Heating of Subsea Pipelines

Patent metadata

Field	Value
Publication number	US-2022018230-A1
Application number	US-201917299771-A
Country	US
Kind code	A1
Filing date	Dec 3, 2019
Priority date	Dec 4, 2018
Publication date	Jan 20, 2022
Grant date	—

Abstract

A technique mitigates or removes a plug of solid-state material such as wax or hydrate coalesced from hydrocarbon fluids in a subsea flowline pipe. In a normal flow mode, a flow of hot production fluids directed from a subsea well into a production flowline pipe extending toward a processing or storage location. Simultaneously, a contra-flow of service fluid such as monoethylene glycol (MEG) is transported along a service fluid pipe extending along and adjacent the production flowline pipe. The service fluid is injected into the well or flow of production fluid upstream of the flowline pipe. On determining plugging or a risk of plugging of the flowline pipe, a heating mode is activated wherein at least some of the flow of the production fluid is diverted into the service fluid pipe. This heats the service fluid pipe which, in turn, heats the flowline pipe to disperse the solid-state material.

First claim

1 - 29 . (canceled)

30 . A method of maintaining production of hydrocarbon fluids subsea comprises:
directing a flow of hot production fluid from a subsea well into at least one production flowline pipe that extends toward a processing or storage location; in a first mode of operation, transporting a flow of service fluid from a source of the service fluid along at least one service fluid pipe that extends along and adjacent to the production flowline pipe and, at least intermittently, injecting the service fluid from the service fluid pipe into the well or into the flow of production fluid upstream of the flowline pipe; and in a second mode of operation, diverting at least some of the flow of the production fluid into the service fluid pipe to apply heat from the production fluid to the service fluid pipe, and transferring the heat from the service fluid pipe to the flowline pipe.

31 . The method of claim 30 , further comprising directing the production fluid from the service fluid pipe to the processing or storage location after the production fluid has flowed along the service fluid pipe.

32 . The method of claim 31 , comprising directing the production fluid from the service fluid pipe to the processing or storage location in response to progress of an interface between the service fluid and the production fluid in the service fluid pipe.

33 . The method of claim 30 , comprising displacing the service fluid from the service fluid pipe by the production fluid flowing into the service fluid pipe.

34 . The method of claim 33 , comprising recovering the service fluid displaced from the service fluid pipe back to the source of the service fluid.

35 . The method of claim 30 , comprising diverting at least some of the flow of the production fluid into the service fluid pipe in response to plugging or expected plugging of the flowline pipe.

36 . The method of claim 35 , comprising diverting at least sonic of the flow of the production fluid into the service fluid pipe in response to shutdown or impending shutdown of the flowline pipe.

37 . The method of claim 35 , comprising diverting at least some of the flow of the production fluid into the service fluid pipe in response to temperature or flowrate of the production fluid in the flowline pipe falling below a threshold value.

38 . The method of claim 30 , further comprising stopping diversion of the flow of the production fluid into the service fluid pipe and directing all of the flow of the production fluid into the at least one flowline pipe.

39 . The method of claim 38 , comprising stopping diversion of the flow of the production fluid in response to temperature or flowrate of the production fluid in the flowline pipe exceeding a threshold value.

40 . The method of claim 38 , comprising flushing the production fluid from the service fluid pipe with the service fluid.

41 . The method of claim 40 , comprising injecting the flushed production fluid from the service fluid pipe into the well or into the flow of production fluid upstream of the flowline pipe.

42 . The method of claim 30 , comprising transferring the heat from the service fluid pipe to the flowline pipe within a thermally insulated enclosure that surrounds the service fluid pipe and the flowline pipe.

43 . A subsea hydrocarbon production system, comprising:
at least one production flowline pipe for transporting a flow of hot production fluid from a subsea well toward a processing or storage location; at least one service fluid pipe extending along and adjacent to the production flowline pipe for transporting a service fluid from a source of the service fluid toward an injection point upstream of the flowline pipe; and a flow diverter upstream of the flowline pipe, the flow diverter being configured selectively to divert at least some of the flow of production fluid into the service fluid pipe to apply heat to the flowline pipe via the service fluid pipe.

44 . The system of claim 43 , wherein the flowline pipe and the service fluid pipe are disposed within, and share, a thermally insulated enclosure.

45 . The system of claim 44 , wherein the enclosure comprises a thermally insulating material that encapsulates the flowline pipe and the service fluid pipe.

46 . The system of claim 44 , wherein the enclosure comprises an outer pipe that surrounds the flowline pipe and the service fluid pipe.

47 . The system of claim 44 , wherein the enclosure contains a fluid in thermally transmitting contact with the flowline pipe and the service fluid pipe.

48 . The system of claim 43 , further comprising a recovery system between the service fluid pipe and the source of the service fluid for recovering the production fluid from the service fluid pipe.

49 . The system of claim 48 , wherein the recovery system comprises a cross-over path for diverting production fluid from the service fluid pipe toward the processing or storage location.

50 . The system of claim 49 , further comprising a valve between the cross-over path and the source of the service fluid, the valve being configured to prevent production fluid from the service fluid pipe flowing to the source.

51 . The system of claim 50 , wherein the valve is switchable to allow service fluid displaced from the service fluid pipe by the production fluid to return to the source.

52 . The system of claim 43 , further comprising a controller that is programmed to activate the flow diverter in response to plugging or expected plugging of the flowline pipe.

53 . The system of claim 52 , wherein the controller is programmed to activate the flow diverter in response to shutdown or impending shutdown of the flowline pipe.

54 . The system of claim 52 , wherein the controller is programmed to activate the flow diverter in response to temperature or flowrate of the production fluid in the flowline pipe falling below a threshold value.

55 . The system of claim 52 , wherein the controller is programmed to deactivate the flow diverter in response to temperature or flowrate of the production fluid in the flowline pipe exceeding a threshold value.

56 . The system of claim 43 , wherein the flow diverter is located in a subsea wellhead or manifold upstream of the flowline pipe.

57 . The system of claim 43 , wherein the source of the service fluid and the processing or storage location are situated on a surface installation.

58 . The system of claim 43 , wherein the flowline pipe and the service fluid pipe are laid on the seabed.

Assignees

• Subsea 7 Norway As

Inventors

• Pakkan Meric
• Moi Per

Classifications

• F17D1/18

  by heating · CPC title

• F16L11/08

  with reinforcements embedded in the wall (F16L11/11 takes precedence) · CPC title

• F16L53/32 Primary

  using hot fluids · CPC title

• E21B43/24 Primary

  using heat, e.g. steam injection · CPC title

• E21B43/01

  specially adapted for obtaining from underwater installations · CPC title