Abstract: A sealant is provided which is a curable resin external emulsion having a fluid internal phase comprising a curable material which expands during, after or before it cures. The resin external phase is, for example, an epoxy resin which may shrink as it cures. The internal phase is captured within micelles to provide discrete internal phase portions supported in an out resin matrix.

Abstract: A treatment fluid is described suitable for use in subterranean formations comprising an aqueous phase, a carboxymethyl hydroxyethyl cellulose, and a breaker. The aqueous phase comprises water having at least 1,000 ppm total dissolved inorganic salts and at least one of: a sulfate concentration of about 4,000 ppm or greater, a phosphate concentration of about 100 ppm or greater, a carbonate concentration of about 100 ppm or greater, or a barium concentration of about 37,000 ppm or greater. The carboxymethyl hydroxyethyl cellulose has a carboxymethyl degree of substitution in the range of about 0.3 to about 0.45 per glucopyranose unit in the carboxymethyl hydroxyethyl cellulose polymer; and a hydroxyethyl molecular substitution in the range of about 2.1 to about 2.9 per glucopyranose unit in the carboxymethyl hydroxyethyl cellulose polymer; The treatment fluid is substantially free of any crosslinker.

Abstract: Methods of treating a wellbore in a subterranean formation including providing a treatment fluid comprising a consolidating agent, wherein the consolidating agent comprises the reaction product of a furfuryl alcohol or a furfuryl alcohol derivative and a silicon derivative compound selected from the group consisting of a silane; a silanol; a silsesquioxane; any derivative thereof; and any combination thereof; introducing the treatment fluid into the wellbore in the subterranean formation; contacting the consolidating agent with a surface of the wellbore in the subterranean formation; and setting the consolidating agent.

Abstract: Methods of treating subterranean formations comprising providing a wellbore in a subterranean formation having at least one fracture therein; providing a first treatment fluid comprising a base fluid and an acid generating inert agent; providing a second treatment fluid comprising a base fluid, and an acid generating activator; introducing the first treatment fluid into the at least one fracture; and introducing the second treatment fluid into the at least one fracture, wherein the acid generating inert agent in the first treatment fluid reacts with the acid generating activator in the second treatment fluid so as to generate an acid in the at least one fracture and create or enhance at least one microfracture therein.

Abstract: Methods of treating a wellbore in a subterranean formation including providing a treatment fluid comprising a consolidating agent, wherein the consolidating agent comprises the reaction product of a furfuryl alcohol or a furfuryl alcohol derivative and a silicon derivative compound selected from the group consisting of a silane; a silanol; a silsesquioxane; any derivative thereof; and any combination thereof; introducing the treatment fluid into the wellbore in the subterranean formation; contacting the consolidating agent with a surface of the wellbore in the subterranean formation; and setting the consolidating agent.

Abstract: Methods of treating a wellbore in a subterranean formation including providing a treatment fluid comprising a consolidating agent, wherein the consolidating agent comprises the reaction product of a furfuryl alcohol or a furfuryl alcohol derivative and a silicon derivative compound selected from the group consisting of a siloxane; a silane; a silanol; a silsesquioxane; any derivative thereof; and any combination thereof; introducing the treatment fluid into the wellbore in the subterranean formation; contacting the consolidating agent with a surface of the wellbore in the subterranean formation; and setting the consolidating agent.

Abstract: A downhole optical sensor system includes at least one optical sensor positioned in a borehole and coupled to an interface via a fiber optic cable. Each of the optical sensors includes a waveguide for conducting light, and a reagent region positioned between the waveguide and a fluid in the borehole to absorb a portion of the light from the waveguide, the portion being dependent upon a concentration of a chemical species in the fluid. A method for operating a well includes deploying one or more downhole optical sensors in a fluid flow path in the well, probing the one or more downhole optical sensors from a surface interface to detect concentrations of one or more chemical species, and deriving a rate of scale buildup or corrosion based at least in part on the detected concentrations.

