초록 ▼

Disclosed is a liquefied natural gas storage apparatus. The apparatus includes a heat insulated tank and liquefied natural gas contained in the tank. The tank has heat insulation sufficient to maintain liquefied natural gas therein such that most of the liquefied natural gas stays in liquid. The con

Disclosed is a liquefied natural gas storage apparatus. The apparatus includes a heat insulated tank and liquefied natural gas contained in the tank. The tank has heat insulation sufficient to maintain liquefied natural gas therein such that most of the liquefied natural gas stays in liquid. The contained liquefied natural gas has a vapor pressure from about 0.3 bar to about 2 bar. The apparatus further includes a safety valve configured to release a part of liquefied natural gas contained in the tank when a vapor pressure of liquefied natural gas within the tank becomes higher than a cut-off pressure. The cut-off pressure is from about 0.3 bar to about 2 bar.

대표청구항 ▼

1. An LNG tank ship comprising: a heat insulated tank;LNG and boil-off gas of the LNG contained in the tank;a safety valve configured to release part of the boil-off gas of the LNG from the tank when a vapor pressure within the tank exceeds a cut-off pressure of the safety valve, wherein the safety

1. An LNG tank ship comprising: a heat insulated tank;LNG and boil-off gas of the LNG contained in the tank;a safety valve configured to release part of the boil-off gas of the LNG from the tank when a vapor pressure within the tank exceeds a cut-off pressure of the safety valve, wherein the safety valve is configured to adjust the cut-off pressure within a range between a first value and a second value, the first value being 0.25 bar (gauge pressure) or below, the second value being between about 0.25 bar (gauge pressure) and about 2 bar (gauge pressure); anda controller configured to monitor settings of the cut-off pressure of the safety valve based on a currently allowable cut-off pressure of the safety valve computed using a volume of the LNG contained in the tank. 2. The LNG tank ship of claim 1, wherein the tank comprises heat insulation sufficient to maintain a substantial portion of the liquefied natural gas as liquid for an extended period. 3. The LNG tank ship of claim 1, wherein the LNG within the tank has a temperature from about −159° C. to about −146° C. 4. The LNG tank ship of claim 1, wherein the tank has a volume greater than about 100,000 m3. 5. The LNG tank ship of claim 1, further comprising a flowing device configured to flow a portion of the LNG from one location within the tank to another location within the tank. 6. The LNG tank ship of claim 5, wherein the flowing device comprises a conduit which is located inside the tank. 7. The LNG tank ship of claim 5, wherein the flowing device comprises a conduit, at least part of which is located outside the tank. 8. The LNG tank ship of claim 1, wherein the tank comprises: an interior wall defining an interior space configured to contain LNG;an exterior wall substantially surrounding the interior wall; andthe heat insulation interposed between the interior wall and the exterior wall. 9. The LNG tank ship of claim 1, wherein the tank is integrated with a body of the ship. 10. The LNG tank ship of claim 9, further comprising: a primary engine of the ship for generating power to move the ship, wherein the engine is designed to use a fuel other than LNG such that the engine does not use LNG to reduce vapor pressure of the LNG within the tank; andat least one liquefier configured to convert at least a portion of gaseous phase LNG to liquid phase LNG, wherein the at least one liquefier has a processing capacity, which is the maximum amount of gaseous phase LNG to be processed by the at least one liquefier for one hour, wherein the tank has a volume, and a ratio of the processing capacity to the volume is smaller than about 0.015 kg/m3·hr. 11. The LNG tank ship of claim 9, further comprising a primary engine of the ship for generating power to move the ship, wherein the engine is designed to use a fuel other than LNG such that the engine does not use LNG to reduce vapor pressure of the LNG within the tank; and wherein the ship does not comprise a liquefier that is configured to convert at least a portion of gaseous phase LNG to liquid phase LNG. 12. The LNG tank ship of claim 1, wherein the cut-off pressure is set at about 0.25 bar (gauge pressure) or lower during loading of LNG into the tank. 13. The LNG tank ship of claim 1, wherein during voyage of the LNG tank ship, the cut-off pressure is set at a pressure higher than the cut-off pressure set during loading of LNG into the LNG tank ship. 14. The LNG tank ship of claim 13, wherein the cut-off pressure is set at about 2 bar (gauge pressure) or lower during voyage of the LNG tank ship. 15. The LNG tank ship of claim 13, wherein the cut-off pressure is adjusted as gradually increasing up to about 2 bar (gauge pressure) or lower during voyage of the LNG tank ship. 16. The LNG tank ship of claim 1, wherein the volume of LNG is calculated using data measured with at least one sensor. 17. The LNG tank ship of claim 16, wherein the measured data comprise at least one selected from the group consisting of temperature, vapor pressure and a level of LNG contained in the tank. 18. The LNG tank ship of claim 16, wherein the measured data comprise at least one selected from the group consisting of a level of LNG contained in the tank and a front-to-back gradient of the LNG carrier. 19. The LNG tank ship of claim 16, wherein the measured data comprise a level of LNG contained in the tank, a longitudinal gradient of the LNG carrier and a lateral gradient of the LNG carrier. 20. A method of operating an LNG tank ship, the method comprising: providing the LNG tank ship of claim 1;monitoring the volume of the LNG within the tank; andchanging the cut-off pressure of the safety valve from the first value to the second value based on the currently allowable cut-off pressure of the safety valve computed using the volume of the LNG contained in the tank. 21. The method of claim 20, wherein the second value is from about 0.5 bar (gauge pressure) to about 1 bar (gauge pressure). 22. The method of claim 20, wherein the volume of LNG is calculated using data measured with at least one sensor. 23. The method of claim 20, wherein changing the cut-off pressure occurs in response to a decrease of the volume of LNG within the tank. 24. The method of claim 22, wherein the measured data comprise at least one selected from the group consisting of temperature, vapor pressure and a level of LNG contained in the tank. 25. The method of claim 22, wherein the measured data comprise at least one selected from the group consisting of a level of LNG contained in the tank and a front-to-back gradient of the LNG carrier. 26. The method of claim 22, wherein the measured data comprise a level of LNG contained in the tank, a longitudinal gradient of the LNG carrier and a lateral gradient of the LNG carrier. 27. A method of operating an LNG tank ship, the method comprising: providing the LNG tank ship of claim 1; andmonitoring a vapor pressure of the LNG in the tank wherein the vapor pressure is from about 0.25 bar (gauge pressure) to 2 bar (gauge pressure). 28. The method of claim 27, further comprising comparing the vapor pressure to a reference pressure so as to determine whether to initiate a safety measure, wherein the reference pressure is from about 0.25 bar (gauge pressure) to about 2 bar (gauge pressure). 29. A method of unloading LNG from an LNG tank containing LNG to a receiving tank, the method comprising: providing the LNG tank ship of claim 1;connecting between the LNG tank and a receiving tank such that a fluid communication between the receiving tank and the LNG tank is established; andunloading at least part of the LNG from the LNG tank to the receiving tank.