CN1266027C - Method for transporting and transferring crude oil and naphtha - Google Patents

Abstract

The invention provides a crude oil and naphtha transfer method which can transfer naphtha and crude oil from a carrier tank in batches by using one pipe. When delivering naphtha (3) from an in-ship tank (11) to a naphtha tank (6) by a pipe (53), the pipe (53) is connected to a crude oil tank (4), the amount of crude oil (2) retained in the pipe (53) is calculated in advance, the delivery amount of the naphtha (3) is measured while the naphtha (3) is delivered from the in-ship tank (11), and when the delivery amount of the naphtha (3) becomes substantially the same amount as the calculated amount of the retained crude oil (2), the delivery of the naphtha (3) is stopped and switched to the crude oil tank (4) to deliver the naphtha (3) again by analyzing the flow of a mixed fluid (7) composed of the crude oil (2) and the naphtha (3) in the pipe (53).

Description

Transportation method and transfer method of crude oil and naphtha

technical field

The present invention relates to a method of transporting crude oil and naphtha using a transport body such as a crude oil tanker, and a method of transferring crude oil and naphtha from the transport body to an onshore storage tank.

Background technique

A tanker capable of transporting a large amount of oil at a time is generally used as a transport body used for oil transport. Furthermore, such tankers include a crude oil tanker that transports crude oil produced from an oil field, and a refined oil tanker that transports clean products (white oil) such as naphtha, kerosene, and light oil, that is, refined oil.

Crude oil tankers transporting crude oil, VLCC (Very Large Crude Carrier) with high transport efficiency of more than 200,000 tons is the mainstream.

Very large crude oil tankers such as VLLCs are difficult to land in general ports. Therefore, crude oil is generally docked at a loading and unloading terminal installed on the sea called a berth, and crude oil is unloaded. Alternatively, the crude oil is unloaded in a state tied to an offshore buoy near the port. Then, after arriving at the destination offshore berth, etc., the crude oil is transferred from the tank of the crude oil tanker to the crude oil tank on land by piping.

In addition, generally, naphtha is transported by a naphtha-only transport ship (refined oil tanker), and when the refined oil tanker arrives at the destination offshore berth, it is transported from the tank of the refined oil tanker using naphtha-only piping. The naphtha is transferred to the dedicated naphtha tank on land.

However, the largest refined oil tanker dedicated to naphtha is a tanker with a loading capacity of 70,000 to 100,000 tons. The transportation volume in one voyage is small, and the transportation cost is relatively high compared with crude oil tankers. Therefore, when using naphtha In the case of a dedicated refined oil tanker, the ratio of transportation costs to the price of naphtha is high, and there is a problem that the purchase price cannot be reduced.

In addition, sometimes there is only crude oil piping from the crude oil tanker that has arrived at the sea berth to the onshore oil tank that is usually several kilometers apart, and there is no dedicated piping for transferring naphtha. In this case, it is desirable to use piping for crude oil. Naphtha is transferred to onshore tanks.

Naphtha is one of the refined products obtained in the petroleum refining process. It is used as raw material naphtha for ethylene production equipment (thermal decomposition equipment) or aromatic production equipment when it is distilled, or when distillation treatment is not required. use.

Moreover, the raw naphtha requires that it contains no more than a certain proportion of heavy compounds.

The above-mentioned "certain ratio" refers to the ratio of heavy compounds contained in naphtha determined by the processing performance of heavy compounds in ethylene production equipment (pyrolysis equipment) or aromatic production equipment.

However, contrary to this requirement, when crude oil and naphtha are transferred in batches using a single pipe, the crude oil is mixed into the naphtha, and the naphtha contains heavy compounds such as crude oil at a certain ratio or more. Distillation treatment cannot be used as raw naphtha.

Therefore, a technique for transferring crude oil and naphtha without mixing crude oil with naphtha or minimizing the mixing amount of crude oil has been desired.

From such a point of view, some techniques for transferring crude oil and naphtha through a single pipe have been proposed.

For example, JP-A-2001-108200 proposes a technique of transporting naphtha through a pipeline for crude oil.

In this technique, the crude oil is transported by a pipeline for crude oil in a state where two condensate batches such as the head condensate batch and the tail condensate batch are sandwiched between two condensate batches, and at the outlet of the pipeline, Naphtha is recovered before or substantially before the end of the head condensate/naphtha interface and after the naphtha/tail condensate interface region occurs or substantially occurs batch technology.

In addition, this technology uses a pipeline of hundreds of kilometers to transfer crude oil and naphtha, and determines the time to recover the naphtha batch by measuring the colorimetric or specific gravity of the transferred fluid.

However, when crude oil and naphtha are transferred using the technology described in JP-A-2001-108200, the transfer process becomes complicated due to the use of a condensate as a special separator, and it is necessary to newly install the condensate. As a result, the recovery device has a problem of being impractical due to an increase in cost.

Moreover, since this technology determines the boundary between crude oil and naphtha by measuring and transferring colorimetry or specific gravity, it cannot precisely seek to switch the tank of the receiving location, and there is a problem that the amount of crude oil mixed with naphtha cannot be minimized. This problem becomes more prominent as the pipeline (piping distance) becomes longer.

When naphtha is transferred through a pipeline for crude oil, use of liquids (water, etc.) disclosed in Japanese Patent Publication No. 56-21960 as a special separator for separating naphtha and crude oil, etc., is considered, however, here Sometimes there is a problem that the transfer process becomes complicated.

The present invention has been made in view of the above-mentioned problems, and its first object is to provide a naphtha transportation method that can greatly reduce the transportation cost of naphtha and can easily reduce the purchase price of naphtha .

In addition, the second object of the present invention is to provide a crude oil and naphtha that can transfer naphtha and crude oil in batches from the transport body compartment to the storage compartment using a single pipe without using a special separator for separating the crude oil. Oil transfer method.

Contents of the invention

To achieve the first object, the inventors of the present invention focused on the fact that the transportation cost of a crude oil tanker is much cheaper than that of a refined oil tanker dedicated to transporting naphtha.

In addition, since naphtha becomes the raw material of other petroleum products through distillation, etc., it is required that it does not contain more than a certain proportion of heavy compounds. The inventors of the present invention paid attention to the fact that if the mixing ratio of heavy compounds can be reduced to less than a certain value, then the characteristics of naphtha can be maintained or enhanced, and they thought of loading naphtha in the interior tank of a crude oil tanker for The invention of transportation.

Specifically, the invention described in claim 1 is a naphtha transportation method using a transportation body for transporting crude oil, characterized in that at least a part of the plurality of transportation body compartments provided in the transportation body is designated as naphtha. For naphtha loading, the interior of the above-mentioned transport body compartment for naphtha loading is cleaned in advance before loading naphtha, and after crude oil is extracted from the piping for loading or unloading crude oil, use this Piping is used to load or unload the above-mentioned naphtha.

