Abstract: Nano-sized clay minerals enhance the viscosity of aqueous fluids that have increased viscosity due to the presence of viscoelastic surfactants (VESs). In one non-limiting theory, the nano-sized phyllosilicate mineral viscosity enhancers associate, link, connect, or relate the VES elongated micelles into associations thereby increasing the viscosity of the fluid, possibly by mechanisms involving chemisorption or surface charge attractions. The nano-sized phyllosilicate mineral particles, also called clay mineral nanoparticles, may have irregular surface charges. The higher fluid viscosity is beneficial to crack the formation rock during a fracturing operation, to reduce fluid leakoff, and to carry high loading proppants to maintain the high conductivity of fractures.

Abstract: The invention discloses a cement slurry composition for cementing a well comprising: an hydraulic cement, water and a combination made of a cellulosic polymer and an acrylamido-methyl-propane sulfonate co- or ter-polymer, wherein the density of said cement slurry is above 1700 kg/m3.

Abstract: An underground formation is consolidated by (a) incorporating into a treatment fluid (i) at least one chemical substance which is capable of undergoing a chemical change that alters the physico-chemical environment of the treatment fluid and which is a bicarbonate or a compound that generates a phosphate, phosphoric acid, sulphate, sulphuric acid, hydrogen sulphide, S2?, carbon dioxide, bicarbonate, base or acid; and, optionally, (ii) at least one additional chemical substance selected from salts and complexes of metals having a valency of 2 or higher; introducing the treatment fluid into the formation; and allowing the chemical substance (i), alone or in combination with the optional chemical substance (ii), to undergo a chemical change that alters the physico-chemical environment of the treatment fluid such that a consolidating mineral is deposited in the underground formation.

Abstract: A method is described to predict the composition of favorable bridging agents for a particular situation in which the solution thermodynamics of the chemicals used in the composition of the bridging material is carefully evaluated. Wellbore service fluids are also described that contain materials such as sodium bicarbonate, a material such as a salt containing water in a crystal structure, a material containing at least one boron-oxygen bond, or a non-polymer material having low solubility at low temperatures and high solubility at temperatures close to an expected long-term static bottom hole temperature. The material is provided in aqueous medium in sufficient concentration in the aqueous medium so as to act as a diverting agent during a hydraulic fracturing procedure using the fluid. The wellbore service fluid is pumped through the wellbore and the flow of the fluid is diverted using a plug that subsequently substantially dissolves due to changes in temperature and/or pressure.

Abstract: Treatments and compounds useful in subterranean formations are discussed, with particular attention to those utilizing ceramic coated particulates. Certain embodiments pertain to particulates and particulate packs with ceramic coatings of subatomic thickness. Of these, certain methods may utilize ceramic coatings on particulates in a subterranean formation, certain methods may utilize ceramic coatings on particulate packs in a subatomic formation, and certain compounds may provide the features of both ceramic coatings and particulates.

Abstract: A slurry and method are disclosed for low damage gravel packing. The slurry comprises a solids mixture comprising a plurality of volume-averaged particle size distribution (PSD) modes such that a packed volume fraction (PVF) exceeds 0.75; a carrier fluid in an amount to provide a solids volume fraction (SVF) less than the PVF of the solids mixture; and a stability additive to inhibit settling of the solids mixture. The method comprises circulating the slurry into a wellbore to deposit the slurry downhole; terminating the slurry circulation for a period of time, wherein the stability additive inhibits settling of the solids mixture; and thereafter circulating the deposited slurry in contact with a surface of a screen. Stability additives disclosed include colloidal particles, hydratable polymer particles, and particles having an aspect ratio above 6.

Abstract: Alkaline earth metal compounds may be fluid loss control (FLC) agents for viscoelastic surfactant (VES) fluids used for fluid loss control pills, lost circulation material pills and kill pills in hydrocarbon recovery operations. The FLC agents may include, but not be limited to oxides and hydroxides of alkaline earth metal, and in one case magnesium oxide where the particle size of the magnesium oxide is between 1 nanometer to 0.4 millimeter. The FLC agent may alternatively be transition metal oxides and/or transition metal hydroxides. The FLC agent appears to associate with the VES micelles and together form a novel pseudo-filter cake quasi-crosslinked viscous fluid layer that limits further VES fluid flow into the porous media. The FLC agent solid particles may be added along with VES fluids. The pills may also contain internal breakers to reduce the viscosity thereof so that the components of the pill may be recovered.

