NO20161036A1 - Method and system for temperature management of a well fluid stream in a subsea pipeline - Google Patents
Method and system for temperature management of a well fluid stream in a subsea pipeline Download PDFInfo
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- NO20161036A1 NO20161036A1 NO20161036A NO20161036A NO20161036A1 NO 20161036 A1 NO20161036 A1 NO 20161036A1 NO 20161036 A NO20161036 A NO 20161036A NO 20161036 A NO20161036 A NO 20161036A NO 20161036 A1 NO20161036 A1 NO 20161036A1
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- Norway
- Prior art keywords
- well fluid
- heat
- pipeline
- converter
- fluid
- Prior art date
Links
- 239000012530 fluid Substances 0.000 title claims abstract description 77
- 238000000034 method Methods 0.000 title claims abstract description 21
- 238000004519 manufacturing process Methods 0.000 claims abstract description 19
- 239000013535 sea water Substances 0.000 claims abstract description 13
- 238000011144 upstream manufacturing Methods 0.000 claims abstract description 13
- 238000001556 precipitation Methods 0.000 claims abstract description 11
- 239000007787 solid Substances 0.000 claims abstract description 11
- 238000000605 extraction Methods 0.000 claims abstract description 5
- 239000000126 substance Substances 0.000 claims description 9
- 229930195733 hydrocarbon Natural products 0.000 claims description 7
- 150000002430 hydrocarbons Chemical class 0.000 claims description 7
- 239000004215 Carbon black (E152) Substances 0.000 claims description 6
- 239000003507 refrigerant Substances 0.000 claims description 2
- 239000012071 phase Substances 0.000 description 6
- 239000010426 asphalt Substances 0.000 description 5
- 230000015572 biosynthetic process Effects 0.000 description 5
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 4
- 238000010586 diagram Methods 0.000 description 3
- 230000000694 effects Effects 0.000 description 3
- 230000005611 electricity Effects 0.000 description 3
- 150000004677 hydrates Chemical class 0.000 description 3
- 239000007924 injection Substances 0.000 description 3
- 238000002347 injection Methods 0.000 description 3
- 241000196324 Embryophyta Species 0.000 description 2
- OFBQJSOFQDEBGM-UHFFFAOYSA-N Pentane Chemical group CCCCC OFBQJSOFQDEBGM-UHFFFAOYSA-N 0.000 description 2
- 238000009835 boiling Methods 0.000 description 2
- 238000006243 chemical reaction Methods 0.000 description 2
- 239000003112 inhibitor Substances 0.000 description 2
- 239000007791 liquid phase Substances 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 241000183024 Populus tremula Species 0.000 description 1
- 230000002528 anti-freeze Effects 0.000 description 1
- 230000033228 biological regulation Effects 0.000 description 1
- 238000010924 continuous production Methods 0.000 description 1
- 230000008021 deposition Effects 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
- 230000008014 freezing Effects 0.000 description 1
- 238000007710 freezing Methods 0.000 description 1
- 239000007789 gas Substances 0.000 description 1
- 230000017525 heat dissipation Effects 0.000 description 1
- 238000010438 heat treatment Methods 0.000 description 1
- 238000009413 insulation Methods 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 230000008018 melting Effects 0.000 description 1
- 238000002844 melting Methods 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 230000000737 periodic effect Effects 0.000 description 1
- 239000002244 precipitate Substances 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 230000000284 resting effect Effects 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 238000009834 vaporization Methods 0.000 description 1
Classifications
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
- F16L—PIPES; JOINTS OR FITTINGS FOR PIPES; SUPPORTS FOR PIPES, CABLES OR PROTECTIVE TUBING; MEANS FOR THERMAL INSULATION IN GENERAL
- F16L53/00—Heating of pipes or pipe systems; Cooling of pipes or pipe systems
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
Landscapes
- Engineering & Computer Science (AREA)
- General Engineering & Computer Science (AREA)
- Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Mechanical Engineering (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Pipeline Systems (AREA)
Abstract
A method for preserving well fluid above solids precipitation temperature during transport in a subsea pipeline is disclosed. The method comprises lowering (T1-T2) the temperature difference between the well fluid and the ambient seawater by extraction of heat from the well fluid at an upstream location (6) of the pipeline near the production well, and raising (T3-T4) the temperature difference between the well fluid and the ambient seawater by returning heat to the well fluid at a downstream location (12) of the pipeline before the well fluid reaches the solids precipitation temperature.A method for preserving well fluid above solids precipitation temperature during transport in a subsea pipeline is disclosed. The method comprises lowering (T1-T2) the temperature difference between the well fluid and the ambient seawater by extraction of heat from the well fluid at an upstream location (6) of the pipeline near the production well, and raising (T3-T4) the temperature difference between the well fluid and the ambient seawater by returning heat to the well fluid at a downstream location (12) of the pipeline before the well fluid reaches the solids precipitation temperature.
