Use of underground gas storage to provide a flow assurance buffer between interlinked processing units

• US 9,458,700 B2
• Filed: 04/02/2010
• Issued: 10/04/2016
• Est. Priority Date: 04/06/2009
• Status: Active Grant

• Current Assignee: Single Buoy Moorings of America Incorporated (Single Buoy Moorings)
• Original Assignee: Single Buoy Moorings of America Incorporated (Single Buoy Moorings)
• Inventors: Wille, Hein, Meek, Harke Jan
• Primary Examiner(s): Buck, Matthew R
• Assistant Examiner(s): TOLEDO-DURAN, EDWIN J
• Application Number:
  US13/262,980
• Publication Number:
  US 20120024391A1
• Time in Patent Office: 2,377 Days
• Field of Search: 166/351, 166/352, 166/357, 166/366, 166/266, 166/267, 166/268, 166/369
• US Class Current: 1/1
• CPC Class Codes: B65G 5/00 Storing fluids in natural or artificial cavities or chambers in the earth
• CPC Class Codes: E21B 41/0007 for underwater installations E21B41/005, E21B41/04, E21B41/06, E21B41/08, E21B41/10 take precedence
• CPC Class Codes: E21B 43/40 Separation associated with re-injection of separated materials E21B43/385 takes precedence
• CPC Class Codes: Y10T 137/0318 Processes

Abstract

A system for developing offshore hydrocarbon fields includes a floating hydrocarbon processing unit moored to the seabed and connected to a hydrocarbon reservoir via a riser and a wellhead on the seabed, the unit receiving and processing the hydrocarbon mixture received from the reservoir via the riser, and having equipment to separate the hydrocarbon mixture into oil, water and gas and store them in storage tanks. A gas storage buffer reservoir is placed at a distance from and isolated from the hydrocarbon reservoir. A gas export riser is connected to the floating hydrocarbon processing unit and the gas buffer reservoir to export separated gas and inject it into the gas buffer reservoir. A gas riser has one end connected to the gas buffer reservoir and another end connected to the floating gas processing unit for processing gas received from the gas buffer reservoir for enabling transportation to shore.

Claims

1. A system for the development of one or more offshore hydrocarbon fields comprising:

at least one floating hydrocarbon processing unit (1) that is moored to a seabed (21) and connected to a hydrocarbon reservoir (40) via a riser (2) and a wellhead (3) on the seabed, the floating hydrocarbon processing unit (1) receiving and processing a hydrocarbon mixture received from the hydrocarbon reservoir (40) via the riser (2), the floating hydrocarbon processing unit (1) being provided with process equipment adapted to separate all of the received hydrocarbon mixture into an oil fraction, a water fraction, and a gas fraction and provided with rectangular storage tanks (12) adapted for storage of the separated oil fraction of the mixture at or near ambient pressure,

a gas storage buffer reservoir (7) placed at a certain distance from and isolated from the hydrocarbon reservoir (40)

a gas export riser (5) connected to the floating hydrocarbon processing unit (1) and the gas storage buffer reservoir (7) to export the separated gas fraction of the mixture from the floating hydrocarbon processing unit (1) and inject the separated gas fraction of the mixture into the gas storage buffer reservoir (7) for temporary storage of the separated gas fraction of the mixture,

a gas riser (8) connected with one end to the gas storage buffer reservoir (7) and with another end connected to a floating gas processing unit (9) for processing the separated gas received from the gas storage buffer reservoir (7) so that the processed separated gas can be transported to shore,

wherein the gas buffer reservoir, serving as temporary storage of the produced gas in case of production interruption on either the floating hydrocarbon processing unit (1) or the floating gas processing unit (9), controls the gas flow between the floating hydrocarbon processing unit (1) and the floating gas processing unit (9) working in conjunction, with no interdependence between the activities of the hydrocarbon processing unit (1) and the gas processing unit (9),

wherein the floating gas processing unit (9) comprises a gas liquefaction plant (13) that processes and stores produced liquefied gas,

at least one oil shuttle tanker (16) adapted to transport the separated oil from the floating hydrocarbon processing unit (1) in rectangular tanks at or near ambient pressure, and

at least one LNG shuttle tanker (15) that transports the produced liquefied gas, from the floating gas processing unit (9).

2. The system according to claim 1, comprising at least two of said floating hydrocarbon processing units (1) wherein the gas export riser (5) from each of the floating hydrocarbon processing units (1) are connected to one another before reaching the gas storage buffer reservoir (7) or each have an independent connection to the gas storage buffer reservoir (7).

3. The system according to claim 1, wherein the floating gas processing unit (9) is moored in a weathervaning manner and can be disconnected and reconnected to a mooring system and the gas riser (8), to store, transport and offload liquefied gas to shore.

4. The system according to claim 1, wherein the gas storage buffer reservoir (7) is an underground/subsurface reservoir.

5. The system according to claim 1, wherein the gas storage buffer reservoir (7) is a depleted well or a salt cavern.

6. The system according to claim 1, wherein the floating gas processing unit (9), for receiving and liquefying of temporary stored gas, is disconnectable from a mooring system and a first gas riser (8) that is connected to the gas storage buffer reservoir (7) and can be connected to a second mooring system and a second gas riser (8′

) that is connected to another of said gas storage buffer reservoir (7′

) isolated from and placed at a distance from the gas storage buffer reservoir.