Abstract: A treatment fluid and system are disclosed for cleaning borehole filtercake using the treatment fluid, wherein the filtercake contains reservoir drilling fluid (RDF) solids. The treatment fluid comprises a fluoride source providing a 1.2 to 5 molar fluoride concentration, and another acid or combination of acids to provide a pH between 1.8 and 5. The treatment fluid is balanced for a dissolving power high enough to have significant dissolution of the filtercake, but low enough for even propagation to avoid premature leak-off.

Abstract: Articles and methods utilizing radiation susceptible materials are provided herein. In one aspect, a proppant, a treatment fluid, or both, may comprise a radiation susceptible material. In another aspect, a method is provided comprising disposing in a formation fracture, a proppant and/or a treatment fluid that comprises a radiation susceptible material, irradiating the radiation susceptible material with neutrons, measuring gamma-radiation emitted from the radiation susceptible material in a single pass, and determining formation fracture height from the measured gamma-radiation. The single-pass may be a continuous process or a periodic process.

Abstract: A method of cleaning a wellbore prior to the production of oil or gas is disclosed, wherein the wellbore has been drilled with an invert emulsion drilling mud that forms an invert emulsion filter cake. The method may include the steps of circulating a breaker fluid into the wellbore, where the breaker fluid includes an aqueous fluid, a water soluble polar organic solvent, a hydrolysable ester of a carboxylic acid, and a weighting age, and where the hydrolysable ester is selected so that upon hydrolysis an organic acid is released and the invert emulsion of the filter cake breaks.

Abstract: The methods described herein generally relate to preparing and delivering a fluid mixture to a confined volume, specifically an annular volume located between two concentrically oriented casing strings within a hydrocarbon fluid producing well. The fluid mixtures disclosed herein are useful in controlling pressure in localized volumes. The fluid mixtures comprise at least one polymerizable monomer and at least one inhibitor. The processes and methods disclosed herein allow the fluid mixture to be stored, shipped and/or injected into localized volumes, for example, an annular volume defined by concentric well casing strings.

Abstract: New fluids are disclosed for use in servicing subterranean formations containing oil and gas. In particular, an improved chemical gelling additive for hydrocarbon based fracturing fluids is disclosed having reduce, negligible or no volatile phosphorus at temperatures below about 250° C.

Abstract: Drilling, drill-in and completion fluids containing nanoparticles for use in hydrocarbon drilling and recovery processes and methods related thereto are provided. The fluids also include a dual acting shield agent that shields the nanoparticles and also acts as a viscosifier. The fluids can be used in various types of hydrocarbon drilling and recovery processes, such as drilling, drill in, completion, and the like.

Abstract: The invention provides a method made of steps of providing a composition comprising a first chemical component and a degradable protective layer, wherein the degradable protective layer is at least partially degradable when subject to temperature, pH or time; and introducing into a wellbore the composition and allowing the degradable protective layer to degrade and release the first chemical component.

Abstract: The present invention relates to aqueous tackifiers and methods of controlling particulates in subterranean formations using aqueous tackifiers. Some embodiments of the present invention provide methods of controlling particulates, comprising placing an aqueous tackifier compound into a portion of a subterranean formation comprising unconsolidated particulates; and, activating the aqueous tackifier compound. Other embodiments of the present invention provide methods of coating a portion of a surface in a subterranean formation comprising substantially coating an aqueous tackifier compound onto a portion of a subterranean formation; and, activating the aqueous tackifier compound. Other embodiments of the present invention provide treatment fluids for controlling fine particulates, comprising a servicing fluid and an aqueous tackifier compound.

Abstract: The invention relates to oil and gas industry, i.e. techniques for making proppants designed to be used as propping agents in oil and gas recovery by the method of formation hydraulic fracturing. A method for the production of a lightweight magnesium silicate proppant, the method comprises heat processing of a magnesium-containing component—a source of magnesium oxide, its co-grinding with a silica- containing component, pelletizing of the batch prepared, sintering and sieving of the pellets prepared, wherein the batch comprises (in terms of calcined substance), in % by weight: SiO2-6 4-72, MgO-11-18, natural impurities—remainder, wherein the heat processing is carried out at temperature not more than 1080 degrees C. A lightweight magnesium silicate proppant is characterized in that the proppant is produced by said method. At least one of the group: serpentine, brucite, caustic magnesite, talc may be used said magnesium-containing component.

