Patent Description:
Water level build-up in hydrocarbon storage tanks is an unfortunate and inevitable side effect in oil production. In order to avoid sending this unwanted byproduct to downstream refineries, operators manually discharge the water from the storage tank using drain lines. However, this task requires large amounts of man-power, which prevents the operators from focusing on more important tasks, as well as placing the operators at risk of injury or exposure to chemicals. In addition, failure to adequately drain water from the hydrocarbon tanks can cause processing issues for subsequent refineries. <CIT> discloses a system which is capable of measuring the thickness of an emulsion layer in a desalter. <CIT> discloses a method and a system for controlling a separator unit for multiphase separation of fluids of different densities, wherein either a pressure in the separator unit or a level of one or more of the liquids in the separator unit is adjusted in relation to a reference value. <CIT> discloses a method for detecting information concerning an emulsion layer within a desalter vessel. <CIT> discloses an adjustable weir apparatus with a wellhead separator system fed by petrochemical source with oil box and water box along with outlets for oil and water. <CIT> discloses a method and apparatus for determining the quantity of a contaminant in a liquid by analysing a characteristic of a radiation signal generated in a liquid column at one end and detected at the other end a known distance from the generation point. <CIT> discloses an improved separator for desalting petroleum crude oils which may be operated in a continuous manner under automatic control.

Automatic tank dewatering apparatuses have been introduced; however, they suffer from serious drawbacks such as: requiring major modifications in the tank or the drain piping for installation, requiring frequent calibration and maintenance, running the risk of service buildup on the sensors or transducers, and having high costs to implement. In addition, automatic tank dewatering apparatuses do not measure the presence or quantity of water in the hydrocarbon storage tank. Typically, the presence or quantity of water is determined when a dewatering cycle is initiated such that fluids are flowing in the drain pipe. However, losses of certain quantities of hydrocarbons flowing in the drain pipe are inevitable when the dewatering cycle is initiated.

Embodiments of the disclosure generally relate to dewatering a hydrocarbon storage tank. More specifically, embodiments of the disclosure relate to a method for removing water level build-up in a hydrocarbon storage tank.

Advantageously, embodiments of the disclosure provide a method for automatically draining water from a hydrocarbon storage tank using an oil-water interface sensor, an analytics sensor, a control system and a controllable valve.

Embodiments of the disclosure provide a method for removing water build-up in a hydrocarbon storage tank. The water build-up creates an oil-water interface in the hydrocarbon storage tank. The method includes the step of generating a first input data stream and a second input data stream using an oil-water interface sensor located in the hydrocarbon storage tank. The oil-water interface sensor includes a first probe and a second probe. The first probe is located at a bottom portion of the hydrocarbon storage tank. The first probe generates the first input data stream. The second probe is located above the first probe. The second probe generates the second input data stream. The method includes the step of processing the first input data stream and the second input data stream to determine a vertical displacement of the oil-water interface. The method includes the step of comparing the vertical displacement of the oil-water interface against a first predetermined value. The method includes the step of generating an output data stream responsive to the comparing step. The output data stream includes instructions to maintain a controllable valve either in an open position or in a closed position. The method includes the step of communicating the output data stream to the controllable valve such that the controllable valve is maintained either in the open position or in the closed position. The controllable valve is fluidly connected to a drain line. The drain line is fluidly connected to the bottom portion of the hydrocarbon storage tank. The integrity of the controllable valve is monitored using an analytics sensor. The analytics sensor is a sound velocity sensor located on a vertical section of the drain line. The sound velocity sensor measures the sound velocity of a transmitted sound wave travelling across the drain line. The water build-up is removed via the drain line as the controllable valve is maintained in the open position.

