present invention may utilize a packing volume fraction suitable for a particular application as desired.
- packing volume fraction refers to the volume of the particuiate materials in a fluid divided by the total volume of the fluid.
- the size ranges of the preferred particulate materials are selected, as well as their respective proportions, in order to provide a maximized packing volume fraction so that the fluid is in a hindered settling state, ' it is known that, in such a state, the particulate materials behave "collectively" like a porous solid material.
- the hindered settling state is believed to correspond, in practice, to a much higher solid material concentration in the fluid than that present in the some traditional cement compositions.
- the present embodiments may include a combination of at least three features io obtain a maximum packing volume fraction.
- One is the use of at least three particulate materials wherein the at least three particulate materials are in size ranges "'disjointed" from one another, hi some embodiments, each of the three particulate materials .may include a different particle size selected from the following ranges: about 7 nra to about 50 nm, about 0,05 microns to about 0.5 microns. 0.5 microns to about ! O microns, about 10 microns to about 20 microns, about 20 microns to about 200 microns, about 200 microns to about 800 microns, and greater than about I millimeter.
- a first particulate material may include particles sized from about 7 nm to about 50 nm s a second particulate material may include particles sized from about 0.05 microns to about 0.5 microns, and a third particulate material may include particles sized from about 10 microns to about 20 microns.
- the first particulate material includes at least one of nano-sslica. nano-alumina, nano-zhic oxide, nano-horon, nano-iron oxide or combinations thereof.
- Another feature of present embodiments may include a choice of the proportions of the three particulate materials in. relation to the mixing, such that, the fluid, when mixed, is in a hindered settling state.
- Another feature may include the choice of the proportions of the three particulate materials between each, other, and according t their respective size ranges, such that the maximum packing volume traction is at least substantially achieved for the sum total of all particulate materials in the fluid system. Packing volume fraction is described in further detail in United States Patent Nos. 5,518,996 and 7,213,646, the .relevant portions of which are incorporated herein by reference.
- the nano-particles may be included in completion fluids in accordance with embodiment of the present invention.
- the nano-particS.es . may be included in the completion iluids to provide a number of different benefits.
- the nano-particles may be used to enhance or otherwise improve the rheologieai properties of the completions fluids.
- the nano-particles may be included in the completion fluids as weighting materials to increase the densit of the fluid. Because the nano-particles are nano-sized, it is believed that they should not undesirably plug formation permeability or other downhole equipment, such as production screens, and thus can be included in compietion fluids.
- the inclusion of the nano-particles in completion fluids may have further beneficial effects, ' especially in shale formations.
- the nano-particles may prevent the influx of well bore fluids into the nano- porosity often found within shaie formations, such as oil shales, b sealing these pores, which isolates and stabilizes the shale formatio from the destabilizing hydraulic forces from the well bore.
- An exemplary embodiment of the completio fluids may comprise nano- particles.
- the nano-particles may have a particle size range in a range of less than or equal to about
- the "nano-particles" may be defined as having a mean particle size of less than I micron.
- nano-particles may have a mean particles size in a range of from about 1 nm to less than 1 micron.
- the nano-particles may have a mean particles size in a range of from about I nm to about 800 nm and. alternatively, from about 1 nm to about 100 nm.
- the nano-partieles may have a mean particle size in a range of about 20 nm to about 100 nm.
- the nano-partieles may ha ve particle size of about 1 nm, about 10 nm, about 50 nm.
- the nano-partieles may be provided in colloidal form, for example, a colloidal nano-particle or a suspension of the nano-particle in a fluid.
- the nano-particle may be a particulate nano-particle.
- the nano-particles may be encapsulated or otherwise contained as discussed above. Examples of suitable nano-particles include nano-aiumina, nano-zmc oxide, nano-boron, nano-iron oxide, and nano-siliea.
- suitable nano-particles include other nano-sized materials, including nano-barium sulphate, nano-manganese tetraoxide, nano-magnesium oxide, nano-calcium carbonate, nano-graphite, nano-barium oxide, nano-ceriurn oxide, naiio-!anthium oxide, nano-titanium dioxide, nano-clay, and nano-aluminosilicates. Combinations of different nano-particles may also be used. In some embodiments, the nano-particle is not aeid- so!ubic.
