Abstract: De-oiled lost circulation materials and methods of using such materials to, for example, reduce fluid loss are provided. In some embodiments, such methods include introducing a first treatment fluid including a base fluid and a de-oiled plant material into a wellbore penetrating at least a portion of a subterranean formation including a loss zone; and allowing the de-oiled plant material to at least partially plug the loss zone.

Abstract: A system and method for applying a cement composition, including storing a slurry, adding magnesium oxide to the slurry to give a magnesium-oxychloride cement slurry, pumping the magnesium-oxychloride cement slurry into a wellbore, and sealing a loss circulation zone in the wellbore.

Abstract: A convertible composition comprising a nanosilica drilling fluid, the nanosilica drilling fluid comprising an aqueous based drilling mud, where the aqueous based drilling mud comprises water, and an alkaline nanosilica dispersion, where the alkaline nanosilica dispersion comprises nanosilica; and a chemical activator, the chemical activator operable to hydrolyze in the presence of water to produce an acid, where a weight ratio of the alkaline nanosilica dispersion to the chemical activator is between 1 to 0.001 and 1 to 0.25.

Abstract: Methods to optimize solvent use in solvent-dominated processes for recovery of hydrocarbons. Methods include injecting a solvent composition into a reservoir at a pressure above a liquid/vapor phase change of the solvent composition; injecting a chaser into the reservoir at a pressure above the liquid/vapor phase change of the solvent composition; allowing the solvent composition to mix with hydrocarbons in the reservoir and at least partially dissolve into the hydrocarbons to produce a solvent/hydrocarbon mixture; reducing the pressure in the reservoir below the liquid/vapor phase change pressure of the solvent composition thereby flowing at least a fraction of the solvent/hydrocarbon mixture from the reservoir; and repeating these steps as required.

Abstract: The present invention relates to a channel fracturing method with alternative injection of conventional and capsule-type soluble proppants. The method includes the following steps: injecting pad fluid into a wellbore to break a formation and form fractures in the formation; alternately injecting a sand-carrying fluid containing conventional proppant and a sand-carrying fluid containing capsule-type soluble proppant into the wellbore in sequence to support fractures in the formation and continue to fracture the formation; injecting displacement fluid into the wellbore to completely displace the sand-carrying fluids in the wellbore into the fractures. The conventional proppant of less dosage is used. The capsule-type soluble proppant is less difficult to be developed and its solubility is sensitive to the fracture closure, which is conducive to the quick flowback after fracturing.

Abstract: Gas hydrates are formed in treatment fluid in situ within the wellbore. Foaming of the treatment fluid can occur both during the introduction of the gas treatment fluid to form hydrates and downhole near the subterranean reservoir where the heat of the reservoir will cause the gas hydrates to revert back to a gaseous state. The method involves preparing a treatment fluid comprising an aqueous base fluid, and a viscosifying agent at the surface. This treatment fluid is then introduced into the wellbore. Also, at the surface, a liquefied natural gas is pressurized and then vaporized to produce a vaporized natural gas. The vaporized natural gas is introduced into the wellbore so as to mix with the treatment fluid also being introduced. The introduction is such that gas hydrates are formed from the natural gas in the treatment fluid in situ within the wellbore.

Abstract: Methods of using specific multiple charged cationic compounds, which are derived from polyamines through an aza-Michael addition with an ?, ?-unsaturated carbonyl compound, in a clay treatment composition to reduces clay swelling, clay migration, and sludge formation in a subterranean formation in oil and gas operations are provided. The disclosed methods or compositions are found to be more effective than those methods or compositions including commonly used for reducing clay swelling, clay migration, and sludge formation.

Abstract: Provided herein are liquid polymer (LP) compositions comprising a synthetic (co)polymer (e.g., an acrylamide (co)polymer), as well as methods for preparing inverted polymer solutions by inverting these LP compositions in an aqueous fluid. The resulting inverted polymer solutions can have a concentration of a synthetic (co)polymer (e.g., an acrylamide (co)polymer) of from 50 to 15,000 ppm, and a filter ratio of 1.5 or less at 15 psi using a 1.2 ?m filter. Also provided are methods of using these inverted polymer solutions in oil and gas operations, including enhanced oil recovery.

Abstract: An electrically conductive proppant coating and a method for applying the coating to the proppant, whereby the coated electrically conductive proppant can determine formation characteristics, such as dimensions, orientation, and conductivity.

Abstract: A method and sealant to seal microcracks as small as 30 ?m by causing methyl methacrylate combined with one or more nanoparticles to flow into the microcrack to be sealed.

Abstract: An additive for oil well cement contains a vinyl alcohol polymer and has good fluid loss reducing performance. The additive for oil well cement is a saponified product of a copolymer of a vinyl ester monomer and a multifunctional monomer, and has a degree of saponification of 70 to 95 mol % and a viscosity-average degree of polymerization of 1000 to 10000.