Description
Method and system for temperature management of a well fluid stream in a subsea pipeline
TECHNICAL FIELD OF THE INVENTION
The present invention relates generally to hydrocarbon flow processes. In particular, the invention relates to a method and a system for subsea pipeline heating and heat management of well fluid to allow long distance transportation subsea.
BACKGROUND AND PRIOR ART
In subsea pipelines, heat is continually lost from the stream of production fluid to the surrounding seawater. In typical subsea systems, where downhole fluid temperature seldom exceeds 200 °C, heat loss from pipelines is mainly caused by heat conduction through the pipeline wall and by convection between the internal production fluid and pipe wall as well as convection between the pipe and the surrounding seawater. The amount of heat loss will be driven by the temperature difference between the internal production fluid and surrounding seawater. The rate in heat loss is therefore at its highest near the well, where the temperature difference is the greatest.
If the temperature of the production fluid falls below a certain level, heavier components such as wax and asphalt will begin to precipitate. These heavy components will typically deposit on the cooler pipe walls, and can cause blockage of the pipeline if untreated. Also gaseous production fluids face a similar issue. If there is water present in natural gas, the water will combine with hydrocarbons to form a hydrate when the temperature reaches the critical level, i.e. the hydrate formation temperature. If hydrates are formed, they may lead to complete blockage of the pipeline if untreated.
In practise there is not one certain temperature at which hydrates, wax and asphalt precipitate and deposit on the walls of a pipeline. The critical temperature is rather a range resulting from local conditions and, e.g., variations in fluid composition, phases, pressure and water cut, e.g..
Traditional methods for avoiding the formation of hydrate and precipitation of wax or asphalt in subsea pipelines include:
● Electric heat tracing: resistive heaters or cables are built into the pipeline along its entire length. Electric current, supplied from a central location, is passed through these elements to generate heat. The method requires a specially designed pipe;
● Chemical injection: inhibitor or antifreeze chemicals are injected into the production fluid to lower the wax appearance temperature and thus prevent formation of heavier elements in the production fluid. The chemicals are then typically extracted at the exit of the pipeline and recycled. Both the injection and the extraction requires chemical plant equipment;
● Periodic pigging: a mechanical plug, either self-propelled or driven by the flow in the pipeline, is placed in the pipeline where it mechanically scrapes any deposits off the pipeline wall. After travelling the length of the pipeline, the pig is extracted and recovered at the other end;
● Pipe-in-pipe solutions wherein heated water is fed internally through the pipeline to heat the well stream.
SUMMARY OF THE INVENTION
It is a general object of the present invention to provide an alternative method for preventing the precipitation and formation of solids in well fluid under transport in a subsea pipeline.
It is a special object of the present invention to provide a method and system arranged to slow down the rate of heat loss from well fluid to seawater, and simultaneously taking advantage of the latent thermal energy in the well fluid near the well.
The object is met in a method comprising:
● lowering the temperature difference between the well fluid and the ambient seawater by extraction of heat from the well fluid at an upstream location of the pipeline near the production well,
● raising the temperature difference between the well fluid and the ambient seawater by returning heat to the well fluid at a downstream location of the pipeline before the well fluid reaches solids precipitation temperature.
The expression “solids precipitation temperature” as used herein shall be interpreted as referring to a fluid temperature within a range of 0-40 °C, above which the occurrence of solid elements such as wax, asphalt or hydrates can be essentially avoided.
Assuming a downhole fluid temperature of about 100-200 °C, which is typical in most cases, the temperature of the produced fluid upon discharge from the well will typically range from about 100 °C, or somewhat lower, to about 180-190 °C. The potential in heat recovery can thus be compared to a temperature reduction in the order of about 50-150 °C, assuming a residual temperature in the well fluid of at least about 40 °C.
The step of lowering the temperature difference between well fluid and the ambient seawater comprises conversion of thermal energy into electrical or chemical energy at the upstream location, and conversion of the electrical or chemical energy into heat at the downstream location. The heat that is extracted at the upstream location can be returned portion-wise to the well fluid at separate downstream locations.
In a preferred embodiment, the method comprises operation of an electrical generator by means of a turbine included in a closed Rankine cycle system. The closed system advantageously includes circulation of an organic or hydrocarbon phase change medium to drive the turbine.