- the nano-particles may be included in a completion fluid in an amount sufficient for a desired application.
- the nano-particles may be included in a completion fluid in an amount sufficient to weight the fluid to a desired density
- the nano-particles may be present in the completion fluid in an amount in a range of from -about 0.1% to about 70% by volume of the completion fluid.
- the nano-particles may be present in m amount ranging between any of and/or including any of about 0.1 %, about 1%, about 10%, about 20%, about. 30%, about 40%, about 50%, about 60%, or about 70% by volume of the completion fluid.
- One of ordinary skill in the art, with the benefit of this disclosure, should be able to .select an appropriate amount of the nano-partteles to use for a particular application.
- the completion fluids may comprise a base fluid, such as an oil-based fluid or a water-based fluid.
- Oil-based fluids may comprise olefins, internal olefins, alkanes, aromatic solvents, cycSoalkanes, liquefied petroleum gas, kerosene, die.se! oils, crude oils, heavy oils, gas oils, fuel oils, paraffin oils, mineral oils, low toxicity mineral oils, esters, amides, synthetic oils (e.g., polyolefins), poiydiorganosiloxanes, siSaxanes, organosiloxanes, ethers, acetals, dialkylcarbonates. hydrocarbons, and combinations thereof.
- Water-based fluids may comprise fresh water or salt water, such as a brine or seawater.
- the base fluid ma be present in an amount in a range of from about 25% to about 99% by volum e of the completion fluid.
- additives -suitable for use in completion operations may also be included in the completion fluids in embodiments of the present invention.
- examples of such additives includes salts, surfactants, fiuid-ioss-eoniro! additives, gases such as nitrogen or carbon dioxide, surface-modifying agents.
- foamers corrosion inhibitors, scale inhibitors, clay-control agents, bioekfes, friction reducers, antifoam agents, dispersams, floeculants, I-SjS scavengers, C0 2 scavengers, oxygen scavengers, lubricants, viscostirers, breakers, wetting agents, and combinations thereof.
- the completion fluids may have a density as desired for a particular application.
- the completion fluid should have a density sufficient to, for example, control formation pressures.
- the nano-partieles may be used in some embodiments as weighting agents to increase the density of the completion fluid.
- the nano ⁇ particl.es may be included in the completion fluid in an. amount sufficient to weight the completion fluid.
- the completion fluid may have a density in the range of from about 7.5 lb gal to about 22 lb/gal, and alternatively from about 12 lb/gal to about 18 lb/gal.
- One of ordinary skill in the art, with the benefit of this disclosure should be able to determine an appropriate density of the completion fluid for a particular appS ication .
- the completion fluids may be used in operations after drilling, but before the start of production, in. some embodiments, the completion operation may include preparing the bottom of the well bore to the required specifications, running in production tubing and its associated downhole equipment, or carrying out production enhancement operations.
- the completion fluid may be present in the well bore while equipment, such as screens, production liners, and/or downho!e valves, is run into the well bore.
- the completion fluid may be present in the well bore while perforations are formed in the casing disposed in the well bore.
- the completion fluid should act to control formation, pressures.
- An embodiment of the present invention may comprise a method of completing a well that comprises providing a completion fluid comprising nano-particles and introducing the completion fluid into a well bore, in some embodiments, downhole equipment may be run into the well while the completion fluid is in the well bore.
- the downhole equipment may include, for example, screens, production liners, and/or downhole valves.
- Wire- wrapped screens may be used, for example, where a well bore liner having a porous screen may be required to mechanically hold back the formation sand, Because the nano-particles are iiano-sized, the nano-particles should not undesirably plug the downhole equipment, in contrast, if micron-sized or larger particles are included in the completio fluids, the downhole equipment, as well as the formation permeability, would be susceptible to plugging events,
- Slurry E were prepared.
