System for processing and transporting compressed natural gas
View Patent ↗A system for processing and transporting compressed natural gas having a separator for separating the pressurized high-energy content gas into saturated gas and liquids; a decontamination unit for removing impurities from the saturated gas to create a decontaminated saturated gas; a dehydration unit for dehydrating the decontaminated saturated gas to remove water forming a dry pressurized gas; a chiller for cooling the dry pressurized gas cooled from ambient temperature to between −80 Fahrenheit and −120 Fahrenheit forming a two-phase gas; a floating vessel; at least one storage module located on the floating vessel that maintains a pressure ranging from 800 psi and 1200 psi; and wherein the floating vessel transports at least one storage module a distance ranging between 500 nautical miles and 2500 nautical miles and utilizes the vapor phase during transit to power the floating vessel.
1. A system for processing and transporting compressed natural gas comprising:
a. a separator for receiving pressurized high-energy content gas from a pipeline, wherein the separator separates the pressurized high-energy content gas into saturated gas, a natural gas liquid, and a condensate;
b. a decontamination unit connected to the separator for receiving the saturated gas, wherein the decontamination unit removes impurities from the saturated gas to create a decontaminated saturated gas;
c. a dehydration unit connected to the decontamination unit for receiving the decontaminated saturated gas, wherein the dehydration unit removes water from the decontaminated saturated gas forming a dry pressurized gas;
d. a chiller connected to the dehydration unit for receiving the dry pressurized gas, wherein the chiller cools the dry pressurized gas from ambient temperature to a temperature ranging from −80 degrees Fahrenheit to −120 degrees Fahrenheit forming a two-phase gas comprising a vapor phase and a liquid phase;
e. at least one storage element located on a floating vessel, wherein the storage element is connected to the chiller and the separator, wherein the storage element receives the two-phase gas, the natural gas liquid, and the condensate, wherein the storage element maintains the two-phase gas, the natural gas liquid, and the condensate at a pressure ranging from 800 psi and 1200 psi, wherein the storage element comprises:
i. an inner wall forming a cavity;
ii. an outer wall; and
iii. an insulation layer disposed between the inner and outer wall, and wherein the cavity is adapted to hold the two-phase gas, the natural gas liquid, and the condensate;
f. the floating vessel adapted to transport the storage element a distance ranging from 500 nautical miles to 2500 nautical miles, and wherein the floating vessel utilizes the vapor phase during transit to power the floating vessel.
2. The system of claim 1 , wherein the separator is a three-phase separation vessel.
3. The method of claim 1 , wherein the impurities are a member of the group consisting of carbon dioxide, mercury, hydrogen sulfide, and combinations thereof.
4. The system of claim 1 , wherein the decontamination unit is an amine contactor, a catalytic bed, a scrubber vessel, or combinations thereof.
5. The system of claim 1 , wherein the dehydration unit is a dry bed adsorption unit, a glycol contact tower, a molecular membrane unit, or combinations thereof.
6. The system of claim 1 , wherein the chiller is a single-stage mixed refrigerant process or a two-stage cascade system.
7. The system of claim 1 , wherein the chiller is used to sub-cool the dry pressurized gas to delay the formation of the vapor phase.
8. The method of claim 1 , wherein the outer wall is thinner than the inner wall.
9. The method of claim 1 , wherein the inner wall is a high-strength steel alloy or a basalt-based fiber pipe.
10. The method of claim 9 , wherein the high-strength steel alloy is a nickel-steel alloy.
11. The method of claim 1 , wherein the outer wall is steel, stainless steel, an aluminum, a thermoplastic, a fiberglass, or combinations thereof.
12. The system of claim 1 , wherein the storage element is cylindrical.
13. The system of claim 12 , wherein the inner wall comprises a diameter ranging from 8 feet to 15 feet.
14. The system of claim 13 , wherein the inner wall comprises a diameter ranging from 10 feet to 12 feet.
15. The system of claim 12 , wherein the outer wall comprises a diameter that is up to four feet larger in diameter than the inner wall.
16. The system of claim 1 , wherein the storage element is spherical.
17. The system of claim 16 , wherein the inner wall comprises a diameter ranging from 30 feet to 40 feet.
18. The system of claim 17 , wherein the outer wall comprises a diameter that is up to three feet larger in diameter than the inner wall.
19. The system of claim 1 , wherein the insulating layer comprises perlite.
20. The system of claim 1 , wherein the insulating layer is a vacuum.
21. The system of claim 1 , wherein the lower cost is up to 50% less than comparable submarine pipeline costs or conventional LNG costs.
22. The method of claim 1 , wherein the at least one storage module is located on land and then loaded on the floating vessel.