7. The system according to claim 1, wherein,

the gas storage buffer reservoir (7) is an undersea reservoir isolated from the hydrocarbon reservoir (40).

8. A method of receiving, processing and distributing a hydrocarbon mixture collected from a hydrocarbon reservoir (40), comprising the steps of:

receiving, via a riser (2), a hydrocarbon mixture at at least one floating hydrocarbon processing unit (1) that is moored to a seabed (21),

processing, on the floating hydrocarbon processing unit (1), to separate all of the received hydrocarbon mixture into an oil fraction, a water fraction, and a gas fraction,

storing the separated oil fraction of the mixture at or near ambient pressure in rectangular storage tanks (12) provided on the floating hydrocarbon processing unit (1),

exporting the separated gas fraction of the mixture from the floating hydrocarbon processing unit (1) to a gas storage buffer reservoir (7) placed at a certain distance from and isolated from the hydrocarbon reservoir (40) for temporary storage of the separated gas fraction of the mixture,

transferring the separated gas via a gas riser (8) from the gas storage buffer reservoir (7) to a floating gas processing unit (9),

in case of production interruption on either the floating hydrocarbon processing unit (1) or the floating gas processing unit (9), controlling, via the gas buffer reservoir serving as temporary storage of the produced gas, the gas flow between the floating hydrocarbon processing unit (1) and the floating gas processing unit (9) working in conjunction, with no interdependence between the activities of the hydrocarbon processing unit (1) and the gas processing unit (9),

processing the separated gas received from the gas storage buffer reservoir (7) on board the floating gas processing unit (9), and

transporting the processed separated gas to shore,

wherein the floating gas processing unit (9) comprises and uses a gas liquefaction plant (13) to process and store produced liquefied gas,

wherein at least one oil shuttle tanker (16) transports the separated oil from the floating hydrocarbon processing unit (1) in rectangular tanks at or near ambient pressure, and

wherein at least one LNG shuttle tanker (15) transports the produced liquefied gas, from the floating gas processing unit (9).

9. The method according to claim 8, wherein the floating gas processing unit (9) is separated with respect to the floating hydrocarbon processing unit (1).

10. The method according to claim 8, wherein the gas storage buffer reservoir (7) is an underground/subsurface reservoir isolated from the hydrocarbon reservoir (40).

11. The method according to claim 8, wherein the gas storage buffer reservoir (7) is a depleted well isolated from the hydrocarbon reservoir (40).

12. The method according to claim 8, wherein the gas storage buffer reservoir (7) is a salt cavern isolated from the hydrocarbon reservoir (40).

13. The method according to claim 8, wherein,

the gas storage buffer reservoir (7) is an undersea reservoir isolated from the hydrocarbon reservoir (40), and

a gas export riser (5) connected to the floating hydrocarbon processing unit (1) is used for introducing and temporarily storing the gas, separated from the received hydrocarbon mixture, in the gas storage buffer reservoir (7).

14. A method of receiving, processing and distributing a hydrocarbon mixture collected from a hydrocarbon reservoir, comprising the steps of:

using a floating liquefaction unit (9) in conjunction with a floating hydrocarbon processing unit (1) to separate oil and gas extracted from an underground hydrocarbon reservoir (40) and then inject, for temporary storage, the separated gas into a gas storage buffer reservoir (7) that is an undersea reservoir isolated from the underground hydrocarbon reservoir, including;

receiving, via a riser (2) feeding from the underground reservoir, a hydrocarbon mixture of the oil and the gas at the floating hydrocarbon processing unit,

processing the oil and the gas on the floating hydrocarbon processing unit to separate all of the received hydrocarbon mixture into an oil fraction, a water fraction, and a gas fraction,

storing the separated oil fraction of the mixture, at or near ambient pressure, in rectangular storage tanks (12) on the floating hydrocarbon processing unit and then using an oil shuttle tanker (16) to transport the separated oil fraction of the mixture from the floating hydrocarbon processing unit (1) in rectangular tanks at or near ambient pressure,

using a gas export riser (5) connected to the floating hydrocarbon processing unit (1), injecting and temporarily storing the separated gas fraction of the mixture into the gas storage buffer reservoir (7) for temporary storage of the separated gas fraction of the mixture,

transferring the temporarily stored separated gas, via a mobile gas riser (8), from the gas storage buffer reservoir (7) to a floating gas processing unit (9),

in case of production interruption on either the floating hydrocarbon processing unit (1) or the floating gas processing unit (9), controlling, via the gas buffer reservoir serving as a temporary buffer storage of the produced gas, the gas flow between the floating hydrocarbon processing unit (1) and the floating gas processing unit (9) working in conjunction, with no interdependence between the activities of the hydrocarbon processing unit (1) and the gas processing unit (9),

processing the separated gas received from the gas storage buffer reservoir (7) on board the floating gas processing unit (9) using a gas liquefaction plant (13) to process and store produced liquefied gas, and

transporting the processed separated gas to shore using a LNG shuttle tanker (15) to transport the produced liquefied gas from the floating gas processing unit (9).