Abstract: A remediation process that a employs improved quantitative method(s) of estimating of the volume and/or mass of contaminant in the subsurface, removal and or in situ degradation of the contamination using subsurface pulsing treatment (“SPT”) technology, and evaluation of the degree of remediation by re-applying the quantitative contaminant evaluation methods. The process uses SPT technology with the addition of a vacuum or sub-atmospheric pressure to an extraction well in order to create a push-pull effect to remove free contaminant or residual in conjunction with the pressure wave driving force created in the excitation or excitation well. The process can quantitatively measure the amount of residual contaminant, which up until now has not been possible or tractable using in situ methods, as well as measure the amount of residual that can be removed by SPT.

Abstract: A particulate suspending agent may be useful for mitigating particulate settling in wellbore applications with high-temperature and/or at near-neutral and higher pH values. Methods of treating a wellbore may include providing a treatment fluid comprising an aqueous liquid, a plurality of particulates, and a particulate suspending agent, wherein the particulate suspending agent comprises a crosslinked polymer particulate formed by a reaction comprising a first monofunctional monomer and an orthoester crosslinker, the orthoester crosslinker comprising an orthoester linkage and at least two crosslinking moieties; and placing the treatment fluid in a wellbore penetrating a subterranean formation.

Abstract: A composition comprises: a treatment fluid comprising a lost-circulation material, wherein the lost-circulation material comprises a ceramic, and wherein the lost-circulation material has a median particle size in the range from about 0.001 millimeters to about 25.4 millimeters. According to another embodiment, a composition comprises: the treatment fluid comprising a lost-circulation material, wherein the lost-circulation material comprises a ceramic, and wherein the median particle size and the concentration of the lost-circulation material is selected such that the treatment fluid has a sealing pressure of at least 50 psi (0.3 MPa). A method of eliminating or reducing lost circulation from a well comprises: introducing the treatment fluid into at least a portion of the well.

Abstract: The present invention relates to compositions comprising tunable polymeric surfactants and methods for enhanced oil recovery.

Abstract: A composition in the form of an emulsion having: (i) a continuous oil phase comprising: (a) an oil; (b) an emulsifier; and (c) a particulate comprising an oxide selected from the group consisting of metal oxides, metalloid oxides, and any combination thereof, wherein the particulate is hydrophobically modified, would not dissolve in oil or 28% hydrochloric acid, and has a surface area in the range of 700 m2/g to 30 m2/g; and (ii) an internal aqueous phase comprising water having a pH of less than zero. A method of acidizing a treatment zone of a subterranean formation in a well includes the steps of: (A) forming a treatment fluid comprising such a composition; and (B) introducing the treatment fluid into a well, wherein the design temperature is at least 275° F. Preferably, the particulate is hydrophobically modified silica.

Abstract: Trivalent-ion chelating agents may be useful in mitigating the formation aluminum and ferric precipitates in subterranean formations during acidizing operations. An acidizing operation may include introducing an acidizing fluid into a wellbore penetrating a subterranean formation, the acidizing fluid comprising an aqueous fluid, an acid source, and a trivalent-ion chelating agent, e.g., hydroxamates, 6,7-dihydroxyquinoline, 3-hydroxy-4-pyridinones, and any combination thereof. In some instances, trivalent-ion chelating agents with a pKa of less than about 7 may be particularly useful in acidizing operations.

Abstract: The invention relates to methods for extracting an organics component from subsurface shale formations comprising kerogen and an extractible organics component in an inorganic matrix. Among other factors, these processes are based on the discovery that to more easily access the kerogen in oil shale, it is helpful to first remove the extractible organics component from the subsurface shale formation. The methods utilize a hydrocarbon solvent to at least partially solubilize the extractible organics component. The extractible organics component can be isolated and upgraded to produce useful products. The processes are more environmentally benign, more economical, and more efficient in producing commercial products and in providing access to kerogen.

Abstract: A shifting sleeve has differential piston areas so that applied pressure displaces the sleeve against spring bias, which preferably is a series of Belleville washer stacks associated with modular mandrel components, to obtain the desired opposing force to the movement initiated with pressure applied to differential piston areas. An indexing feature is located between the sleeve and the mandrel passage wall and on a predetermined number of cycles disables the Belleville washer stacks from biasing the sleeve in an opposed direction as when pressure is applied. At this time the pressure in the mandrel acting on the differential piston area simply shifts the sleeve to open a lateral port so that fracturing through the cement that was earlier placed with the port closed can take place.

