An anti-coking equipment, a preparation method therefor, and the use thereof. The preparation method comprises: bringing a low-oxygen partial pressure gas into contact with an equipment for reaction to obtain an anti-coking equipment containing an oxide film on the inner surface, wherein the dew point of the low-oxygen partial pressure gas is -40° C. to 40° C.

A dense and stable oxide film is formed on the inner surface of the equipment prepared by the method, which can inhibit or slow down the catalytic coking phenomenon, reduce the degree of equipment carburization, and prolong the service life of the equipment.

A halides removal washing system for absorbing halides from a process gas within a process gas duct comprising a wash water injection nozzle and anti-precipitation means arranged around the nozzle, injection pipe and within the process gas duct.

Methods for operating a hydroprocessing reactor and preventing corrosion in a hydroprocessing unit are provided. The hydroprocessing reactor includes surfaces exposed to corrosive compounds. In one aspect, a graphene-based coating is applied to the surfaces of the reactor. A feed comprising crude oil or its fractions and hydrogen is introduced into the reactor, and the operating temperature of the reactor is increased to 36° C.-600° C. The reactor is operated at a pressure of 10 bar-250 bar. The feed is then hydroprocessed in the reactor and the coating defines a barrier on the surfaces of the reactor to prevent corrosion. In another aspect, after application of the coating, the coated surface is tested to determine whether the coating covers the entire surface. Additional coating is then applied to one or more areas of the surface that were determined not to be covered by the initial coating.

Methods for operating a hydroprocessing reactor and preventing corrosion in a hydroprocessing unit are provided. The hydroprocessing reactor includes surfaces exposed to corrosive compounds. In one aspect, a graphene-based coating is applied to the surfaces of the reactor. A feed comprising crude oil or its fractions and hydrogen is introduced into the reactor, and the operating temperature of the reactor is increased to 36° C.-600° C. The reactor is operated at a pressure of 10 bar-250 bar. The feed is then hydroprocessed in the reactor and the coating defines a barrier on the surfaces of the reactor to prevent corrosion. In another aspect, after application of the coating, the coated surface is tested to determine whether the coating covers the entire surface. Additional coating is then applied to one or more areas of the surface that were determined not to be covered by the initial coating.

The present disclosure provides compositions and methods for use with hydrogen gas. A method may include adding hydrogen gas to a medium and adding a production chemical to the medium. As examples, the production chemical may be a corrosion inhibitor, an anti-foulant, a hydrate anti-agglomerate, a kinetic hydrate inhibitor, an amine for gas sweetening, a regenerable H.sub.2S scavenger, a non-regenerable H.sub.2S scavenger, an alcohol for gas dehydration, an alcohol for hydrate control, a thermodynamic hydrate inhibitor, or any combination thereof. The present disclosure also provides test methods to determine the susceptibility of a production chemical to reaction with hydrogen gas.

A system and method for preparing and conditioning a heavy oil feedstock for hydroprocessing in a hydroprocessing system includes forming metal sulfide catalyst particles in situ within the heavy oil feedstock. The metal sulfide catalyst particles are formed in situ by (1) premixing a catalyst precursor with a hydrocarbon diluent to form a diluted precursor mixture, (2) mixing the diluted precursor mixture with the heavy oil feedstock to form a conditioned feedstock, and (3) heating the conditioned feedstock to decompose the catalyst precursor and cause or allow metal from the precursor to react with sulfur in the heavy oil feedstock to form metal sulfide catalyst particles in situ in the heavy oil feedstock. The in situ formed metal sulfide catalyst particles catalyze beneficial upgrading reactions between the heavy oil feedstock and hydrogen and eliminates or reduces formation of coke precursors and sediment.

Embodiments of processes for upgrading a petroleum-based composition while decreasing plugging comprise mixing a supercritical water stream with a pressurized, heated petroleum-based composition in a mixing device to create a combined feed stream, and introducing to a supercritical upgrading reactor system are provided. The processes also comprise cooling the upgraded product in a cooling device, and decreasing the pressure of the cooled upgraded product in a pressure reducer. To reduce plugging, the processes also comprises injecting plug remover solution into one or more of the following injection locations: an injection port on a process line connecting the mixing device with the upgrading reactor system; an injection port on a process line connecting the upgrading reactor system with the cooling device; or an injection port on a process line connecting the cooling device with the pressure reducer.

The present disclosure generally relates to methods for reducing fouling in tar upgrading processes and to apparatus for carrying out such processes. In some embodiments, a method is provided that includes providing a first tar stream, combining the first tar stream with a utility fluid to form a first process stream having a viscosity lower than that of the first tar stream, and heating the first process stream in a pre-heater under liquid phase conditions without feeding molecular hydrogen gas into the pre-heater to form a second process stream exiting the pre-heater.

A hydrocracking system is upgraded by modifying an existing ebullated bed initially utilizing a supported ebullated bed catalyst to thereafter utilize a dual catalyst system that includes metal sulfide catalyst particles and supported ebullated bed catalyst. The upgraded hydrocracking system achieves at least one of: (1) hydroprocess lower quality heavy oil; (2) increase conversion of higher boiling hydrocarbons that boil at 524 C. (975 F.) or higher; (3) reduce the concentration of supported ebullated bed catalyst required to operate an ebullated bed reactor at a given conversion level; and/or (4) proportionally convert the asphaltene fraction in heavy oil at the same conversion level as the heavy oil as a whole. The metal sulfide catalyst may include colloidal or molecular catalyst particles less than 1 micron in size and formed in situ within the heavy oil using a catalyst precursor well-mixed within the heavy oil and decomposed to form catalyst particles.

Embodiments of processes for upgrading a petroleum-based composition while decreasing plugging comprise mixing a supercritical water stream with a pressurized, heated petroleum-based composition in a mixing device to create a combined feed stream, and introducing to a supercritical upgrading reactor system are provided. The processes also comprise cooling the upgraded product in a cooling device, and decreasing the pressure of the cooled upgraded product in a pressure reducer. To reduce plugging, the processes also comprises injecting plug remover solution into one or more of the following injection locations: an injection port on a process line connecting the mixing device with the upgrading reactor system; an injection port on a process line connecting the upgrading reactor system with the cooling device; or an injection port on a process line connecting the cooling device with the pressure reducer.