Abstract: A method includes controlling an oil and gas extraction process, controlling a production separation process, and controlling a de-gassing process. The method also includes optimizing the oil and gas extraction process, the production separation process, and the degassing process to optimize at least one process objective. The method could further include controlling a lift-gas compression process. The optimizing could include optimizing the lift-gas compression process, the oil and gas extraction process, the production separation process, and the degassing process to optimize the at least one process objective.

Abstract: A natural gas liquefaction train includes a nitrogen cooling loop. A controller is provided for controlling one or more controlled variables by adjusting one or more manipulated variables. The one or more manipulated variables may include a nitrogen flow associated with the nitrogen cooling loop in the natural gas liquefaction train. The controller could adjust the nitrogen flow by adjusting operation of a compressor associated with the nitrogen cooling loop. The one or more controlled variables may include a rundown temperature of liquefied natural gas exiting the nitrogen loop and/or a calorific or heating value of the liquefied natural gas exiting the nitrogen loop. A second controller could control other aspects of the natural gas liquefaction train, such as by controlling a mass flow rate of a feed gas in the natural gas liquefaction train.

Abstract: A method includes controlling a lift-gas compression process, controlling a lift-gas extraction process, and controlling a production separation process. The method also includes receiving asset data and optimizing the lift-gas compression process, the lift-gas injection process, and the production separation process according to the asset data.

Abstract: A process for liquefying a gaseous methane-rich feed (20) to obtain liquefied natural gas, wherein a gaseous methane-rich feed at elevated pressure is conducted through a heat exchanger (1), where it is cooled, liquefied and sub-cooled against evaporating refrigerant. The liquefied product (21) is discharged from the heat exchanger. The refrigerant cycles in a closed loop, wherein the evaporated refrigerant (22) is removed from the heat exchanger, and is compressed (30) to get high pressure refrigerant which is cooled (31,32) and divided into a liquid (heavy) portion (24) and a gaseous (light) portion (25), which are conducted to the heat exchanger for sub-cooling and liquefying the gaseous methane-rich feed. The sub-cooled refrigerant portions are introduced (35,37) into the shell of the heat exchanger at respective positions for being evaporated.

Abstract: A method includes controlling a first process using a first process control system. The method also includes controlling a second process using a second process control system. The method further includes controlling the first and second process control systems together. In addition, the method includes optimizing at least one process objective using both the first and second process control systems. The first process can be a natural gas liquids production process, and the second process can be a liquefied natural gas production process. The process objective could include at least one of: profit, natural gas liquids quantity, natural gas liquids quality, liquefied natural gas quantity, and liquefied natural gas quality.

Abstract: A natural gas liquefaction train includes a nitrogen cooling loop. A controller is provided for controlling one or more controlled variables by adjusting one or more manipulated variables. The one or more manipulated variables may include a nitrogen flow associated with the nitrogen cooling loop in the natural gas liquefaction train. The controller could adjust the nitrogen flow by adjusting operation of a compressor associated with the nitrogen cooling loop. The one or more controlled variables may include a rundown temperature of liquefied natural gas exiting the nitrogen loop and/or a calorific or heating value of the liquefied natural gas exiting the nitrogen loop. A second controller could control other aspects of the natural gas liquefaction train, such as by controlling a mass flow rate of a feed gas in the natural gas liquefaction train.

Abstract: A protection system is provided that mitigates damage caused by slug flow in oil and gas production systems. The protection system opens or closes a choke valve based upon flow parameters such as the separator pressure and level, and the riser pressure. The choke valve position is calculated based upon a number of factors of the production system in order to maintain efficiency while providing safety.

Abstract: A method includes controlling a lift-gas compression process, controlling a lift-gas extraction process, and controlling a production separation process. The method also includes receiving asset data and optimizing the lift-gas compression process, the lift-gas injection process, and the production separation process according to the asset data.

Abstract: A method includes controlling an oil and gas extraction process, controlling a production separation process, and controlling a de-gassing process. The method also includes optimizing the oil and gas extraction process, the production separation process, and the degassing process to optimize at least one process objective. The method could further include controlling a lift-gas compression process. The optimizing could include optimizing the lift-gas compression process, the oil and gas extraction process, the production separation process, and the degassing process to optimize the at least one process objective.

Abstract: A method includes controlling a first process using a first process control system. The method also includes controlling a second process using a second process control system. The method further includes controlling the first and second process control systems together. In addition, the method includes optimizing at least one process objective using both the first and second process control systems. The first process can be a natural gas liquids production process, and the second process can be a liquefied natural gas production process. The process objective could include at least one of: profit, natural gas liquids quantity, natural gas liquids quality, liquefied natural gas quantity, and liquefied natural gas quality.

Abstract: A protection system is provided that mitigates damage caused by slug flow in oil and gas production systems. The protection system opens or closes a choke valve based upon flow parameters such as the separator pressure and level, and the riser pressure. The choke valve position is calculated based upon a number of factors of the production system in order to maintain efficiency while providing safety.