In some embodiments, the second probe is tethered from a top portion of the hydrocarbon storage tank. In some embodiments, the first probe and the second probe are located on a side wall of the hydrocarbon storage tank. In some embodiments, the first probe is located below the oil-water interface and the second probe is located above the oil-water interface. In some embodiments, the first probe and the second probe are pressure sensors. The first input data stream and the second input data stream include hydraulic pressure data. In some embodiments, the method further includes the step of generating a third input data stream using the oil-water interface sensor. The oil-water interface sensor includes a temperature sensor. The third input data stream includes liquid temperature data. In the processing step, the third input data stream is used to correct density values of liquid hydrocarbon and water present in the hydrocarbon storage tank. In some embodiments, the first probe and the second probe are sound velocity sensors. The first input data stream and the second input data stream include sound velocity data. In some embodiments, the method further includes the step of generating a third input data stream using the oil-water interface sensor. The oil-water interface sensor includes a temperature sensor. The third input data stream includes liquid temperature data. In the processing step, the third input data stream is used to correct sound velocity values in liquid hydrocarbon and water present in the hydrocarbon storage tank. In some embodiments, one of the first probe and the second probe includes a transducer and one of the first probe and the second probe includes a receiver. In some embodiments, the method further includes the step of generating a fourth input data stream using the analytics sensor. The fourth input data stream includes sound velocity data. The method further includes the step of comparing sound velocity against a second predetermined value. In some embodiments, the method further includes the step of providing an alarm to an operator responsive to the comparing sound velocity step.

There is described but not claimed a dewatering system for removing water build-up in a hydrocarbon storage tank. The water build-up creates an oil-water interface in the hydrocarbon storage tank. The dewatering system includes the hydrocarbon storage tank, an oil-water interface sensor, a drain line, a controllable valve, an analytics sensor, and a control system. The oil-water interface sensor is located in the hydrocarbon storage tank. The oil-water interface sensor includes a first probe and a second probe. The first probe is located at a bottom portion of the hydrocarbon storage tank. The first probe generates a first input data stream. The second probe is located above the first probe. The second probe generates a second input data stream. The drain line is fluidly connected to the bottom portion of the hydrocarbon storage tank. The controllable valve is fluidly connected to the drain line. The controllable valve is configured to remove the water build-up via the drain line in an open position. The analytics sensor is a sound velocity sensor located on a vertical section of the drain line. The sound velocity sensor is configured to measure the sound velocity of a transmitted sound wave travelling across the drain line. The analytics sensor is configured to monitor integrity of the controllable valve. The control system is electronically connected to the first probe, the second probe, the controllable valve, and the analytics sensor. The control system is configured to receive and process the first input data stream and the second input data stream to determine a vertical displacement of the oil-water interface. The control system is configured to make a comparison of the vertical displacement of the oil-water interface against a first predetermined value. The control system is configured to generate an output data stream responsive to the comparison. The control system is configured to transmit the output data stream to the controllable valve. The output data stream includes instructions to maintain the controllable valve either in the open position or in a closed position.

In some designs of the dewatering system, the second probe is tethered from a top portion of the hydrocarbon storage tank. The first probe is located below the oil-water interface and the second probe is located above the oil-water interface. In some embodiments, the first probe and the second probe are pressure sensors. The first input data stream and the second input data stream include hydraulic pressure data. In some embodiments, the oil-water interface sensor includes a temperature sensor. The temperature sensor generates a third input data stream including liquid temperature data. The third input data stream is received and processed by the control system to correct density values of liquid hydrocarbon and water present in the hydrocarbon storage tank. In some embodiments, the first probe and the second probe are sound velocity sensors. The first input data stream and the second input data stream include sound velocity data. In some embodiments, the oil-water interface sensor includes a temperature sensor. The temperature sensor generates a third input data stream including liquid temperature data. The third input data stream is received and processed by the control system to correct sound velocity values in liquid hydrocarbon and water present in the hydrocarbon storage tank. The sound velocity sensor generates a fourth input data stream including sound velocity data. The fourth input data stream is received and processed by the control system to make a comparison of sound velocity against a second predetermined value.

So that the manner in which the previously-recited features, aspects, and advantages of the embodiments of this disclosure as well as others that will become apparent are attained and can be understood in detail, a more particular description of the disclosure briefly summarized previously may be had by reference to the embodiments that are illustrated in the drawings that form a part of this specification. However, it is to be noted that the appended drawings illustrate only certain embodiments of the disclosure and are not to be considered limiting of the disclosure's scope as the disclosure may admit to other equally effective embodiments.

The disclosure refers to particular features, including process or method steps and systems. Those of skill in the art understand that the disclosure is not limited to or by the description of embodiments given in the specification. The subject matter of this disclosure is not restricted except only in the appended claims.

Those of skill in the art also understand that the terminology used for describing particular embodiments does not limit the scope or breadth of the embodiments of the disclosure. In interpreting the specification and appended claims, all terms should be interpreted in the broadest possible manner consistent with the context of each term. All technical and scientific terms used in the specification and appended claims have the same meaning as commonly understood by one of ordinary skill in the art to which this disclosure belongs unless defined otherwise.

