Methods of treating a subterranean formation penetrated by a well bore, by providing a treatment fluid comprising non-homogeneous particulates including a degradable material and a hydrolysis catalyst; by introducing the treatment fluid into the well bore; and by creating a plug with the treatment fluid.

A method including introducing a treatment fluid into a subterranean formation having a downhole temperature in the range of between about 60° C. to about 95° C. The treatment fluid comprises an aqueous fluid, a swelling agent, and an oxidizing agent. Forming a diverter plug at a first permeable zone in the subterranean formation with the swelling agent, and breaking at least a portion of the swelling agent with the oxidizing agent.

A method for the fracking or stimulation of a hydrocarbon-bearing formation, said method comprising the steps of: providing a wellbore in need of stimulation; inserting a plug in the wellbore at a predetermined location; inserting a perforating tool and a spearhead or breakdown acid into the wellbore; positioning the tool at said predetermined location; perforating the wellbore with the tool thereby creating a perforated area; allowing the spearhead acid to come into contact with the perforated area for a predetermined period of time sufficient to prepare the formation for fracking or stimulation; removing the tool from the wellbore; and initiating the fracking of the perforated area using a fracking fluid. Also disclosed is a corrosion inhibiting composition for use with the acid composition.

This disclosure relates to a foamable resin composition containing a nitrogen gas-generating compound and methods of using the composition for loss circulation control.

Provided are aqueous resin solutions having unique rheologies and products incorporating the same. The water-based materials provided herein are thermo-thickening, and the materials increase dramatically in viscosity (at least 100 times) in a desired temperature range increase (20 C to <100 C) at ambient pressure. Suitable resins comprising a hydrophobic group and a hydrophilic group may be selected from an epoxy resin, a phenol-formaldehyde resin, a polyurethane resin, an acrylic resin, a polyester resin, an acrylic-urethane resin, a melamine resin, a melamine-formaldehyde resin, an amino resin, and combinations thereof. A specific epoxy functional resin/polymer suitable for the resin solutions are prepared by reacting (A) an epoxy pre-polymer of (1) one or more polyols and (2) one or more epoxy functional materials with (B) a di- or polyamine, thereby forming the aqueous thermo-thickening resin solution. The resin solutions are substantially free of cross-linking agents.

A wellbore fluid comprising a first aqueous base fluid and a plurality of silica nanoparticles suspended in the first aqueous base fluid. The nanoparticles are present in the fluid in an amount to have an effect of decreasing a crystallization temperature by at least 4 to 55° F. as compared to a second aqueous base fluid without the silica nanoparticles.

A vulcanized rubber and date tree based lost circulation material (LCM) is provided. The vulcanized rubber and date tree based LCM includes vulcanized rubber particles, date tree seed particles produced from date tree seeds, and date tree fibers produced from date tree waste. The LCM may include vulcanized rubber particles in the range of 20 pounds-per-barrel (ppb) to 40 ppb in the drilling fluid, date tree seed particles in the range of 50 ppb to 70 ppb in the drilling fluid, and date tree fibers in the range of 10 ppb to 40 ppb in a drilling fluid, including a first size of fibers in the range of 5 ppb to 20 ppb, and a second size of fibers in the range of 5 ppb to 20 ppb. Methods of lost circulation control and manufacture of the vulcanized rubber and date tree based LCM are also provided.

The present invention relates to a method of providing a barrier in a fracture-containing system, comprising: i) Providing a treatment fluid comprising: a) a base fluid; b) an elastomeric material, wherein said elastomeric material comprises at least one polymer capable of crosslinking into an elastomer, and c) at least one crosslinking agent; ii) Placing the treatment fluid in a fracture-containing system; iii) Allowing the elastomeric material to crosslink with itself to form a barrier in said fracture-containing system; wherein the elastomeric material and/or the crosslinking agent are of neutral buoyancy with regard to the base fluid. The invention is contemplated to having utility not only in the oil-drilling industry but also in the plugging of fractures in sewer drains, pipelines etc.

A method for the fracking or stimulation of a hydrocarbon-bearing formation, said method comprising the steps of: providing a wellbore in need of stimulation; inserting a plug in the wellbore at a predetermined location; inserting a perforating tool and a spearhead or breakdown acid into the wellbore; positioning the tool at said predetermined location; perforating the wellbore with the tool thereby creating a perforated area; allowing the spearhead acid to come into contact with the perforated area for a predetermined period of time sufficient to prepare the formation for fracking or stimulation; removing the tool form the wellbore; and initiating the fracking of the perforated area using a fracking fluid.

Also disclosed is a corrosion inhibiting composition for us with the acid composition.

Methods and compositions for using geopolymers to create storable cementitious slurries used for oil and gas well cementing are provided. The methods of the present disclosure include providing a set-delayed geopolymer cement composition including a geopolymer; activating the set-delayed geopolymer cement composition; introducing the set-delayed geopolymer cement composition into at least a portion of a subterranean formation; and allowing the set-delayed geopolymer cement composition to set in the subterranean formation.