A wellbore fluid comprising an aqueous base fluid and a plurality of nanoparticles suspended in the aqueous base fluid. The nanoparticles are present in the wellbore fluid in an amount effective to have an effect of increasing the density by at least 0.2 lb/gal.

A wellbore fluid comprising an aqueous base fluid and a plurality of nanoparticles suspended in the aqueous base fluid. The nanoparticles are present in the wellbore fluid in an amount effective to have an effect of increasing the density by at least 0.2 lb/gal.

An inexpensive electrically conductive carrier is added to well bore fluids thereby allowing for a closed loop real-time data communication system for topside management of all downhole equipment including drilling, completion, production, logging, and workover equipment. Conductive carrier fluid provides a “real-time” digital and analog bi-directional data and communication solution between the surface operations of a well-bore and downhole tools. Conductive carrier fluid provides for the application of more sophisticated software essential for exact control requirements of sophisticated downhole equipment, thereby achieving optimized tool performance as well as future downhole tools.

An inexpensive electrically conductive carrier is added to well bore fluids thereby allowing for a closed loop real-time data communication system for topside management of all downhole equipment including drilling, completion, production, logging, and workover equipment. Conductive carrier fluid provides a “real-time” digital and analog bi-directional data and communication solution between the surface operations of a well-bore and downhole tools. Conductive carrier fluid provides for the application of more sophisticated software essential for exact control requirements of sophisticated downhole equipment, thereby achieving optimized tool performance as well as future downhole tools.

Waste water is remanufactured with ozone in a series of mixing vessels. The ozone is dispersed to both a top and a bottom portion of each mixing vessel, but in different amounts. This creates an electrical potential difference across the height of each mixing vessel which significantly improves the oxidation of organic carbon-based impurities and eliminates H2S and bacteria. Sludge and solids floating to the top of each mixing vessels are removed, as well as sludge and solids settling to the bottom of the mixing vessels. When oil and gas well waste water is treated in this manner, the resulting treated water is purified and has a high salt content suitable for oil or gas well injection.

Waste water is remanufactured with ozone in a series of mixing vessels. The ozone is dispersed to both a top and a bottom portion of each mixing vessel, but in different amounts. This creates an electrical potential difference across the height of each mixing vessel which significantly improves the oxidation of organic carbon-based impurities and eliminates H2S and bacteria. Sludge and solids floating to the top of each mixing vessels are removed, as well as sludge and solids settling to the bottom of the mixing vessels. When oil and gas well waste water is treated in this manner, the resulting treated water is purified and has a high salt content suitable for oil or gas well injection.

Methods and treatments fluids for treating a wellbore. One example method introduces the treatment fluid into the wellbore. The treatment fluid comprises an aqueous fluid, an aminopolycarboxylic acid, a nanoparticle dispersed, and an organic solvent. The treatment fluid has a pH in a range between about 5 to about 9. The method further includes contacting a rock surface in the subterranean formation; wherein at least a portion of the rock surface is coated with a hydrocarbon. The treatment fluid removes a portion of the hydrocarbon from the rock surface and alters the rock surface to be water-wet.

Methods and treatments fluids for treating a wellbore. One example method introduces the treatment fluid into the wellbore. The treatment fluid comprises an aqueous fluid, an aminopolycarboxylic acid, a nanoparticle dispersed, and an organic solvent. The treatment fluid has a pH in a range between about 5 to about 9. The method further includes contacting a rock surface in the subterranean formation; wherein at least a portion of the rock surface is coated with a hydrocarbon. The treatment fluid removes a portion of the hydrocarbon from the rock surface and alters the rock surface to be water-wet.

Compositions and methods for using those compositions to at least partially stabilize subterranean formations are provided. In one embodiment, the methods include providing a treatment fluid including an aqueous base fluid and an additive including a low molecular mass organic gelator; introducing the treatment fluid into at least a portion of a subterranean formation to contact at least a portion of the subterranean formation that includes shale; and allowing the additive to interact with the shale to at least partially stabilize the shale.

Compositions and methods for using those compositions to at least partially stabilize subterranean formations are provided. In one embodiment, the methods include providing a treatment fluid including an aqueous base fluid and an additive including a low molecular mass organic gelator; introducing the treatment fluid into at least a portion of a subterranean formation to contact at least a portion of the subterranean formation that includes shale; and allowing the additive to interact with the shale to at least partially stabilize the shale.