Patent Description:
As a gas turbine engine system operates, airborne contaminants that are not captured by the inlet air filtration system may accumulate naturally or form complex compounds with combustion byproducts and bond to various internal metallic components of the engine, such as the blades and the vanes of internal components. These internal metallic components may include but are not limited to the gas turbine and the compressor. Although the gas turbine engine system may include an inlet air filtration system, a certain degree of contaminant accumulation may be unavoidable and may depend on various environmental conditions at the site of operation. Common contaminants may include small amounts of dust and debris that pass through the inlet air filtration system as well as un-filterable hydrocarbon-based materials such as smoke, soot, grease, oil film, and organic vapors. Accumulated contaminants on, for example, the blades and vanes may restrict airflow through the compressor and may shift the airfoil pattern. In this manner, such accumulation may compromise cooling passages and adversely affect the performance and efficiency of the compressor or turbine section and thus the overall performance and efficiency of the gas turbine engine system. Such effects may decrease power output, increase fuel consumption, and/or increase operating costs.

To reduce contaminant accumulation, the gas turbine engine operating and maintenance regime may include the utilization of a water wash procedure for removing contaminating particles from, for example, the compressor blades and vanes. An on-line water wash protocol may be used to remove contaminant particles from compressor blades and vanes via a flow of water, such as demineralized water, while the gas turbine engine system is operating at full speed and at a predetermined load. The on-line water wash protocol may deliver water upstream of the compressor via an installed manifold including nozzles positioned about a bellmouth of the compressor. The nozzles may create a spray mist of water droplets in this region of relatively low velocity air, and the negative pressure produced by the operating compressor may draw the spray mist into contact with the compressor blades and vanes for contaminant removal.

An off-line water wash protocol may be used in a similar manner to remove contaminating particles via a sequential flow of water and detergent while the gas turbine engine system is shut down or operating at a turning gear speed and is not loaded. Known off-line water wash systems may sequentially deliver the flow of water and detergent upstream of the compressor via an off-line manifold including nozzles positioned about a bellmouth of the compressor. In certain applications, a water wash system may be configured to operate in either an on-line mode or an off-line mode. In this manner, on-line washes may be carried out periodically to increase performance and efficiency of the gas turbine engine system when the operating schedule does not permit shutdown time to perform a more effective off-line wash. The frequency and duration of on-line and off-line washes may vary depending on the degree of contaminant accumulation and environmental conditions at the site of operation.

Although conventional water wash systems and methods may be effective in removing contaminants from the blades and vanes of early compressor stages, such systems and methods often are less effective in removing contaminants from the higher numbered stages of blades and vanes of the gas turbine because the flow of water and detergent (if any) injected about the bellmouth of the compressor sometimes has limited reach. Gas turbine hot gas path components, including but not limited to, gas turbine blades and nozzles, shrouds may still have some contamination. Moreover, following a wash with such systems and methods, residual amounts of the water and detergent may remain on the blades and vanes. Remaining water and/or detergent may adversely affect subsequent restart and operation of the gas turbine engine system. Depending on the idle time after wash, the residual amounts of water and detergent also may facilitate surface rusting, corrosion, or subsequent accumulation of contaminants on the compressor blades and vanes and/or gas turbine blades and vanes, and on uncoated combustion components along the hot gas flow path. Further, the performance gain provided by conventional water wash systems and methods may be of limited duration, necessitating frequent washes carried out with the water wash systems to maintain adequate performance, which ultimately may increase total operating costs of the gas turbine engine system.

<CIT> relates to off-line wash systems and methods for a gas turbine engine. In particular, the document is directed to the cleaning of the compressor through the injection of a cleaning agent in the compressor bellmouth via a supply line.

According to a first aspect, the present invention provides a method of washing an off-line gas turbine engine as set forth in claim <NUM>. Further aspects of the present invention are provided in the dependent claims.

The scope of the invention is solely defined by the appended claims.

The drawings are intended to depict only typical aspects of the disclosure and therefore should not be considered as limiting the scope of the disclosure. In the drawings, like numbering generally represents like elements between the drawings.

As an initial matter, in order to clearly describe the subject matter of the current disclosure, it will become necessary to select certain terminology when referring to and describing relevant machine components within a turbine system, such as but not limited to a gas turbine engine system. To the extent possible, common industry terminology will be used and employed in a manner consistent with its accepted meaning. Unless otherwise stated, such terminology should be given a broad interpretation consistent with the context of the present application and the scope of the appended claims. Those of ordinary skill in the art will appreciate that often a particular component may be referred to using several different or overlapping terms. What may be described herein as being a single part may include and be referenced in another context as consisting of multiple components. Alternatively, what may be described herein as including multiple components may be referred to elsewhere as a single part.

In addition, several descriptive terms may be used regularly herein, and it should prove helpful to define these terms at the onset of this section. These terms and their definitions, unless stated otherwise, are as follows. As used herein, "downstream" and "upstream" are terms that indicate a direction relative to the flow of a fluid, such as the working fluid through the turbine engine or, for example, the flow of air through the combustor or coolant through one of the turbine's component systems. The term "downstream" corresponds to the direction of flow of the fluid, and the term "upstream" refers to the direction opposite to the flow (i.e., the direction from which the flow originates). The terms "forward" and "aft," without any further specificity, refer to directions, with "forward" referring to the front or compressor end of the engine, and "aft" referring to the rearward section of the turbomachine.

It is often required to describe parts that are disposed at differing radial positions with regard to a center axis. The term "radial" refers to movement or position perpendicular to an axis. For example, if a first component resides closer to the axis than a second component, it will be stated herein that the first component is "radially inward" or "inboard" of the second component. If, on the other hand, the first component resides further from the axis than the second component, it may be stated herein that the first component is "radially outward" or "outboard" of the second component. The term "axial" refers to movement or position parallel to an axis. Finally, the term "circumferential" refers to movement or position around an axis. It will be appreciated that such terms may be applied in relation to the center axis of the turbine.