Abstract: Disclosed herein is a nanoparticle modified fluid that comprises nanoparticles; and a liquid carrier; where the nanoparticles have their surfaces modified so as to increase the viscosity of the nanoparticle modified fluid above that of a comparative nanoparticle modified fluid that contains the same nanoparticles whose surfaces are not modified, when both nanoparticle modified fluids are tested at the same shear rate and temperature.

Abstract: A method of recovering crude oil from a subterranean hydrocarbon-containing formation, comprises the steps: i) injecting into said formation an enhanced oil recovery composition comprising a) a surfactant having the general formula: R1-X—R2, wherein R1 is an open chain sugar alcohol, wherein X is one selected from NH, NCH3 and NCH2CH3, and wherein R2 is an aliphatic or aromatic group comprising at least 5 carbon atoms, b) water, and ii) recovering the crude oil, typically from one or more production wells. One advantage is that the composition is natural product-based. It has superior emulsification, wetting and dispersion capabilities. The composition functions well under heat, pressure, high salinity and high water hardness. The starting materials of the surfactant are renewable and inexpensive. The surfactant is non-toxic and degradable.

Abstract: A method of treating a hydrocarbon-bearing formation and treated hydrocarbon-bearing formations. The method includes contacting the hydrocarbon-bearing formation with a composition having solvent and a fluorinated polymer. The fluorinated polymer has units having formula (I): A method for making a composition containing these units is also disclosed.

Abstract: Anhydrous borate compounds can be used in a variety of subterranean treatment operations, where particulates of the anhydrous borate compounds slowly become soluble in an aqueous fluid after facilitating the treatment operation. Cleanup fluids can be used for affecting a more rapid removal of the anhydrous borate compounds from a subterranean formation. Methods for performing a cleanup of anhydrous borate compounds within a subterranean formation can comprise providing a cleanup fluid comprising a polyhydroxylated compound, introducing the cleanup fluid into a subterranean formation having a plurality of anhydrous borate particulates therein, and interacting the polyhydroxylated compound with the anhydrous borate particulates such that the anhydrous borate particulates become soluble in an aqueous fluid.

Abstract: Method of improving performance or efficiency of a wellbore pump associated with a wellbore and/or for increasing the rate of production of reservoir fluid from a reservoir, in which a wellbore pump is arranged to pump wellbore fluid within the wellbore to a surface. The method includes (a) selecting a wellbore which includes an associated wellbore pump associated with a production tube and arranged within a casing. An annulus is defined between the casing and the pump/production tube, the annulus including reservoir fluid which has a hydrostatic head which is at least 15 m above the level of an inlet of the wellbore pump, and (b) contacting a reservoir fluid in the annulus upstream of an inlet of the wellbore pump with a treatment formulation. The treatment formulation has a first polymeric material which includes —O— moieties pendent from a polymeric backbone thereof, and the first polymeric material is optionally cross-linked.

Abstract: Compositions, apparatus incorporating a composition, and methods of use are described, one composition embodiment consisting essentially of one or more reactive metals in major proportion, and one or more alloying elements in minor proportion, with the provisos that the composition is high-strength, controllably reactive, and degradable under defined conditions. Compositions of the invention may exist in a variety of morphologies, including a reactive metal or degradable alloy processed into an alloy of crystalline, amorphous or mixed structure that may constitute the matrix of other composition, for instance a composite. Methods of using apparatus comprising a composition, particularly in oilfield operations are also described (e.g. flow and displacement control, sensors, actuators). This abstract allows a searcher or other reader to quickly ascertain the subject matter of the disclosure. It will not be used to interpret or limit the scope or meaning of the claims.

Abstract: Methods of controlling fluid loss, providing fluid diversion, or plugging a portion of a well bore using a treatment fluid including relatively insoluble borate material particulates that are placed into a subterranean formation to provide the desired action and then degrade over time in the subterranean formation in the presence of an aqueous fluid such as water.