Abstract: An aqueous caustic composition comprising: a caustic component; an amino acid additive adapted to provide an extended buffering effect to the caustic composition when such is exposed to an acid; and water, wherein the caustic component and the amino acid additive are present in a molar ratio ranging from 15:1 to 5:1. Methods of using such compositions are also disclosed.

Abstract: A method for isolating a first region and a proximate second region of a subterranean formation is disclosed that includes introducing an asphaltene composition into the first region of the subterranean formation, the asphaltene composition including asphaltene dissolved in a solvent, and after introducing the asphaltene composition, introducing an aqueous composition to the first region to precipitate the asphaltene in the first region. The precipitated asphaltene forms a barrier that isolates the second region from at least a portion of the first region.

Abstract: A method of reducing corrosion of a metal surface comprises contacting a fluoride ion-containing acidic fluid with a corrosion inhibitor composition before the fluoride ion-containing acidic fluid contacts the metal surface, the corrosion inhibitor composition comprising a zirconium compound, an antimony compound, or a combination comprising at least one of the foregoing; and exposing the metal surface to the fluoride ion-containing acidic fluid.

Abstract: Lithium-containing cement admixtures including a calcium aluminate phosphate cement; a lithium-ion-containing compound; and an aqueous base fluid and methods of introducing the lithium-containing cement admixtures into a subterranean formation. The lithium-containing cement admixtures may further comprise an aluminosilicate or an additive including a set retarder, a set accelerator, a suspension aid, a density reducing agent, a fluid loss control agent, a defoamer, and any combination thereof.

Abstract: A method of servicing a wellbore penetrating a subterranean formation, comprising: placing a wellbore servicing fluid (WSF) into the wellbore, wherein the WSF comprises a first polymer, a second polymer, and water, wherein the first polymer is formed by polymerizing monomers comprising three of 2-Acrylamido-2-methyl propane sulfonic acid (AMPS), N,N-dimethylacrylamide (NNDMA), acrylamide, N-vinylacetamide, allyloxy-2-hydroxy propane sulfonic acid (AHPS), acrylic acid (AA), 2-acrylamido-2-tert.-butyl sulfonic acid (ATBS), or N,N-Dimethylaniline, and the second polymer is formed by polymerizing monomers and/or crosslinkers comprising AMPS, vinylpyrrolidinone, pentaerythritol allyl ether, and methylenebisacrylamide, wherein in the vinylpyrrolidinone, the 2-Pyrrolidone group can be substituted by a heterocyclic group, comprising one or more Z membered rings with Y heteroatoms, wherein Z is equal to or greater than three, and wherein Y is equal to or greater than one.

Abstract: The fracturing methods can provide an advantage over the current fracturing methods. The fracturing methods can change the fracture gradient of the downhole subterranean formation. For example, one or more of the fracture gradients of the low and high stress zones of the downhole subterranean formation can be changed. Furthermore, the methods, in relation to current practices, can decrease the extent and/or degree of fracturing within low stress downhole formations and increase the degree of fracturing within high stress formations.

Abstract: A method including introducing a well cementing composition into a wellbore, the cementing composition including a pumpable slurry of cement comprising a liquid anti-shrinkage additive including: an aqueous base fluid; a calcined magnesium oxide; and an anti-hydration agent; and allowing at least a portion of the cementing composition to harden. A liquid anti-shrinkage additive for cement including an aqueous base fluid, a calcined magnesium oxide, and an anti-hydration agent.

Abstract: A well cementation working solution prepared from red mud, slag and waste drilling fluids. The working solution is prepared from the following components in parts by weight: 100 parts of waste drilling fluids, 50-100 parts of slag, 5-50 parts of red mud, 4-7 parts of a suspension stabilizer, 1-7 parts of an activating aid, 0.5-5 parts of an anti-pollution agent and 0.4-3.5 parts of a diluent. The waste drilling fluids are waste waterborne drilling fluids. The slag is blast furnace slag or vanadium-titanium slag. The suspension stabilizer is sodium bentonite, carboxymethyl cellulose or a mixture of sodium bentonite and carboxymethyl cellulose. The activating aid is sodium metasilicate nonahydrate, sodium carbonate or a mixture of sodium metasilicate nonahydrate and sodium carbonate. The anti-pollution agent is sodium salicylate, potassium citrate or a mixture of sodium salicylate and potassium citrate. The diluent is sodium lignin sulfonate.

Abstract: A method for recovering hydrocarbons in a carbonate reservoir by introducing a saline solution injection containing a saline soluble surfactant and a saline soluble polymer. The method provides for increased hydrocarbon recovery as compared to conventional waterflooding techniques.