The terms "first," "second," and "third," may be used interchangeably to distinguish one component from another and are not intended to signify location or importance of the individual components.

It will be further understood that the terms "comprises" and/or "comprising," when used in this specification, specify the presence of stated features, integers, steps, operations, elements, and/or components but do not preclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and/or groups thereof. "Optional" or "optionally" means that the subsequently described event or circumstance may or may not occur or that the subsequently describe component or element may or may not be present, and that the description includes instances where the event occurs or the component is present and instances where it does not or is not present.

Where an element or layer is referred to as being "on," "engaged to," "connected to" or "coupled to" another element or layer, it may be directly on, engaged to, connected to, or coupled to the other element or layer, or intervening elements or layers may be present. In contrast, when an element is referred to as being "directly on," "directly engaged to," "directly connected to" or "directly coupled to" another element or layer, there may be no intervening elements or layers present.

Gas turbine fuels can range from natural gas and high-quality liquid distillate fuels to crude oils and low-grade refinery residues and combustible residual gases from some processes like steel manufacturing. For some gas turbine fuels, there may be additives needed for efficiency and effective operation of a gas turbine. Additives can vary based on the fuel type and the nature and quantity of contaminants from all sources that enter the gas turbine. Additional factors for additive selection, such as but not limited to firing temperature and original equipment manufacturer (OEM) specifications, are also considered.

Many fuel additives are intended to control high temperature corrosion and ash fouling of gas turbine hot gas path section components. Several different corrosion mechanisms can occur during combustion, and generally may be attributed to formation of low melting point ash deposits. These ash deposits may originate from trace metal impurities in gas turbine fuels. For example, heavy fuel oils (HFOs), including but not limited to crude oils and residual-grade fuel oils, typically contain quantities of vanadium (V). Vanadium is a naturally occurring component of petroleum.

During combustion, fuels including vanadium may create vanadic ash deposits. Vanadic ash deposits are formed mainly of vanadium pentoxide (V<NUM>O<NUM>), and have a "low" melting point of about <NUM> (<NUM>°F). At typical gas turbine operating temperatures, vanadic ash deposits are molten. Being molten, vanadic ash deposits may accelerate surface oxidation rate of hot gas path components of gas turbines. Gas turbine hot gas path components include, but are not limited to combustion liners, transition pieces, turbine nozzles, turbine blades, and turbine vanes. Other trace metal impurities, such as lead, and zinc, may also initiate high temperature corrosion, by similar mechanisms.

Alkali metal impurities, namely sodium (Na) and potassium (K), can also cause high temperature corrosion, known as sulfidation corrosion. Sulfidation corrosion involves formation of sodium sulfates, through reaction with fuel sulfur. Sulfidation corrosion results in intergranular pitting of gas turbine hot gas path components, which is metallurgically undesirable.

In certain regions, especially the Middle East, vanadium and sodium impurities are common in fuel. Thus, lower melting point ash deposits can readily form in a gas turbine system in this region. Accordingly, with non-treated or additive free gas turbine fuel from these regions, a risk of high temperature corrosion in a gas turbine system is increased.

Sodium and potassium salts are water-soluble and can be removed (or at least reduced to within acceptable specification limits) by on-site treatment processes. These on-site treatments processes are known as "fuel washing.

Distillate-grade fuels are not typically washed at the gas turbine power plant. Distillate-grade fuels may often be delivered containing some amount of contamination, such as but not limited to sodium contamination. Moreover, vanadium and other oil-soluble trace metals cannot be removed by fuel washing. Corrosion inhibition processes and treatments to remove some contamination, such as but not limited to vanadium contamination, may have to be achieved using chemical additives, as described herein.

Liquid fuels are not the only source of ash-forming impurities or contamination. Sodium salts and other contaminants can be found in gas turbine fuel and thusly enter gas turbine engine systems in various manners. Contaminants may enter a gas turbine engine system from gas turbine fuel, from compressor inlet air, from water and steam that may be injected for nitrogen oxide (NOx) control, from power augmentation steps, and/or from other such sources. Thus, risk of contamination from non-fuel sources should also be considered in gas turbine engine system applications.

Fuel additives that include magnesium (Mg) can be used to control vanadic ash deposits and vanadic oxidation. Magnesium can modify vanadic ash composition and increase vanadic ash melting points, which reduces the possibility of molten vanadium causing issues. Through combination with V<NUM>O<NUM> at an appropriate magnesium-to-vanadium (Mg/V) treatment ratio, magnesium ortho-vanadate [3MgO. V<NUM>O<NUM>] is formed as a new ash component. V<NUM>O<NUM> has a high melting point of about <NUM> (<NUM>°F). Accordingly, with 3MgO. V<NUM>O<NUM> vanadic ash corrosion of a gas turbine engine system is limited and controlled. By ensuring that vanadic ash as a combustion ash does not melt and remains in a solid state on gas turbine blades and vanes, vanadic ash corrosion can be reduced.

Through reaction with sulfur in gas turbine fuel, magnesium inhibition mechanisms through formation of 3MgO. V<NUM>O<NUM> also generate magnesium sulfate (MgSO<NUM>) as an additional ash component. MgSO<NUM> is water-soluble. Thus, MgSO<NUM> facilitates removal of combustion ash through periodic water washing of gas turbine hot gas path components. The removal of combustion ash can enable power to be recovered that may have been lost due to ash formation on gas turbine hot gas path components.

