Abstract: A method of extracting hydrocarbons from a subterranean formation comprises forming a suspension comprising reactive particles and a carrier fluid. The suspension is introduced into a subterranean formation containing a hydrocarbon material. At least a portion of the reactive particles are exothermically reacted with at least one other material within the subterranean formation to form a treated hydrocarbon material from the hydrocarbon material. The treated hydrocarbon material is extracted from the subterranean formation. An additional method of extracting hydrocarbons from a subterranean formation, and a method of treating a hydrocarbon material within a subterranean formation are also described.

Abstract: An aqueous-based downhole fluid having a lubricant therein may be circulated within a subterranean reservoir wellbore where the downhole fluid may be or include a drilling fluid, a completion fluid, a fracturing fluid, a drill-in fluid, a workover fluid, and combinations thereof. The lubricant may include a clay stabilizer and a vegetable oil derivative, such as but not limited to, a sulfonated vegetable oil. The downhole fluid may include the lubricant in an effective amount for lubricating a first surface.

Abstract: A self-triggering, in-situ crosslinking fluid system is provided for controlling lost circulation for drilling in a carbonate formation. Methods of drilling a well include the steps of: (A) forming a drilling fluid comprising an aqueous phase, wherein the aqueous phase comprises: (i) water; (ii) acid, wherein the acid is at least sufficiently strong and in at least a sufficient concentration such that the aqueous phase has an initial pH of less than about 2; (iii) a viscosity-increasing agent; and (iv) a crosslinker, wherein the crosslinker is selected or controlled to crosslink the viscosity-increasing agent at a pH range anywhere in a range of about 1.5 to about 6.5 and that is at least higher than the initial pH of the aqueous phase; and (B) drilling with the drilling fluid to form a wellbore penetrating a subterranean formation.

Abstract: Inhibiting gas hydrate formation while transporting hydrocarbon fluids may include providing a kinetic gas hydrate inhibitor, adding the kinetic gas hydrate inhibitor to a fluid capable of producing gas hydrates, and transporting the fluid that comprises the kinetic gas hydrate inhibitor. Generally a kinetic gas hydrate inhibitor may include a heterocyclic compound comprising nitrogen, e.g., polyvinyl pyrrolidone).

Abstract: A method of monitoring fluid flow in an oil reservoir includes the step of delivering a nutrient package to an oil reservoir. The nutrient package stimulates the growth of resident microbes/organisms which changes the morphology and function of the microbes. A sample is taken from produced fluids from wells in the reservoir and possible connections thereof and analyzed. Based on the analysis, determinations are made regarding the movement of fluids in the reservoir by observing changes in the range, concentration, and cell morphology of the microbes after nutrient stimulation by comparing pre-treatment versus post treatment measurements.

Abstract: A method for enhancing production from multiple-fractured underground “tight” formations. Spaced upwardly-extending injection fissures are created along a horizontal injection wellbore, and upwardly-extending collection fissures, alternately spaced with the injection fissures, are created along the horizontal injection wellbore or another adjacent production wellbore. The injection wellbore is supplied with fluid under pressure, which flows into such created fissures and drives reservoir fluids within the formation to the remaining (alternately) spaced adjacent fissures along such wellbore or another parallel adjacent (production) wellbore, thereby allowing reservoir fluids to flow downwardly along such alternately spaced production fissures for collection.

Abstract: A method of hydraulic fracturing is provided which uses metal silicides to generate significant pressure inside a wellbore. The method comprises injecting a fracturing fluid and an aqueous or reacting fluid into the wellbore to react with the fracturing fluid. The fracturing fluid comprises metal silicide, which may be uncoated or coated, and hydrocarbon fluid. The reacting fluid comprises water or a solvent. A method of removing buildup in pipelines such as subsea pipelines which uses metal silicides to generate heat and pressure inside the pipeline is also provided. The method comprises injecting an organic slug and an aqueous slug. The organic slug comprises metal silicide and hydrocarbon fluid. The aqueous slug comprises water. Alternatively, there is also provided a method for purifying flowback water produced from a hydraulic fracturing process comprising adding metal silicide to the flowback water produced from a hydraulic fracturing process.