Although the disclosure has been described with respect to certain features, it should be understood that the features and embodiments of the features can be combined with other features and embodiments of those features.

Although the disclosure has been described in detail, it should be understood that various changes, substitutions, and alternations can be made without departing from the principle and scope of the disclosure. Accordingly, the scope of the present disclosure should be determined by the following claims and their appropriate legal equivalents.

As used throughout the disclosure, the singular forms "a," "an," and "the" include plural references unless the context clearly indicates otherwise.

As used throughout the disclosure, the word "about" includes +/- <NUM>% of the cited magnitude.

As used throughout the disclosure, the words "comprise," "has," "includes," and all other grammatical variations are each intended to have an open, non-limiting meaning that does not exclude additional elements, components or steps. Embodiments of the present disclosure may suitably "comprise," "consist," or "consist essentially of" the limiting features disclosed, and may be practiced in the absence of a limiting feature not disclosed. For example, it can be recognized by those skilled in the art that certain steps can be combined into a single step.

As used throughout the disclosure, the words "optional" or "optionally" means that the subsequently described event or circumstances can or may not occur. The description includes instances where the event or circumstance occurs and instances where it does not occur.

Where a range of values is provided in the specification or in the appended claims, it is understood that the interval encompasses each intervening value between the upper limit and the lower limit as well as the upper limit and the lower limit. The disclosure encompasses and bounds smaller ranges of the interval subject to any specific exclusion provided.

Where reference is made in the specification and appended claims to a method comprising two or more defined steps, the defined steps can be carried out in any order or simultaneously except where the context excludes that possibility.

As used throughout the disclosure, terms such as "first" and "second" are arbitrarily assigned and are merely intended to differentiate between two or more components of an apparatus. It is to be understood that the words "first" and "second" serve no other purpose and are not part of the name or description of the component, nor do they necessarily define a relative location or position of the component. Furthermore, it is to be understood that that the mere use of the term "first" and "second" does not require that there be any "third" component, although that possibility is contemplated under the scope of the present disclosure.

As used throughout the disclosure, spatial terms described the relative position of an object or a group of objects relative to another object or group of objects. The spatial relationships apply along vertical and horizontal axes. Orientation and relational words such are for descriptive convenience and are not limiting unless otherwise indicated.

<FIG> shows a schematic diagram of a prior art dewatering system <NUM>. The dewatering system <NUM> includes dewatering tank <NUM>, drain line <NUM>, sound velocity detector <NUM>, control system <NUM>, electronic wiring <NUM>, <NUM>, and controllable valve <NUM>.

Dewatering tank <NUM> contains hydrocarbons and water. Because the hydrocarbons are less dense than the water, the hydrocarbons float to the top, and the water settles to the bottom, thus forming two layers. Drain line <NUM> is generally located on the bottom portion of dewatering tank <NUM> in order to remove water as opposed to hydrocarbons. Sound velocity detector <NUM> is located on a vertical section of drain line <NUM> in order to ensure that there is a full volumetric flow at the point where the measurements are being taken. Control system <NUM> is in electronic communication <NUM> with sound velocity detector <NUM>. Control system <NUM> is in electronic communication <NUM> with controllable valve <NUM>. Controllable valve <NUM> is open when only water is detected and is closed when oil is detected.

Sound velocity detector <NUM> detects and passes water during a dewatering sequence. The dewatering sequence continues until sound velocity detector <NUM> detects hydrocarbons which triggers the closing of controllable valve <NUM>. Because sound velocity detector <NUM> must detect hydrocarbons to terminate the dewatering sequence, drain line <NUM> inevitably includes a certain degree of hydrocarbons between sound velocity detector <NUM> and controllable valve <NUM>. In some embodiments, the residual hydrocarbons trapped in drain line <NUM> could result in damage to controllable valve <NUM>. This leads to necessarily flushing drain line <NUM> in order to reinitiate the dewatering sequence.

<FIG> shows a schematic diagram of a dewatering system <NUM>, according to an embodiment of the disclosure. The dewatering system <NUM> includes dewatering tank <NUM>, drain line <NUM>, oil-water interface sensor including first probe <NUM> and second probe <NUM>, analytics sensor <NUM>, control system <NUM>, electronic wiring <NUM>, <NUM>, <NUM>, <NUM>, and controllable valve <NUM>.