Chromium (Cr) additives for gas turbine fuels can inhibit sulfidation corrosion promoted by alkali metal contaminants, such as, but not limited to, sodium and potassium. Chromium additives have also been shown to reduce ash fouling. Chromium additive ash fouling reduction may involve formation of volatile compounds with contaminants, which pass through the gas turbine without depositing on hot gas path components. Moreover, additives can include chromium alone, or can be in combination with magnesium and other constituents. Additives containing silicon (Si) can also be added to provide added corrosion protection and improved ash friability from hot gas path components of a gas turbine system.

Magnesium additives are of a sulfonate type chemistry. Sulfonate type chemistry in ash formation is resistant to hydrolysis. Any tendency for gel formation of sulfonate type additives because of water contact with sulfonate ash formations is extremely low. Thus, sulfonate type chemistry additives can mitigate plugging of gas turbine system components, including but not limited to, filters, flow dividers, nozzles, blades, and/or fuel nozzles.

Sulfonate type additives also enable high reactivity during combustion. The high reactivity may permit magnesium to be consumed more efficiently during vanadium inhibition. This high reactivity may be due to extremely small particle sizes of sulfonate type additives, where the particle size of sulfonate type additives are about <NUM> times smaller than magnesium carboxylate (C<NUM>H<NUM>MgN<NUM>O<NUM>) particles. Accordingly, sulfonate magnesium additives can be safely added to gas turbine fuel, thereby ensuring protection without over-treatment.

As used in this application, "offline washing" is where the gas turbine is spun by an external crank, and the gas turbine is in a cooled state using cranking speed. When a gas turbine is off-line, it is not burning fuel or supplying power. As embodied by the disclosure, conversely, an online process is conducted with the gas turbine being at an operating temperature, burning fuel and supplying power.

Referring now to the drawings, in which like numerals refer to like elements throughout the several views, <FIG> illustrates a schematic view of gas turbine engine system or gas turbine engine system <NUM>, as embodied by the disclosure. Gas turbine engine system <NUM> may include a compressor <NUM>. Compressor <NUM> compresses an incoming flow of air <NUM> after air <NUM> flows through inlet filter house <NUM>'. Compressor <NUM> delivers the compressed flow of air <NUM> to a combustor <NUM>. Combustor <NUM> mixes the compressed flow of air <NUM> with a pressurized flow of fuel <NUM> and ignites the mixture to create a flow of combustion gases <NUM>. Although only a single combustor <NUM> is shown, gas turbine engine system <NUM> may include any number of combustors <NUM>. The flow of combustion gases <NUM> is in turn delivered to a gas turbine <NUM>. The flow of combustion gases <NUM> drives gas turbine <NUM> to produce mechanical work. Mechanical work produced in gas turbine <NUM> drives compressor <NUM> via a shaft <NUM> and an external load <NUM>, such as but not limited to, an electrical generator and the like.

Gas turbine fuels can range from natural gas and high-quality liquid distillate fuels to crude oils and low-grade refinery residues. Gas turbine engine system <NUM> may be any one of a number of different gas turbine engines offered by General Electric Company of Schenectady, N. Y, including but not limited to, those such as a <NUM> or a <NUM> series heavy duty gas turbine engine, an H class series heavy duty gas turbine engine, such as an HA gas turbine engine, and the like. The gas turbine engine system <NUM> may have different configurations and may use other types of components. Other gas turbine engines may also be used herein. Multiple gas turbine engines, other types of turbines, and other types of power generation equipment also are also within the scope of the embodiments described herein.

<FIG> is an example of a compressor <NUM> as may be used with gas turbine engine system <NUM> and the like. Compressor <NUM> may include a number of stages <NUM>. Although eighteen stages <NUM> are shown, any number of stages <NUM> may be used. Each stage <NUM> includes a number of circumferentially arranged rotating blades <NUM>. Any number of blades <NUM> may be used. Blades <NUM> may be mounted onto a rotor wheel <NUM>. Rotor wheel <NUM> may be coupled to shaft <NUM> (<FIG>) for rotation therewith. Each stage <NUM> also may include a number of circumferentially arranged stationary vanes <NUM>. Any number of vanes <NUM> may be used. Vanes <NUM> may be mounted within an outer casing <NUM>. Outer casing <NUM> may extend from a bellmouth <NUM> towards gas turbine <NUM>. The flow of air <NUM> (<FIG>) thus enters compressor <NUM> about bellmouth <NUM> and is compressed through blades <NUM> and vanes <NUM> of stages <NUM> before flowing to combustor <NUM> (<FIG>). Bellmouth <NUM> may be provided with water wash injection nozzles (not illustrated for ease of understanding and clarity) for applying water and/or detergents to compressor blades <NUM> and vanes <NUM> of stages <NUM>. However, the water and/or detergent may not flow to all blades <NUM> and vanes <NUM> of stages <NUM> of compressor <NUM>. Moreover, compressor water wash systems do not provide a direct path to gas turbine components, including but not limited to hot gas path components including stage one nozzles (S1N) and stage <NUM> nozzles (S2N), as well as associated wheel space cavities of gas turbine <NUM> (<FIG>) that may get contamination thereon. Accordingly, as embodied by the disclosure, providing injection points for washing gas turbine components, including but not limited to hot gas path components including stage <NUM> nozzles (S1N) and stage <NUM> nozzles (S2N), as well as associated wheel space cavities, may be obtained by locating injection closer to the gas turbine itself.

With reference to <FIG>, a combustor <NUM> includes a first interior <NUM> in which a first fuel supplied thereto by fuel circuit is combustible, and a transition zone <NUM> to gas turbine <NUM>. Gas turbine <NUM> includes rotating turbine blades and nozzles in stages, into which products of at least the combustion are receivable to power rotation of turbine blades. The transition zone <NUM> fluidly couples combustor <NUM> to turbine <NUM>. Transition zone <NUM> includes a second interior <NUM> into which a second fuel is supplied to further the combustion. As shown, combustor <NUM> and transition zone <NUM> combine with one another to generally have a form of a head end <NUM>.

