Patent Application
20100000251
The present invention relates to a method of liquefying a hydrocarbon stream such as a natural gas stream.
Several methods of liquefying a natural gas stream thereby obtaining liquefied natural gas (LNG) are known. It is desirable to liquefy a natural gas stream for a number of reasons. As an example, natural gas can be stored and transported over long distances more readily as a liquid than in gaseous form, because it occupies a smaller volume and does not need to be stored at high pressures.
Usually, the natural gas stream to be liquefied (mainly comprising methane) contains ethane, heavier hydrocarbons and possibly other components that are to be removed to a certain extent before the natural gas is liquefied. To this end, the natural gas stream is treated. One of the treatments may involve the removal of undesired components such as H2O, CO2 and H2S and some of the ethane, propane and higher hydrocarbons such as butane and pentane.
In WO 2006/009646 A2 a method is disclosed for liquefying natural gas. In
A problem of the known method is that, if at the place where the natural gas is treated and liquefied no easy access exist for ships or vessels intended for transporting the LNG to remote markets, the LNG has to be transported via a pipeline to a remote port first. This is highly undesirable in view of the high costs for cryogenic pipelines.
It is an object of the invention to minimize the above problem.
It is a further object of the present invention to provide an alternative method for liquefying a hydrocarbon stream such as a natural gas stream, in particular under very cold conditions such as those that are encountered in the Arctic region.
One or more of the above or other objects are achieved according to the present invention by providing a method of liquefying a hydrocarbon stream such as natural gas, the method at least comprising the steps of:
An advantage of the present invention is that the liquefied hydrocarbon product can be easily transported from the second location using a transportation vessel, as the second location is situated off-shore. Thus, no liquefied hydrocarbon product, in particular LNG, has to be transported over long distances via a pipeline.
Another advantage is that less equipment is needed in both locations; this enables liquefying a hydrocarbon stream even when limited plot space is available onshore and/or off-shore.
Yet another advantage is that, in particular if the method of the present invention is applied in very cold regions such as the Arctic, use can be made of the cold ambient whereby the treated hydrocarbon stream can be cooled to a certain extent before the actual liquefaction takes place. This may result in a reduced CAPEX (capital expenses) for the liquefaction equipment.
The first and second locations are not limited to include only a single process or treating unit but are rather intended to include a plant site containing one or more process units. The first and second locations are at a distance of at least 2 km from each other, preferably at least 5 km, more preferably at least 10 km. The distance may be longer than 1000 km but is preferably less than 900 km.
The first location is usually situated near a site where the hydrocarbon stream to be treated and liquefied is produced, such as a natural gas or a petroleum reservoir. On the first location one or more treating units are located. These treating units may include conventional treating units such as a slug catcher, a condensate stabilizer, acid gas removal (AGR) units, dehydration units, sulphur recovery units (SRU), mercury removal units, nitrogen rejection units (NRU), helium recovery units (HRU), hydrocarbon dewpoint units, etc. Also fractionation or extraction units for recovery of e.g. C3/C4 liquid petroleum gas (LPG) and C5+ liquid (condensate) may be present on the first location. As these treating units as such are well known to the person skilled in the art, they are not further discussed here.
The second location is usually situated near an LNG export terminal from where the liquefied natural gas is shipped or otherwise transported to the desired markets. On the second location at least a liquefaction plant is present to obtain a liquefied hydrocarbon product. If desired, also some of the treating units mentioned in respect of the first location may be present at the second location. However, preferably as few treating units as possible are located at the second location. Herewith the amount of handling (and thereby the presence of workpeople) near the liquefaction plant can be minimized. Furthermore, the plot space on the second location is minimised.
The hydrocarbon stream may be any suitable gas stream to be treated and liquefied, but is usually a natural gas stream produced at and obtained from natural gas or petroleum reservoirs. As an alternative the natural gas stream may also be obtained from another source, also including a synthetic source such as a Fischer-Tropsch process wherein methane is produced from synthesis gas.
Usually the natural gas is comprised substantially of methane. Preferably the feed stream comprises at least 60 mol % methane, more preferably at least 80 mol % methane.
Depending on the source, the natural gas may contain varying amounts of hydrocarbons heavier than methane such as ethane, propane, butanes and pentanes as well as some aromatic hydrocarbons. The natural gas may also contain non-hydrocarbons such as H2O, N2, CO2, H2S and other sulphur compounds, and the like.
According to preferred embodiment, the treating in step (b) at least comprises removal of CO2, preferably such that the treated hydrocarbon stream comprises less than 500 ppm CO2, more preferably less than 200 ppm CO2, even more preferably less than 50 ppm CO2. It is especially preferred that no CO2 removal takes place at the second location.
Further it is preferred that the treating in step (b) at least comprises removal of H2O, preferably such that the treated hydrocarbon stream comprises less than 100 ppm H2O, more preferably less than 10 ppm H2O, even more preferably less than 1 ppm H2O.
In addition it is preferred that the treating in step (b) comprises removal of mercury (Hg).
Preferably, the treated hydrocarbon stream to be liquefied comprises at least 70 mole % of methane, more preferably at least 80 mole %. Preferably, the treated hydrocarbon stream to be liquefied comprises less than 5 mole % of C5+ hydrocarbons, meaning pentanes and heavier hydrocarbons.
Preferably the treated hydrocarbon stream is compressed before transporting in step (c), preferably to a pressure above 50 bar, more preferably above 60 bar, still more preferably above 70 bar. It is especially preferred that the treated hydrocarbon stream is transported in a state being substantially above the critical point. In this way, the treated hydrocarbon stream can be transported in substantially a dense phase.