Abstract: Treatment fluid suitable for use in subterranean formations may comprise: (i) an aqueous phase comprising water having at least 1,000 ppm total dissolved inorganic salts, wherein the aqueous phase comprises at least one of: a sulfate concentration of about 4,000 ppm or greater, a phosphate concentration of about 100 ppm or greater, a carbonate concentration of about 100 ppm or greater, or a barium concentration of about 37,000 ppm or greater; (ii) a carboxymethyl hydroxyethyl cellulose, wherein: (a) the carboxymethyl hydroxyethyl cellulose has a carboxymethyl degree of substitution is in the range of about 0.3 to about 0.45 per glucopyranose unit in the polymer; and (b) the carboxymethyl hydroxyethyl cellulose has a hydroxyethyl molecular substitution is in the range of about 2.1 to about 2.9 per glucopyranose unit in the polymer; and (c) the treatment fluid is substantially free of any crosslinker; and (iii) a breaker.

Abstract: Method of treating a subterranean formation comprising providing a consolidation fluid, introducing the resin consolidation fluid into a subterranean formation comprising unconsolidated particulates; and, curing the resin to at least partially consolidate the unconsolidated particulates. The consolidation fluid comprises a resin in emulsified form with an aqueous external phase and an organic internal phase wherein the emulsified resin does not comprise a hardening agent and an aqueous base fluid that further comprises a hardening agent. The consolidation fluid may further comprise an emulsifying agent.

Abstract: Treatment fluids containing biodegradable chelating agents can be used in various treatment methods. The methods can comprise providing a treatment fluid that comprises an aqueous base fluid and a chelating agent composition, and introducing the treatment fluid into at least a portion of a subterranean formation. The treatment fluids can also be used for treatment of pipes or tubing such as, for example, well bore pipes or tubing penetrating a subterranean formation and above-ground pipelines. Illustrative biodegradable chelating agents include, but are not limited to, glutamic acid diacetic acid, methylglycine diacetic acid, ?-alanine diacetic acid, S,S-ethylenediaminedisuccinic acid, iminodisuccinic acid, hydroxyiminodisuccinic acid, any salt thereof, any derivative thereof, and any combination thereof. The treatment fluids can optionally comprise an acid, which can include hydrofluoric acid or a hydrofluoric acid generating compound.

Abstract: Methods for treating a subterranean formation can comprise introducing a treatment fluid comprising dicarboxymethyl glutamic acid (GLDA) or a salt thereof into a subterranean formation. Methods for treating a sandstone formation can comprise introducing a treatment fluid comprising GLDA or a salt thereof into a sandstone formation, the treatment fluid having a pH above about 3.

Abstract: Methods for treating a subterranean formation can include: providing a treatment fluid that comprises: an aqueous base fluid; a hydrofluoric acid source selected from the group consisting of hydrofluoric acid, a hydrofluoric acid generating compound, and a combination thereof; and a biodegradable chelating agent comprising one of the following selected from the group consisting of: glutamic acid diacetic acid, a glutamic acid diacetic acid salt, a derivative thereof, and a combination thereof. The treatment fluid may then be introduced into at least a portion of a subterranean formation.

Abstract: A method of increasing the fracture complexity in a treatment zone of a subterranean formation is provided. The subterranean formation is characterized by having a matrix permeability less than 1.0 microDarcy. The method includes the step of pumping one or more fracturing fluids into a far-field region of a treatment zone of the subterranean formation at a rate and pressure above the fracture pressure of the treatment zone. A first fracturing fluid of the one or more fracturing fluids includes a first solid particulate, wherein: (a) the first solid particulate includes a particle size distribution for bridging the pore throats of a proppant pack previously formed or to be formed in the treatment zone; and (b) the first solid particulate comprises a degradable material. In an embodiment, the first solid particulate is in an insufficient amount in the first fracturing fluid to increase the packed volume fraction of any region of the proppant pack to greater than 73%.