As illustrated in <FIG>, head end <NUM> may include multiple premixing nozzles <NUM>. However, other head end <NUM> configurations are possible. It is understood that versions of other head end <NUM> configurations may be late lean injection (LLI) or axial fuel staging (AFS) combustors(to be described hereinafter with respect to secondary fuel injected into combustor <NUM> AT fuel injectors <NUM>) compatible. For purposes of this description, LLI and AFS are similar and equivalent. An LLI compatible combustor is a combustor with either an exit temperature that exceeds about <NUM>° F or about <NUM>, or a combustor that handles fuels with components that are more reactive than methane with a hot side residence time greater than <NUM> milliseconds (ms).

A plurality of late lean fuel injectors <NUM> are structurally supported by an exterior wall of transition zone <NUM> or by an exterior wall of a sleeve <NUM> around transition zone <NUM> and extend into second interior <NUM> to varying depths. With this configuration, fuel injectors <NUM> may be configured to provide late lean injection (LLI) fuel staging capability. That is, fuel injectors <NUM> are each configured to supply a second fuel (i.e., LLI fuel) to second interior <NUM> by, e.g., fuel injection in a direction that is generally transverse to a predominant flow direction. Fuel injectors <NUM> may inject fuel in this manner through transition zone <NUM>, in any one of a single axial stage, multiple axial stages, a single axial circumferential stage, and/or multiple axial circumferential stages. Conditions within combustor <NUM> and transition zone <NUM> are thus staged to create local zones of stable combustion.

As embodied by the disclosure, an aspect provides a single axial stage that includes operating a single fuel injector <NUM>. Alternatively, multiple axial stages may be operated at multiple axial locations at transition zone <NUM>. Further, embodiments may include a single axial circumferential stage operating fuel injector <NUM> disposed around a circumference of a single axial location of transition zone <NUM>. In other embodiments, multiple axial circumferential stages may be operating fuel injectors <NUM> disposed around a circumference of the transition zone <NUM> at multiple axial locations.

Here, where multiple fuel injectors <NUM> are disposed around a circumference of transition zone <NUM>, fuel injectors <NUM> may be spaced substantially evenly or unevenly from one another. As a non-limiting illustration, eight or ten fuel injectors <NUM> may be disposed at a particular circumferential stage, and for example with two, three, four or five or more fuel injectors <NUM> installed with varying degrees of separation from one another around transition zone <NUM>. Also, where multiple fuel injectors <NUM> are disposed at multiple axial stages of transition zone <NUM>, fuel injectors <NUM> may be in-line and/or staggered with respect to one another.

During operations of gas turbine engine system <NUM>, each fuel injector <NUM> may be jointly or separately activated or deactivated to form one of the single axial stage, the multiple axial stages, the single axial circumferential stage, and the multiple axial circumferential stages. Thus, in an aspect of the embodiments, fuel injectors <NUM> each may be supplied with LLI fuel by a fuel injector <NUM> port or valve <NUM> (hereinafter "valve" <NUM>) disposed between a corresponding fuel injector <NUM> and a fuel circuit. Valve <NUM> signal communicates with a controller <NUM> that sends a signal to valve <NUM> that causes the valve <NUM> to open or close and to thereby activate or deactivate corresponding fuel injector <NUM>.

Thus, if each fuel injector <NUM> is to be simultaneously activated (i.e., multiple axial circumferential stages), controller <NUM> signals to each of the valves <NUM> to open and thereby activate each of the fuel injectors <NUM>. Conversely, if each fuel injector <NUM> of a particular axial stage of transition zone <NUM> is to be activated (i.e., single axial circumferential stage), controller <NUM> includes an element (e.g., but not limited to an electro-mechanical transducer) configured to convert an electrical signal from controller <NUM> to a corresponding adjustment to valves <NUM>, <NUM>. Signals to each of valves <NUM> may correspond to only the fuel injectors <NUM> of the single axial circumferential stage to open and thereby activate each of the fuel injectors <NUM>. Of course, this control system is merely illustrative and it is understood that multiple combinations of fuel injector configurations are possible and that other systems and methods for controlling the activation and deactivation of at least one of fuel injectors <NUM> are available.

In accordance with another aspect of the disclosure, a method of operating a gas turbine engine system <NUM>, in which a turbine <NUM> is fluidly coupled to a combustor <NUM> by a transition zone <NUM> interposed therebetween, is provided. The method includes supplying a first fuel to a first interior <NUM> within combustor <NUM>, combusting the first fuel in first interior <NUM> within combustor <NUM>, supplying a second fuel to second interior <NUM> within transition zone <NUM> in any one of a single axial stage, multiple axial stages, a single axial circumferential stage and multiple axial circumferential stages, and combusting the second fuel and a stream of combustion products, received from first interior <NUM>, in second interior <NUM> within the transition zone.

Supplying of the second fuel to second interior <NUM> in the single axial stage may include activating a single fuel injector <NUM>. Supplying the second fuel to the second interior <NUM> in the multiple axial stages may include activating multiple fuel injectors <NUM> respectively disposed at multiple axial locations of the transition zone <NUM>. Supplying the second fuel to second interior <NUM> in the single axial circumferential stage also includes activating multiple fuel injectors <NUM> respectively disposed around a circumference of transition zone <NUM> at a single axial location thereof. Additionally, supplying the second fuel to second interior <NUM> in the multiple axial circumferential stages includes activating multiple fuel injectors <NUM> disposed around a circumference of transition zone <NUM> at multiple axial locations thereof.