According to an especially preferred embodiment of the present invention, the treated hydrocarbon stream is cooled during transporting by heat exchanging against the ambient. Preferably, the treated hydrocarbon stream is cooled to a temperature <10° C., preferably <0° C., more preferably <−10° C. before it reaches the second location. Herewith the cooling duty in the liquefaction plant at the second location can be significantly decreased. It is desirable that the distance between the first and second location is such that the treated hydrocarbon stream is cooled as much as possible, preferably reaching ambient temperatures, if it is transported via a pipeline that is substantially not thermally insulated. Herewith, full advantage of cold ambient conditions may be used, in particular if the pipeline is in a cold area such as in Arctic regions. It is believed that this can be achieved when the distance between the first and second location is more than 2 km, preferably more than 5 km, still more preferably more than 10 km.
In step (d) the treated hydrocarbon stream is liquefied. Suitably, this is done using one or more refrigerants. The refrigerants may be produced in the second location or may be produced elsewhere and transported to the second location. Preferably, the refrigerants needed for liquefying the treated hydrocarbon stream are produced in a location that is geographically removed from the second location where liquefaction takes place. Preferably the distance between the location where the refrigerants are produced and the second location is more than 2 km, more preferably more than 5 km.
In one preferred embodiment, a mixed refrigerant comprising at least two refrigerants is used and the refrigerants are transported to the second location via separate pipelines for each of the pure component refrigerants that make up the mixed refrigerant as used in the liquefaction process. This solution offers the simplest line-up operation-wise for the supply and make-up of the required refrigerants.
In another embodiment, a mixed refrigerant comprising at least two refrigerants is used and the different pure component refrigerants are delivered pre-mixed via a common pipeline. The advantage of this embodiment is the elimination of the other pipelines that would otherwise be required to transport the different refrigerant components separately.
In yet another embodiment, a mixed refrigerant comprising at least two refrigerants is used and the different pure refrigerant components are delivered to the second location via a single pipeline in successive plug-flows. The advantage is that there is no need for a fractionation column at the second location to separate the mixed refrigerants.
In another embodiment, refrigerant is supplied to the second location via pipelines and the refrigerant supply pipelines are used as storage vessels to eliminate (or reduce) storage of the refrigerants at the second location. This further reduces the plot space needed at the second location.
The refrigerant is used to cool down the treated hydrocarbon stream to less than −140° C., preferably less than −150° C. The cooling step is followed by expansion to atmospheric pressure. The liquefied hydrocarbon product is obtained at atmospheric pressure.
After liquefaction the liquefied hydrocarbon product is usually transported and regasified. The transportation of the liquefied hydrocarbon product such as LNG is usually performed by shipping. Regasification is usually done at e.g. an LNG import terminal that may be onshore or offshore.
The person skilled in the art will readily understand that after liquefaction, the liquefied hydrocarbon product may be further processed before transporting, if desired.
In a further aspect the present invention provides an apparatus for liquefying a hydrocarbon stream such as a natural gas stream, the apparatus at least comprising:
Preferably one of the treating units at the first location is adapted for removal of CO2. Further it is preferred that no CO2 removal from the treated hydrocarbon stream takes place at the second location. Also it is preferred that one of the treating units at the first location is adapted for removal of H2O.
Usually the apparatus according to the present invention further comprises a compressor for compressing the treated hydrocarbon stream at the first location, preferably to a pressure above 50 bar, preferably above 60 bar, more preferably above 70 bar.
According to an especially preferred embodiment the pipeline is substantially not thermally insulated. This enables cooling of the treated hydrocarbon stream against the ambient during transport from the first to the second location. If the transport takes place in a cold environment such as the Arctic region, use of the cold ambient can be made.
Hereinafter the invention will be further illustrated by the following non-limiting drawing. Herein shows:
For the purpose of this description, a single reference number will be assigned to a line as well as a stream carried in that line. Same reference numbers refer to similar components.
The process scheme of
In the embodiment of
The second location 3 is usually situated near an LNG export terminal from where the produced liquefied natural gas is shipped or otherwise transported to the desired markets. The second location is on a distance from the first location of at least 2 km, and may be as high as 900 km. On the second location 3 at least a liquefaction plant 21 is present to obtain LNG.
If desired, also some of the treating units mentioned in respect of the first location 2 may be present at the second location 3. In the embodiment of
During use of the process scheme shown in
Stream 20 is subsequently transported via pipeline 4 to the second location 3. The pipeline may be above or under the ground, or surrounded by sea water. In particular if the pipeline 4 is in a cold area, such as the Arctic region, it is preferred that the pipeline 4 is substantially not thermally insulated from the ambient such that the treated stream 20 is cooled against the ambient. To this end, the pipeline 4 may be substantially made from low temperature resistant carbon steel. Preferably, the treated stream 20 is cooled during transport in the pipeline 4 to a temperature <10° C., preferably <0° C., more preferably <−10° C. before it reaches the second location 3. Of course, the amount of cooling in the pipeline will depend on various factors such as the ambient temperature, the length of the pipeline 4 and the materials used in the pipeline 4. It has been found that suitable results may be obtained if the pipeline 4 is at least 2 km long.
In the embodiment of
The (one or more) product(s) obtained may be used as fuel or refrigerant. If desired, at least a part of the product 70 may be sent back to the first location 2.
The person skilled in the art will readily understand that many modifications may be made without departing from the scope of the invention.
| Number | Date | Country | Kind |
|---|---|---|---|
| 06117142.7 | Jul 2006 | EP | regional |
| Filing Document | Filing Date | Country | Kind | 371c Date |
|---|---|---|---|---|
| PCT/EP07/56929 | 7/9/2007 | WO | 00 | 1/29/2009 |