In this case, the cleaning of the carrier loaded with naphtha can be performed with crude oil as described in Claim 2.

By cleaning the transport body compartment in advance, crude oil, oil sludge, etc. remaining in the transport body compartment can be almost removed. It is also possible to use a special cleaning agent and sea water, etc., but by cleaning the inside of the transport body with crude oil, although the crude oil remains in the state where the crude oil is attached to the inner wall and bottom of the transport body, it is different from loading the transport body. The ratio of the amount of naphtha in the mixture and the amount of remaining crude oil are extremely small, and the mixing ratio of crude oil can be made sufficiently smaller than the allowable value.

The invention described in claim 3 is a method in which the transport body is a very large crude oil tanker exceeding 150,000 tons in weight.

Very large crude oil tankers such as VLCC (Very Large Crude Carrier) or ULCC (Ultra Large Crude Carrier) can transport a large amount of crude oil and naphtha at one time, and the transportation cost is lower than that of naphtha dedicated tankers, so it can Reduce the transportation cost of naphtha.

The invention described in claim 4 is a method of designating a transport tank for naphtha loading, avoiding the oil transfer tank connected to a drain pipe for extracting crude oil from the piping.

By doing so, since the crude oil in the pipe is not mixed into the naphtha when the crude oil in the pipe is drawn out, the amount of crude oil mixed into the naphtha can be reduced.

In the invention described in claim 5, when the naphtha is loaded, it is loaded slowly at a speed that does not stir up the crude oil residue that may remain at the bottom of the transport body compartment in the early stage after the loading starts. The naphtha method described above.

In addition, in the invention described in claim 6, when the above-mentioned naphtha is unloaded, the above-mentioned naphtha is slowly removed at a speed that does not stir up the crude oil residue that may remain at the bottom of the above-mentioned transport body compartment. method of removal.

By doing so, the amount of crude oil mixed into naphtha can be reduced as much as possible.

In the invention described in claim 7, the number of the above-mentioned transport tanks to be used is determined according to the loading amount of the above-mentioned naphtha, and in order to control the center of gravity of the above-mentioned crude oil tanker due to the difference in density or specific gravity between crude oil and naphtha A method of moving and specifying the above-mentioned transport body compartment loaded with the above-mentioned naphtha.

In the case of mixed loading of crude oil and light gasoline, the movement of the center of gravity of the crude oil tanker caused by the difference in density or specific gravity of the two must be considered. By designating the transport compartment as in the invention described in claim 7, the movement of the above-mentioned center of gravity can be suppressed, and stable navigation can be ensured even in the case of mixed loading of crude oil and naphtha.

In order to achieve the second object, the inventors of the present invention conducted assiduous research and found that the crude oil and naphtha in the piping when the piping for crude oil is used to alternately transfer naphtha and crude oil from the transport body compartment to the storage compartment And flow analysis of a mixed fluid composed of crude oil and naphtha (hereinafter sometimes referred to as "flow analysis"), by adopting a transfer method based on this flow analysis, it is possible to suppress the occurrence of crude oil without using a special separator, etc. The state transporting naphtha in the state of the naphtha pollution, thus completed the present invention.

Therefore, even when naphtha is transported from a crude oil tanker to an onshore tank using only piping for crude oil when there is no dedicated piping for transporting naphtha, naphtha can be transported together with crude oil by a large crude oil tanker. Compared with the conventional transportation by naphtha tanker, the transportation cost can be greatly reduced.

Specifically, in the transfer method of crude oil and naphtha of the present invention, as described in claim 8, in the method of transferring crude oil and naphtha from the transport body compartment to the storage compartment with one pipe,

(1) When the above-mentioned naphtha or crude oil is sent from the above-mentioned transport body compartment to the above-mentioned storage tank by the above-mentioned piping, the above-mentioned piping is connected to a tank for crude oil or naphtha,

At the same time, (2) calculate in advance the amount of crude oil or naphtha remaining in the piping connecting the transport tank and the storage tank,

(3) Naphtha or crude oil is sent out from the above-mentioned transport body compartment, and the amount sent out is calculated at the same time,

(4) When the amount of naphtha or crude oil sent from the above-mentioned transport body compartment is almost equal to the estimated amount of crude oil or naphtha remaining in the above-mentioned piping, stop the delivery of naphtha or crude oil from the above-mentioned transport body compartment. Send, switch the tank at the receiving location from a tank for crude oil or naphtha to a tank for naphtha or crude oil,

(5) After the above-mentioned tanks are switched, the naphtha or crude oil is sent out from the above-mentioned transport body tank, and the naphtha or crude oil is stored in the tank for naphtha or crude oil.

In this way, since the crude oil or naphtha remaining in the piping can be pushed out into the tank for crude oil or the tank for naphtha by the action of the pump when the naphtha or crude oil is sent out, the flow of crude oil into the naphtha can be effectively reduced. the mixing amount.

In addition, since there is no need to use a special separator for separating naphtha and crude oil, the transfer process can be simplified.

In the invention described in claim 9, flow analysis of crude oil, naphtha, and a mixed fluid composed of crude oil and naphtha in the piping is performed, and the result of the flow analysis is used to determine stoppage of naphtha from the transport body compartment. Or the delivery method of crude oil.

In this way, the amount of crude oil mixed into naphtha can be controlled with high precision, and heavy compounds above a certain ratio can be prevented from being mixed into naphtha, thereby preventing the problem of naphtha being contaminated by oily heavy compounds.

The invention described in claim 10 is a method of using at least the temperature, density, and specific gravity of the stagnant crude oil or naphtha as correction factors when calculating in advance the amount of crude oil or naphtha stagnant in the piping.

In this way, flow analysis can be performed with high accuracy. For example, when measuring the amount of naphtha or crude oil delivered from the tank of the transport body based on the amount of crude oil or naphtha pushed into the tank at the receiving point, it is possible to measure the amount of naphtha with high accuracy. The output of naphtha or crude oil.

In addition, the invention described in claim 11 is a method of measuring the delivery amount of naphtha or crude oil from the tank of the transport body using a fixed gauge of the tank at the receiving point.

In this way, it is possible to simply and reliably measure the amount of naphtha or crude oil delivered from the transport tank, and it is possible to accurately calculate the switching of the tank at the receiving point from a tank for crude oil or naphtha to a tank for naphtha or crude oil. The cabin time used.

The invention described in claim 12 is a method of changing the sending speed of the naphtha or crude oil when pushing out the crude oil or naphtha stagnant in the piping to the tank based on the flow analysis result.

In this way, the transfer can be performed with the mixing of crude oil into naphtha minimized.

In addition, the invention described in claim 13 is a method of changing the delivery rate of the naphtha or crude oil immediately after the delivery of the naphtha or crude oil is started or immediately before the delivery is stopped.