<FIG> shows a wash system <NUM> as embodied by the disclosure. Wash system <NUM> may include a water source <NUM>. The water source <NUM> may have any size, shape, or configuration. The water source <NUM> may have a volume of water <NUM> therein. Wash system <NUM> also may include a detergent source <NUM>. The detergent source <NUM> may have any size, shape, volume, or other configuration. The detergent source <NUM> may have a supply of a detergent <NUM> therein. The detergent <NUM> may be any type of cleaning solution. The detergent <NUM> may be diluted with the water <NUM> in a predetermined ratio.

In another aspect of the embodiments, wash system <NUM> also may include a chemical source <NUM>. Chemical source <NUM> may have any size, shape, or configuration. In certain embodiments, chemical source <NUM> may have a volume of an anti-static solution <NUM> therein. Anti-static solution <NUM> may be any type of anti-static fluid. Anti-static solution <NUM> may be diluted with the water <NUM> in a predetermined ratio. Water source <NUM>, detergent source <NUM>, and/or chemical source <NUM> may be positioned on a wash skid <NUM> in whole or in part. Wash skid <NUM> may be mobile and may have any size, shape, or configuration. Other components and other configurations may be used herein. Each source <NUM>, <NUM> and <NUM> are referred to in general as a "source" and may provide particular wash materials, such as, but not limited to, being a water source <NUM>; a detergent source <NUM>; and a solution or chemical source <NUM>. Each source <NUM>, <NUM>, and <NUM> may include level sensors (not illustrated in <FIG>, see <FIG>) to provide an indication of source content level. Moreover, as used herein, source(s) <NUM>, <NUM>, and <NUM> may be referred generally as a "source" or alternatively, with respect to particulars of the wash material(s) it may include.

Wash system <NUM> also may include a mixing chamber <NUM>. Mixing chamber <NUM> may be used to mix detergent <NUM> with water <NUM>, or anti-static solution <NUM> with water <NUM>. Other combinations of fluids may also be used. Non-diluted fluids also may be used herein. <FIG> illustrates a non-limiting illustrative mixing chamber <NUM>. Mixing chamber <NUM> may include one or more of angled counter flow nozzles <NUM> for the flow of detergent <NUM> and/or anti-static solution <NUM> or other type of secondary flows. Flow of detergent <NUM> or anti-static solution <NUM> may be injected at a non-diametrically opposed or counter angle via angled counter flow nozzles <NUM> into an incoming flow of water or other type of primary flow for good mixing therein without the use of moving parts. Effective mixing also may be provided by injecting flow of detergent <NUM> or anti-static solution <NUM> at a higher pressure as compared to flow of water <NUM>. Mixing chamber <NUM> may have any size, shape, or configuration. The one or more angled counter flow nozzles <NUM> extend into the mixing chamber at an angle with respect to a central axis of mixing chamber <NUM> and can be configured to inject a first fluid at an angle in a direction counter to a flow of the water in mixing chamber <NUM>.

As shown in <FIG>, water source <NUM> may be in communication with mixing chamber <NUM> via a water line <NUM>. Water line <NUM> may have a water pump thereon. Water pump may be e.g., of conventional design. Water line <NUM> may have a pair of water line isolation valves <NUM> thereon. Detergent source <NUM> may be in communication with mixing chamber <NUM> via a detergent line. Detergent line may have a detergent pump <NUM> thereon. Detergent pump <NUM> may be, e.g., of conventional design. Detergent line may have a pair of detergent line isolation valves <NUM> thereon. Anti-static solution source <NUM> may be in communication with mixing chamber <NUM> via an anti-static solution line <NUM>. Anti-static solution line <NUM> may have an anti-static solution pump <NUM> thereon. Anti-static solution pump <NUM> may be of conventional design. Anti-static solution line <NUM> may have a pair of anti-static solution line isolation valves <NUM>, <NUM> thereon Other components and other configurations may be used herein.

Wash system <NUM> also may include a conduit or line <NUM>, i.e., an output line from mixing chamber <NUM>. In this example, with respect to <FIG> and <FIG>, line <NUM> leads from skid <NUM> to one or more of valves <NUM> for late lean injection (axial fuel staging) in combustor <NUM>. Thus, wash materials, such as at least one of water <NUM>, detergent <NUM>, anti-static solution <NUM>, and passivation solution (to be described hereinafter) can be fed to combustor <NUM>. When fed to combustor <NUM> at valves <NUM> for late lean injection, wash materials are proximate hot gas path components of gas turbine <NUM>, and in particular S1N of gas turbine <NUM>. Therefore, as at least one of washing, detergent, anti-static, and passivation solution materials can proceed to late lean injectors valves <NUM> of gas turbine <NUM> (<FIG>) via combustion gas <NUM> (<FIG>) streams to act on and clean gas turbine <NUM> components, including but not limited to, blades and nozzles of gas turbine <NUM>.

With respect to <FIG> and <FIG>, a wash controller <NUM> may operate wash system <NUM>. Wash controller <NUM> may provide at least one of water <NUM>, detergent <NUM>, anti-static solution <NUM>, and/or passivation solution (as described hereinafter) to mixing chamber <NUM> and then to combustor <NUM> in appropriate ratios thereof. Wash controller <NUM> may be any type of programmable logic device (as discussed hereinafter) and may be in communication with or part of an overall control system of gas turbine engine system <NUM>. Specifically, wash controller <NUM> may control valve interlocks, fluid levels, pump operation, connectivity signals, flow sensors, temperature, pressure, timing, and the like, as discussed herein. Various types of sensors (such as but not limited to, thermometers, flow meters, pressure sensors, and the like. ) may be used herein to provide feedback to wash controller <NUM>. Access to wash controller <NUM> and operation parameters herein may be restricted to ensure adequate cleaning and coverage.

In use, wash skid <NUM> with fluid sources <NUM>, <NUM>, <NUM> may be positioned adjacent gas turbine engine system <NUM> (<FIG>). Alternatively, the fluid sources <NUM>, <NUM>, <NUM> may be more permanently located nearby in whole or in part, to gas turbine engine system <NUM>.

