Configurations and methods for waste heat recovery and ambient air vaporizers in LNG regasification

• US 8,950,196 B2
• Filed: 07/17/2009
• Issued: 02/10/2015
• Est. Priority Date: 07/17/2008
• Status: Expired due to Fees

• Current Assignee: Fluor Technologies Corporation (Fluor Corporation)
• Original Assignee: Fluor Technologies Corporation (Fluor Corporation)
• Inventors: Mak, John
• Primary Examiner(s): Denion, Thomas
• Assistant Examiner(s): Shipe, Steven D
• Application Number:
  US13/003,249
• Publication Number:
  US 20110167824A1
• Time in Patent Office: 2,034 Days
• Field of Search: 62/502, 62/503
• US Class Current: 62/50.2
• CPC Class Codes: F17C 2201/052 large (>1000 m3)
• CPC Class Codes: F17C 2201/054 medium (>1 m3)
• CPC Class Codes: F17C 2205/0323 Valves
• CPC Class Codes: F17C 2221/033 Methane, e.g. natural gas, CNG, LNG, GNL, GNC, PLNG
• CPC Class Codes: F17C 2223/0161 cryogenic, e.g. LNG, GNL, PLNG
• CPC Class Codes: F17C 2223/033 Small pressure, e.g. for liquefied gas
• CPC Class Codes: F17C 2225/0123 gaseous, e.g. CNG, GNC
• CPC Class Codes: F17C 2225/035 High pressure, i.e. between 10 and 80 bars
• CPC Class Codes: F17C 2227/0135 Pumps
• CPC Class Codes: F17C 2227/0311 Air heating
• CPC Class Codes: F17C 2227/0316 Water heating
• CPC Class Codes: F17C 2227/0323 in a closed loop
• CPC Class Codes: F17C 2227/0327 with recovery of heat
• CPC Class Codes: F17C 2227/0362 in a turbine
• CPC Class Codes: F17C 2250/0631 Temperature
• CPC Class Codes: F17C 2250/0636 Flow or movement of content
• CPC Class Codes: F17C 2260/046 Enhancing energy recovery
• CPC Class Codes: F17C 2260/053 Reducing corrosion
• CPC Class Codes: F17C 2265/05 Regasification
• CPC Class Codes: F17C 2270/0581 Power plants
• CPC Class Codes: F17C 5/06 : for filling with compressed gases
• CPC Class Codes: F17C 9/02 : with change of state, e.g. vaporisation
• CPC Class Codes: Y02E 20/16 : Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]
• CPC Class Codes: Y02E 20/18 : Integrated gasification combined cycle [IGCC], e.g. combined with carbon capture and storage [CCS]

Abstract

Contemplated power plants and LNG regasification facilities employ a combination of ambient air and non-ambient air as continuous heat sources to regasify LNG and to optimize power production. Most preferably, contemplated plants and methods are operable without the need for supplemental heat sources under varying temperature conditions.

Claims

1. A power plant comprising:

an ambient air exchanger configured to vaporize LNG to a cold vaporized natural gas stream having a first temperature;

a first heat exchanger coupled to the ambient air exchanger and configured to receive and heat the cold vaporized natural gas stream to a second temperature using heat from a heat transfer medium in a heat transfer medium circuit;

wherein the heat transfer medium circuit is thermally coupled to a heat recovery steam generator via a power steam circuit, the power steam circuit comprising a steam turbine exhausting steam into a second heat exchanger for condensing the exhaust steam into feedwater the second heat exchanger being configured to provide heat to the heat transfer medium circuit;

a first feedwater pump configured for pumping the feedwater to the heat recovery steam generator for heating into hot feedwater;

a third heat exchanger configured to receive at least a portion of the hot feedwater and to provide heat to the heat transfer medium circuit, and wherein the heat recovery steam generator is a primary and continuous source of heat for the heat transfer medium circuit; and

wherein the heat recovery steam generator is configured to allow heating of the heat transfer medium in an amount sufficient to raise the temperature of the cold vaporized natural gas stream from the first temperature to the second temperature.

2. The power plant of claim 1 wherein the heat recovery steam generator is the only source of heat to the heat transfer medium circuit.

3. The power plant of claim 1 wherein the heat recovery steam generator comprises a selective catalyst reduction unit.

4. The power plant of claim 3 further comprising a control unit that is configured to adjust flow rates of the heat transfer medium in various lines of the heat transfer medium circuit to thereby maintain a desired temperature in the selective catalyst reduction unit.

5. The power plant of claim 1 further comprising a second ambient air exchanger, wherein the plant is configured to allow alternate operation of the ambient air exchanger and second ambient air exchanger.

6. The power plant of claim 1 further comprising a conduit that is configured to provide condensed water from the ambient air exchanger to the heat recovery steam generator.

7. A method of regasification of LNG and producing power, comprising:

vaporizing LNG in an ambient air exchanger to form a cold vaporized natural gas stream;

heating the cold vaporized natural gas stream in a first heat exchanger using a heat transfer medium of a heat transfer medium circuit,

wherein the heat transfer medium circuit is thermally coupled to a heat recovery steam generator via a power steam circuit, the power steam circuit comprising a steam turbine exhausting steam into a second heat exchanger for condensing the exhaust steam into feedwater, the feedwater being pumped by a first feedwater pump to the heat recovery steam generator for heating into hot feedwater, the hot feedwater subsequently providing heat to the heat transfer medium circuit via a third heat exchanger; and

wherein the heat recovery steam generator operates as primary and continuous source of heat for the heat transfer medium circuit.

8. The method of claim 7 wherein the heat recovery steam generator is the only source of heat to the heat transfer medium circuit.

9. The method of claim 8 wherein the heat recovery steam generator comprises a selective catalyst reduction unit.

10. The method of claim 9 further comprising a step of using a control unit to adjust flow rates of the heat transfer medium in various lines of the heat transfer medium circuit to thereby maintain a desired temperature in the selective catalyst reduction unit.

11. The method of claim 8 further comprising a step of using condensed water from the ambient air exchanger as working fluid in the heat recovery steam generator.

12. The method of claim 7 further comprising a second ambient air exchanger, and alternately operating the ambient air exchanger and second ambient air exchanger.