Disclosed are compositions and methods for the pressure protection of existing wells during infill drilling operations. The methods can include injecting a foamed pressure protection composition into the existing wellbore in fluid communication with an unconventional subterranean formation prior to and/or during fracturing of the new wellbore in fluid communication with the unconventional subterranean formation.

Disclosed are compositions and methods for the pressure protection of existing wells during infill drilling operations. The methods can include injecting an aqueous pressure protection composition into an unconventional subterranean formation via an existing wellbore in fluid communication with a rock matrix of the unconventional subterranean formation prior to and/or during injection of a fracturing fluid into the unconventional subterranean formation via a new wellbore in fluid communication with the rock matrix of the unconventional subterranean formation; and producing a hydrocarbon from the existing wellbore during and/or after the injection of the fracturing fluid into the unconventional subterranean formation via the new wellbore.

Systems, methods, and compositions that provide an energized natural gas (ENG) fracturing fluid including a complexing agent. A fracturing fluid may include: methane; water; a complexing agent; a surfactant; and wherein the fracturing fluid is an emulsion, the water is in a continuous phase of the emulsion, and methane is in a discrete phase of the emulsion.

Systems and methods for predicting and optimizing the effects of acidizing treatment of carbonate rock are disclosed. The disclosed methods predict the conflicting effects of increased production (i.e., wormhole creation) and reduced rock compressive strength due to acid rock reactions. The mechanical stability of stimulated wellbores, such as horizontal wellbores, can be determined under different acidizing conditions, such as acid type and volume. The acidizing conditions can be optimized to maximize short and long-term production.

Method for enabling the optimized production of hydrocarbons from shale oil reservoirs via cyclic injection to reservoir pressures that exceed the formation fracture pressure to achieve an improved and optimal recovery of oil. The method determines and optimizes the composition of injected fluids to be injected, the rate, pressure and duration of injection, the production rate and pressure of produced fluids; determines and utilizes the optimum number of injection and production cycles; and the amount of soaking time; and determines the equipment design and operating characteristics to provide for the optimized injection of injection fluids, and the separation of produced fluids for both reinjection and delivery to sales or storage.

A pump system includes a centrifugal pump having an impeller, a first inlet arranged to receive a first flow of liquid, a second inlet arranged to receive a flow of gas at a first pressure, the gas being soluble in the liquid, and an outlet arranged to discharge a second flow of liquid that contains the flow of gas solubilized therein. An injection pump has an inlet arranged to receive the second flow of liquid. The injection pump is operable to increase the pressure of the second flow of liquid to produce a high-pressure flow of liquid, and includes a discharge arranged to discharge the high-pressure flow of liquid.

To improve or optimize a wellbore treatment operation, a target net treating pressure may be determined and the constant net treating pressure maintained to effectively enhance formation breakdown and fracture complexity as well as provide a reduction in wear and tear of equipment and completion time. The target net treating pressure may be based on one or more treatment parameters and these parameters may be adjusted during the wellbore treatment operation to maintain a constant net treating pressure at or about the target net treating pressure. The injection rate or pressure of a treatment fluid may be adjusted to maintain the constant net treating pressure. Measurements associated with the wellbore treatment operation may be compared to an operational constraint and adjustments to the wellbore treatment operation may be made based on the comparison. The wellbore treatment operation may be terminated based on a parameter falling below or exceeding a threshold.

A fluid control device includes a housing, a fluid channel defined within the housing, the fluid channel having an inlet, and a flow control body disposed in the fluid channel, the flow control body tapering towards the inlet. The flow control body, in use, causes a fluid flowing through the fluid channel to flow into an annular fluid flow path within the fluid channel. The annular fluid flow path has a geometry selected based on a subcool of the fluid at a pressure of the fluid entering the fluid channel, and the geometry is selected to induce cavitation of the fluid to choke fluid flow through the fluid channel.

A method and system of treating a formation and a well extending therethrough, including storing liquefied natural gas (LNG) at an on-site location of the well, injecting a first stream of LNG into the formation through the well to contact at least one of a surface of the formation or a metal surface locatable in the well, injecting a chemical agent into the formation through the well to contact at least one of the surface of the formation or the metal surface locatable in the well, and treating at least one of the surface of the formation or the metal surface locatable in the well with the chemical agent and the first stream of LNG.

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.