Abstract: The invention is a composition, for use in treating oil wells, comprising fibres, hot melt adhesives and particulate solids. This composition has a wide range of applications including preventing or lessening lost circulation, wellbore strengthening or consolidation, controlling fluid loss, producing a “stress cage” effect, gravel packing, acting as an aid to cementing, and for proppant backflow control.

Abstract: An annular fluid or packer fluid, and methods of making the same, that includes a water-miscible solvent, a viscosifying additive, a crosslinking agent, a crosslinking inhibitor having the facility to inhibit crosslinking between the viscosifying additive and the crosslinking agent, and an initiating agent having the facility to overcome an action of the crosslinking inhibitor and to initiate crosslinking between the viscosifying additive and the crosslinking agent, is shown and described. The fluid has a thermal conductivity of no more than about 0.25 btu/(hr·ft·° F.) and a potential to substantially increase its viscosity upon sitting for a selected period of time.

Abstract: A nano-dispersion well servicing fluid is disclosed. The well servicing fluid is formulated with components comprising: nanoparticles comprising at least one material chosen from aluminum oxides, aluminum hydroxides, aluminum hydroxyoxides, zirconium oxides, zirconium hydroxides, zirconium hydroxyoxides, wherein the concentration of nanoparticles is greater than 0.5% by weight based on the total weight of the nano-dispersion well servicing fluid. The well servicing fluid also comprises an aqueous base continuous phase. Methods of employing the nano-dispersion to service a wellbore are also disclosed.

Abstract: Materials and methods for making low bulk density proppant capable of providing permeability at subterranean pressures. The low bulk density proppant is made from kaolin clay and at least one of calcined diatomaceous earth and burned kaolin clay.

Abstract: A slurry for treating a wellbore that includes a base fluid; at least one fibrous structure; and a plurality of calcium silicate particles is disclosed. Methods of reducing loss of wellbore fluid in a wellbore to a formation using an LCM pill having calcium silicate particles therein is also disclosed.

Abstract: A composite proppant having an increased buoyancy comprising a proppant substrate such as a porous ceramic or a silica sand coated with a material of a lesser actual density than the apparent density of the proppant substrate to increase the buoyancy of the composite proppant.

Abstract: Non-aqueous carrier fluids containing nano-sized particles in high concentration are effective for zone isolation and flow control in water shutoff applications for subterranean formations. The nanoparticles interact with water and solidify it to inhibit its flow, but do not have the same effect on hydrocarbons and thus selectively assist the production of hydrocarbons while suppressing water. Suitable nanoparticles include alkaline earth metal oxides, alkaline earth metal hydroxides, alkali metal oxides, alkali metal hydroxides, transition metal oxides, transition metal hydroxides, post-transition metal oxides, post-transition metal hydroxides, piezoelectric crystals, and/or pyroelectric crystals.

Abstract: Among the methods described herein are methods using low-specific gravity particulates wherein the particulates comprise silica and an aluminum oxide in an amount of about 0.1% to about 25% by weight and having at least one void, a specific gravity of less than about 2.2, a particle sized of 8 U.S. Mesh or smaller, and a substantially spherical shape.

Abstract: This invention relates to compositions and methods of treating a subterranean formation penetrated by a well bore including providing a treatment composition comprising a rheological polymer, a partitioning agent, a charged polyelectrolyte, and a first liquid medium, forming a stabilized heterogeneous mixture comprising a dispersed rheological polymer-rich phase and a partitioning agent-rich phase, and injecting the treatment fluid into the well bore. The invention relates to methods and compositions for preparing a well treatment fluid, including mixing polyethylene glycol partitioning agent, a charged polyelectrolyte, a first aqueous medium, and one or more rheological polymers selected from the group consisting of guar, modified guar, cellulose, modified cellulose, heteropolysaccharide, heteropolysaccharide derivative, or polyacrylamide, to hydrate the one or more polymers and form a water-in-water emulsion, and mixing the water-in-water emulsion with a second aqueous medium to form a well treatment fluid.