- the slurries and resulting set cements were then tested to determine setting or thickening times and other physical properties of each of the live different slurries, As set forth, below, the respective test results for the five different slurries demonstrate that inclusion of particulate nano-silica in the slurry reduces the sei time and increases the strength of the resulting cement relative to cements resulting from inclusion of the other silica components that, were tested,
- Slurries A, B, C and D were prepared by dry blending dry components with cement prior to adding water to form the respective slurry.
- Slurry E was prepared b dry blending dry components with cement prior to adding water and then adding colloidal silica to form the respective slurry.
- each of the five slurries included a different type of silica.
- Two of the five slurries included particulate nano-siliea m accordance with present embodiments, and the other three included silica in different forms and sizes (e.g., colloidal silica and micro-silica). While the silica included in each of the fi ve slurries was different, the other components utilized in each of the five slurries were similar.
- each of the five slurries included 100% bvvoc of Class G cement, 0.5% bwoc of a retarder, and sufficient water to make the density of the slurry approximately 12.00 lbs/gal
- the specific retarder utilized in the slurries was HR-S cement retarder, which is a sulfomethy!ated Iignosulfonate.
- HR-S cement retarder which is a sulfomethy!ated Iignosulfonate.
- BR5 cement retarder is available irom Halliburton Energy Services, Inc. and is described in U.S. Patent No. RE31J 0.
- each of the five slurries included a different type of silica and sufficient water to make the resulting slurry have a density of 12,00 lb/gal.
- Slurries A and B included paniculate nano-siliea in accordance with present embodiments and 15.36 gal/sk of water. Specifically, Slurry A included 1.5% bwoc of particulate nano-siliea having a particle size of approximately 30 nm, and Slurry B included particulate nano-siliea having a particle size of approximately 10 nm.
- Slurry C included 15% bwoc of SIliCALlTB cement additive and 15.68 gal/sk of water
- SILICALITE (compacted) cement additive which is available from Halliburton Energy Services, Inc., Duncan, Oklahoma, is an amorphous silica generally sized in a range from about 2.5 microns to about 50 microns.
- Slurry D included 15% bwoc of ICRGSAND cement additive and 15.77 gal/sk of water.
- MICROSA .D cement additive which is available from Halliburton Energy Services, Inc., Duncan, Oklahoma, is a crystalline silica ground to a substantially uniform particle size distribution of approximately 5 to 10 microns.
- GASCOND 469 lightweight cement additive is available from Halliburton Energy Services, Inc.. Duncan, Oklahoma, and may be defined as a colloidal silicic acid suspension containing suspended silicic acid particles generally having a particle size of less than about 20 nm,
- force- resistance properties e.g., compressive strength, shear-bond strength, and tensile strength
- force-resistance property tests were performed on. the respective cement slurries at a temperature of 80°F and after ihe slurries had set for 72 hours.
- the force-resistance properly test included nondestructive and destructive ultrasonic strength tests, a compressive-strength test, a shear-bond test, and tensile-strength test.
- the nondestructive and destructive ultrasonic analyzer tests were conducted using a UCA ultrasonic cement analyzer to determine a UC A?;; t value and a i..iCA t ., US h value, respectively.
- the compressive-strength tests and UCA analyze tests were performed in accordance with API Recommended Practice J OB.
- shear-bond and Brazilian-tensile-strength tests were performed to determine shear strength and tensile strength values, respectively, for the different cement compositions.
- the shear-bond-strength tests were performed as described in SPE 764 entitled "A Study of Cement - Pipe Bondine" bv L,G. Carter and GAY. Evans.
- the Brazilian-tensile-strength tests were performed in accordance with ASTM C496-96, The results of the tests performed on each of the five compositions are shown in Table 1 below.
- Example 1 determines various additional physical properties associated with the resulting set cements and to confirm relative differences demonstrated above. While different instruments and calibration settings were used in the additional testing of the slurries, the test data indicates that relative differences between the different slurries are similar to those differences illustrated in Example 1. Indeed, as indicated above in Example 1 , the respective lest results in Example 2 for the five different cements demonstrate that inclusion of particulate nano- silica in the cement composition increases the strength of the resulting cement relative to cements resulting from inclusion of the other silica components that were tested,
- the Young's modulus or modulus of elasticity for each sample was obtained by taking a ratio of a simple tension stress applied to each sample to a resulting strain parallel to the tension in that sample.