The step of returning heat to the well fluid at the downstream location preferably includes the operation of a resistive heater element in heat transferring contact with the well fluid. The step of returning heat to the well fluid may alternatively include operation of a heat pump on electricity generated at the upstream location.
In the system aspect, the object of the invention is met in a system comprising ● a first converter of thermal energy connected to a subsea pipeline at an upstream location near a production well, the first converter arranged to extract heat from the well fluid at the upstream location,
● a second converter of thermal energy connected to the first converter and to the subsea pipeline at a downstream location, the second converter arranged to deliver heat to the well fluid at said downstream location.
In a preferred realization of the invention, the first converter is an electrical generator driven by a closed Rankine cycle system comprising a pump, a heat exchanger, a turbine and a condenser.
The Rankine cycle is advantageously operated on an organic refrigerant or hydrocarbon fluid. A suitable phase change fluid for this purpose has a low boiling point, a high heat of vaporisation and a freezing point that lies below the temperature of the ambient seawater. A potential candidate is n-Pentane (C5H12), e.g., which has a boiling point of approximately 36 °C and a melting point of approximately -130 °C, depending on conditions.
The second converter may be a resistive heater element which is powered by the generator. The second converter may alternatively be a heat pump powered by the generator.
SHORT DESCRIPTION OF THE DRAWINGS
Embodiments of the invention will be further explained below with reference made to the drawings, wherein
Fig. 1 is a schematic view of a system arranged for implementation of the method of the present invention, and
Fig. 2 is a dimensionless diagram illustrating the development of temperature in a well fluid stream that passes the system of Fig. 1.
DETAILED DESCRIPTION OF PREFERRED EMBODIMENTS
With reference to Fig. 1, a subsea pipeline 1 has an upstream end 2 arranged to receive a stream of production fluid at a hydrocarbon production site. The pipeline 1 can be connected to a singular well 3, or to a well template 4 grouping a set of wells, or to a manifold 5 collecting the well fluid streams from a number of distributed wells. The pipeline 1, which is resting on the seafloor, can have a length of several kilometres to effect transport of well fluid from the production site to a receiving facility on the seafloor, on land, or at the surface of the sea.
A short distance downstream of its receiving end 2 the pipeline 1 passes a heatsink station 6 arranged to effect a substantial reduction of the temperature in the well fluid (see also the temp vs. distance diagram of Fig. 2). In particular, the heat sink station 6 comprises a heat exchanger or boiler 7 in which heat is transferred from the well fluid to a phase change medium that is circulated in a closed Rankine cycle system. The phase change medium is vaporized in the boiler 7, expanded in a turbine 8, returned to liquid phase in a condenser 9 from where the medium is returned to the boiler as liquid by means of a pump or compressor 10.
The turbine 8 is drivingly connected to an electrical generator 11. The heatsink 6 and the electrical generator 11 in combination constitute a first converter 6-11 which converts thermal energy in the well fluid to electricity. A portion of the latent thermal energy in the well fluid is this way preserved and prevented from dissipation into the sea. The recovered heat is converted into an energy form that is suitable for distribution within the subsea system.
In this connection it can be pointed out the heatsink and first converter 6-11 shall be located near the well, advantageously as close to the well as is practically possible, in order to take full advantage of the thermal energy in the well fluid before it is cooled by the sea. Without restricting the scope of the invention thereto, and as a general advice only, the location of the heatsink and first converter 6-11, and thus the point of extraction of heat from the well fluid, may be positioned preferably within about 0.5 km from a well, or from a well template or a manifold, e.g.
According to the present invention, the heat recovered by the first converter 6-11 is returned to the well fluid at a downstream location by means of a second converter 12. The second converter may alternatively be realized as a resistive heater element 13. One embodiment of the invention particularly foresees the arrangement of two or more second converters 12arranged in succession at separate downstream locations along the pipeline for a portion-wise return of the heat recovered by the first converter 6-11 at said upstream location of the pipeline. The second converter may be realized as a heat pump (not shown) which is driven by the electricity generated by the first converter 6-11.
It will be understood that the choice of phase change fluid and dimensioning of components and volumes in the Rankine cycle system are tasks that require consideration of case specific parameters. Some of the considerations which require numerical solving are, e.g., mass and energy balance, heat transfer, pressure and pressure drops, mechanical losses, leakage etc. Several commercial tools are however available to the skilled person to carry out the necessary calculation, such as the software products sold under registered tradenames like MATLAB, Aspen HYSYS or Scilab, just to mention a few.