Abstract: This invention relates to compositions and methods for treating subterranean formations, in particular, oilfield stimulation compositions and methods using water-in-water polymer emulsions to uniformly dissolve a rheologically active polymer, such as a thickener or friction reducer, in the treatment fluid. The emulsions have a low viscosity and are easily pumped for mixing into a treatment fluid, where upon dilution with an aqueous medium, the polymer is easily hydrated without forming fish-eyes. The partitioning agent in the water-in-water emulsion does not generally affect the rheology of the treatment fluid. The invention also relates to further processing of the emulsion by wet grinding, high shear mixing and/or heating to enhance the hydration rate in the preparation of the well treatment fluid.

Abstract: A method of using nitrates, nitrites, or ammonium recovered from contaminated water for feeding microbes used in microbial enhanced oil recovery (MEOR). If required, the nitrogen waste removed from contaminated waters is treated to be converted as nitrates or nitrites. The nitrates and nitrites are mixed with microbes that are then injected into oil wells for improved tertiary oil production or injected separately depending on balance of feed and microbes in well brine as judged from examining brine that exits well with the oil. The use of nitrates recovered from contaminated waters to feed microbes in MEOR is cost effective for both the process of water decontamination and oil recovery.

Abstract: Of the many compositions provided herein, an embodiment includes a foamed cement composition comprising a cementitious component, an oil-swellable particle comprising at least one swellable elastomer selected from the group consisting of acrylate butadiene rubber, polyacrylate rubber, isoprene rubber, choloroprene rubber, butyl rubber, brominated butyl rubber, chlorinated butyl rubber, chlorinated polyethylene, neoprene rubber, styrene butadiene block copolymer, sulphonated polyethylene, ethylene acrylate rubber, epichlorohydrin ethylene oxide copolymer, ethylene-propylene rubber, ethylene vinyl acetate copolymer, fluorosilicone rubber, silicone rubber, and combinations thereof, a foaming and stabilizing surfactant, gas, and water. Another embodiment includes a foamed cement composition comprising a cementitious component, an oil-swellable particle comprising a block copolymer of styrene butadiene rubber, a foaming and stabilizing surfactant, and gas.

Abstract: The present invention is directed to completion fluid compositions and methods of making same. Such completion fluids are unique in that they utilize nanoparticles as weighting (densification) agents that increase the specific gravity (or density) of the fluid into which they are dispersed. Depending on their properties, such nanoparticulate weighting agents can vastly broaden the types of base fluid used in the completion fluid, permitting the use of non-aqueous and even hydrocarbon base fluids. Additionally, such nanoparticle-densified completion fluids can provide reduced environmental risks, and the nanoparticle weighting agents used therein can be more easily recovered from the based fluids into which they are dispersed.

Abstract: The invention consists in loading a chemical wash fluid with solid particles to enhance annulus cleanup prior to placing cement slurries (or during the completion phase). The presence of solid particles in a low-viscosity fluid will induce an abrasive cleanup of all soft material present in the annulus in particular gelled mud and mud cake. There is no need for special hardware and no harm to metallic parts. The particles have a size of at least 100 microns and a density ranging from 0.1 to 2g/cm3.

Abstract: Method and system for making a spherical proppant having a selected grade from a naturally occurring mined mineral having a hardness of over 6.0 Mohs. The method and system involves preprocessing the mineral mechanically into a semi-dry feedstock comprising a mass of particles with initial sphericity values generally less than 0.60; subjecting the semi-dry feedstock to an aggressive abrasive attrition operation for a process time; and, controlling the process time to a value wherein the particles of the feedstock are converted to final processed particles having a sphericity greater than 0.60 by increasing the sphericity of the feedstock particles by at least 0.10. In addition, the processed particles are screened to obtain a proppant having a selected grade.

Abstract: A method of preventing fluid loss to a wellbore that includes pumping a wellbore fluid into the wellbore through a subterranean formation, the wellbore fluid comprising: a base fluid; and a plurality of particulate bridging agents comprising a solid breaking agent encapsulated by one of an inorganic solid material and an oil-soluble resin; and allowing some filtration of the wellbore fluid into the subterranean formation to produce a filter cake comprising the particulate bridging agents is disclosed.

Abstract: A method of making a proppant is provided, wherein the method includes the steps of: (a) forming a particulate comprising: (i) a binder; and (ii) a filler; and (b) sintering the particulate to form a sintered proppant, wherein the sintered proppant comprises: (i) at least 20 wt % of alkaline earth oxide equivalent; and (ii) at least 20 wt % of silicon dioxide equivalent. A method of treating (e.g., fracturing) a subterranean formation is provided, the method including the steps of: (a) suspending the sintered proppant in a treatment fluid; and (b) introducing the sintered proppant into the subterranean formation. The sintered proppant is made with a raw material selected from the group consisting of: unhydrated cement, hydrated cement (e.g., construction cement or concrete waste), kiln dust, fly ash, limestone, lime, talc, olivine, dolomite, clay that contains a substantial concentration of alkaline earth oxide equivalent, and any combination thereof in any proportion.