Abstract: Methods for acidizing subterranean formations may include introducing into a wellbore penetrating the subterranean formation having a temperature of about 275° F. or greater a treatment fluid comprising an aqueous fluid, a Lewis acid catalyst and a precursor; wherein the precursor is selected from the group consisting of a saccharide, a saccharide derivative, and a combination thereof; and reacting the precursor and the Lewis acid catalyst to yield an organic acid in a portion of the subterranean formation, a portion of the wellbore, or both.

Abstract: A method for increasing oil production in a carbonate reservoir by incorporating a saline solution injection including a saline soluble surfactant and a saline soluble polymer. The method provides for increased oil production as compared to conventional waterflooding techniques.

Abstract: The invention relates to injecting steam into crude oil for several benefits, primarily of which is to remove salt by transferring the salt into the condensed water from the steam. Steam transfers salt via a different transfer mechanism and therefore doesn't require the high shear mixing of conventional water injection systems. As such, steam injection through a variety of procedures, is more efficient at gathering salt into water that itself is easier to remove from the crude oil.

Abstract: The present invention relates to hollow hydrogel capsules. In various embodiments, the present invention provides a method of treating a subterranean formation with a hollow hydrogel capsule including a hydrogel shell including a hydrolyzed and crosslinked polymerized composition. The hollow hydrogel capsule also includes a hollow interior including at least one component of a downhole composition for subterranean petroleum or water well drilling, stimulation, clean-up, production, completion, abandonment, or a combination thereof. In various embodiments, the present invention provides compositions comprising the hollow hydrogel capsules and methods of making the hollow hydrogel capsules.

Abstract: Methods and systems of delivering a treatment chemical are disclosed, including providing a plurality of porous particles each having an outer surface, wherein each of the plurality of porous particles comprises a plurality of pores; infusing the plurality of porous particles with the treatment chemical; coating the plurality of porous particles with a degradable film; adding the plurality of porous particles to a carrier fluid, wherein the degradable film substantially separates the treatment chemical from the carrier fluid; introducing the carrier fluid into a formation; and allowing the degradable film to degrade within the formation.

Abstract: A method for sweeping a subterranean petroleum reservoir and recovering hydrocarbons therefrom. Such method utilizes a plurality of spaced hydraulic fractures extending radially outwardly from, and spaced laterally along, a length of a single horizontal wellbore drilled through the reservoir. The hydraulic fractures are each in fluid communication with the drilled wellbore. A multi-channel tubing having a plurality of individual discrete channels therein extending along substantially a length thereof is placed in the horizontal wellbore, and at least one packer element situated along a length of said tubing is employed. The plurality of channels in the multi-channel tubing comprise, at a minimum, a fluid injection channel for transmitting a driving fluid to hydraulic fractures in the reservoir, and a separate hydrocarbon recovery channel for collecting hydrocarbons which drain into the reservoir and producing them to surface.

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: A drilling fluid and method for drilling in a coal containing formation with a mixed metal-viscosified drilling fluid including at least 0.05% calcium sulfate.

Abstract: A process for producing mineral oil from mineral oil deposits, in which the mineral oil yield is increased by blocking highly permeable regions of the mineral oil formation by separate injection of at least one acidic formulation which comprises water-soluble Al(III) salts, and one urea- or urea derivative-comprising formulation into the deposit, said formulations not mixing with one another until within the deposit, and the mixture forming highly viscous gels under the influence of the deposit temperature. The process can be used especially in the final stage of deposit development, when watering out in production increases, and particularly after the steam flooding of the deposits.

Abstract: Embodiments including methods comprising providing a treatment fluid comprising a first aqueous base fluid and a polymeric gelling agent, wherein the treatment fluid comprises a first surface tension; introducing a fluid mobility modifier into the treatment fluid, wherein the fluid mobility modifier comprises: a first surfactant selected from the group consisting of a non-ionic surfactant; a cationic surfactant; and any combination thereof, and a solvent-surfactant blend comprising a second aqueous base fluid, a second surfactant, a solvent, and a co-solvent, wherein the ratio of the first surfactant to the solvent-surfactant blend is in the range of between about 1:5 to about 5:1, wherein the fluid mobility modifier causes the treatment fluid to adopt a second surface tension that is less than the first surface tension; and introducing the treatment fluid into a subterranean formation.