A method includes receiving a water stream from a hydrocarbon production facility, the water stream having a first concentration of a kinetic hydrate inhibitor (KHI); flowing the water stream through a heat exchanger to heat the water stream to a target temperature; mixing the heated water stream with a treatment chemical to form a two-phase mixture, the treatment chemical having an affinity for the KHI; flowing the two-phase mixture into a separator; and physically separating the two-phase mixture into a first phase and a second phase, the first phase including water and having a second concentration of the KHI less than the first concentration, and the second phase including the KHI and the treatment chemical, the density of the second phase being less than the density of the first phase.

A method includes receiving a water stream from a hydrocarbon production facility, the water stream having a first concentration of a kinetic hydrate inhibitor (KHI); flowing the water stream through a heat exchanger to heat the water stream to a target temperature; mixing the heated water stream with a treatment chemical to form a two-phase mixture, the treatment chemical having an affinity for the KHI; flowing the two-phase mixture into a separator; and physically separating the two-phase mixture into a first phase and a second phase, the first phase including water and having a second concentration of the KHI less than the first concentration, and the second phase including the KHI and the treatment chemical, the density of the second phase being less than the density of the first phase.

A method includes receiving a water stream from a hydrocarbon production facility, the water stream having a first concentration of a kinetic hydrate inhibitor (KHI); flowing the water stream through a heat exchanger to heat the water stream to a target temperature; mixing the heated water stream with a treatment chemical to form a two-phase mixture, the treatment chemical having an affinity for the KHI; flowing the two-phase mixture into a separator; and physically separating the two-phase mixture into a first phase and a second phase, the first phase including water and having a second concentration of the KHI less than the first concentration, and the second phase including the KHI and the treatment chemical, the density of the second phase being less than the density of the first phase.

Supercritical upgrading reactors and reactor systems are provided for upgrading a petroleum-based composition using one or more purging fluid inlets to prevent plugging of the catalyst layer in the reactor. Processes for upgrading petroleum-based compositions by utilizing a reactor having at least one purging fluid inlet are also provided.

Supercritical upgrading reactors and reactor systems are provided for upgrading a petroleum-based composition using one or more purging fluid inlets to prevent plugging of the catalyst layer in the reactor. Processes for upgrading petroleum-based compositions by utilizing a reactor having at least one purging fluid inlet are also provided.

Fouling and/or asphaltene agglomeration (or flocculation) in midstream processes and transportation and in upstream transportation of a hydrocarbon oil is reduced by providing in the oil an additive combination including; (A) a polyalkenyl-substituted carboxylic acid or anhydride, and (B) a metal detergent system comprising a hydrocarbyl-substituted hydroxybenzoate metal salt or a hydrocarbyl-substituted sulfonate metal salt or a mixure of both salts or a complex thereof,
where the mass:mass ratio of (A) to (B) is in the range of 20:1 to 1:20 and the treat rate of the additive is in the range of 5 to 10000 ppm by mass.

Fouling and/or asphaltene agglomeration (or flocculation) in midstream processes and transportation and in upstream transportation of a hydrocarbon oil is reduced by providing in the oil an additive combination including; (A) a polyalkenyl-substituted carboxylic acid or anhydride, and (B) a metal detergent system comprising a hydrocarbyl-substituted hydroxybenzoate metal salt or a hydrocarbyl-substituted sulfonate metal salt or a mixure of both salts or a complex thereof,
where the mass:mass ratio of (A) to (B) is in the range of 20:1 to 1:20 and the treat rate of the additive is in the range of 5 to 10000 ppm by mass.

A method for reducing fouling in an aqueous system of an olefin production plant is disclosed. The method includes adding an effective amount of a surfmer to the aqueous system, wherein the surfmer forms a water soluble adduct by covalently bonding to one or more fouling precursor compounds formed during olefin production.

A method for reducing fouling in an aqueous system of an olefin production plant is disclosed. The method includes adding an effective amount of a surfmer to the aqueous system, wherein the surfmer forms a water soluble adduct by covalently bonding to one or more fouling precursor compounds formed during olefin production.

A method for installing a device into a crude oil service operation, the method may include installing the device into a section of the crude oil service operation, wherein the device comprises a surface comprising a Self-Assembled Monolayer of Phosphonate (SAMP) coating, and may also include contacting the surface with the contaminant, wherein the contaminant is selected from the group consisting of paraffins and asphaltenes. Various systems include one having a liquid environment of paraffins and asphaltene, and a surface residing within the environment comprising a Self-Assembled Monolayer of Phosphonate (SAMP) composition. Systems also include pipelines and vessels having an internal surface therein comprising a Self-Assembled Monolayer of Phosphonate (SAMP) composition, and with hydrocarbon liquids present in the pipeline or vessel.