Abstract: The present invention relates to proppants which can be used to prop open subterranean formation fractions. Proppant formulations are further disclosed which use one or more proppants of the present invention. Methods to prop open subterranean formation fractions are further disclosed. In addition, other uses for the proppants of the present invention are further disclosed, as well as methods of making the proppants.

Abstract: A wellbore fluid comprising a base fluid and a particulate bridging agent comprised of a sparingly water-soluble material selected from the group consisting of melamine (2,4,5-triamino-1,3,5-triazine), lithium carbonate, lithium phosphate (Li3PO4), and magnesium sulfite.

Abstract: Many methods are provided including a method comprising: providing a surfactant gel having a first viscosity that comprises an aqueous base fluid and a surfactant; providing an ortho ester breaker; contacting the surfactant gel with the ortho ester breaker; allowing the ortho ester breaker to hydrolyze to produce an acid and an alcohol; and allowing the acid and/or the alcohol to interact with the surfactant gel so as to reduce the first viscosity of the surfactant gel to a second viscosity.

Abstract: An aqueous composition for treating hydrocarbon wells contains (a) a scale inhibitor and (b) a viscoelastic surfactant, and further contains from 0 to less than 1% by weight of acid selected from the group consisting of hydrochloric acid, sulfuric acid, phosphoric acid, formic acid, acetic acid, citric acid, maleic acid, hydrofluoric acid, and mixtures thereof.

Abstract: The present invention relates to proppants which can be used to prop open subterranean formation fractions. Proppant formulations are further disclosed which use one or more proppants of the present invention. Methods to prop open subterranean formation fractions are further disclosed. In addition, other uses for the proppants of the present invention are further disclosed, as well as methods of making the proppants.

Abstract: An iron control agent capable of reducing ferric iron containing compounds to ferrous iron containing compounds in an acidic solution, such as one used for formation acidizing. The iron control agent comprises a combination of a sulfur dioxide, sulfurous acid, sulfite salts, bisulfite salts, or thiosulfate salts or mixtures thereof, with a source of copper ions and a source of iodine or iodine ions. The iron control agent may also include small amounts of an adjunct such as stannous chloride, 2-mercaptoethanol, and thioglycolic acid and its salts.

Abstract: Brine-based well treatment compositions containing alkali nitrate exhibit greater thermal stability when used in deep wells than substantially similar brine-based well treatment compositions which do not contain an alkali nitrate. The brine is thickened with a water-soluble crosslinkable polymer and crosslinking agent. The enhanced thermal stability of the well treatment compositions allows use of the fluids at elevated temperatures, for instance as high as 400° F.

Abstract: A modified sol-gel method to create metal-rich siliceous material, such as colloidal silica or aluminosilicate particles is disclosed. Initially, the metal salt of choice is added to a silicic acid solution or a silicic acid solution containing aluminum salt. The aluminum is added to vary the metal-support interaction as it forms Al—O—Si linkages within the silica matrix. Besides aluminum, other metals can be added that form M—O—Si (M=Ti, B, etc.) linkages, which do not become reduced when treated with a reducing agent. Once the metal, silicic acid and/or aluminum salt is generated, it is subjected to colloidal growth by addition to a basic heel. Upon colloidal synthesis, the metal salt containing colloidal particle is left as is to maximize colloidal stability or is reduced with hydrazine to produce the zero valence metal-containing colloidal particle.

Abstract: Methods and compositions useful in treating subterranean formations, and more particularly, breaker compositions that may be useful in treating subterranean formations wherein synthetic polymers are used, are provided. Of the many methods and compositions provided herein, one composition comprises a source of hydrogen peroxide and an activator. One method comprises providing a polymer breaker composition comprising a source of hydrogen peroxide and an activator; introducing the polymer breaker composition into a well bore which penetrates a subterranean formation; allowing the activator to activate the source of hydrogen peroxide to create an oxidizing species; and allowing the oxidizing species to break synthetic polymers present in the subterranean formation.

