Natural gas liquids recovery plant management systems and methods

Abstract

Methods for managing natural gas liquids (NGL) recovery systems may comprise receiving a dryout gas by at least one first exchanger, the at least one first exchanger being part of a first NGL recovery train; receiving the dryout gas from the at least one first exchanger by a first dehydrator; receiving the dryout gas from the first dehydrator by at least one second exchanger, the second exchanger being part of a second NGL recovery train; receiving the dryout gas from the at least one first exchanger and the at least one second exchanger by a third exchanger; and bypassing a flare burner by directing the dryout gas from the third exchanger to a gas sales compressor through a first bypass fluid conduit.

The invention claimed is: 
     
         1 . A method for managing a natural gas liquids (NGL) recovery system comprising:
 receiving a dryout gas by at least one first exchanger, the at least one first exchanger being part of a first NGL recovery train;   receiving the dryout gas from the at least one first exchanger by a first dehydrator;   receiving the dryout gas from the first dehydrator by at least one second exchanger, the second exchanger being part of a second NGL recovery train;   receiving the dryout gas from the at least one first exchanger and the at least one second exchanger by a third exchanger; and   bypassing a flare burner by directing the dryout gas from the third exchanger to a gas sales compressor through a first bypass fluid conduit.   
     
     
         2 . The method of  claim 1 , further comprising monitoring data including at least one of flowrate, temperature, or pressure. 
     
     
         3 . The method of  claim 2 , further comprising adjusting at least one of the flowrate, the temperature, or pressure to achieve a sales gas pipeline specification equal to or less than 147 PPMV. 
     
     
         4 . The method of  claim 1 , further comprising monitoring data including at least one of flowrate, temperature, or pressure using a chemical process simulator. 
     
     
         5 . The method of  claim 4 , further comprising adjusting at least one of flowrate, temperature, or pressure to achieve a sales gas pipeline specification equal to or less than 147 PPMV. 
     
     
         6 . The method of  claim 4 , wherein the chemical process simulator is an Aspen HYSYS® simulator. 
     
     
         7 . The method of  claim 1 , further comprising:
 receiving the dryout gas from the at least one first exchanger by a demethanizer;   receiving the dryout gas from the demethanizer by at least one fourth exchanger; and   bypassing the flare burner by directing the dryout gas from the at least one fourth exchanger to a fuel sales compressor through a second bypass fluid conduit.   
     
     
         8 . The method of  claim 7 , further comprising monitoring data including at least one of flowrate, temperature, or pressure. 
     
     
         9 . The method of  claim 8 , further comprising adjusting at least one of flowrate, temperature, or pressure to achieve a sales gas pipeline specification equal to or less than 147 PPMV. 
     
     
         10 . The method of  claim 7 , further comprising monitoring data including at least one of flowrate, temperature, or pressure using a chemical process simulator. 
     
     
         11 . The method of  claim 10 , further comprising adjusting at least one of flowrate, temperature, or pressure to achieve a sales gas pipeline specification equal to or less than 147 PPMV. 
     
     
         12 . The method of  claim 10 , wherein the chemical process simulator is an Aspen HYSYS® simulator. 
     
     
         13 . A natural gas liquids (NGL) recovery system comprising:
 a first NGL recovery train for receiving a dryout gas, the first NGL recovery train comprising a plurality of first exchangers;   a first dehydrator in fluid communication with at least one of the pluralities of first exchangers for receiving the dryout gas;   a second dehydrator in fluid communication with the first dehydrator for receiving the dryout gas;   a second NGL recovery train comprising a plurality of second exchangers, wherein at least one of the pluralities of second exchangers is in fluid communication with the second dehydrator;   wherein at least one of the pluralities of first exchangers is in fluid communication with at least one of the pluralities of second exchangers for receiving the dryout gas from the second NGL recovery train;   a third NGL recovery train comprising at least one third exchanger in fluid communication with at least one of the pluralities of first exchangers for receiving the dryout gas; and   a first bypass fluid conduit in fluid communication with the at least one third exchanger and a sales gas compressor,   wherein the first bypass fluid conduit directs the dryout gas to the sales gas compressor and away from a flare burner.   
     
     
         14 . The system of  claim 13 , further comprising a chemical process simulator in data communication with one or more of the at least one of the plurality of first exchangers, the first dehydrator, the second dehydrator, at least one of the plurality of second exchangers, the at least one third exchanger, the first bypass fluid conduit, or the sales gas compressor for monitoring data including at least one of flowrate, temperature, and pressure. 
     
     
         15 . The system of  claim 14 , wherein the chemical process simulator is an Aspen HYSYS® simulator. 
     
     
         16 . The NGL system of  claim 13 , further comprising:
 a demethanizer in fluid communication with at least one of the pluralities of first exchangers for receiving the dryout gas;   a fourth exchanger in fluid communication with the demethanizer for receiving the dryout gas;   a fifth exchanger in fluid communication with the fourth exchanger for receiving the dryout gas; and   a second bypass fluid conduit in fluid communication with the fifth exchanger and a fuel gas compressor,   wherein the second bypass fluid conduit directs the dryout gas to the fuel gas compressor and away from the flare burner.   
     
     
         17 . The system of  claim 7 , further comprising a chemical process simulator in data communication with one or more of the at least one of the plurality of first exchangers, the first dehydrator, the second dehydrator, at least one of the plurality of second exchangers, the at least one third exchanger, the first bypass fluid conduit, the sales gas compressor, the demethanizer, the fourth exchanger, the fifth exchanger, the second bypass fluid conduit, or the fuel gas compressor for monitoring data including at least one of flowrate, temperature, and pressure. 
     
     
         18 . The system of  claim 17 , wherein the chemical process simulator is an Aspen HYSYS® simulator.