When the delivery rate of naphtha or crude oil is changed just after the start of delivery in this way, the length of the mixed fluid of naphtha and crude oil in the piping can be shortened, and the mixing of naphtha and crude oil in the piping can be suppressed to a minimum. minimum. In addition, when the sending speed of naphtha or crude oil is changed immediately before the stop of sending out, the time for switching the tank at the receiving point from a tank for crude oil or naphtha to one for naphtha or crude oil can be obtained with good accuracy. cabin time.

In addition, the invention described in claim 14 is a method of rapidly increasing the delivery rate of the naphtha or crude oil at a predetermined delivery rate immediately after the start of delivery of the naphtha or crude oil.

In this way, the mixed fluid of crude oil and naphtha can be formed in a short time, that is, the length of the mixed fluid of naphtha and crude oil in the piping can be shortened.

Description of drawings

FIG. 1 is a flowchart for explaining the steps of the transportation method of the present invention.

2 is a schematic configuration diagram of an example of a judging device for automatically judging and determining the designation of a crude oil tanker and the amount of naphtha mixed in the crude oil tanker.

Fig. 3 is a top view of a very large crude oil tanker loaded with naphtha or crude oil.

Fig. 4 is a schematic block diagram illustrating a state of weighing in an embodiment of the method of transferring crude oil and naphtha according to the present invention.

Fig. 5 is a schematic flow chart showing an example of the transfer method of crude oil and naphtha according to the present invention.

Fig. 6 is a schematic diagram for explaining mixed fluid in piping in an embodiment of the present invention, (a) is a cross-sectional view showing a state in which naphtha is sent out to a piping stagnant in crude oil, and (b) is a cross-sectional view showing A cross-sectional view of the state in which crude oil is sent to the piping in which naphtha stagnates.

FIG. 7 shows the continuity equation (1), momentum equation (2), turbulence model equation (3) and diffusion equation (4) for analyzing the flow state of this embodiment.

Fig. 8 is a schematic diagram for explaining an example of flow state analysis in this embodiment, (a) showing an analysis schematic diagram, and (b) showing a graph showing changes in delivery speed (flow rate).

FIG. 9 is a graph showing the transfer amount with respect to the transfer time for explaining the transfer state of crude oil and naphtha in the analysis example of the present embodiment.

FIG. 10 is a concentration graph illustrating the distribution of naphtha concentration in the pipe length direction in an analysis example of the present embodiment.

Detailed ways

Hereinafter, preferred embodiments of the present invention will be described in detail with reference to the accompanying drawings.

[Explanation of the shipping method]

Fig. 1 is a flow chart of the transportation method of the present invention.

Firstly, a crude oil tanker for mixed loading of naphtha and crude oil is designated according to the amount of naphtha to be transported, the amount of crude oil and the berthing place of the crude oil tanker (step S1). At this time, the combination with the cheapest transportation cost of naphtha and crude oil is selected from a plurality of combinations, and the designation of the crude oil tanker and the amount of naphtha to be mixed are determined. In addition, for crude oil tankers that may carry naphtha and crude oil mixedly, in order to prevent premature corrosion of parts such as tanks and seals due to the different properties of crude oil and naphtha, these parts can be replaced with hard-to-reach Parts with premature corrosion caused by naphtha and crude oil.

The above designation of the crude oil tanker and the amount of naphtha mixed in the crude oil tanker can be automatically determined by a determination device such as a computer.

2 is a schematic configuration diagram of an example of a judging device for automatically judging and designating designation of a crude oil tanker and the amount of naphtha mixed in the crude oil tanker.

The judging device 21 has an input unit 22 such as a keyboard for inputting an input plan of crude oil and naphtha, a navigation status monitoring unit 24 that monitors the navigation status of all crude oil tankers and refined oil tankers, and the transport status input from the input unit 22. The plan and the voyage status of the crude oil tanker and the refined oil tanker are written into the database 25, or the reading/writing unit 23 read from the database 25, and the designation of the crude oil tanker is determined based on the above-mentioned transportation plan and the voyage status of the crude oil tanker and the refined oil tanker and an output unit 27 such as a printer or a display that outputs the processing results of the processing unit 26 .

The navigation status monitoring unit 24 reads the navigation status input from each crude oil tanker and refined oil tanker underway one by one, sends it to the reading/writing unit 23 , and writes it in the database 25 .

The database 25 stores the types and names of all crude oil tankers and refined oil tankers, the loading capacity of each crude oil tanker and refined oil tanker, and the current navigation status of each crude oil tanker and refined oil tanker input from the navigation status monitoring unit 24. (current position, destination, berthing place, expected date of entry, etc.), schedule for regular inspection, and the next transportation plan (transported tonnage of crude oil and naphtha, berthing place, etc.) input from the input unit 22 is also stored. (purchase location of crude oil and naphtha), destination and transportation schedule, etc.).

The processing unit 26 infers the crude oil tanker and refined oil tanker that can be transported according to the above-mentioned transportation plan according to the above-mentioned navigation status stored in the database 25, and then calculates from the inferred transportation capacity of the crude oil tanker and the amount of crude oil transported by the above-mentioned transportation plan. The amount of naphtha that can be mixed.

Next, the processing unit 26 calculates the total transportation cost of the crude oil and naphtha in the transportation plan while considering the purchase locations (parking locations) of the crude oil and naphtha in the transportation plan, and uses The amount of mixed naphtha is increased or decreased, and the crude oil tanker with the lowest total transportation cost is calculated if how much naphtha is mixed.

In this way, the crude oil tanker to be loaded with naphtha is determined, and the berth and schedule of each crude oil tanker and refined oil tanker are determined at the same time, and then output to the output unit 27 such as a display.

If the crude oil tanker to be mixed with naphtha is determined by the above steps, then according to the amount of mixed naphtha, the interior tank for loading naphtha is designated from among the plurality of tanks installed on the crude oil tanker (step S2).

Fig. 3 is a schematic plan view showing a very large crude oil tanker such as a VLCC carrying naphtha.

A plurality of inboard tanks 11 are provided in the crude oil tanker 1 . Since naphtha 3 and crude oil 2 have different densities (or specific gravity, referred to as density in the following description), when naphtha 3 and crude oil 2 are transported together, it is necessary to balance them in order not to hinder the navigation of crude oil tanker 1. Well loaded naphtha3.

FIG. 3 shows a state in which naphtha is loaded in five of the plurality of inboard tanks 11 . In the figure, the inboard tank 11 filled with naphtha is indicated by symbol N, and the inboard tank 11 filled with crude oil is indicated by O. Also, WBT is a ballast tank.

As shown in the figure, in order not to move the position of the center of gravity of the crude oil tanker 1 as much as possible, the inboard tank 11 filled with naphtha and the inboard tank 11 loaded with crude oil are well balanced in the left, right, front and rear relative to the direction of travel of the crude oil tanker 1. specified. In addition, it is preferable to replace the inner tank of the ship which may be designated for naphtha filling with a gasket such as NBR (nitrile butadiene rubber) which is less corrosive due to naphtha in advance.