Abstract: Methods and compositions including a method comprising: providing a treatment fluid comprising an aqueous fluid, a relative permeability modifier, and a chelating agent; introducing the treatment fluid into a well bore that penetrates a subterranean formation; and allowing at least a first portion of the treatment fluid to penetrate into a portion of the subterranean formation so as to substantially divert a second portion of the treatment fluid to another portion of the subterranean formation.

Abstract: Method including the steps of providing a treatment fluid that comprises a base fluid and polymeric particulates and introducing the treatment fluid into a subterranean formation having a temperature above about 65° C. The polymeric particulates comprise a degradable polymer and a plasticizer and exhibit a Tg above about ?15° C. When the polymeric particulates are placed into a subterranean formation having a temperature above about 65° C. they transform from rigid form to malleable form and are able to provide fluid loss, seal the rock surfaces for fluid diversion, or plug an area along the annulus of a well bore. The malleable particulates then degrade over time in the subterranean formation.

Abstract: A method of increasing the fracture complexity in a treatment zone of a subterranean formation is provided. The subterranean formation is characterized by having a matrix permeability less than 1.0 microDarcy. The method includes the step of pumping one or more fracturing fluids into a far-field region of a treatment zone of the subterranean formation at a rate and pressure above the fracture pressure of the treatment zone. A first fracturing fluid of the one or more fracturing fluids includes a first solid particulate, wherein: (a) the first solid particulate includes a particle size distribution for bridging the pore throats of a proppant pack previously formed or to be formed in the treatment zone; and (b) the first solid particulate comprises a degradable material. In an embodiment, the first solid particulate is in an insufficient amount in the first fracturing fluid to increase the packed volume fraction of any region of the proppant pack to greater than 73%.

Abstract: Methods of treating a wellbore in a subterranean formation including providing a treatment fluid comprising a consolidating agent, wherein the consolidating agent comprises the reaction product of a furfuryl alcohol or a furfuryl alcohol derivative and a silicon derivative compound selected from the group consisting of a siloxane; a silane; a silanol; a silsesquioxane; any derivative thereof; and any combination thereof; introducing the treatment fluid into the wellbore in the subterranean formation; contacting the consolidating agent with a surface of the wellbore in the subterranean formation; and setting the consolidating agent.

Abstract: Methods for creating a fluid diverting barrier in a zone of a subterranean formation are provided. Certain methods comprise providing a treatment fluid that comprises an aqueous base fluid, a viscoelastic surfactant, and a soap component; placing the treatment fluid in a subterranean formation penetrated by a well bore; and allowing the soap component of the treatment fluid to interact with a metal ion present in the subterranean formation to form a precipitate.

Abstract: Methods of treating an ultra-low permeability subterranean formation having a fracture complexity comprising interconnected fractures including providing a fracturing fluid comprising a base fluid and coated proppant, wherein the coated proppant comprise proppant coated with a degradable material; introducing the fracturing fluid into the ultra-low permeability subterranean formation at a rate and pressure above a fracture gradient of the ultra-low permeability subterranean formation; placing the coated proppant into a fracture of the interconnected fractures so as to form a temporarily impermeable proppant pack comprising the coated proppant therein and reduce or prevent the extension of the fracture; reducing the pressure below the fracture gradient; and degrading the degradable material coated onto the coated proppant so as to cause the temporarily impermeable proppant pack to become a permeable proppant pack.

Abstract: Methods of treating subterranean formations comprising providing a wellbore in a subterranean formation having at least one fracture therein; providing a first treatment fluid comprising a base fluid and an acid generating inert agent; providing a second treatment fluid comprising a base fluid, and an acid generating activator; introducing the first treatment fluid into the at least one fracture; and introducing the second treatment fluid into the at least one fracture, wherein the acid generating inert agent in the first treatment fluid reacts with the acid generating activator in the second treatment fluid so as to generate an acid in the at least one fracture and create or enhance at least one microfracture therein.