Abstract: A hydration acceleration surfactant may be utilized in conjunction with high molecular weight polymers in forming high viscosity, aqueous based treatment fluids. Forming such fluids may involve mixing an aqueous base fluid, a hydration acceleration surfactant, a crosslinker polymer, and a base polymer, thereby yielding a treatment fluid, wherein the base polymer is provided in the form of a first polymeric emulsion before mixing and/or the crosslinker polymer is provided in the form of a second polymeric emulsion before mixing. Further, such fluids may be useful in subterranean operations to perform for at least one function within the wellbore and/or the subterranean formation including bridge a fracture, provide fluid loss control, seal a rock surface, enable fluid diversion, plug a void, reduce formation permeability, control water production, and any combination thereof.

Abstract: Methods for mitigating precipitation during matrix acidizing of a subterranean formation. The methods generally comprise introducing a treatment fluid into a subterranean formation. The treatment fluid comprises a chelating agent; a hydrofluoric acid source; and a stabilizing compound. The stabilizing compound has two or more quaternized amine groups. In some cases the treatment fluid further comprises alkali metal ions.

Abstract: A method and apparatus for the management of injection and production of well fluids in a subterranean well is described to optimize the use of stimulation fluids to enhance their compatibility with subterranean reservoirs and the surface environment and thereby reducing the damage said fluids induce in subterranean reservoirs and upon flow back to the surface reduce their damage to the environment is described. More specifically, this method is directed to the subterranean treatment of injection fluids.

Abstract: A method includes treating a first formation intersecting a wellbore, preparing a diversion fluid including an inactivated viscosifier and an inactivated thinning agent, and positioning an amount of the diversion fluid to isolate the first formation. An activator is then delivered to the diversion fluid, thereby activating the inactivated viscosifier and triggering a thinning agent activation process.

Abstract: Methods and apparatus for running a completion string with sand screen assemblies through multiple zones are presented allowing sequential stimulation of zones, and production without multiple trips. An exemplary method includes running a completion string and isolating target zones. If desired, the formation can be produced prior to stimulation. To stimulate the zones, a first tubing valve is closed, for example by ball-drop, forcing fluid through the first screen assembly. After stimulating the zone is complete, a first screen valve is closed by increased tubing pressure. The first work string valve is re-opened by further increasing tubing pressure. A subsequent tubing valve is then closed, for example, by flowing the ball to the next ball seat. The process is repeated until all zones are stimulated. Valves are then opened at each screen assembly to allow production flow through the screen assemblies.

Abstract: Disclosed herein is a fracturing fluid comprising a carrier fluid; a polymer that is soluble in the carrier fluid; the polymer being a synthetic polymer; the synthetic polymer being operative to increase the viscosity of the carrier fluid to about 5 to about 50 centipoise; the fracturing fluid being operative to reduce friction during a downhole fracturing operation and to transport a proppant during the downhole fracturing operation.

Abstract: A treatment tool treats downhole features with one additive using sensors that acquire information relating to the downhole feature. A conveyance device selectively positions the treatment tool in a borehole. A related method includes acquiring information relating to the downhole feature using a treatment tool positioned in a borehole, estimating a condition relating to the downhole feature based on the acquired information, and treating the downhole feature using at least one additive applied by the treatment tool. The method may also include estimating a change in the condition of the downhole feature after the treatment of the downhole feature.

Abstract: Methods of drilling wellbores, placing proppant packs in subterranean formations, and placing gravel packs in wellbores may involve fluids, optionally foamed fluids, comprising nanoparticle suspension aids. Methods may be advantageously employed in deviated wellbores. Some methods may involve introducing a pad treatment fluid into at least a portion of the subterranean formation at a pressure sufficient to create or extend at least one fracture in the subterranean formation; introducing a proppant slurry treatment fluid into at least a portion of a subterranean formation, the treatment fluid comprising a base fluid, proppant particles, and a nanoparticle suspension aid; and forming a proppant pack in the fracture.

Abstract: A composition comprises: a treatment fluid comprising a lost-circulation material, wherein the lost-circulation material comprises asphalt, and wherein the lost-circulation material has a median particle size in the range from about 0.001 millimeters to about 25.4 millimeters. According to another embodiment, the composition comprises: a treatment fluid comprising a lost-circulation material, wherein the lost-circulation material comprises asphalt, and wherein the median particle size and the concentration of the lost-circulation material is selected such that the treatment fluid has a sealing pressure of at least 30 psi (0.2 MPa). A method of eliminating or reducing lost circulation from a well comprises: introducing the treatment fluid into at least a portion of the well.

