Provided is a system including a planning section that generates a production plan for a production site, using a planning model; a simulating section that simulates operation of at least a portion of the production site, based on a simulation model of the at least a portion of the production site; a monitoring section that monitors actual operation of the at least a portion of the production site; a calibrating section that calibrates the simulation model, based on a difference between the simulated operation and the actual operation; and a control section that controls the at least a portion of the production site, based on a simulation result obtained by simulating the operation of the at least a portion of the production site in accordance with the production plan, using the simulation model that has been calibrated.

When operating a production site, it is preferable to maintain accurate models continuously. Provided is a system including a simulating section that simulates operation of at least a portion of a production site, based on a simulation model of the at least a portion of the production site; a monitoring section that monitors actual operation of the at least a portion of the production site; a calibrating section that calibrates the simulation model, based on a difference between the simulated operation and the actual operation; and an updating section that updates a planning model used to generate a production plan for the production site, according to the calibration of the simulation model.

Embodiments of the present invention are generally related to a system and method to remove hydrogen sulfide from sour water and sour oil. Particularly, hydrogen sulfide is removed from sour water and sour oil without the need for special chemicals, such as catalyst chemicals, scavenger chemicals, hydrocarbon sources, or a large-scale facility. The system and method in the present invention is particularly useful in exploratory oil and gas fields, where large facilities to remove hydrogen sulfide may be inaccessible. The present invention addresses the need for safe and cost-effective transport of the deadly neurotoxin. Particular embodiments involve a system and method that can be executed both on a small and large scale to sweeten sour water and sour oil.

Embodiments of the present invention are generally related to a system and method to remove hydrogen sulfide from sour water and sour oil. Particularly, hydrogen sulfide is removed from sour water and sour oil without the need for special chemicals, such as catalyst chemicals, scavenger chemicals, hydrocarbon sources, or a large-scale facility. The system and method in the present invention is particularly useful in exploratory oil and gas fields, where large facilities to remove hydrogen sulfide may be inaccessible. The present invention addresses the need for safe and cost-effective transport of the deadly neurotoxin. Particular embodiments involve a system and method that can be executed both on a small and large scale to sweeten sour water and sour oil.

A method and composition for isolating a paraffinic hydrocarbon layer from a sludge comprising paraffinic hydrocarbons, water, and solids. The method includes contacting the sludge with isopropylamine dodecylbenzene sulfonate, a cutter stock, and water. The isopropylamine dodecylbenzene sulfonate comprises a concentration of at least 1500 ppm. The ratio of sludge:cutter:water is at least 4:2:1. The method also includes determining if the sludge has separated into a three phase separation comprising a paraffinic hydrocarbon layer, a water layer, and a layer of settled solids.

A method and composition for isolating a paraffinic hydrocarbon layer from a sludge comprising paraffinic hydrocarbons, water, and solids. The method includes contacting the sludge with isopropylamine dodecylbenzene sulfonate, a cutter stock, and water. The isopropylamine dodecylbenzene sulfonate comprises a concentration of at least 1500 ppm. The ratio of sludge:cutter:water is at least 4:2:1. The method also includes determining if the sludge has separated into a three phase separation comprising a paraffinic hydrocarbon layer, a water layer, and a layer of settled solids.

The present invention describes the coprocessing of a lignocellulosic liquid stream and an intermediate fossil stream in the oil refining process comprising the steps of (a) contacting said intermediate fossil stream and said lignocellulosic liquid stream with a stream of solvent of C.sub.3-C.sub.10 hydrocarbons in an extraction section, obtaining a stream of extract with solvent and a stream of raffinate with solvent; and (b) sending said stream of extract with solvent to a separation section, obtaining a deasphalted oil stream comprising solvent-free carbon of renewable origin and a stream of recovered solvent. The present invention further relates to a process for producing fuels from the deasphalted oil stream comprising carbon of renewable origin, wherein the process comprises sending the deasphalted oil stream to a conversion section of an oil refinery. The conversion section is selected from catalytic hydrocracking unit, thermal cracking, fluidized-bed catalytic cracking, visbreaking, delayed coking and catalytic reforming.

The present invention describes the coprocessing of a lignocellulosic liquid stream and an intermediate fossil stream in the oil refining process comprising the steps of (a) contacting said intermediate fossil stream and said lignocellulosic liquid stream with a stream of solvent of C.sub.3-C.sub.10 hydrocarbons in an extraction section, obtaining a stream of extract with solvent and a stream of raffinate with solvent; and (b) sending said stream of extract with solvent to a separation section, obtaining a deasphalted oil stream comprising solvent-free carbon of renewable origin and a stream of recovered solvent. The present invention further relates to a process for producing fuels from the deasphalted oil stream comprising carbon of renewable origin, wherein the process comprises sending the deasphalted oil stream to a conversion section of an oil refinery. The conversion section is selected from catalytic hydrocracking unit, thermal cracking, fluidized-bed catalytic cracking, visbreaking, delayed coking and catalytic reforming.

Systems and processes for removing sulfur compounds from a hydrocarbon stream. Sulfur compounds are extracted from a hydrocarbon feed stream with a caustic stream to provide a treated hydrocarbon stream and a rich caustic stream. The sulfur compounds in the rich caustic stream are oxidized in the presence of a catalyst to provide a lean caustic stream. The lean caustic stream is returned to extract sulfur from the hydrocarbon stream. Data such as a concentration of sulfurs species and degree of caustic saturation with the sulfur species in the rich caustic stream may be provided by a sensor, compared against other real-time or historical data and used to provide a recommended adjustment to process conditions associated with an extraction unit, or an oxidation unit, or both.

Systems and processes for removing sulfur compounds from a hydrocarbon stream. Sulfur compounds are extracted from a hydrocarbon feed stream with a caustic stream to provide a treated hydrocarbon stream and a rich caustic stream. The sulfur compounds in the rich caustic stream are oxidized in the presence of a catalyst to provide a lean caustic stream. The lean caustic stream is returned to extract sulfur from the hydrocarbon stream. Data such as a concentration of sulfurs species and degree of caustic saturation with the sulfur species in the rich caustic stream may be provided by a sensor, compared against other real-time or historical data and used to provide a recommended adjustment to process conditions associated with an extraction unit, or an oxidation unit, or both.