As preferred, the effect of the heatsink 6 or first converter 6-11 is controlled to lower the temperature in the well fluid down to a minimum residual temperature of at least about 40 °C at the upstream location. Return of heat to the well fluid, in other words the second converter 12, is initiated at a distance along the pipeline 1 where the well fluid temperature is still above the solids precipitation temperature as predicted in the specific case, or at least above the temperature of the seawater. At this point, the second converter can be controlled to raise the temperature in the well fluid to about 40 °C at least.
It shall be pointed out that the preferred location of the second converter 12 needs to be determined in each specific case, and that the distance from the heatsink and first converter 6-11 to the second converter 12 can vary within wide limits depending on local conditions. Without restricting the scope of the invention thereto, and as a general advice only, the location of the second converter 12, and thus the point of return of heat to the well fluid, may be positioned within about 0.5 to 5 km from the heatsink and first converter 6-11.
The management of temperature in production well fluid with application of the disclosed invention is illustrated in the diagram of Fig. 2. Heat is removed from the well fluid at the start of the pipeline, preferably at a distance within a few tenths of metres from a pipeline end termination assembly. Upon passage of the heatsink 6, the well fluid temperature is lowered from T1 to T2. From T2 onwards, the rate of temperature decrease is lower than would have been the case if no measures were taken to slow down the heat dissipation (compare the dashed curve that symbolizes the temperature development in well fluid when not subjected to a temperature regulation as taught by the present invention). As the temperature reaches a certain point above the solids precipitation temperature, which will be specific to the subject system, heat is applied at T3 until the temperature reaches a new maximum at T4. From T4 onwards the temperature will again decrease along a temperature curve corresponding to the flack curve between T2 and T3.
In aim for improved efficiency, the system can be modified by introduction of a regenerator in the closed Rankine cycle. This regenerator can be realized in the form of a counter-current heat exchanger wherein the liquid phase of the medium is pre-heated by expanded gas from the turbine/expander before entering the boiler.
The invention provides several technical and commercial advantages:
● Controlled production fluid temperature resulting in essentially no risk of wax or asphalt deposition or hydrate formation
● Energy savings: heat in production fluid is efficiently utilized for long distance transport
● Allows the use of standard pipeline (i.e. no heat tracing or insulation needed) ● Allows continuous production with no halts for pipeline pigging
● Eliminates the need for inhibitor (MEG) injection and chemical plant.
Claims (12)
1. A method for preserving well fluid above solids precipitation temperature during transport in a subsea pipeline (1), the method comprising:
- lowering (T1-T2) the temperature difference between the well fluid and the ambient seawater by extraction of heat from the well fluid at an upstream location (6) of the pipeline near the production well,
- raising (T3-T4) the temperature difference between the well fluid and the ambient seawater by returning heat to the well fluid at a downstream location (12) of the pipeline before the well fluid reaches solids precipitation temperature.
2. The method of claim 1 further comprising:
- converting (6-11) thermal energy recovered near the production well into electrical or chemical energy, and
- converting (12, 13) the electrical or chemical energy into heat at the downstream location.
3. The method of claim 2, comprising operation of an electrical generator (11) by means of a turbine (8) included in a closed Rankine cycle system also comprising a pump (10), a heat exchanger (7) and a condenser (9).
4. The method of claim 3, comprising circulation of an organic fluid or hydrocarbon fluid through the Rankine cycle system.
5. The method of any previous claim, comprising returning the extracted heat portion-wise to the well fluid at separate downstream locations.
6. The method of any previous claim, comprising operation of a resistive heater element (13) in heat transferring contact with the well fluid at said downstream location.
7. The method of any previous claim, comprising a temperature reduction in well fluid in the order of about 50-150 °C, or down to a residual temperature of at least about 40 °C.
8. A system for preserving well fluid above solids precipitation temperature during transport in a subsea pipeline (1), the system comprising:
- a first converter (6-11) of thermal energy connected to the pipeline at an upstream location near the production well, the first converter arranged to extract heat from the well fluid at the upstream location,
- a second converter (12) of thermal energy connected to the first converter and to the pipeline at a downstream location of the pipeline, the second converter arranged to deliver heat to the well fluid at said downstream location.
9. The system of claim 8, wherein the first converter is an electrical generator (11) operatively coupled to a gas turbine (8) of a closed Rankine cycle system further comprising a pump (10), a heat exchanger (7) and a condenser (9).