- the Poisson's ratio for each sample was determined by calculating a ratio of transverse strain to a corresponding axial strain resulting from uniformly distributed axial stress below a proportional limit of each sample.
- the values determined for the three samples of each of the five different cement slurries are set forth below in Table 2,
- S O Embodiments is to be understood as referring to the power set (the set of all subsets) of the respective range of values, and set for the every range encompassed within the broader range of va! e.
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- General Life Sciences & Earth Sciences (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
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- Nanotechnology (AREA)
- Structural Engineering (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Physics & Mathematics (AREA)
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- Condensed Matter Physics & Semiconductors (AREA)
- General Physics & Mathematics (AREA)
- Crystallography & Structural Chemistry (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Curing Cements, Concrete, And Artificial Stone (AREA)
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Abstract
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EA201491980A EA032791B1 (en) | 2012-04-27 | 2013-04-26 | Well treatment compositions and methods utilizing nano-particles |
AU2013251467A AU2013251467A1 (en) | 2012-04-27 | 2013-04-26 | Well treatment compositions and methods utilizing nano-particles |
BR112014026544A BR112014026544A2 (en) | 2012-04-27 | 2013-04-26 | well completion method |
CA2870367A CA2870367A1 (en) | 2012-04-27 | 2013-04-26 | Well treatment compositions and methods utilizing nano-particles |
MX2014012972A MX355755B (en) | 2012-04-27 | 2013-04-26 | Well treatment compositions and methods utilizing nano-particles. |
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US20080277116A1 (en) * | 2007-05-10 | 2008-11-13 | Halliburton Energy Services, Inc. | Well Treatment Compositions and Methods Utilizing Nano-Particles |
US20100243236A1 (en) * | 2009-03-30 | 2010-09-30 | Chevron U.S.A. Inc. | Nanoparticle-densified newtonian fluids for use as cementation spacer fluids and completion spacer fluids in oil and gas wells |
US20110237467A1 (en) * | 2010-03-25 | 2011-09-29 | Chevron U.S.A. Inc. | Nanoparticle-densified completion fluids |
US20110312857A1 (en) * | 2010-06-16 | 2011-12-22 | Amanullah Md | Drilling, Drill-In and Completion Fluids Containing Nanoparticles for Use in Oil and Gas Field Applications and Methods Related Thereto |
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2013
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- 2013-04-26 WO PCT/US2013/038343 patent/WO2013163504A1/en active Application Filing
- 2013-04-26 MX MX2014012972A patent/MX355755B/en active IP Right Grant
- 2013-04-26 BR BR112014026544A patent/BR112014026544A2/en not_active Application Discontinuation
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Publication number | Priority date | Publication date | Assignee | Title |
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US20080277116A1 (en) * | 2007-05-10 | 2008-11-13 | Halliburton Energy Services, Inc. | Well Treatment Compositions and Methods Utilizing Nano-Particles |
US20100243236A1 (en) * | 2009-03-30 | 2010-09-30 | Chevron U.S.A. Inc. | Nanoparticle-densified newtonian fluids for use as cementation spacer fluids and completion spacer fluids in oil and gas wells |
US20110237467A1 (en) * | 2010-03-25 | 2011-09-29 | Chevron U.S.A. Inc. | Nanoparticle-densified completion fluids |
US20110312857A1 (en) * | 2010-06-16 | 2011-12-22 | Amanullah Md | Drilling, Drill-In and Completion Fluids Containing Nanoparticles for Use in Oil and Gas Field Applications and Methods Related Thereto |
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EA032791B1 (en) | 2019-07-31 |
EA201491980A1 (en) | 2015-02-27 |
AR090782A1 (en) | 2014-12-03 |
CA2870367A1 (en) | 2013-10-31 |
MX355755B (en) | 2018-04-27 |
EP2841523A1 (en) | 2015-03-04 |
MX2014012972A (en) | 2015-03-05 |
BR112014026544A2 (en) | 2017-06-27 |
AU2013251467A1 (en) | 2014-10-23 |
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