Abstract: A method of treating a well including the steps of: (A) forming a treatment fluid comprising: (i) water; (ii) a water-soluble ?-polysaccharide selected from the group consisting of a ?-galactomannan, a water-soluble derivative thereof retaining ?-O-glycosidic linkages and a mannose:galactose of at least 5:1; and any combination thereof; (iii) a borate cross-linker; (iv) a base to adjust the pH of the water in the treatment fluid to be at least 8.5; and (v) a water-soluble ?-polysaccharide or water-soluble derivative thereof retaining ?-O-glycosidic linkages; and (B) introducing the treatment fluid into the well.

Abstract: Compositions comprising a proppant core having an outer surface and polymeric microspheres attached to at least a portion of the outer surface are described. The compositions are useful, for example, to increase the productivity of a hydrocarbon oil or gas bearing well.

Abstract: A method for treating a wellbore in a hydrogen sulfide-containing formation that includes injecting a first slug in the wellbore, the first slug comprising: at least one of primary amine and ammonia; and a base fluid; injecting a second slug in the wellbore, the second slug comprising: a triazine scavenger; and a base fluid; and allowing the triazine scavenger to react with the hydrogen sulfide is disclosed.

Abstract: Biomimetic adhesive compositions can be used in various aspects of subterranean treatment operations. Methods for treating a subterranean formation can comprise: providing an adhesive composition that comprises a first polymer comprising a plurality of monomers that comprise a phenolic moiety, a biopolymer that is crosslinkable with the first polymer, a crosslinking agent, and an oxidizing agent; introducing the adhesive composition into a subterranean formation; and forming a coacervate-bound surface in the subterranean formation by crosslinking the first polymer.

Abstract: A relative permeability modifier may be used to protect a hydrocarbon-producing zone of a subterranean formation without detrimentally affecting its ability to produce hydrocarbons. Methods for protecting a hydrocarbon-producing zone of a subterranean formation can comprise: introducing a first treatment fluid comprising a relative permeability modifier to a hydrocarbon-producing zone of a subterranean formation also comprising a water-producing zone; concurrently with or after introducing the first treatment fluid to the hydrocarbon-producing zone, introducing a second treatment fluid comprising a sealant composition to the water-producing zone; and allowing the relative permeability modifier to substantially prevent the sealant composition from entering the hydrocarbon-producing zone.

Abstract: The invention relates to methods and compositions for producing or recovering an aqueous-based fluid to be utilized or injected in a wellbore or surrounding subterranean formation. The method comprises the step of contacting an aqueous-based fluid with an aqueous-soluble breaker composition comprising an oxidizing agent and a catalyst for a time sufficient to reduce or eliminate one or more deleterious substances in the aqueous-based fluid to produce a treated aqueous-based fluid suitable for use or injection in a wellbore or surrounding subterranean formation.

Abstract: Methods are provided for treating production fluid in an oil reservoir to reduce the amount of sulfide in the production fluid. The production fluid is treated with nitrate and/or nitrite ions in an aqueous solution that is added to an injection well that is in contact with the production well.

Abstract: A method of forming a gelled liquid hydrocarbon treatment fluid is disclosed. The method comprises combining a liquid hydrocarbon, a phosphoric acid ester and a pre-mixed solution comprising water, ferrous ion (Fe2+) and an amine; and forming the gelled liquid hydrocarbon treatment fluid. A method of treating a portion of a subterranean formation is also disclosed and comprises: providing a gelled liquid hydrocarbon treatment fluid, by combining a liquid hydrocarbon, a phosphoric acid ester and a pre-mixed solution comprising water, ferrous ion and an amine, and treating the portion of the subterranean formation with the gelled liquid hydrocarbon treatment fluid.

Abstract: Treatment fluids comprising hydrofluoric acid, a hydrofluoric acid-generating compound, or any combination thereof can be used in conjunction with acidizing a subterranean formation that contains a siliceous material. Inclusion of a salt block inhibitor in the treatment fluids may eliminate or reduce the formation of insoluble fluorosilicates and aluminosilicates that can occur when an acidizing operation is conducted. Methods for treating a subterranean formation can comprise: providing a treatment fluid that comprises a salt block inhibitor comprising a fructan, and hydrofluoric acid, a hydrofluoric acid-generating compound, or any combination thereof; and introducing the treatment fluid into a subterranean formation.