Dewatering tank <NUM> contains hydrocarbons and water. Because the hydrocarbons are less dense than the water, the hydrocarbons float to the top, and the water settles to the bottom, thus forming two layers, hydrocarbon layer <NUM> and water layer <NUM>. The vertical displacement of the oil-water interface <NUM> is calculated by processing certain data generated via first probe <NUM> and second probe <NUM>, which are located inside of dewatering tank <NUM>. As a non-limiting example, first probe <NUM> can be generally located close to or at the bottom portion of dewatering tank <NUM>. First probe <NUM> can be tethered from the top of the dewatering tank <NUM>. Second probe <NUM> can be located in hydrocarbon layer <NUM> by tethering it from the top of dewatering tank <NUM>. In alternate embodiments, first probe <NUM> and second probe <NUM> can be located on the side wall of dewatering tank <NUM>. Control system <NUM> is in electronic communication <NUM>, <NUM> with first probe <NUM> and second probe <NUM>, respectively. Drain line <NUM> is generally located close to or at the bottom portion of dewatering tank <NUM> in order to remove water as opposed to hydrocarbons. Analytics sensor <NUM> is located on a vertical section of drain line <NUM> in order to ensure that there is a full volumetric flow at the point where the measurement is being taken. Control system <NUM> is in electronic communication <NUM> with analytics sensor <NUM>. Control system <NUM> is in electronic communication <NUM> with controllable valve <NUM>. Controllable valve <NUM> is in its open configuration during a dewatering sequence. Controllable valve <NUM> is in its closed configuration before the dewatering sequence or when the dewatering sequence is ceased.

In some embodiments, first probe <NUM> and second probe <NUM> can include pressure sensors. The pressure sensors can provide hydraulic pressure data to control system <NUM> wiredly or wirelessly using communication protocols known in the art. In an embodiment, each of the pressure sensors can generate the hydraulic pressure data at its predetermined height and communicate the hydraulic pressure data to control system <NUM>. Control system <NUM> calculates the vertical displacement of oil-water interface <NUM> to determine whether to maintain controllable valve <NUM> in the open or closed configuration. For example, if the vertical displacement of oil-water interface <NUM> is greater than a predetermined value, control system <NUM> can transmit an output signal to controllable valve <NUM> to be in its open configuration. In this manner, the dewatering sequence can be initiated to drain water. Conversely, if the vertical displacement of oil-water interface <NUM> is less than a predetermined value, control system <NUM> can transmit an output signal to controllable valve <NUM> to be in its closed configuration. In this manner, the dewatering sequence can be ceased. Optionally, oil-water interface sensor can include a temperature sensor to generate liquid temperature data and communicate the liquid temperature data to control system <NUM>. Control system <NUM> can adjust the temperature-dependent density values of each of hydrocarbon layer <NUM> and water layer <NUM>. In some embodiments, control system <NUM> can calculate the vertical displacement of the top surface of hydrocarbon layer <NUM>.

The vertical displacement of oil-water interface <NUM> (denoted as Δh) can be calculated by using the following formula (<NUM>): <MAT> where the vertical displacement between first probe <NUM> and second probe <NUM> is denoted as h<NUM>, the vertical displacement between second probe <NUM> and the top of hydrocarbon layer <NUM> is denoted as h<NUM>, hydraulic pressure data measured by first probe <NUM> is denoted as P<NUM>, hydraulic pressure data measured by second probe <NUM> is denoted as P<NUM>, density of hydrocarbon layer <NUM> is denoted as ρo, density of water layer <NUM> is denoted as ρw, and gravitational acceleration is denoted as g.

