A control process and apparatus provide feed forward control of stoichiometric proportions of hydrogen sulfide and ammonia to a thermal oxidizer and an ammonia scrubber, respectively. To account for unmeasured or uncalculated sulfur feed to the thermal oxidizer, a feed back measurement of sulfur dioxide and ammonia concentration is used to correct the flow rate of hydrogen sulfide to the thermal oxidizer and/or ammonia to the ammonia scrubber.

A particle separation system for a catalytic chemical reactor.

A process for treating a plastics pyrolysis oil: a) selective hydrogenation of feedstock in the presence of hydrogen and at least one selective hydrogenation catalyst, at 100 to 150° C., a partial pressure of hydrogen of 1.0 to 10.0 MPa abs. and an hourly space velocity of 1.0 to 10.0 h.sup.−1, to obtain a hydrogenated effluent; b) hydrotreatment of hydrogenated effluent in the presence of hydrogen and at least one hydrotreatment catalyst, at 250 to 370° C., a partial pressure of hydrogen of 1.0 to 10.0 MPa abs. and an hourly space velocity of 1.0 to 10.0 h.sup.−1, to obtain a hydrotreatment effluent; c) separation of hydrotreatment effluent obtained from b) in the presence of an aqueous stream, at a temperature of 50 to 370° C., to obtain at least one gaseous effluent, an aqueous liquid effluent and a hydrocarbon liquid effluent.

A method of producing fuel that includes providing a feed comprising natural gas, a portion of which is renewable natural gas, to a steam methane reformer in a hydrogen production unit. The feed includes a first portion that is converted to syngas and a second portion that passes through the steam methane reformer unconverted. The unconverted feed is directed to one or more burners of the steam methane reformer as fuel. The renewable natural gas is apportioned such that the first portion of the feed, which is feedstock, has a larger renewable fraction than the second portion, which is fuel. Apportioning a higher renewable fraction to the portion of the feed that is converted increases the yield of renewable content.

The invention concerns a process for the treatment of a hydrocarbon feed, said process comprising the following steps: a) a hydrotreatment step, in which the hydrocarbon feed and hydrogen are brought into contact over a hydrotreatment catalyst, b) an optional step of separating the effluent obtained from the hydrotreatment step a), c) a step of hydrocracking at least a portion of the effluent obtained from step a) or at least a portion of the heavy fraction obtained from step b), d) a step of separating the effluent obtained from step c), e) a step of precipitating sediments, f) a step of physical separation of the sediments from the heavy liquid fraction obtained from step e), g) a step of recovering a liquid hydrocarbon fraction having a sediment content, measured using the ISO 10307-2 method, of 0.1% by weight or less.

The present invention relates to a process for producing olefins from a hydrocarbon feedstock 11 having a sulfur content of at least 0.1 weight %, an initial boiling point of at least 180° C. and a final boiling point of at least 600° C.

Processes herein may be used to thermally crack various hydrocarbon feeds, and may eliminate the refinery altogether while making the crude to chemicals process very flexible in terms of crude. In embodiments herein, crude is progressively separated into light and heavy fractions utilizing convection heat from heaters used in steam cracking. Depending on the quality of the light and heavy fractions, these are routed to one of three upgrading operations, including a fixed bed hydroconversion unit, a fluidized catalytic conversion unit, or a residue hydrocracking unit that may utilize either an ebullated bed reactor with extrudate catalysts or a slurry hydrocracking reactor using a homogeneous catalyst system, such as a molybdenum based catalysts which may optionally be promoted with nickel. Products from the upgrading operations can be finished olefins and/or aromatics, or, for heavier products from the upgrading operations, may be used as feed to the steam cracker.

Systems and methods are provided for hydroprocessing of bio-derived feeds, such as bio-oils and/or other types of feeds including triglycerides, fatty acids, and/or fatty acid derivatives. The systems and methods can assist with maintaining a desired temperature profile within a reactor while performing hydroprocessing on a feed with substantial oxygen content. In various aspects, the initial bed of the reactor can be exposed to 30 vol % or less of the total fresh feed. The remaining portions of the fresh feed can be introduced below one or more of the catalyst beds in the reactor. By reducing or minimizing the amount of fresh feed introduced upstream from the initial catalyst bed that contains a catalyst with hydrodeoxygenation activity, the net amount of product recycle can be reduced or minimized while still maintaining a target temperature profile across individual catalyst beds and/or across the reactor.

Processes herein may be used to thermally crack various hydrocarbon feeds, and may eliminate the refinery altogether while making the crude to chemicals process very flexible in terms of crude. In embodiments herein, crude is progressively separated into light and heavy fractions utilizing convection heat from heaters used in steam cracking. Depending on the quality of the light and heavy fractions, these are routed to one of three upgrading operations, including a fixed bed hydroconversion unit, a fluidized catalytic conversion unit, or a residue hydrocracking unit that may utilize either an ebullated bed reactor with extrudate catalysts or a slurry hydrocracking reactor using a homogeneous catalyst system, such as a molybdenum based catalysts which may optionally be promoted with nickel. Products from the upgrading operations can be finished olefins and/or aromatics, or, for heavier products from the upgrading operations, may be used as feed to the steam cracker.

A method of upgrading a petroleum feedstock, the method comprising the steps of introducing a disulfide oil, a water feed, and a petroleum feedstock to a supercritical water upgrading unit, and operating the supercritical water upgrading unit to produce a product gas stream, a product oil stream, and a used water stream.