A coated system for containing or conveying a hydrogen-containing fluid including a hydrogen susceptible metallic substrate and a coating on the hydrogen susceptible metallic substrate. The hydrogen-containing fluid is in contact with the coating and the coating reduces or eliminates the effect of hydrogen on the hydrogen susceptible metallic substrate. A coating process for coating a hydrogen susceptible metallic substrate is also disclosed.

Described herein is a process for producing insulated pipes including providing a media pipe and a film hose continuously formed from a film or a media pipe and a jacketing pipe, wherein the media pipe is arranged inside the film hose or the jacketing pipe and a slot is formed between the media pipe and the film hose or jacketing pipe, wherein an adhesion promoter is applied to the surface of the media pipe facing the film hose or the jacketing pipe, introducing a polyurethane system at least including an isocyanate component (a) including at least one isocyanate, a polyol component (b), and at least one catalyst into the slot before the adhesion promoter is fully cured, and foaming and curing the polyurethane system. Also described herein are insulated pipes obtainable or obtained by such a process.

Coating compositions for coating an oilfield operational component, and related methods, may include in some aspects a coating composition having a trifunctional silane, a silanol, and a filler. The coating composition may be applied to a surface of the oilfield operational component that is configured to be exposed to a fluid. The coating composition may be applied to at least partially cover or coat the surface. The coating composition may be configured to chemically bond with a cured primer composition that includes an epoxy.

A pipe lining having at least two material layers, a first elastomeric layer spray applied directly to the inside of a pipe which acts as a hydrophobic, ductile membrane, and a second rigid layer is spray applied to the first layer prior to complete curing of the first layer. One or more additional layers may be applied to the second layer to provide additional abrasion, erosion or chemical resistance to the second layer. An intermediate reinforcing layer may be disposed between the first and second layers. The first layer cures into a closed cell elastomeric foam, such that stress and other forces are not passed from the pipe to the rigid second layer.

Minimum Federal Safety Standards for corrosion control on buried oil & gas pipelines stipulate that metallic pipes should be properly coated and have impressed-current cathodic protection (ICCP) systems in place to control the electrical potential field around a protected pipe. In certain examples described herein, electrically-conductive composites can be used and provide intrinsically-safe materials without the dielectric shielding issues of existing materials used with pipelines. As reacted by customary spray applications, the nanocomposite foams described herein are directly compatible with ICCP functionality wherever foam contacts the metallic pipe. Various compositions and their use with underground and/or above ground pipelines are described.

Induction heating facilitated coating systems and processes for pipes overcome corrosion and erosion of the pipes at extreme temperatures and pressures in applications including oil and gas downhole tubulars and pipelines as well as processing facilities. Being based on vitreous fused inorganic compounds, the present invention achieves very high corrosion resistance at remarkably modest cost. Attractive economics and immunity to chlorides and moisture permeation at extreme concentrations and temperatures also make it well suited to desalination plants and potable water piping applications. Due to its extreme temperature resistance, it also is very well suited for geothermal wells. Additionally, due to its characteristic smooth durable surface, the present invention is ideally suited for applications involving the opposite of corrosion, namely scaling problems, such as fouling in sewage systems and scale buildup in heavy oil wells.

An apparatus includes an intake assembly, the intake assembly including a connector, the connector configured for coupling to a pressurized liquid source. The apparatus also includes a chemical storage assembly. The chemical storage assembly is coupled to at least one outlet of the intake assembly. The chemical storage assembly is configured for at least one of (a) storing a chemical or (b) mixing a chemical with a liquid from the pressurized liquid source. The apparatus further includes an outlet assembly. The outlet assembly includes a first outlet configured for expelling pressurized liquid from the pressurized liquid source in a first direction. The outlet assembly also includes a second outlet or a nozzle for expelling the chemical, the chemical mixed with the liquid, a chemical agent, or a foam mixture in a second direction.

A method of automated pipeline chemical batch treatment includes receiving treatment information at a control system of a pipeline. If the treatment information includes an instruction to activate a pump system, the method includes transmitting an activation signal from the control system to the pump system in accordance with the treatment information. The activation signal causes the pump system to pump one or more chemicals from a chemical feed system into the pipeline. If the treatment information includes an instruction to deactivate the pump system, the method includes transmitting a deactivation signal from the control system to the pump system in accordance with the treatment information, wherein the deactivation signal causes the pump system to stop pumping one or more chemicals from the chemical feed system into the pipeline.

A method of lining a pipe with a lining mixture formed from a dry component and a liquid is discussed. The method includes placing the dry component in a dry component surface container located above ground, conveying the dry component from the dry component surface container to a dry component subterranean supply container located underground, conveying the dry component from the dry component subterranean supply container to a mixer located underground, mixing the dry component with the liquid to form the lining mixture, and applying the lining mixture to the pipe with a mixture applicator.

A method for depositing an electrically conductive metal onto at least one portion of the inner surface (3) of an internal cavity (2) of a waveguide (1) includes: preparing a suspension containing at least one liquid and at least one precursor of the electrically conductive metal in suspension in said at least one liquid; coating at least one portion of the inner surface (3) of the internal cavity (2) of the waveguide (1) with the suspension, and heat-treating at least said portion of the inner surface (3) of the internal cavity (2) of the waveguide (1) coated with the suspension. A method for manufacturing a metallized waveguide can implement this deposition method.