Abstract: A method and system for pressurizing and stimulating a formation with a parent well therethrough, the method including storing and de-liquefying liquefied natural gas (LNG) at an on-site location near the parent well, injecting a first stream of de-liquefied LNG into the parent well to pressurize the formation, and injecting a second stream of de-liquefied LNG into the parent well at a fracturing pressure sufficient to fracture the pressurized formation.

Abstract: 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.

Abstract: Gas hydrates are formed in treatment fluid in situ within the wellbore. Foaming of the treatment fluid can occur both during the introduction of the gas treatment fluid to form hydrates and downhole near the subterranean reservoir where the heat of the reservoir will cause the gas hydrates to revert back to a gaseous state. The method involves preparing a treatment fluid comprising an aqueous base fluid, and a viscosifying agent at the surface. This treatment fluid is then introduced into the wellbore. Also, at the surface, a liquefied natural gas is pressurized and then vaporized to produce a vaporized natural gas. The vaporized natural gas is introduced into the wellbore so as to mix with the treatment fluid also being introduced. The introduction is such that gas hydrates are formed from the natural gas in the treatment fluid in situ within the wellbore.

Abstract: Methods including introducing a first treatment fluid comprising a first aqueous base fluid and a chelating etching agent into a low-permeability subterranean formation comprising carbonate material having a first fracture network at a first treatment interval therein, wherein the first fracture network comprises a first main fracture and a first microfracture. The method further comprises placing the chelating etching agent in the first fracture network and reacting it with the carbonate material in the first fracture network. In certain embodiments, the reacting removes the carbonate material, thereby creating at least one conductive channel on a face of the first fracture network. The method further comprises introducing a second treatment fluid comprising a second aqueous base fluid and micro-sized proppant particulates into the low-permeability subterranean formation and placing the micro-sized proppant particulates into the first fracture network to form a partial monolayer in the first microfracture.

Abstract: 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.

Abstract: Gas hydrates are formed in treatment fluid in situ within the wellbore. Foaming of the treatment fluid can occur both during the introduction of the gas treatment fluid to form hydrates and downhole near the subterranean reservoir where the heat of the reservoir will cause the gas hydrates to revert back to a gaseous state. The method involves preparing a treatment fluid comprising an aqueous base fluid, and a viscosifying agent at the surface. This treatment fluid is then introduced into the wellbore. Also, at the surface, a liquefied natural gas is pressurized and then vaporized to produce a vaporized natural gas. The vaporized natural gas is introduced into the wellbore so as to mix with the treatment fluid also being introduced. The introduction is such that gas hydrates are formed from the natural gas in the treatment fluid in situ within the wellbore.

Abstract: 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.

Abstract: A method and system for pressurizing and stimulating a formation with a parent well therethrough, the method including storing and de-liquefying liquefied natural gas (LNG) at an on-site location near the parent well, injecting a first stream of de-liquefied LNG into the parent well to pressurize the formation, and injecting a second stream of de-liquefied LNG into the parent well at a fracturing pressure sufficient to fracture the pressurized formation.

Abstract: A selective stimulation system includes coiled tubing in which a distributed sensor array is disposed. The distributed sensor array is to measure hydrocarbon production parameters along the distributed sensor array in a wellbore of a formation. A selective fracturing apparatus is coupled to the coiled tubing. The selective fracturing apparatus is to fracture selected areas of the wellbore. A controller is coupled to the distributed sensor array and controls operation of the selective fracturing apparatus based on the measured hydrocarbon production parameters.

Abstract: A method and a system for pressurizing a reservoir volume including fluid in a formation with a parent well extending through the formation includes storing liquefied natural gas (LNG) at an on-site location of the parent well, de-liquefying the LNG to form natural gas at the on-site location, and injecting the natural gas into the parent well to pressurize the reservoir volume through the parent well.

Abstract: A method of fracturing a formation penetrated by a wellbore, the method includes fracturing the formation by increasing an annulus pressure in the wellbore above a fracture initiation pressure. The method also includes decreasing the annulus pressure below a fracture closure pressure, and re-fracturing the formation by increasing the annulus pressure in the wellbore above the fracture initiation pressure.

Abstract: 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.