In addition, when loading naphtha, it is necessary to discharge the crude oil remaining in the on-board piping of the crude oil tanker 1 from the discharge pipe. Naphtha is excluded in the designation of inboard compartment 11.

If the inboard tank in which naphtha is stored is designated, the level gauge installed in the inboard tank is corrected in consideration of the density difference between naphtha and crude oil (step S3).

In addition, the inside of the inboard tank filled with naphtha is cleaned, and residual crude oil and sludge are removed from the inboard tank as much as possible (step S4).

The internal cleaning of the inner compartment of the ship can be carried out with a special cleaning agent and sea water, etc., but it can also be carried out using the crude oil transported during the last voyage. Although crude oil remains in a state attached to the inner wall of the ship's inner tank, the amount is small compared to the amount of naphtha put into the ship's inner tank, and it is possible to mix the naphtha (raw material naphtha) The amount of crude oil is below the allowable value. In addition, the amount of crude oil mixed into the naphtha can be reduced by draining the residual crude oil before charging the naphtha.

The loading of naphtha may be after or before the loading of crude oil. It is preferable to discharge the crude oil and the sludge remaining at the bottom of the inboard tank again (step S5 ) before loading the naphtha. In this way, the amount of crude oil mixed with naphtha can be further reduced.

In order to prevent the mixing of crude oil into the naphtha as much as possible, when loading naphtha, use a discharge pipe to discharge the crude oil remaining in the piping of the crude oil tanker to the crude oil loaded (or already loaded) ship In the cabin (step S5).

The preparations for loading of naphtha are completed through the above steps, and thereafter, loading of naphtha into a designated interior tank is started (step S6).

At this time, in order to reduce the amount of crude oil mixed with the naphtha, the naphtha is charged at a relatively slow speed at the beginning of the initial charging of the naphtha, so that the oil remaining at the bottom of the inner tank can not be stirred. crude oil or sludge.

In addition, by slowly charging the naphtha at the initial stage of loading in this way, the generation of static electricity due to the friction between the naphtha and the inner tank of the ship can be suppressed as much as possible, which is also advantageous in terms of safety.

With the above steps, the loading of naphtha is completed. After the filling of the naphtha is completed, the naphtha remaining in the piping is discharged to the inner compartment loaded with the naphtha, thereby preventing shortage as much as possible.

The gasoline and crude oil loaded by the above steps are transported to the destination by the shared crude oil tanker (step S7). Furthermore, when the pressure of the interior compartment increases during navigation, water can be sprayed on the deck to cool the interior compartment. Thus, loss due to evaporation of naphtha can be prevented.

At the destination, naphtha or crude oil can be unloaded first. When loading, if naphtha is loaded after crude oil, it is best to unload naphtha first. In this way, the work of removing crude oil from the piping on the ship can be omitted, and the amount of crude oil mixed with naphtha can also be reduced. When unloading naphtha, use the ship's take-out device to completely take out the naphtha from the inner compartment of the ship.

In addition, when loading, if the crude oil is loaded after the naphtha is loaded, the crude oil can be unloaded, and the crude oil in the pipeline can be discharged in the same order as above (step S8), and the naphtha-filled After piping, unloading of naphtha starts (step S9).

When unloading the oil, it is preferable to slowly unload the naphtha near the bottom of the inner tank so as not to stir up the crude oil or sludge remaining in the inner tank. In addition, after the naphtha is unloaded, it is best to wash the interior of the ship with crude oil and carry out anti-rust treatment for the interior of the ship.

Naphtha can be used when the onshore piping connected to the ship's piping (in addition to the onshore piping, including the offshore piping extending from the land to the berth at sea) is divided into naphtha and crude oil Naphtha is unloaded from the above-mentioned land piping dedicated to oil, and crude oil is unloaded from the above-mentioned land piping dedicated to crude oil.

According to the present invention, since naphtha can be transported by a crude oil tanker having a low transportation cost, there is an effect that the transportation cost of naphtha can be significantly reduced.

The following table shows specific effects of the present invention.

This table shows the degree of reduction in transportation costs when 50,000 tons of naphtha is mixed with crude oil on a very large crude oil tanker VLCC. The transportation cost per ton in 2001 was about $20 when using a crude oil tanker, and about $31 when using a refined oil tanker dedicated to naphtha. Transportation unit price $/t Transport tonnage transportation cost VLCC $20 50,000 tons $1 million refined oil tanker $31 50,000 tons $1.55 million difference $11 $550,000

In this way, if the present invention is adopted, the transportation cost can be reduced by about 550,000 U.S. dollars (71.5 million yen in conversion of 1 ton=130 yen) for one transportation. This shows that the transportation cost of naphtha can be reduced to about 2/3. Therefore, according to the present invention, the cost reduction of raw material naphtha, which has been difficult to achieve, can be easily and significantly realized.

In addition, when the properties of raw naphtha or cost naphtha were checked after unloading, although some discoloration was confirmed, the amount of crude oil mixed in was very small, which was lower than that stipulated by the law restricting the operation of the plant and other laws. Much lower values are allowed.

[explanation of transfer method]

However, when the land piping is not divided into naphtha and crude oil, naphtha can be unloaded using the land piping for crude oil.

At this time, the naphtha 3 can be transferred using known techniques such as JP-A-2001-108200, JP-A-7-83399, and JP-A-57-25760.

In this example, crude oil and naphtha were transferred using a common land pipeline by the following method described with reference to FIGS. 4 to 10 while minimizing the mixing amount of crude oil.

Fig. 4 is a schematic block diagram illustrating a transfer state in an embodiment of the crude oil and naphtha transfer method of the present invention.

For ease of understanding, bypass pipes and the like are omitted in FIG. 4 .

In FIG. 4 , a large oil tanker 1 has a plurality of inboard compartments 11 as transport compartments, and crude oil 2 and naphtha 3 are loaded in separate compartments 11 so as not to be mixed in, and are moored at sea berths at the destination of transport. .

In addition, a pump 12 for transferring loaded crude oil 2 to an onshore crude oil tank 4 is usually installed on a large oil tanker 1, and a valve 51 and a pressure gauge for transferring the crude oil 2 sent from the pump 12 are installed on an offshore berth. Count 52, 1 piping 53. In addition, a densitometer 54 is provided as needed.

Also, a plurality of tanks 4 for crude oil and tanks 5 and 6 for naphtha are provided on land as storage tanks, and are connected to the front ends of pipes 53 auxiliary provided in the vicinity of the tanks 4 and 6 through valves 61 .

In addition, FIG. 5 shows a schematic flow chart of an example of the transfer method of crude oil and naphtha according to the present invention. Specifically, it will be an example showing that crude oil is transferred after naphtha is transferred.