In certain aspects of the embodiments, wash controller <NUM> may determine a ratio of water <NUM> to detergent <NUM>. Wash controller <NUM> may activate water pump <NUM> and/or detergent pump <NUM> to pump corresponding volumes of water <NUM> and detergent <NUM> to mixing chamber <NUM>. A portion of a detergent/water mixture from mixing chamber <NUM> may flow through conduit or line <NUM> to a connection with one or more of valves <NUM> of combustor <NUM> for resultant flow to S1N of gas turbine <NUM>. Flow may occur with gas turbine <NUM> off-line with gas turbine <NUM> under cranking power to permit flow from combustor <NUM> to gas turbine <NUM>. Also, the flow of mixture through conduit or line <NUM> may occur when gas turbine <NUM> is on-line with mixture flowing with combustion gas <NUM> to gas turbine <NUM>. Wash controller <NUM> then may turn pumps <NUM>, <NUM> off once the predetermined volume of detergent/water mixture <NUM> has been injected into valves <NUM> of combustor <NUM>. Wash controller <NUM> may again activate water pump <NUM> to provide a water rinse, if requested. A volume of water <NUM> in a rinse may vary.

Wash system <NUM> can provide improved cleaning and application of anti-static solution <NUM> throughout combustor <NUM> including through valves <NUM> to be fed to gas turbine <NUM>, including washing and treating, for example, stage one and two nozzles (S1N)(S2N) and associated wheel space cavities. The increased coverage of anti-static solution <NUM> may enhance the ability to suppress the electrostatic attraction of material on the gas turbine blades as well as the stationary nozzles with a reduced propensity to form deposits, such as ash contaminants. Anti-static coverage may provide water wash recovered gas turbine operational gains for a longer period of time. Accordingly, gas turbine engine system <NUM> may have improved sustainable performance characteristics. Moreover, wash system <NUM> uses existing LLI (axial fuel staging) piping of combustor <NUM> such that reconstruction or retrofitting is not required.

Wash system <NUM> also may provide the ability to control an injection rate and quantity of anti-static solution <NUM> to ensure adequate coverage to gas turbine <NUM> and including stage one and two nozzles (S1N and S2N) and associated wheel space cavities. Wash controller <NUM> may vary the ratio and volume of a detergent/water mixture and/or anti-static solution/water mixture that may be delivered to combustor <NUM>.

Embodiments of the disclosure may provide off-line cleaning of combustor <NUM>, gas turbine <NUM>, and especially stage one and two nozzles (S1N and S2N) and associated wheel space cavities of gas turbine <NUM>. With reference to <FIG>, where like reference numerals refer to like elements, and a further discussion of those elements is omitted for clarity and brevity, a schematic illustration of a gas turbine engine system <NUM> is illustrated with a wash system <NUM>. Off-line cleaning as embodied by the disclosure provides anti-oxidant cleaning to stage one and two nozzles (S1N and S2N) and associated wheel space cavities of gas turbine <NUM>. Wash system <NUM> provides a mixture of demineralized/deionized water and at least one of magnesium (Mg), yttrium (Y) for vanadium mitigation, as described here, or detergent from wash system <NUM> injected into combustor <NUM> through late lean injection (axial fuel staging) valves <NUM>. Moreover, water and at least one of magnesium (Mg), yttrium (Y), or detergent from wash system <NUM> can be delivered to the off-line gas turbine engine system <NUM> as a foam or water, for example, in a homogeneous stream at late lean injector valves <NUM>.

In aspects of the embodiments, anti-oxidant cleaner, water and magnesium, is provided for targeted stage one and two nozzles (S1N and S2N) and associated wheel space cavities in situ cleaning in gas turbine <NUM>. Wash system <NUM> and the associated process use existing LLI (axial fuel staging) valves <NUM> to dispense a predetermined mixture of demineralized water and magnesium into combustor <NUM>. As embodied by the disclosure, wash system <NUM> , when applied to a gas turbine engine system <NUM> can: remove vanadium, including vanadium in ash form, from a stage one and stage two nozzle (S1N) and (S2N) and associated wheel space cavities and/or other internal components of gas turbine <NUM>; enhance the ability to retain recovered performance of gas turbine engine system <NUM> for longer durations after cleaning; mitigate against nozzle plugging and rust formation/oxidation in gas turbine engine system <NUM> and especially in gas turbine <NUM>; clean and remove ash formations; clean and remove oxidation and particulate from combustor surfaces; provide increased plant reliability and efficiency that is attributable to reduction in cooling air path plugging; and improve reliability of gas turbine engine systems operating on heavy fuel oils.

With reference to <FIG>, wash system <NUM> provides wash materials to combustor <NUM> and then to stage one and two nozzles (S1N and S2N) and associated wheel space cavities for in situ cleaning in gas turbine <NUM> when gas turbine engine system <NUM> is offline. It is to be noted that compressor washing through providing wash materials at the bellmouth <NUM> (<FIG>) of compressor <NUM> (<FIG>) may still be provided with any operation and aspect described herein, as embodied by the disclosure. However, the exact system, process, and other details with respect to compressor washing are not germane to aspects of the embodiments, and further discussion will be omitted.

Conduit or line <NUM> extends from water supply <NUM> and line <NUM> extends from supply <NUM> (such as a chemical supply of, for example, a water-based magnesium sulphite), and lines <NUM> and <NUM> meet at mixing chamber <NUM>. From mixing chamber <NUM>, line <NUM> extends to combustor <NUM>. Line <NUM> may include at least one of chemical sensor <NUM> for detecting chemical characteristics of mixture, flow senor <NUM>, modulating or control valve <NUM>, temperature sensor <NUM>, and filter <NUM>. Each of at least one of chemical sensor <NUM>, flow senor <NUM>, modulating valve <NUM>, temperature sensor <NUM>, as well as motor <NUM> and chemical source <NUM> level sensor <NUM>, communicate with controller <NUM>. Accordingly, controller <NUM> may regulate and manage operation of wash system <NUM> in its off-line operation in accordance with the embodiments herein.