In alternate embodiments, first probe <NUM> and second probe <NUM> can include sound velocity sensors. One of the first probe <NUM> and second probe <NUM> can include a transducer. The other of first probe <NUM> and second probe <NUM> can include a receiver. In other embodiments, the first probe <NUM> and second probe <NUM> can include a transceiver. The sound velocity sensors can measure the sound velocity of a transmitted sound wave travelling through oil layer <NUM> and water layer <NUM> between first probe <NUM> and second probe <NUM>. The sound velocity sensors can provide sound velocity data to control system <NUM> wiredly or wirelessly using communication protocols known in the art. In an embodiment, the sound velocity sensors can generate the sound velocity data and communicate the sound velocity data to control system <NUM>. Control system <NUM> calculates the vertical displacement of oil-water interface <NUM> to determine whether to maintain controllable valve <NUM> in the open or closed configuration. For example, if the vertical displacement of oil-water interface <NUM> is greater than a predetermined value, control system <NUM> can transmit an output signal to controllable valve <NUM> to be in its open configuration. In this manner, the dewatering sequence can be initiated to drain water. Conversely, if the vertical displacement of oil-water interface <NUM> is less than a predetermined value, control system <NUM> can transmit an output signal to controllable valve <NUM> to be in its closed configuration. In this manner, the dewatering sequence can be ceased. Optionally, oil-water interface sensor can include a temperature sensor to collect liquid temperature data and communicate the liquid temperature data to control system <NUM>. Control system <NUM> can adjust the temperature-dependent sound velocity values in each of hydrocarbon layer <NUM> and water layer <NUM>. In some embodiments, control system <NUM> can calculate the vertical displacement of the top surface of hydrocarbon layer <NUM>.

Analytics sensor <NUM> is a sound velocity sensor. Analytics sensor <NUM> can include a transceiver. In other embodiments, analytics sensor <NUM> can include two sensors, a transmitter and a receiver. The sound velocity sensor can measure the sound velocity of a transmitted sound wave travelling across drain line <NUM> where water fully encompasses the inner volume of drain line <NUM> at the point of measurement. The sound velocity sensor can also measure flow rate and volume of the liquid at the point of measurement in drain line <NUM>. The sound velocity sensor can provide sound velocity data to control system <NUM> wiredly or wirelessly using communication protocols known in the art. In an embodiment, the sound velocity sensor can generate the sound velocity data and communicate the sound velocity data to control system <NUM>. Control system <NUM> can determine whether there is a deviation in the continuously provided sound velocity data which is indicative of non-water media present in drain line <NUM>. For example, a sound velocity at any given moment less than a predetermined value can be indicative of hydrocarbon present in drain line <NUM> due to a reduction in density. In an embodiment, an alarm can be provided to an operator when non-water media is detected in drain line <NUM>. In an embodiment, control system <NUM> can transmit an output signal to controllable vale <NUM> to be in its closed configuration such that drainage of hydrocarbons is prevented. In this manner, the dewatering sequence can be ceased. Advantageously, analytics sensor <NUM> can be used as a backup to oil-water interface sensor in the event oil-water interface sensor is not properly operating.

Analytics sensor <NUM> monitors the integrity of controllable valve <NUM>. Analytics sensor <NUM> can provide information whether controllable valve <NUM> is defective. For example, a defective controllable valve <NUM> can be observed if analytics sensor <NUM> detects a flow in drain line <NUM> in the event controllable valve <NUM> is in its closed configuration. In addition, a defective controllable valve <NUM> can be observed if analytics sensor <NUM> detects a flow in drain line <NUM> despite control system <NUM> transmitting an output signal to close controllable valve <NUM>.

In some embodiments, control system <NUM> can be a distributed control system (DCS), a terminal monitoring system (TMS), a programmable logic controller (PLC), or any other similar customizable control system. Control system <NUM> can be either mounted in the field or in a control room. Control system <NUM> is operable to receive hydraulic pressure data or sound velocity data from first probe <NUM> and second probe <NUM>. Control system <NUM> is operable to receive sound velocity data from analytics sensor <NUM>. Control system <NUM> is operable to generate and transmit output data to controllable valve <NUM>. Control system <NUM> is operable to display such data. Such data can be in analog or digital form.

Controllable valve <NUM> can be any type of automatically operated valve that provides zero-leakage. Non-limiting examples of controllable valve <NUM> include an air-operated valve with a solenoid, a motor operated valve (MOV), or the like. Non-limiting examples of controllable valve <NUM> also include a gate valve, a ball valve, a butterfly valve, or the like.

As shown in <FIG>, the dewatering sequence is initiated or ceased based on certain data generated by oil-water interface sensor which is located inside the hydrocarbon storage tank. Because oil-water interface sensor is capable of detecting the presence of water inside the hydrocarbon storage tank, the dewatering sequence can be initiated only when water is present in the hydrocarbon storage tank. In this manner, an accidental drainage of hydrocarbons in the absence of water can be prevented. In addition, because oil-water interface sensor is located inside the hydrocarbon storage tank, the dewatering sequence can be ceased before having any hydrocarbons trapped in drain line <NUM>. Accordingly, damage to controllable valve <NUM> can be prevented and flushing drain line <NUM> is no longer a necessary step when reinitiating the dewatering sequence.