Abstract: A method and a system for pressurizing a reservoir volume including fluid in a formation with a parent well extending through the formation includes storing liquefied natural gas (LNG) at an on-site location of the parent well, de-liquefying the LNG to form natural gas at the on-site location, and injecting the natural gas into the parent well to pressurize the reservoir volume through the parent well.

Abstract: Methods comprising: introducing a micro-proppant treatment fluid into a formation at a rate and pressure sufficient to create or enhance at least one fracture in a first treatment interval, wherein the micro-proppant treatment fluid comprises a first aqueous base fluid, micro-proppant particulates, and a first aqueous-based surface modification agent (“ASMA”); placing the micro-proppant particulates into the at least one fracture; introducing a surface modification treatment fluid into the subterranean formation, wherein the surface modification treatment fluid comprises a second aqueous base fluid and a second ASMA; coating at least a portion of a face of the at least one fracture with the second ASMA; introducing a macro-proppant treatment fluid into the subterranean formation, wherein the macro-proppant treatment fluid comprises a third base fluid and macro-proppant particulates; and placing the macro-proppant particulates into the at least one fracture.

Abstract: Compositions and methods for forming and using clusters of micron- and/or nano-sized solid materials (e.g., particulates, fibers, etc.) as proppants in subterranean operations are provided. In one embodiment, the methods comprise: providing a fracturing fluid comprising a base fluid, a plurality of small-sized solid materials and one or more surface modifying agents; forming a plurality of proppant clusters, each proppant cluster comprising two or more of the small-sized solid materials bound together with a portion of the one or more surface modifying agents; and introducing the fracturing fluid into a well bore penetrating at least a portion of a subterranean formation at or above a pressure sufficient to create or enhance one or more fractures in the portion of the subterranean formation.

Abstract: A method of fracturing a formation penetrated by a wellbore, the method includes fracturing the formation by increasing an annulus pressure in the wellbore above a fracture initiation pressure. The method also includes decreasing the annulus pressure below a fracture closure pressure, and re-fracturing the formation by increasing the annulus pressure in the wellbore above the fracture initiation pressure.

Abstract: A selective stimulation system includes coiled tubing in which a distributed sensor array is disposed. The distributed sensor array is to measure hydrocarbon production parameters along the distributed sensor array in a wellbore of a formation. A selective fracturing apparatus is coupled to the coiled tubing. The selective fracturing apparatus is to fracture selected areas of the wellbore. A controller is coupled to the distributed sensor array and controls operation of the selective fracturing apparatus based on the measured hydrocarbon production parameters.

Abstract: Enhanced methods for use in subterranean operations and, more particularly, for fracturing a subterranean formation are disclosed. In one embodiment, the method comprises: introducing into a wellbore penetrating a portion of a subterranean formation alternating intervals of a particulate-laden fluid comprising a plurality of particulates sized 100 U.S. mesh or smaller, and a treatment fluid comprising a lesser amount of particulates than the particulate-laden fluid; wherein the alternating intervals of the particulate-laden fluid and the treatment fluid are introduced into the wellbore at or above a pressure sufficient to create or enhance one or more fractures in the subterranean formation.

Abstract: Methods including introducing a first treatment fluid into a low-permeability subterranean formation comprising carbonate material having a first fracture network at a first treatment interval therein, wherein the first treatment fluid comprises a first aqueous base fluid and a chelating etching agent, and wherein the first fracture network comprises a first main fracture and a first microfracture; placing the chelating etching agent in the first fracture network; reacting the chelating etching agent with the carbonate material in the first fracture network, wherein the reacting removes the carbonate material, thereby creating at least one conductive channel on a face of the first fracture network; introducing a second treatment fluid into the low-permeability subterranean formation, the second treatment fluid comprising a second aqueous base fluid and micro-sized proppant particulates; and placing the micro-sized proppant particulates into the first fracture network to form a partial monolayer in the first m

Abstract: Determining characteristics of a formation. At least some of the illustrative embodiments are methods including determining at least one characteristics of a shale formation. The determining may include: collecting optically interacted electromagnetic radiation from a portion of the shale formation; directing a first portion of the optically interacted electromagnetic radiation from the formation to a first multivariate optical element (MOE), the first MOE creates first modified electromagnetic radiation; applying the first modified electromagnetic radiation to a first detector, the first detector creates a first signal; and determining a first characteristic of the shale formation from the first signal.