Another aspect of the embodiments provides cleaning of combustor <NUM>, gas turbine <NUM>, and in particular stage one and stage two nozzles (S1N) and (S2N) and associated wheelspace cavities of gas turbine <NUM> and additionally ash formation mitigation, during operation of gas turbine engine system <NUM>. Reference can again be made to <FIG>, wash system <NUM> provides wash materials to combustor <NUM> and then stage one and two nozzles (S1N and S2N) and associated wheel space cavities for in situ cleaning in gas turbine <NUM>, and also provides ash formation mitigation materials to gas turbine engine system <NUM> during operation of gas turbine engine system <NUM>.

As embodied by the disclosure, this aspect of the wash system <NUM> provides and distributes low temperature ash formation mitigants with wash materials from combustor <NUM> and its late lean injection valves or nozzles <NUM>, and then to gas turbine <NUM> internal components, including stage one and two nozzles (S1N and S2N) and associated wheel space cavities of gas turbine <NUM>. Wash system <NUM>, as per this aspect of the embodiments, provides a mixture of demineralized/deionized water from wash system <NUM> injected into combustor <NUM> through late lean injection (axial fuel staging) valves <NUM>. Also, wash system <NUM> may also provide yttrium, magnesium or any now known or later developed low temperature ash formation mitigant, in sources <NUM> and/or <NUM> from wash system <NUM> into existing late lean injection (axial fuel staging) valves or nozzles <NUM> of combustor <NUM>. Non-limiting types of low temperature ash formation mitigant may include water or oil based yttrium or magnesium. As noted herein, wash system <NUM> provides wash water, such as demineralized/deionized water, and low temperature ash formation mitigant into combustor <NUM> LLI (axial fuel staging) valves <NUM>. As embodied by the disclosure, the late lean injection (axial fuel staging) valves <NUM> are ahead of stage one and two nozzles (S1N) and (S2N) and associated wheel space cavities in gas turbine <NUM> and flow of combustion gases <NUM> is in turn delivered to gas turbine <NUM>. Low temperature ash formation mitigant delivered to LLI (axial fuel staging) valves <NUM> is conveyed to internal components of gas turbine <NUM> with the flow <NUM> of combustion gases.

As embodied by the disclosure, method and system for ash formation mitigation and cleaning during operation of gas turbine engine system <NUM> can: reduce a rate of ash formation on a gas turbine stage one and two nozzles (S1N and S2N), associated wheel space cavities and other gas turbine internal turbine components; enhance the ability to retain recovered performance of gas turbine engine system <NUM> for longer durations after cleaning; mitigate against nozzle plugging, hot corrosion/oxidation, aero shape/profile deformation that may be due to plugging; enhances the ability to meet and exceed degradation guarantee bonus opportunity, especially in gas turbine engines that operate on heavy fuel oxide (HFO) gas turbines and gas turbine units that rely on gas fuel with high concentrations of vanadium and other ash forming impurities; increased plant reliability, output and efficiency that can be attributable to reduction in nozzle effective area and changes to blade aerodynamic profiles; clean and remove ash formations; clean and remove oxidation and particulate from combustor surfaces; and provide increased plant reliability and efficiency that is attributable to reduction in cooling air path plugging.

As embodied by the disclosure, wash system <NUM> for ash formation mitigation during gas turbine engine system <NUM> (<FIG>) operation can be illustrated by the configuration of <FIG>. Line <NUM> extends from water supply <NUM> and line <NUM> extends from chemical source <NUM>, for example, chemical source <NUM> in this aspect includes a volume of yttrium, magnesium or another low temperature ash formation mitigant, and lines <NUM> and <NUM> meet at mixing chamber <NUM>. From mixing chamber <NUM>, line <NUM> extends to combustor <NUM>. Line <NUM> may include at least one of chemical sensor <NUM>, flow senor <NUM>, modulating valve <NUM>, temperature sensor <NUM>, and filter <NUM>. Each of at least one of chemical sensor <NUM>, flow senor <NUM>, modulating valve <NUM>, temperature sensor <NUM>, as well as motor <NUM>, chemical source <NUM> level sensor <NUM> communicate with controller <NUM>. Accordingly, controller <NUM> may regulate and mange operation of wash system <NUM> in its off-line operation in accordance with the embodiments herein.

A further aspect of the embodiments provides off-line cleaning and passivation of combustor <NUM>, gas turbine <NUM>, and especially stage one and stage two nozzles (S1N) and (S2N) and associated wheel space cavities of gas turbine <NUM>. With continued reference to <FIG> and <FIG>, where like reference numerals refer to like elements, and a further discussion of those elements is omitted for clarity and brevity, a schematic illustration of a gas turbine engine system <NUM> is illustrated with a wash system <NUM>. Off-line cleaning as embodied by the disclosure, provides anti-oxidant cleaning and passivation of combustor <NUM>, gas turbine <NUM>, and especially stage <NUM> nozzle of gas turbine <NUM> to stage <NUM> nozzle of gas turbine <NUM>. Wash system <NUM> provides a mixture of demineralized/deionized water and at least one of a polyamine or magnesium (Mg) from wash system <NUM> injected into combustor <NUM> through late lean injection (axial fuel staging) valves <NUM>.

