A method of producing a fuel additive includes passing a feed stream comprising C4 hydrocarbons through a butadiene extraction unit producing a first process stream; passing the first process stream through a methyl tertiary butyl ether unit producing a second process stream and a methyl tertiary butyl ether product; passing the second process stream through a hydration unit producing the fuel additive and a recycle stream; passing the recycle stream through a hydrogenation unit; and recycling the recycle stream to a steam cracker unit and/or to the feed stream

A high-efficiency food waste carbonization process using a carbonizer specially designed to function at a specific range of temperatures to work efficiently, with minimal energy input and designed to reduce volume and to produce charcoal that may be used as a fuel. The invention is designed to work with high-moisture materials such as food waste.

A method for preparing biochar, including steps as follows: dosing: putting pre-crushed biomass into a reactor; charring conversion: heating the reactor to a certain temperature and pressure, and putting an active group-containing active agent containing 1% to 5% by mass of biomass and a catalyst containing 1% to 10% by mass of biomass (or putting the catalyst first and then putting the active agent) into the reactor to perform solid solution charring on the biomass; and cooling: after the charring conversion is completed, cooling the reactor to 40° C. or lower to obtain the biochar. Feedstocks are abundant and cheap, farmland biomass waste is reused, and the active group-containing active agent is added in biomass charring, which can effectively inhibit side reactions and coordinate with the catalyst to perform solid solution charring on the biomass, thereby improving a biochar conversion rate and making the charring process clean and environmentally friendly.

Organic sulfur compounds which are generally present in the crude oil undergoes various transformations while processing the crude oil in the secondary processing units such as fluid catalytic cracker, hydrocracker, delayed coker, visbreaker, etc. The sulfur present in the feed which enters into these secondary processing units are distributed into various products coming out of the units. Sulfur compounds which are present in the various product fractions are removed to meet the desired specifications before routing to the final product pool. Conventionally, sulfur present in the LPG has been removed by amine treatment followed by caustic and water wash. The present invention relates to a process for removal of sulfur and other impurities from Liquefied Petroleum Gas (LPG) comprising olefins through reactive desulfurization route. The present invention is an eco-friendly process as it minimizes or eliminates the use of caustic which is conventionally used to remove the sulfur from LPG.

A system for recovering natural gas liquid from a gas source, comprising compression means (206) for increasing the temperature and pressure of the fluid from the gas source, cooling means (230) for cooling the fluid from the compression means, a gas/gas heat exchanger (204), fluid from the gas source flowing from a first inlet to a first outlet; at least one separator (208) for receiving the fluid from the first outlet of the gas/gas heat exchanger (204) and separating liquid from the gas, the gas from the separator being directed to expansion means (206) for reducing the temperature and pressure of the gas, the aqueous part of the liquid from the separator and/or the gas from the expansion means being directed to the gas/gas heat exchanger (204) where it flows therethrough from a second inlet to a second outlet for cooling the fluid flowing between the first inlet and first outlet, wherein injection means are provided between the cooling means and the gas/gas heat exchanger for saturating the gas with a liquid agent, wherein the liquid agent comprises an evaporant and an antifreeze agent; and a recovery vessel (240) is provided downstream of the second outlet, the antifreeze agent being recovered therein for injection into the fluid from the gas source upstream of the first inlet.

The present invention is directed to the removal of mercury in a gas dehydration process using thermally table chemical additives.

A method of dissolving a gas hydrate in a pipeline includes introducing a gas hydrate dissolving solution into the pipeline and allowing the gas hydrate dissolving solution to at least partially dissolve the gas hydrate in the pipeline. The gas hydrate dissolving solution includes a glycol, dimethylformamide, or both, and has a boiling point of greater than 80° C. A method of dissolving a gas hydrate in a pipeline may also include introducing a gas hydrate dissolving solution into the pipeline and allowing the gas hydrate dissolving solution to at least partially dissolve the gas hydrate in the pipeline. The gas hydrate dissolving solution includes comprises a glycol, dimethylformamide, cesium formate, potassium formate, or combinations thereof, and has a flash point of greater than 50° C.

A method of dissolving a gas hydrate in a pipeline includes introducing a gas hydrate dissolving solution into the pipeline and allowing the gas hydrate dissolving solution to at least partially dissolve the gas hydrate in the pipeline. The gas hydrate dissolving solution includes cesium formate, potassium formate, or both, and has a flash point of greater than 50° C.

Implementations described and claimed herein provide systems and methods for processing liquefied natural gas (LNG). In one implementation, a solvent is injected into a feed of natural gas at a solvent injection point. A mixed feed is produced from a dispersal of the solvent into the feed of natural gas. The mixed feed contains heavy components. A chilled feed is produced by chilling the mixed feed. The chilled feed includes a vapor and a condensed liquid. The condensed liquid contains a fouling portion of the heavy components condensed by the solvent during chilling. The liquid containing the fouling portion of the heavy components is separated from the vapor. The vapor is directed into a feed chiller heat exchanger following separation of the liquid containing the fouling portion of the heavy components from the vapor, such that the vapor being directed into feed chiller heat exchanger is free of freezing components.

Production chemicals and methods of selecting the production chemicals based on Hansen Solubility Parameters (HSP) are disclosed. The production chemicals selected by the methods mitigate or reduce one or more issues or problems associated with oil and gas productions and transportations. The methods measure HSP values for the production chemicals and/or crude oil and select at least one production chemical for at least one application on the crude oil based on the HSP values of the production chemicals and the crude oil.