A method may include: hydropyrolyzing a bio feedstock in a hydropyrolysis unit to produce at least a hydropyrolysis oil; introducing at least a portion of the hydropyrolysis oil with a hydrocarbon co-feed into a fluidized catalytic cracking unit; and cracking the hydropyrolysis oil in the fluidized catalytic cracking unit to produce at least fuel range hydrocarbons.

The present invention relates to a process for the production of high value chemicals, preferably including at least ethylene and propylene, by steam cracking a mixture of non-cyclic paraffin stream (A) comprising at least 90% of components having at least 12 carbon atoms, with either a mixture of hydrocarbons having from 3 to 4 carbon atoms or a mixture of hydrocarbons comprising at least 90% of components having a boiling point ranging from 15° C. to 200° C.

The invention pertains to a method for processing a Fischer-Tropsch off-gas wherein Fischer-Tropsch off-gas is contacted with a wash fluid in a scrubber, and wherein the wash fluid is recycled in a closed loop with a dedicated scrubber, stripper and splitter. The wash fluid preferably is kerosene or LDF. The C.sub.3+ hydrocarbons that are recovered from the off-gas are, together with other Fischer-Tropsch product, subjected to hydrocracking or hydrocracking/hydroisomerization. Additionally, hydrogen is recovered from the off-gas.

A process for recovery hydrogen and LPG from a gaseous separated hydroprocessed stream and a stripper gaseous stream and/or a fractionator gaseous stream by increasing the pressure of the stripper gaseous stream and/or the fractionator gaseous stream. Both streams or all three streams can be subjected to sponge absorption and hydrogen recovery in series.

Process and plant for producing hydrocarbon products from a feedstock originating from a renewable source, where a hydrogen-rich stream and on off-gas stream comprising hydrocarbons is formed. A portion of the hydrogen-rich stream is used as a recycle gas stream in a hydroprocessing stage for the production of said hydrocarbon products, and another portion may be used for hydrogen production, while the off-gas stream is treated to remove its H.sub.2S content and used as a recycle gas stream in the hydrogen producing unit, from which the hydrogen produced i.e. make-up hydrogen, is used in the hydroprocessing stage. The invention enables minimizing natural gas consumption in the hydrogen producing unit as well as steam reformer size.

A reformer system (11) having a hydrodesulfurizer (12) provides desulfurized natural gas feedstock to a catalytic steam reformer (16), the outflow of which is treated by a water gas shift reactor (20) and optionally a preferential CO oxidizer (58) to provide reformate gas (28, 28a) having high hydrogen and moderate carbon dioxide content. To avoid damage to the hydrodesulfurizer from overheating, any deleterious hydrogen reactants, such as the oxygen in peak shave gas or olefins, in the non-desulfurized natural gas feedstock (35) are reacted (38) with hydrogen (28, 28a; 71) to convert them to alkanes (e.g., ethylene and propylene to ethane and propane) and to convert oxygen to water in a catalytic reactor (38) having no sulfide sorbent, and cooled (46), below a temperature which would damage the reactor, by evaporative cooling with pressurized hot water (42). Hydrogen for the desulfurizer and the hydrogen reactions may be provided as recycle reformate (28, 28a) or from a mini-CPO (67), or from other sources.

A bio-renewable conversion process for making fuel from bio-renewable feedstocks is combined with a hydrogen production process that includes recovery of CO.sub.2. The integrated process uses a purge gas stream comprising hydrogen from the bio-renewable hydrocarbon production process in the hydrogen production process.

A method and apparatus for upgrading heavy oil is described, having a symbiotic relationship between a cracking reactor vessel and a steam reformer vessel. A first portion of an uncracked residue oil stream from the cracking reactor vessel is passed through a heat exchanger positioned within the steam reformer vessel and back to the cracking reactor vessel, such that a heat exchange takes place which heats the uncracked residue oil stream to promote cracking. A second portion of the uncracked residue oil stream from the cracking reactor vessel is injected directly into the steam reformer vessel. That portion of the uncracked residue oil stream not vaporized in the steam reformer vessel is converted into coke which becomes deposited in a fluidized bed of the steam reformer vessel. The fluidized bed activates steam which reacts with the coke to generate hydrogen. Hydrogen from the steam reformer vessel is directed into the cracking reactor vessel to assist with cracking.

Systems and methods are provided for co-processing of biomass oil in a fluid catalytic cracking (FCC) system that include recovering an additional source of H.sub.2 or synthesis gas from the overhead product gas stream. The additional H.sub.2 can be used to partially hydrogenate biomass oil prior to co-processing the biomass oil in the fluid catalytic cracking system. Additionally or alternately, the additional synthesis gas can represent an additional yield of products from the process, such as an additional yield that can be used for synthesis of further liquid products.

A processing facility is provided. The processing facility includes an asphaltenes and metals (AM) removal system configured to process a feed stream to produce a power generation stream, a hydroprocessing feed stream, and an asphaltenes stream. A power generation system is fed by the power generation feed stream. A hydroprocessing system is configured to process the hydroprocessing feed stream to form a gas stream and a liquid stream. A hydrogen production system is configured to produce hydrogen, carbon monoxide and carbon dioxide from the gas feed stream. A carbon dioxide conversion system is configured to produce synthetic hydrocarbons from the carbon dioxide, and a cracking system is configured to process the liquid feed stream.