According to the transfer method of crude oil and naphtha of this embodiment, the crude oil 2 and naphtha 3 are transferred from the inboard tank 11 to the land tanks 4 and 6 by one piping 53, and the piping 53 is first connected to the crude oil. Go up with cabin 4 (step S11).

At this time, since the crude oil 2 is stagnated in the piping 53, in order to transfer the naphtha 3 to the naphtha tank 6 first, it is necessary to send the naphtha 3 to the piping 53, and pump the naphtha 3 into the piping 53 by the action of the pump. The crude oil 2 is pushed out on the tank 4 for crude oil.

Next, the amount of crude oil remaining in the piping 53 connecting the inboard tank 11 and the tanks 4 and 6 is calculated in advance (step S12).

Here, the crude oil 2 in the piping 53 is stored in the piping 53 with the valves 51 and 61 closed in a state almost full. In this case, the volume in the piping 53 can be calculated as the volume (amount) of the crude oil 2 .

Next, when starting to send out, the valves 51 and 61 are opened, and the naphtha 33 is sent out from the inboard tank 11, while measuring the delivery amount of the naphtha 3 (step S13).

This measurement can be performed, for example, by using a flowmeter connected to the piping 31, measuring the liquid level of the tank 11 in the ship, or measuring the liquid level of the tank 4 at the receiving point.

Next, when the amount of the naphtha 3 delivered from the inboard tank 11 becomes almost the same amount as the previously calculated amount of crude oil 2 staying, the delivery of the naphtha 3 from the inboard tank 11 is stopped, and the tank at the receiving location is transferred from the crude oil The tank 4 is switched to the tank 6 for naphtha (step S14).

In addition, the reason why the amount is almost the same is because the allowable mixing amount of the crude oil 2 into the naphtha 3 is changed by the ratio of heavy compounds contained in the crude oil 2 and the total transfer amount of the naphtha 3 .

Then, after the cabin of the receiving place is switched to the naphtha cabin 6 from the crude oil tank 4, the naphtha 3 is sent out from the inboard cabin 11, and the naphtha 3 is stored in the naphtha cabin 6 (step S15 ).

In addition, when the naphtha 3 has been transferred from the inboard tank 11, the pump 12 of the large oil tanker 1 is stopped.

Like this, according to the transfer method of crude oil and naphtha of the present invention, owing to send out naphtha 3, the crude oil 2 that stays in the piping 53 can be pressed out in the tank 4 for crude oil by pump action, therefore can reduce effectively. The mixing amount of crude oil 2 to naphtha 3.

In addition, since there is no need for a special separator for separating the crude oil 3 and the naphtha 2, the transfer process can be simplified.

Next, the crude oil 2 in the inboard tank 11 of the large oil tanker 1 is transferred to the crude oil tank 4 .

At this time, since the naphtha 3 remains in the piping 53 , it is necessary to push the naphtha 3 in the piping 53 into the naphtha tank 6 .

Therefore, the state in which the piping 53 is connected to the naphtha tank 6 is maintained (step S16).

Next, the amount of naphtha 3 remaining in the piping 53 connecting the inboard tank 11 and the tanks 4 and 6 is calculated in advance (step S17).

Next, while sending out the crude oil 2 from the inboard tank 11, the delivery amount of the crude oil 2 is measured (step S18). When the amount of crude oil 2 sent from the inboard tank 11 is almost the same amount as the previously calculated amount of naphtha 3 staying, the delivery of crude oil from the inboard tank 11 is stopped, and the tank at the receiving location is transferred from the naphtha tank 6 Switch to the tank 4 for crude oil (step S19).

After the tank at the receiving location is switched from the naphtha tank 6 to the crude oil tank 4, the crude oil 2 is delivered from the inboard tank 11, and the crude oil 2 is stored in the crude oil tank 4 (step S20).

When the transfer of the crude oil 2 from the inboard tank 11 is completed, the pump 12 is stopped and the valves 51 and 61 are closed. Therefore, the crude oil 2 stays in the pipe 53 .

In this way, since the naphtha 3 remaining in the piping 53 can be pumped out into the naphtha tank 6 by sending out the crude oil 2 , the amount of naphtha 3 mixed into the crude oil 2 can be effectively reduced.

In addition, the present embodiment first unloads the naphtha 3 from the large oil tanker 1 and then unloads the crude oil and the transfer method of the crude oil. Sequential (naphtha unloading followed by crude oil unloading) is performed. This sequence is determined after considering the loading (whether crude oil only or crude oil/naphtha) of the tanker to be unloaded.

In the crude oil and naphtha transfer method of this embodiment, for example, when calculating in advance the amount of crude oil 2 stagnant in the piping 53 (step S12), it is preferable to use at least the temperature and density of the stagnant crude oil 2 as correction factors. .

In this way, when the amount of naphtha 3 sent out from the inboard tank 11 is obtained from the amount of crude oil 2 measured by the fixed scale 42 of the crude oil tank 4 at the receiving place, it is possible to correct and store the crude oil in the crude oil tank 4. Therefore, the timing for switching from the tank 4 for crude oil to the tank 6 for naphtha can be obtained more accurately.

In this embodiment, the above-mentioned density can be measured by the density meter 54 installed on the pump 12 side of the piping 53 .

Also, of course, when calculating the amount of naphtha 3 remaining in the piping 53 in advance (step S17 ), the temperature and density of the naphtha 3 may be used as correction factors in the same manner as above.

In addition, when measuring the delivery amount of naphtha 3 (step S13), it is also possible to use the fixed scale 42 of the crude oil tank 4 at the receiving place to measure the amount of naphtha 3 sent from the interior tank 11 of the ship. By accurately measuring the amount of naphtha 3 delivered from the inboard tank 11, it is possible to accurately determine the timing at which the receiving point ground tank is switched from the crude oil tank 4 to the naphtha tank 6.

Similarly, when measuring the delivery amount of crude oil 2 (step S18), it is of course also possible to measure the amount of crude oil 2 delivered from the inboard tank 11 by using the fixed scale 62 of the naphtha tank 6 at the receiving location.

Since the present invention does not use a special separator separating the naphtha 3 and the crude oil 2, the boundary between the naphtha 3 and the crude oil 2 is a mixed fluid 7 where the naphtha 3 and the crude oil 2 are mixed.

Since this mixed fluid 7 is formed at a distance determined according to various conditions in the piping 53, in order to prevent the mixing of the crude oil 2 into the naphtha 3 or to control the mixing amount of the crude oil 2 into the naphtha 3, it is necessary to know the relationship between the crude oil 2 and the naphtha 3. The state of the mixed fluid 7 corresponding to the delivery amount of naphtha 3 or crude oil 2 .

