Included are methods and systems for enhancing recovery of a hydrocarbon fluid. An example method includes selecting a liquefied natural gas capable of being processed into a modified liquefied natural gas having a desired composition and adjusting the composition of the liquefied natural gas to provide the modified liquefied natural gas with the desired composition. The method further includes preparing a treatment fluid from the modified liquefied natural gas, introducing the treatment fluid into a wellbore, and contacting the hydrocarbon fluid with the treatment fluid in the wellbore.

A method for stimulating production of hydrocarbons from a sandstone formation includes the steps of injecting a stimulation fluid into the sandstone formation, the stimulation fluid formed from a hydrofluoric acid precursor and an oxidizer; injecting an ammonium containing compound into the sandstone formation; and injecting a nitrite containing compound into the sandstone formation. The method further includes maintaining the stimulation fluid, the ammonium containing compound, and the nitrite containing compound in the sandstone formation to initiate reaction of the ammonium containing compound and the nitrite containing compound to generate heat and nitrogen gas, where upon generation of heat within the formation the hydrofluoric acid precursor and the oxidizer react to form hydrofluoric acid in-situ to dissolve silica and silicate minerals and stimulate the sandstone formation. A treatment fluid for use in stimulating sandstone formations includes the stimulation fluid, the ammonium containing compound, and the nitrite containing compound.

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 monitoring system operable to monitor an oilfield additive system having multiple components. The oilfield additive system is operable to transfer an additive-containing substance for injection into a wellbore. The monitoring system includes sensors each associated with, and operable to generate information related to an operational parameter of, a corresponding one of the oilfield additive system components. The monitoring system also includes a monitoring device in communication with the sensors and operable to record the information generated by the sensors to generate a database. The database includes information indicative of maintenance aspects of the oilfield additive system and/or the oilfield additive system components.

Systems and methods of optimizing stimulation fluids in the form of a hydrocarbon foam, an emulsion based foam, an emulsion, and a gelled stimulation fluid, each comprising Y-Grade NGL, which is an unfractionated hydrocarbon mixture that comprises ethane, propane, butane, isobutane, and pentane plus, wherein the unfractionated hydrocarbon mixture is a byproduct of a condensed and demethanized hydrocarbon stream.

A method of treating a wellbore in a subterranean formation includes attaching a surface located inert gas generator to an annular space in a wellbore that comprises a tubular element. A heated inert gas is generated using the inert gas generator, wherein the inert gas comprises CO2 and nitrogen. The heated inert gas is placed from the inert gas generator into the annular space. The heated inert gas is circulated from the surface, down the annulus, and returns up through the tubular element back to the surface for a period of time. At least one well treatment chemical is combined with the heated inert gas to form a matrix injection gas, wherein the chemical is at least one of suspended in the heated inert gas as droplets, in a vapor state of the chemical, and combinations thereof. The matrix injection gas is delivered to the formation.

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.

In a well related to the production of hydrocarbons, an injection apparatus including: a base pipe including a radial port; an in-flow control device including a flow restriction device and a housing, with the housing being external and concentric of the base pipe. The housing includes a closed end portion and an open, opposite end portion and a housing channel communicating the opposite end portion. The flow restriction device is disposed at an intermediate location along the housing channel and adapted to control a rate of flow along the housing channel. A fluid transmissive screen is concentric of the base pipe and extends from the open, opposite end portion of the housing. A check valve assembly is interposed between the opposite end portion of the housing and a screened space.

In a well related to the production of hydrocarbons, an injection apparatus including: a base pipe including a radial port; an in-flow control device including a flow restriction device and a housing, with the housing being external and concentric of the base pipe. The housing includes a closed end portion and an open, opposite end portion and a housing channel communicating the opposite end portion. The flow restriction device is disposed at an intermediate location along the housing channel and adapted to control a rate of flow along the housing channel. A fluid transmissive screen is concentric of the base pipe and extends from the open, opposite end portion of the housing. A check valve assembly is interposed between the opposite end portion of the housing and a screened space.

An injection sleeve and apparatus for injecting fluid into a well includes a flow tube having a piston which upon fluid flow opens one or more outlet ports. The injection sleeve is adapted to include a variable orifice insert which prevents flow through the tool at a first selected pressure level until the outlet ports are in an open position, thereby protecting packing seals on either side of the outlet ports from undue wear and tear, and prolonging the life of the tool. At a second pressure level, the variable orifice insert permits flow through injection sleeve to the formation injection zones. A plurality of the sleeves may be used for sequentially injecting fluid into a plurality of injection formation zones surrounding a well. When injection fluid flow is terminated, the injection sleeves act as a dual barrier valve for preventing flow from the injection formation zones back to the well head.