Abstract: Treatment fluids comprising a silicate complexing agent can be used in conjunction with acidizing a subterranean formation that contains a siliceous material. Inclusion of the silicate complexing agent in the treatment fluids may eliminate or reduce the production of insoluble fluorosilicates and aluminosilicates that can occur when an acidizing operation is conducted. Methods for treating a subterranean formation can comprise: providing a treatment fluid that comprises a silicate complexing agent comprising a tertiary amine compound, a functionalized pyridine compound, any salt thereof, or any combination thereof; and hydrofluoric acid, a hydrofluoric acid-generating compound, or any combination thereof; and introducing the treatment fluid into a subterranean formation.

Abstract: A method of treating a treatment zone in a well is provided. The method includes the step of introducing into the treatment zone: (a) a hydrated sheet silicate mineral; and (b) a chemical activator for expanding the hydrated sheet silicate mineral. According to an embodiment, a method of treating a treatment zone in a well, where the method includes the steps of, in any order: (a) introducing into the treatment zone a first treatment fluid, wherein the first treatment fluid includes: (i) a hydrated sheet silicate mineral; and (ii) water; and (b) introducing into the zone a second treatment fluid including a chemical activator for expanding the hydrated sheet silicate mineral in the treatment zone.

Abstract: A method including the steps of: (a) providing a dispersion comprising: a water-soluble polysaccharide and a carrier fluid, wherein the carrier fluid comprises: (i) glycerol, and (ii) a mono-hydroxylic alcohol having 1-3 carbons, wherein the mono-hydroxylic alcohol is present in at least 0.1% by weight of the glycerol, wherein the polysaccharide is insoluble in the carrier fluid; (b) mixing the dispersion with at least water to form an aqueous well treatment fluid, wherein the polysaccharide is soluble in the aqueous phase of the aqueous wellbore treatment fluid; and (c) introducing the aqueous treatment fluid into a subterranean formation.

Abstract: The current application discloses methods and systems for preparing a pump-ready treatment fluid, delivering the pump-ready treatment fluid to a location operationally coupled to a wellsite, providing the pump-ready treatment fluid to a pump; and pumping the pump-ready treatment fluid into a wellbore. In some embodiments, the treatment fluid is a fracturing fluid for conducting a hydraulic fracturing operation on a subterranean formation penetrated by a wellbore.

Abstract: The present invention relates to nitrogen-containing hydroxyethyl substituted compounds to be used as corrosion inhibitors for metal surfaces, for example in aqueous systems and in particular in oil-field applications, e.g. in oil or gas wells, and which could be used under sweet-well conditions as well as under sour-well conditions. It may also be used in oil-field acidizing and fracture-acidizing well stimulation treatment. The compounds belong to the group of partly ethoxylated fatty alkylamines, partly ethoxylated alkyletheramines and partly or fully hydroxyethyl substituted alkylamidopropylamines.

Abstract: A method for introducing inhibitor into a fluid to be treated by forming a dispersion comprising droplets, particles, or gas bubbles of inhibitor dispersed in a continuous phase of a carrier, wherein forming the dispersion comprises subjecting a mixture of the inhibitor and the carrier to a shear rate of greater than about 20,000 s?1 in a high shear device comprising at least one generator comprising a rotor and a complementarily-shaped stator, wherein the rotor and the stator each comprise grooves, and wherein the grooves of the stator and the grooves of the rotor of each generator are disposed in alternating directions, and using at least a portion of the dispersion to inhibit corrosion.

Abstract: A treatment fluid for a well includes: (a) a water-soluble polymer, wherein the water-soluble polymer comprises a polymer of at least one non-acidic ethylenically unsaturated polar monomer; (b) an organic crosslinker comprising amine groups, wherein the organic crosslinker is capable of crosslinking the water-soluble polymer; (c) a weak organic acid; and (d) water; wherein the treatment fluid is a crosslinkable polymer composition.

Abstract: Described herein is a method of well treatment that includes providing a well treatment composition containing a non-functionalized cellulose material and a halide salt composition containing at least zinc halide, calcium halide or a mixture thereof, and placing the well treatment composition within a wellbore or a subterranean formation, and wherein the halide salt composition dissolves at least a portion of the non-functionalized cellulose material.