6 is a schematic view showing a mixed fluid in a pipe for explaining an embodiment of the present invention, (a) is a cross-sectional view showing a state in which naphtha is sent out to a pipe stagnant in crude oil, and (b) is a cross-sectional view showing A cross-sectional view of the state in which crude oil is sent to the piping where naphtha is stagnant.

In this figure (a), when the naphtha 3 is sent out to the piping 53 where the crude oil 2 is stagnant, a mixed fluid 7 at a distance L1 is formed in the piping 53, and the distance L1 of the mixed fluid 7 depends on the length of the piping (refer to Figure 10).

In addition, the concentration curve shows the ratio of naphtha 3 to crude oil 2 in the cross section of the pipe 53. The ratio of naphtha increases toward the front end side of the mixed fluid 7, and the ratio of naphtha increases toward the rear end side. lower.

In addition, in this figure (b), when the crude oil 2 is sent to the piping 53 where the naphtha 3 is stagnant, the mixed fluid 7 at a distance L2 is formed in the piping 53, and the distance L2 of the mixed fluid 7 also depends on the piping. length.

In addition, the concentration curve shows the ratio of crude oil 2 to naphtha 3 in the cross section of the pipe 53 , and the ratio of crude oil decreases toward the front end side of the mixed fluid 7 and increases toward the rear end side.

Here, in order to minimize the mixing of the crude oil 2 and the naphtha 3 , it is necessary to accurately control the flow rate of the naphtha 3 or the crude oil 2 and the switching control of the storage tanks.

That is, by controlling the flow velocity of the sent naphtha 3 or crude oil 2 (control of the sending speed), the shorter the distance of the mixed fluid 7 in the pipe 53, the smaller the mixing amount of the naphtha 3 and crude oil 2 can be reduced.

In addition, the switching control of the storage compartment, that is, the control of when to stop sending the naphtha 3 or crude oil 2, since the state of the mixed fluid 7 during transfer cannot be directly observed, it is best to carry out the crude oil 2 and naphtha in the piping 3. The analysis of the flow states of the oil 3 and the mixed fluid 7 utilizes the results of the flow analysis. By doing so, the mixing amount of the crude oil 2 into the naphtha 3 can be precisely controlled, and the heavy compound can be prevented from being mixed into the naphtha 3 beyond a certain ratio, thereby preventing the problem of contamination of the naphtha 3 by the heavy compound.

The above flow analysis is based on the continuity equation (1), momentum equation (2), turbulence model equation (3) and diffusion equation (4) shown in Figure 7 to analyze the crude oil 2, naphtha 3 and mixed The flow state of the fluid 7.

In this figure, the concentration distribution in the pipe 53 can be calculated from the continuity equation (1), the momentum equation (2) and the diffusion equation (4).

Then, the flow state of the mixed fluid 7 is analyzed, and the time to stop sending the naphtha 3 or the crude oil 2 from the inboard tank 11 is determined using the result of the flow analysis.

When doing this, since the naphtha ratio or the crude oil ratio at any position in the piping 53 can be obtained, for example, even when a part of the mixed fluid 7 is pushed out of the chambers 4 and 6, it is possible to accurately calculate the ratio of the naphtha in the piping 53. The amount of crude oil or naphtha in the confluent fluid 7 of .

In addition, the flow state of the mixed fluid 7 is simulated by changing the sending speed of the crude oil 2 or naphtha 3 stagnant in the piping 53 and transporting the naphtha 3 or crude oil 2 to the crude oil tank 4 or the naphtha tank 6 , can select the sending speed of naphtha 3 or crude oil 2 that can shorten the distance L1, L2 of mixed fluid 7, and can transfer under the state that the mixing of crude oil 2 to naphtha 3 is restricted to the minimum.

Hereinafter, referring to the accompanying drawings, the crude oil and naphtha transfer method of the present embodiment, using the piping 3 filled with crude oil 2, is used to transfer the crude oil 2 and naphtha 3 from the inboard tank 11 to the crude oil tank 4 and the crude oil tank on land. An analysis example of naphtha tank 6 will be described.

(analysis example)

Fig. 8 is a schematic diagram showing an analysis example of a flow state in this embodiment, (a) showing an analysis schematic diagram, and (b) showing a graph showing changes in delivery speed (flow rate).

In this figure (a), the pipe 53 has an inner diameter of about 1.2 m and a length of about 9 km, holds crude oil 2 , and sends out naphtha 3 (not shown) from the pump 12 of the large tanker 1 .

In addition, in the figure (b), the delivery rate of naphtha generally increases the flow rate almost proportional to time, and as in the usual delivery curve, when the delivery rate reaches a predetermined rate (for example, about 4800kl/hr), The transfer is continued at the predetermined sending speed, and before the transfer is stopped, the flow rate is similarly reduced in almost proportion to the time, and the transfer is stopped.

On the other hand, in the crude oil and naphtha transfer method of the present invention, the delivery speed of the naphtha 3 immediately after the start of delivery is rapidly increased to the above-mentioned predetermined delivery rate. In this way, by rapidly increasing the delivery speed immediately after the delivery of naphtha starts, the tip flow state can be established as early as possible, and the distance of the mixed fluid 7 can be minimized.

That is, by simulating the flow state of the mixed fluid 7, the sending speed of the naphtha 3 or the crude oil 2 can be changed immediately after sending out, the length of the mixed fluid 7 of the naphtha 3 and the crude oil 2 in the piping 53 can be shortened, and the The mixing of naphtha 3 and crude oil 2 in the piping 53 is minimized.

According to the flow analysis of the crude oil 2, naphtha 3 and the mixed fluid 7 composed of the crude oil 2 and the naphtha 3 in the piping 53, the crude oil 2 or the naphtha 3 remaining in the piping 53 is transferred to the tanks 4 and 6. The method of changing the sending speed of naphtha 3 or crude oil 2 during extrusion is not limited to the above-mentioned change in sending speed, and varies depending on, for example, piping laying conditions.

In addition, it is also possible to change the sending speeds of naphtha 3 and crude oil 2 immediately before sending out, and by doing so, it is possible to more accurately determine the difference between the crude oil tank 4 and the naphtha tank at the receiving point. When switching 6 to the tank 6 for naphtha or the tank 4 for crude oil, it is possible to more reliably prevent the crude oil 2 from being mixed into the naphtha 3 .

FIG. 9 is a graph showing the transfer amount with respect to the transfer time for explaining the transfer state of crude oil and naphtha in the analysis example of the present embodiment.

First, the situation of this analysis example will be described along the flow chart shown in FIG. 5 .

The large oil tanker 1 is a 300,000 ton class oil tanker, and is loaded with about 200,000 KL of crude oil and about 7 KL of naphtha into a plurality of inboard tanks 11 without mixing them.

In addition, the crude oil 2 stagnates in the piping 53 before the start of the transfer.

When the naphtha 3 is sent from the inboard tank 11 to the naphtha tank 6 by the piping 53 in which the crude oil 2 is stored, the piping 53 is connected to the crude oil tank 4 (step S11 ).

