The present invention relates to a coke reducing additive composition capable of simultaneously (a) reducing coke formation and (b) increasing distillate yield during pyrolysis of a feedstock in the presence of a plastic material, wherein the feedstock is a vacuum residue (VR), plastic material is a waste plastic material or an olefin polymer (OP) material, or a mixture thereof, and the coke reducing additive composition comprises a naphthenate, preferably a calcium naphthenate, or sodium naphthenate, or a mixture thereof, and to a method of employing the coke reducing additive composition, and to a method of use of the coke reducing additive composition of the present invention.

Particularly, in another embodiment, the present invention relates to a coke reducing additive composition capable of simultaneously (a) reducing formation of coke deposits on walls of the processing unit; and (b) reducing fouling caused due to deposits of coke products on walls of the processing unit during pyrolysis of a feedstock in the presence of a plastic material, wherein the feedstock is a vacuum residue (VR), plastic material is a waste plastic material or an olefin polymer (OP) material, or a mixture thereof, and the coke reducing additive composition comprises a naphthenate, preferably a calcium naphthenate, or sodium naphthenate, or a mixture thereof, and to a method of employing the coke reducing additive composition, and to a method of use of the coke reducing additive composition of the present invention.

Particularly, in yet another embodiment, the present invention relates to a method to convert a waste plastic into useful chemical commodity.

Methods for preventing elemental sulfur deposition from a hydrocarbon fluid is disclosed. A mercaptan is added to a hydrocarbon fluid that has elemental sulfur and reacted with the elemental sulfur to produce a disulfide and hydrogen sulfide. Amines and/or surfactants can assist with the process. Secondary reactions between the disulfide and the elemental sulfur result in a polysulfide and a solvated sulfur-disulfide complex. The disulfide, hydrogen sulfide, polysulfide and solvated sulfur-disulfide complex do not deposit, and can optionally be removed.

The present invention reduces viscosity of highly viscous materials before entering a pump inlet by applying radio-frequency heating to the volume of material in a cage of rods that serve as electrodes surrounding a perforated inlet conduit. Applications include heavy hydrocarbonaceous materials such as tar and pitch in reservoirs, and sludge accumulating within oil storage tanks, ships, and barges. A mixer can be added to aid the process.

Scavenging chemicals used in mitigation treatments of hydrogen sulfide in hydrocarbon streams often continue to react and form polymers that foul the processing system. Disclosed herein are methods for determining if a scavenging chemical mitigator, or its reaction or degradation product, will polymerized during or after mitigation treatments. This information allows for the optimization of mitigation treatments that pre-emptively control or prevent polymer formation. Such pre-emption measures reduce the cost and time related to remedial actions to treat polymer-fouled equipment.

Compositions inhibit corrosion in various commercial settings, such as in a refinery and/or in an oil and gas application. The compositions include at least one fatty acid and at least two amphipathic molecules selected from the group consisting of dodecenyl succinic acid, dimer fatty acid and benzalkonium chloride.

The present invention addresses to a system and methodology for evaluating the deposition in tubes of the furnaces of delayed coking unit (DCU) in order to reduce the costs involved with premature shutdowns. With this system, load rankings are obtained, influences of certain loads on processing are evaluated, and additives that reduce deposition are further evaluated. Consequently, the results obtained by such a system allow greater flexibility for the follow-up engineer to optimize his delayed coking unit in order to increase load or increase the unit campaign time, drastically reducing costs in premature shutdowns, or increasing its return by increasing load and shutdowns, since the load is limited by the degree of deposit formation, and that directly affects the wall temperature.

Ionic liquid containing compositions may be used in the production, recovery and refining of oil and gas. In addition, they may be used to treat cooling water and/or to inhibit and/or prevent corrosion of metals.

Processing of a reaction product mixture containing at least one volatile organic compound as well as lignin, lignin derived compounds, and/or unextracted cellulose and hemicellulose using a recovery system comprising at least two flashers or at least one flasher and at least two reboilers. In a particular embodiment, the reaction product mixture comes from reactions involving deconstruction (or digestion) of biomass, particularly cellulosic biomass which contains various polysaccharides (e.g., carbohydrates) and lignin.

Methods and systems for using temperature measurements taken from a compact insulated skin thermowell to optimize a pyrolysis reaction are provided. In the present systems and methods, the upstream temperature and the upstream pressure of a pyrolysis reactor is measured through an adiabatic restriction in the inlet manifold of a parallel tube assembly to provide an absolute upstream temperature and an upstream pressure. The downstream temperature of the pyrolysis reactor is also measured following an adiabatic restriction to provide an absolute downstream temperature. The downstream pressure is then determined by multiplying the absolute upstream pressure with the quotient of the downstream temperature divided by the upstream temperature as taken to the power of k/k−1, where k is the ratio of fluid specific heat at constant pressure (Cp) to fluid specific heat at constant volume (Cv).

A method of demulsifying an emulsion with an ionic liquid having a nitrogen or phosphorus cation.