A method and hydraulic fracturing fluid that is a viscoelastic surfactant (VES) fracturing fluid having a surfactant and an inorganic oxidizer salt for hydraulic fracturing of a geological formation. The VES fracturing fluid is provided through a wellbore into the geological formation to hydraulically fracture the geological formation to form hydraulic fractures in the geological formation. The method includes oxidizing organic material in the hydraulic fractures with the VES fracturing fluid.

A method of stimulating petroleum production includes introducing a fracturing fluid into a petroleum bearing carbonate formation, thereby creating at least one fracture to stimulate the petroleum production. The fracturing fluid is introduced into the petroleum bearing carbonate formation at a pressure above the breakdown pressure of the formation. The fracturing fluid includes a plurality of proppants where from 1 to 50 wt. % of the plurality of proppants includes micro proppants having a particle size ranging from 0.5 to 150 μm, and from 50 to 99 wt. % of the plurality of proppants includes macro proppants having a particle size greater than 100 mesh.

A method of repairing a well is provided. The method includes injecting a brine solution into the well, injecting carbon dioxide into the well, and reacting the brine solution in the reservoir rock with the carbon dioxide to form calcite such that calcite precipitates into the desired flow path between a cold well and a hot well to effectively repair short circuits within the EGS reservoir.

A system for utilizing oolitic aragonite as a proppant in hydraulic fracking is provided. The system includes a proppant storage tank including a stockpile of the oolitic aragonite. The system further includes a proppant pumping unit operable to pump the oolitic aragonite from the proppant storage tank, through an underground shaft, and into an underground fracture proximate to the underground shaft.

A system for fracturing a subterranean formation that includes a supply of a slurry including at least 5% by weight of particles; a pump coupled to the supply of the slurry; a conduit coupled to the pump and extending into the subterranean formation; and a controller operably coupled to the pump for controlling the operation of the pump. The particles have an average equivalent particle diameter of less than 50 microns.

A system and method for generating base water and precipitate, including combining produced water with seawater to precipitate barium sulfate from barium in the produced water and from sulfate in the seawater, and separating the precipitate to give the base water and the precipitate. The base water may have less than a specified amount of sulfate and be utilized for hydraulic fracturing fluid. The precipitate may give a weighting agent for drilling.

Release of hydrochloric acid, hydrofluoric acid and fluoroboric acid into a well may be controlled by introducing into the well an aqueous fluid containing ammonium chloride, ammonium bifluoride, ammonium fluoroborate, ammonium tetrafluoroborate or a mixture thereof and a breaker. After being introduced into the well, the ammonium salt reacts with the breaker and the acid is released into the well.

Compositions and methods for use in fracturing treatments using friction reducing additives that include nanoparticles are provided. In some embodiments, the methods include: providing a treatment fluid that includes an aqueous base fluid and a friction reducing additive, the friction reducing additive including at least one polymer and a plurality of nanoparticles; and introducing the treatment fluid into a portion of a subterranean formation at or above a pressure sufficient to create or enhance at least one fracture in the subterranean formation.

This document relates to energetic salts that contain an organic cation and an oxidizing anion and methods of using the energetic salt compositions, including methods of hydraulic fracturing, pressure pulse fracturing, formation damage removal, and lowering the viscosity of heavy oil.

Well treatment operation comprises introducing nanosized particulates into a formation. The nanosized particulates are synthesized by combining PMIDA, a calcium source, a pH adjusting agent, and an aqueous medium. This combination results in a degradable (i.e., dissolvable) solid that can be used in heterogeneous formations like shale type rock reservoirs, as well as sedimentary rock formations like clastic, siliclastic, sandstone, limestone, calcite, dolomite, and chalk formations, and formations where there is large fluid leak-off due to stimulation treatments. The disclosed particulates may also be used for acidizing treatments in mature fields and deep water formations commonly characterized by high permeability matrices. The solubility of the particulates advantageously allows the material to act as a temporary agent having a lifespan that is a function of temperature, water flux, and pH, making it adaptable to various reservoir conditions with minimal to no risk of adverse effects on the reservoir.