Next, the amount of crude oil remaining in the piping 53 connecting the inboard tank 11 and the crude oil tank 4 is calculated in advance (step S12).

In a large oil tanker 1 moored at an offshore berth, an inboard tank 11 filled with naphtha 3 is connected to a pump 12 installed on the large oil tanker 1, and the pump 12 pushes out the crude oil 2 stagnant in the piping 53 to the tank for crude oil 4, the naphtha 3 is delivered from the inboard tank 11 to the pipe 53. Then, the transportation amount of the crude oil 2 is measured by the fixed scale 42 of the tank 4 for crude oil (step S13).

Here, the naphtha 3 is delivered according to the delivery curve shown in FIG. 8( b ) based on the above analysis results.

FIG. 10 is a graph illustrating a concentration curve of naphtha concentration distribution in the piping longitudinal direction in an analysis example of the present embodiment.

In this figure, the concentration curves A, B, and C are the concentration curves of naphtha in each pipe length. For example, the concentration curve A shows the mixing that exists in the pipe length from about 2350 m to about 2650 m after about 0.6 hours from the start of delivery. Concentration curve for naphtha in stream 7.

That is, when the naphtha 3 is sent out with the above-mentioned sending curve, only the crude oil 2 exists in the pipe 53 before the pipe length of about 2650 m, and exists corresponding to the concentration curve A pair in the pipe 53 from the pipe length of about 2650 m to about 2350 m. Crude oil 2 and naphtha 3 are deposited, and only naphtha 3 exists in the pipe 53 in front of the pipe with a length of about 2350 m.

In addition, the mixed fluid 7 has a length of about 300 m in the pipe 53 , and the naphtha ratio in the central portion (that is, the position of the pipe length of about 2500 m) is about 40 vol %.

In this way, the reason why the naphtha ratio in the center of the mixed fluid 7 is not about 50 vol is because the density of the naphtha 3 is smaller than that of the crude oil 2, and the density of the crude oil 3 and the naphtha 3 can be measured with good accuracy. The flow analysis in the piping 53 is performed in an accurate manner.

In addition, the mixed fluid 7 becomes longer as it is transferred in the piping 53. For example, after about 1.2 hours from the start of delivery, as shown in the concentration curve B, the front end of the mixed fluid 7 is at about 5225 m, and the rear end is at about 5225 m. At about 4775 m, the mixed fluid 7 has a length of about 450 m in the piping 53 .

After further transfer, for example, after about 2.4 hours from the beginning of sending, as shown in the concentration curve C, when the front end of the mixed fluid is at about 9365m, the rear end is at about 8635m, and the mixed fluid 7 has about 730m in length.

In this way, when the concentration curve when the tip of the mixed fluid 7 reaches the end of the pipe 53 is calculated, the amount of crude oil in the mixed fluid 7 can be accurately calculated. Therefore, it can be seen that the tip of the mixed fluid 7 reaches the end of the pipe 53 when the crude oil amount subtracted from the crude oil remaining in the pipe 53 is pushed out to the crude oil tank 4 in the mixed fluid 7 .

That is, it can be known that the front end of the mixed fluid 7 has reached the end of the pipe 53 or arrives a few seconds later, and even when the front end of the mixed fluid 7 is pushed out into the tank 4 for crude oil, it can be known from the flow analysis result that the remaining The length and concentration curve of the mixed fluid 7 in the pipe 53 can accurately calculate the amount of crude oil mixed in, so the amount of crude oil mixed with the naphtha 3 can be kept in the pipe 53 under extremely accurate control. Crude 2 launched.

In order not to mix crude oil into the naphtha 3 in the naphtha tank 6 and to minimize the naphtha 3 transferred to the crude oil tank 4, only when the mixed fluid 7 passes through the pipe 53 What is necessary is just to stop sending out of naphtha.

In addition, when the amount of crude oil that can be mixed in the naphtha 3 is set, since the sending stop position of the mixed fluid 7 corresponding to the amount of crude oil mixed can be calculated from the concentration curve, the flow of the crude oil 2 to the naphtha 3 can be accurately controlled. The mixing amount of naphtha 3.

Next, when the delivery amount of the naphtha 3 delivered from the inboard tank 11 is almost the same amount as the previously calculated amount of crude oil 2 retained, the delivery of the naphtha 3 from the inboard tank 11 is stopped, and the tank at the receiving location The tank 4 for crude oil is switched to the tank 6 for naphtha (step S14).

Then, after the cabin of the receiving place is switched from the cabin 4 for naphtha to the cabin 6 for naphtha, the naphtha 3 from the inboard cabin 11 is sent out, and the naphtha 3 is stored in the cabin for naphtha 6 (step S15).

Next, crude oil 2 needs to be transferred. However, at this stage, the naphtha 3 remains in the piping 53 .

Therefore, in order to push out the crude oil 2 stagnant in the pipe 53 with the naphtha 3, this time, the naphtha 3 stagnated in the pipe 53 is pushed out into the naphtha tank 6 with the crude oil.

Thereafter, it can be implemented in the same manner as in the above case.

That is, in order not to completely mix the crude oil 2 into the naphtha 3 in the naphtha tank 6 and to maximize the naphtha 3 transferred to the naphtha tank 6, only the front end of the mixed fluid 7 It is sufficient to stop the delivery of the crude oil 2 when it reaches the end of the pipe 53. In addition, when the amount of crude oil that can be mixed into the naphtha 3 is set, the delivery stop of the mixed fluid 7 corresponding to the amount of mixed crude oil can be calculated from the concentration curve. In order to stop the mixed fluid 7 at this stop position, it is only necessary to stop the delivery of the crude oil 2 .

In the present invention, a control device (not shown) calculates the crude oil remaining in the piping, compares the calculated remaining crude oil amount with the measured crude oil amount, analyzes the flow of the mixed fluid, and the like.

The control device may be configured to automatically control the opening and closing of the pump 12 or the valves 51 and 61 using the flow analysis results. By doing so, the mixing amount of the crude oil 2 into the naphtha 3 can be controlled more precisely.

When the valves 56 and 61 are operated manually, the operator opens and closes the valves according to instructions from the control device.

In addition, when the amount of crude oil 2 or naphtha 3 pushed out is measured with fixed scale 42 or fixed scale 62, and the amount of naphtha 3 and crude oil 2 pushed out from the inboard tank 11 is calculated from the measurement result, each specified When the metering result is input into the control device, the flow state of the mixed fluid 7 can be known.

Here, regarding the time for inputting the above-mentioned measurement results into the control device, for example, the measurement results can be input to the control device every time the number of fixed scales increases by about 1000 kl before about 5000 kl. The measurement result of about 200kl is input to the control device, so that the flow state of the mixed fluid 7 can be known more accurately.

The preferred embodiments of the present invention have been described, and the present invention is not limited to the above-mentioned embodiments.