Abstract: A thickened aqueous composition is delivered to a subterranean location accessible via a wellbore by steps of i. providing a biphasic aqueous mixture comprising two aqueous solutions which, at surface temperature and pressure, are able to co-exist as separate aqueous phases in contact with each other, ii. pumping said biphasic aqueous system down the wellbore to the subterranean location, and iii. converting the biphasic mixture below ground so that its phases combine into a single aqueous phase which is more viscous than the biphasic mixture. The two phases of the aqueous biphasic mixture contain dissolved solutes which segregate between the two phases such that at least one first solute is present at a greater concentration in the first aqueous phase than in the second aqueous phase while at least one second solute is present at a greater concentration in the second aqueous phase than in the first aqueous phase.

Abstract: Methods and systems for in situ extraction of bitumen from deposits of bitumen-containing material are described. The methods and systems can generally include establishing freeze walls within the deposit of bitumen-containing material to establish a confined zone into which solvents can be injected in order to extract bitumen from the bitumen-containing deposits. Different types of solvents can be sequentially injected in order to extract bitumen and also help reduce the amount of solvent left behind in the deposit.

Abstract: Novel aminoacid alkylphosphonic acid compounds are disclosed. These compounds can be used in multiple applications, in particular in a scale inhibitor functionality in aqueous systems, including in marine oil recovery.

Abstract: The components of surfactant-laden fluids, such as those used in hydrocarbon recovery operations such as for stimulation, e.g. hydraulic fracturing, may be re-used and re-cycled into components for subsequent use in a wide range of similar or different operational fluids. In particular, aqueous fluids gelled with viscoelastic surfactants and having components therein to pseudo-crosslink the elongated VES micelles and for internal breaking may be separated into its component parts by relatively inexpensive methods such as filtration. One filtration method includes contacting the surfactant-containing fluid with a particle pack having particulate additives therein which filter out or extract fine solids from the fluid. In an alternate embodiment the surfactant-laden fluid is a nano- and/or micro-emulsion wellbore cleanup fluid.

Abstract: A composition comprising crosslinked expandable polymeric microparticles capable of hydrolysis at or below neutral pH and a method of modifying the permeability to water of a subterranean formation by introducing such compositions into the subterranean formation is disclosed and claimed. This invention further relates to compositions and methods for the recovery of hydrocarbon fluids from a subterranean reservoir or formation subjected to CO2 or CO2 Water Alternating Gas flooding at low pH and increases the mobilization and/or recovery rate of hydrocarbon fluids present in the subterranean formations.

Abstract: A method of treating a zone of a subterranean carbonate formation penetrated by a wellbore is provided. The method includes the steps of: According to an embodiment, a method of treating a zone of a subterranean carbonate formation penetrated by a wellbore is provided, the method including the steps of: (a) forming a treatment fluid comprising: (i) water; (ii) a water-soluble polymer having at least one functional group that can be crosslinked with aluminum(III); and (iii) a water-soluble aluminum carboxylate; wherein the pH of the treatment fluid is less than 1; (b) introducing the treatment fluid through the wellbore into the zone; and (c) allowing time for the strong acid in the treatment fluid to spend in the formation such that the pH of the fluid increases sufficiently for the aluminum of the aluminum carboxylate to crosslink the polymer.

Abstract: The application is directed to a hydraulic fracturing method and can be used for enhancement of the well production. The method for enhancement of fracture conductivity comprises the chemical treatment of the fracture surface and the space between the proppant pillars over the protective mask formed by material precipitated out from the proppant pillar.

Abstract: Disclosed herein are methods for extracting an organics component from subsurface shale formations comprising kerogen and an extractible organics component in an inorganic matrix. Among other factors, these processes are based on the discovery that to more easily access the kerogen in oil shale, it is helpful to first remove the extractible organics component from the subsurface shale formation. The methods utilize a hydrocarbon solvent to at least partially solubilize the extractible organics component. The extractible organics component can be isolated and upgraded to produce useful products. The presently disclosed processes are more environmentally benign, more economical, and more efficient in producing commercial products and in providing access to kerogen.

Abstract: Compositions of lost circulation materials are provided that are useful for identifying the location of fluid loss in a wellbore. The compositions include additives which enhance a property of the composition such that they can be detected by an LWD or MWD tool capable of measuring the property when the composition is deployed in a region of loss, and can be distinguished by the LWD or MWD tool from the formation and mud fluid. Methods are also provided for using the composition to detect the location of fluid loss and for controlling the loss of fluid from the wellbore. The methods involve deploying the compositions in loss regions by adding the compositions to drilling mud, and measuring a property of the compositions using an LWD or MWD tool.