Abstract: Methods and compositions useful for subterranean formation treatments, such as hydraulic fracturing treatments and sand control that include porous materials. Such porous materials may be selectively configured porous material particles manufactured and/or treated with selected glazing materials, coating materials and/or penetrating materials to have desired strength and/or apparent density to fit particular downhole conditions for well treating such as hydraulic fracturing treatments and sand control treatments. Porous materials may also be employed in selected combinations to optimize fracture or sand control performance, and/or may be employed as relatively lightweight materials in liquid carbon dioxide-based well treatment systems.

Abstract: Crystalline ceramic particles including at least 90 percent by weight Al2O3, based on the total weight of the crystalline ceramic particle, and having a density in a range from 50 to 75 percent of theoretical density, a long term flow conductivity of at least 4.5×10?12 m2-m at 55.2 MPa, and a smallest dimension of at least 100 micrometers. The crystalline ceramic particles described herein are useful for example, as proppants, insulation (thermal and/or sound), and filler.

Abstract: Disclosed is a method for introducing additives into formation fluid from an oil and gas well in or moving through equipment and systems located downstream from the oil and gas well. The method is practiced using pellets having a density sufficient to suspend the pellet at an interface of two phases of fluid within the Downstream Equipment. The pellets are prepared from a pellet matrix, such as an ethoxylated wax, and, optionally, a weighting agent as well as an additive. By varying the amount of weighting agent, the density of the pellet can be varied to suspend it at a desired point for a time sufficient to deliver the additive to the desired point within the Downstream Equipment. The method of the invention may also be used with Refinery Equipment such as a fuel distribution system or a waste water treatment system.

Abstract: An acid treatment composition is provided including a corrosion inhibitor and an optional corrosion inhibitor intensifier in an acidic solution. More specifically, the composition includes an anionic surfactant. Methods for treating wells with these acid treatment compositions are also provided that help control corrosion of the steel used in the wells during the acid treatment.

Abstract: The invention provides a method for treating a subterranean formation penetrated by a wellbore, the method comprising the steps of formulating a treatment fluid and introducing the treatment fluid through the wellbore. The treatment fluid comprises water; diutan; and a sufficient amount of salt to increase the density of the treatment fluid to at least 8.5 lb/gal, wherein at least 50% by weight of the salt is selected from the group consisting of: bromide salts, non-bromide salts having a higher salting-in effect than bromide according to the Hofmeister series as measured by the salt's effect on the cloud point of poly(ethylene oxide) that has a molecular weight of 4×106, and any combination in any proportion thereof. The invention also provides a treatment fluid for use in a subterranean formation penetrated by a wellbore, the treatment fluid comprising: water; diutan; and a sufficient amount of salt to increase the density of the treatment fluid to at least 8.

Abstract: This invention relates to methods and compositions useful in treating crude sources, and more specifically, to methods and compositions useful in reducing the concentration of phosphorus in crude streams and hydrocarbon flowback fluids. In some embodiments, the present invention provides methods that include a method comprising: providing a crude stream or a hydrocarbon flowback fluid; optionally testing the crude stream or the hydrocarbon flowback fluid for total phosphorus content; optionally testing the crude stream or hydrocarbon flowback fluid for volatile phosphorus content; adding a solution comprising a trivalent metal ion to the crude stream or the hydrocarbon flowback fluid; adding a sufficient amount of a caustic solution to the crude stream or the hydrocarbon flowback fluid to raise the pH of the stream or the fluid to about 8 or more; allowing at least a plurality of precipitates to form; removing at least one precipitate; and forming a clean crude stream or a clean hydrocarbon flowback fluid.

Abstract: The use of a surfactant mixture comprising at least one surfactant having a hydrocarbon radical composed of from 12 to 30 carbon atoms and at least one cosurfactant having a branched hydrocarbon radical composed of from 6 to 11 carbon atoms for tertiary mineral oil extraction.

Abstract: Methods and compositions for the treatment of subterranean formations, and more specifically, treatment fluids containing vitrified shale and methods of using these treatment fluids in subterranean formations, are provided. A method of displacing a fluid in a wellbore comprises providing a wellbore having a first fluid disposed therein; and placing a second fluid into the wellbore to at least partially displace the first fluid therefrom; wherein the second fluid comprises a base liquid; vitrified shale; a clay weighting agent present in the range of about 5% to about 20% by weight of the second fluid; and a viscosifying agent present in the range of about 1% to about 10% by weight of the second fluid.