For example, the present invention is applicable not only to a VLCC, but also to a VLCC, which is a crude oil tanker larger than a VLCC, or a crude oil tanker smaller than a VLCC.

According to the naphtha transportation method of the present invention, since the crude oil tanker with low transportation cost can be used to transport the naphtha, the cost of the naphtha can be greatly reduced, and the purchase price of the naphtha can be reduced.

According to the transfer method of crude oil and naphtha of the present invention, the crude oil group and the naphtha group are loaded together on the crude oil tanker, and the piping dedicated to crude oil is shared from the offshore berth, so that the mixing of crude oil and naphtha can be minimized. Crude oil and naphtha are separately received into separate tanks.

That is, even if the naphtha is transferred from the crude oil tanker that transports the naphtha to the tank on land using the piping for crude oil, the mixing of crude oil and naphtha (naphtha contamination) can be suppressed as a raw material Below the level where naphtha can be used.

Industrial availability

The present invention can be applied not only to tankers (ships), but also to, for example, trucks with oil tanks, automobiles, airplanes, and the like.

Claims (14)

1. method with carrier transportation coal tar naphtha, it is the transportation resources that utilizes the coal tar naphtha of the carrier that transports crude oil, it is characterized in that, the at least a portion that is located at a plurality of carrier cabin in the above-mentioned carrier is appointed as coal tar naphtha loads usefulness, this coal tar naphtha being loaded the inside in the above-mentioned carrier cabin of usefulness cleans before the coal tar naphtha of packing in advance, from be used to pack into crude oil or unload extract crude oil out in the pipe arrangement of crude oil after, adopt this pipe arrangement to carry out packing into of above-mentioned coal tar naphtha or draw off.

2. the method with carrier transportation coal tar naphtha as claimed in claim 1 is characterized in that the in-to-in that is loaded the above-mentioned carrier cabin of above-mentioned coal tar naphtha by crude oil cleans.

3. the method with carrier transportation coal tar naphtha as claimed in claim 1 or 2 is characterized in that above-mentioned carrier is the ultra-large type crude oil tanker that surpasses 150,000 weight ton.

4. the method with carrier transportation coal tar naphtha as claimed in claim 1 is characterized in that, avoids connecting the above-mentioned oil transportation body cabin that is used to extract out the gargle pipe of crude oil in the above-mentioned pipe arrangement, specifies coal tar naphtha to load the carrier cabin of usefulness.

5. the method with carrier transportation coal tar naphtha as claimed in claim 1, it is characterized in that, when packing above-mentioned coal tar naphtha into, at the initial stage of loading after just having begun, the speed that stirs with the former oil residue that is unlikely to the to remain in above-mentioned carrier bilge portion above-mentioned coal tar naphtha of packing at leisure.

6. the method with carrier transportation coal tar naphtha as claimed in claim 1, it is characterized in that the speed that stirs with the former oil residue that is unlikely to remain in above-mentioned carrier bilge portion is carried out unloading of above-mentioned coal tar naphtha at leisure when unloading above-mentioned coal tar naphtha.

7. the method with carrier transportation coal tar naphtha as claimed in claim 1, it is characterized in that, the quantity in the above-mentioned carrier cabin that decision is used according to the carrying capacity of above-mentioned coal tar naphtha, and in order to control because the center of gravity of the density of crude oil and coal tar naphtha or the different above-mentioned carrier of bringing of proportion moves the above-mentioned carrier cabin of specifying the above-mentioned coal tar naphtha of loading.

8. the forwarding method of crude oil and coal tar naphtha in the method conveying naphtha according to the transportation coal tar naphtha of claim 1, with shared carrier conveying crude oil, passes on crude oil and coal tar naphtha by a pipe arrangement from the carrier cabin to holding bay, it is characterized in that,

(1) with above-mentioned pipe arrangement from above-mentioned carrier cabin when above-mentioned holding bay is sent above-mentioned coal tar naphtha or crude oil, in advance with above-mentioned pipe arrangement and crude oil with or the cabin used of coal tar naphtha be connected,

Simultaneously, (2) calculate the crude oil that is trapped in the above-mentioned pipe arrangement that connects above-mentioned carrier cabin and holding bay or the amount of coal tar naphtha in advance,

(3) send from above-mentioned carrier cabin coal tar naphtha or crude oil, calculate its sendout simultaneously,

(4) in the amount of the amount of sending coal tar naphtha or crude oil from above-mentioned carrier cabin and stagnate the crude oil above-mentioned pipe arrangement or the coal tar naphtha of calculating in advance during almost with amount, stop from the coal tar naphtha in above-mentioned carrier cabin or sending of crude oil, the cabin of accepting the place is switched to the cabin that coal tar naphtha or crude oil are used from the cabin that crude oil is used or coal tar naphtha is used

(5) after having switched above-mentioned cabin, carry out again from the coal tar naphtha in above-mentioned carrier cabin or sending of crude oil, coal tar naphtha or crude oil are stored in the cabin that coal tar naphtha or crude oil uses.

9. the forwarding method of crude oil as claimed in claim 8 and coal tar naphtha, it is characterized in that, carry out the mobile parsing of the fluid-mixing of forming by crude oil, coal tar naphtha and by crude oil and coal tar naphtha in the above-mentioned pipe arrangement, utilize this mobile analysis result to determine to stop from the coal tar naphtha in above-mentioned carrier cabin or sending of crude oil.

10. the forwarding method of crude oil and coal tar naphtha as claimed in claim 8 or 9 is characterized in that, when calculating the crude oil that stagnates in above-mentioned pipe arrangement or coal tar naphtha amount in advance, with temperature at least, density or the proportion of the crude oil that is being detained or coal tar naphtha as the revisal key element.

11. the forwarding method of crude oil as claimed in claim 8 and coal tar naphtha is characterized in that, utilizes the above-mentioned nonadjustable signal of accepting the cabin in place to measure from the coal tar naphtha in above-mentioned carrier cabin or the sendout of crude oil.

12. the forwarding method of crude oil as claimed in claim 8 and coal tar naphtha is characterized in that, according to above-mentioned mobile analysis result the coal tar naphtha when the crude oil be trapped in the above-mentioned pipe arrangement or coal tar naphtha are released in the cabin or the rate of delivery of crude oil is changed.

13. the forwarding method of crude oil as claimed in claim 12 and coal tar naphtha is characterized in that, before just beginning the sending the back or be about to stop to send of above-mentioned coal tar naphtha or crude oil, the rate of delivery of above-mentioned coal tar naphtha or crude oil is changed.

14. the forwarding method of crude oil as claimed in claim 13 and coal tar naphtha is characterized in that, improves the above-mentioned coal tar naphtha after sending of above-mentioned coal tar naphtha or crude oil just begins or the rate of delivery of crude oil hastily with the rate of delivery of regulation.

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