<FIG> is a schematic representation of a process <NUM> for removing water in a hydrocarbon storage tank <NUM>, according to an embodiment of the disclosure.

In block <NUM>, a first input data stream and a second input data stream are generated using an oil-water interface sensor located in hydrocarbon storage tank <NUM>. The oil-water interface sensor includes first probe <NUM> and second probe <NUM>. First probe <NUM> is located at a bottom portion of hydrocarbon storage tank <NUM>. First probe <NUM> generates the first input data stream. Second probe <NUM> is located above first probe <NUM>. Second probe <NUM> generates the second input data stream.

In block <NUM>, the first input data stream and the second input data stream are communicated to control system <NUM>. Control system <NUM> processes the first input data stream and the second input data stream to determine a vertical displacement of oil-water interface <NUM>.

In block <NUM>, control system <NUM> compares the calculated vertical displacement of oil-water interface <NUM> against a predetermined value.

In block <NUM>, control system <NUM> generates an output data stream responsive to the comparison made in block <NUM>. The output data stream includes instructions to maintain controllable valve <NUM> either in the open configuration or in the closed configuration. For example, if the vertical displacement of oil-water interface <NUM> is greater than the predetermined value, the output data stream can include instructions to maintain controllable valve <NUM> in the open configuration. If the vertical displacement of oil-water interface <NUM> is less than the predetermined value, the output data stream can include instructions to maintain controllable valve <NUM> in the closed configuration.

In block <NUM>, the output data stream is communicated to controllable valve <NUM>. Controllable valve <NUM> is either in the open configuration or in the closed configuration depending on the instructions included in the output data stream. A dewatering sequence is initiated when controllable valve <NUM> changes from the closed configuration to the open configuration. A dewatering sequence is ceased when controllable valve <NUM> changes from the open configuration to the closed configuration.

The disclosure is illustrated by the following examples, which are presented for illustrative purposes only, and are not intended as limiting the scope of the invention which is defined by the appended claims.

A system having a configuration similar to <FIG> was used to determine the vertical displacement of the oil-water interface of a dewatering tank. The dewatering tank was a crude oil tank located at Riyadh Refinery, Saudi Arabia. Two pressure sensors were used as the probes. The first probe was placed about <NUM> meters above the bottom portion of the dewatering tank, tethered from the top of the dewatering tank. The second probe was placed about <NUM> meters vertically above the first probe, also tethered from the top of the dewatering tank. A manual gauge was installed to verify the vertical displacement of the oil-water interface determined by the two probes. Density of the oil present in the dewatering tank was about <NUM> kilogram per cubic decimeter (kg/dm<NUM>). Density of the water present in the dewatering tank was about <NUM>/dm<NUM>. The results are shown in Table <NUM>. The reading values correspond to the vertical displacement of the oil-water interface above the first probe.

Claim 1:
A method for removing water build-up in a hydrocarbon storage tank (<NUM>), wherein the water build-up creates an oil-water interface (<NUM>) in the hydrocarbon storage tank, the method comprising the steps of:
generating a first input data stream and a second input data stream using an oil-water interface sensor located in the hydrocarbon storage tank, the oil-water interface sensor comprising:
a first probe (<NUM>), the first probe located at a bottom portion of the hydrocarbon storage tank, the first probe generating the first input data stream; and
a second probe (<NUM>), the second probe located in the hydrocarbon storage tank above the first probe, the second probe generating the second input data stream;
processing the first input data stream and the second input data stream to determine a vertical displacement of the oil-water interface;
comparing the vertical displacement of the oil-water interface against a first predetermined value;
generating an output data stream responsive to the comparing step, wherein the output data stream includes instructions to maintain a controllable valve (<NUM>) either in an open position or in a closed position;
communicating the output data stream to the controllable valve such that the controllable valve is maintained either in the open position or in the closed position;
wherein the controllable valve is fluidly connected to a drain line (<NUM>), the drain line fluidly connected to the bottom portion of the hydrocarbon storage tank; and
monitoring integrity of the controllable valve using an analytics sensor (<NUM>), wherein the analytics sensor is a sound velocity sensor located on a vertical section of the drain line, the sound velocity sensor measuring the sound velocity of a transmitted sound wave travelling across the drain line,
wherein the water build-up is removed via the drain line as the controllable valve is maintained in the open position.