10. The system of claim 9, wherein the Rankine cycle operates on an organic refrigerant or hydrocarbon fluid.
11. The system of any of claims 8-10, wherein said second converter (12) comprises a resistive heater element (13) or a heat pump.
12. The system of any of claims 8-11, wherein the first converter (6-11) is electrically connected to at least two second converters (12) arranged in succession at separate downstream locations along the pipeline.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| NO20161036A NO342129B1 (en) | 2016-06-17 | 2016-06-17 | Method and system for temperature management of a well fluid stream in a subsea pipeline |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| NO20161036A NO342129B1 (en) | 2016-06-17 | 2016-06-17 | Method and system for temperature management of a well fluid stream in a subsea pipeline |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| NO20161036A1 true NO20161036A1 (en) | 2017-12-18 |
| NO342129B1 NO342129B1 (en) | 2018-03-26 |
Family
ID=60997136
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| NO20161036A NO342129B1 (en) | 2016-06-17 | 2016-06-17 | Method and system for temperature management of a well fluid stream in a subsea pipeline |
Country Status (1)
| Country | Link |
|---|---|
| NO (1) | NO342129B1 (en) |
Citations (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| EP0485220A1 (en) * | 1990-11-07 | 1992-05-13 | Petroleo Brasileiro S.A. - Petrobras | Electrical heating system for subsea flexible pipelines |
| US5803161A (en) * | 1996-09-04 | 1998-09-08 | The Babcock & Wilcox Company | Heat pipe heat exchanger for cooling or heating high temperature/high-pressure sub-sea well streams |
| WO2008032067A1 (en) * | 2006-09-14 | 2008-03-20 | Halliburton Energy Services, Inc. | Methods and compositions for thermally treating a conduit used for hydrocarbon production or transmission to help remove paraffin wax buildup |
| WO2010110676A2 (en) * | 2009-03-27 | 2010-09-30 | Framo Engineering As | Subsea cooler and method for cleaning the subsea cooler |
| WO2014003575A1 (en) * | 2012-06-26 | 2014-01-03 | Aker Subsea As | Cooling system for subsea elements |
| EP2725206A2 (en) * | 2012-10-25 | 2014-04-30 | General Electric Company | System and method for generating electric power |
| EP2781688A1 (en) * | 2013-03-18 | 2014-09-24 | Vetco Gray Scandinavia AS | Pipe assembly and flow assurance system |
| WO2015144693A1 (en) * | 2014-03-25 | 2015-10-01 | Vetco Gray Scandinavia As | A subsea heat exchanger arrangement and a method for improving heat dissipating efficiency in a subsea heat exchanger |
| WO2016009220A2 (en) * | 2014-07-18 | 2016-01-21 | Tullow Group Services Limited | A hydrocarbon heating system |
-
2016
- 2016-06-17 NO NO20161036A patent/NO342129B1/en not_active IP Right Cessation
Patent Citations (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| EP0485220A1 (en) * | 1990-11-07 | 1992-05-13 | Petroleo Brasileiro S.A. - Petrobras | Electrical heating system for subsea flexible pipelines |
| US5803161A (en) * | 1996-09-04 | 1998-09-08 | The Babcock & Wilcox Company | Heat pipe heat exchanger for cooling or heating high temperature/high-pressure sub-sea well streams |
| WO2008032067A1 (en) * | 2006-09-14 | 2008-03-20 | Halliburton Energy Services, Inc. | Methods and compositions for thermally treating a conduit used for hydrocarbon production or transmission to help remove paraffin wax buildup |
| WO2010110676A2 (en) * | 2009-03-27 | 2010-09-30 | Framo Engineering As | Subsea cooler and method for cleaning the subsea cooler |
| WO2014003575A1 (en) * | 2012-06-26 | 2014-01-03 | Aker Subsea As | Cooling system for subsea elements |
| EP2725206A2 (en) * | 2012-10-25 | 2014-04-30 | General Electric Company | System and method for generating electric power |
| EP2781688A1 (en) * | 2013-03-18 | 2014-09-24 | Vetco Gray Scandinavia AS | Pipe assembly and flow assurance system |
| WO2015144693A1 (en) * | 2014-03-25 | 2015-10-01 | Vetco Gray Scandinavia As | A subsea heat exchanger arrangement and a method for improving heat dissipating efficiency in a subsea heat exchanger |
| WO2016009220A2 (en) * | 2014-07-18 | 2016-01-21 | Tullow Group Services Limited | A hydrocarbon heating system |
Also Published As
| Publication number | Publication date |
|---|---|
| NO342129B1 (en) | 2018-03-26 |
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