In this aspect of the embodiments, mixture of demineralized/deionized water and at least one of a polyamine or magnesium is provided for targeted stage one and two nozzles (S1N and S2N) and associated wheel space cavities in situ cleaning in gas turbine <NUM>, including stage one and two nozzles (S 1N and S2N) and associated wheel space cavities of gas turbine <NUM>, when gas turbine <NUM> is off-line. Wash system <NUM> and the associated process use existing late lean injection (axial fuel staging) valves <NUM> to dispense a predetermined mixture of demineralized/deionized water and at least one of a polyamine or magnesium into combustor <NUM>, from where predetermined mixture of demineralized water and magnesium can flow into gas turbine <NUM>. As embodied by the disclosure, wash system <NUM> of <FIG>, when applied to a gas turbine engine system <NUM> can coat internal gas turbine components to passivate them. Included in the internal gas turbine components that are coated and passivated are stage one and stage two nozzles (S 1N) and (S2N) plus associated wheel space cavities and/or other internal components of gas turbine <NUM>. Passivation, as embodied by the disclosure, can: enhance the ability to retain recovered performance of gas turbine engine system <NUM> for longer durations after cleaning; mitigate against nozzle plugging and rust formation/oxidation in gas turbine engine system <NUM> and especially in gas turbine <NUM>; clean and remove ash formations; may reduce severity and frequency to perform degradation based maintenance; clean and remove oxidation and particulate from combustor surfaces; provide increased plant reliability and efficiency that is attributable to reduction in cooling air path plugging; reduce potential crack propagation and surface degradation of stage one and two nozzles (S 1N and S2N) and associated wheel space cavities and/or other gas turbine components; and improve reliability gas turbine engines operating on heavy fuel oils.

With reference to <FIG>, wash system <NUM> provides mixed demineralized/deionized water and at least one of a polyamine or magnesium to combustor <NUM> and then for S1N in situ cleaning in gas turbine <NUM> when gas turbine engine system <NUM> is offline. Being offline means it is to be noted that compressor washing through providing wash materials at the bellmouth <NUM> (<FIG>) of compressor <NUM> (<FIG>) may still be provided with any operation and aspect described herein, as embodied by the disclosure. However, the exact system, process, and other details with respect to compressor washing are not germane to aspects of the embodiments, and further discussion will be omitted.

Line <NUM> extends from water supply <NUM> and line <NUM> extends from chemical supply <NUM>, for example, a mixture of demineralized/deionized water and at least one of a polyamine or magnesium, and lines <NUM> and <NUM> meet at mixing chamber <NUM>. From mixing chamber <NUM>, line <NUM> extends to combustor <NUM>. Line <NUM> may include at least one of chemical sensor <NUM>, flow senor <NUM>, modulating valve <NUM>, temperature sensor <NUM>, and filter <NUM>. Each of at least one of chemical sensor <NUM>, flow senor <NUM>, modulating valve <NUM>, temperature sensor <NUM>, as well as motor <NUM> and chemical source <NUM> level sensor <NUM> communicate with controller <NUM>. Accordingly, controller <NUM> may regulate and mange operation of wash system <NUM> in its off-line operation in accordance with the embodiments herein.

As embodied by the disclosure, the passivation material, for example but not limited to at least one of a polyamine or magnesium, can be provided in a liquid form or a foam form. Aspects of the disclosure enable the mixture of demineralized/deionized water and at least one of a polyamine or magnesium to flow from late lean injection valves or nozzles to stage one and two nozzles (S 1N and S2N) and associated wheel space cavities of gas turbine <NUM> for passivation of stage one and two nozzles (S 1N and S2N) and associated wheel space cavities, and other internal gas turbine components.

An anti-corrosion mixture, as embodied by the disclosure, can include an anti-corrosion agent and water. Anti-corrosion mixture can be supplied as an aqueous solution (e.g., using water as a liquid carrier) to combustor <NUM> and then to gas turbine <NUM> sections of gas turbine engine system <NUM>. Anti-corrosion mixture can coat gas turbine engine components therein with a metal passivation coating which mitigates corrosion on those coated parts.

Magnesium sulfate can be used as a cleaning agent, in accordance with certain aspects of the embodiments. For applications in which gas turbine engine system <NUM> employs heavy oil as a fuel, heavy oil can be treated with a vanadium-based corrosion/deposit inhibitor. A vanadium-based corrosion/deposit inhibitor can form slag in gas turbine engine system <NUM> during operation. Magnesium sulfate may prevent formation of vanadium-based slag promoted by the use of crude, heavy oils as a gas turbine fuel. Magnesium sulfate, as a vanadium-based corrosion/deposit inhibitor, can be connected to a water-based magnesium sulfate solution, in certain aspects of the embodiments.

As embodied by the disclosure, anti-corrosion mixture can be pre-mixed (in mixing chamber <NUM>) and supplied to gas turbine engine system <NUM>. Further, anti-corrosion mixture can be provided to combustor <NUM> through washing system <NUM>.

Anti-corrosion mixture imparts corrosion resistance and/or inhibition to gas turbine engine system <NUM> and gas turbine <NUM> including its stage one and stage two nozzles (S1N) and (S2N) and associated wheel space cavities by metal passivation. Metal passivation provides an anti-corrosion coating on the metal and/or metal alloy substrates in gas turbine engine system <NUM> with which the anti-corrosion mixture, as embodied by the disclosure, comes into contact via entry at late lean injection valves <NUM> of combustor <NUM>, as discussed above. A resultant anti-corrosion coating therefore (partially or fully) coats gas turbine <NUM> especially its stage one nozzles, and various metallic hot gas path components, such as gas turbine blades and other nozzles).

Metal passivation imparts a protective shield to metal and/or metal alloy substrates from environmental factors, such as but not limited to, high temperatures, combustion by-products, debris, etc. exhibited in gas turbine engines by forming a metal oxide layer/coating. Metal oxide layer/coating protects metal or metal alloy substrate components of gas turbine <NUM> from corrosive species. Anti-corrosion coatings can be seen as a molecular layer, or on other words, a micro coating. In one aspect of the disclosure, anti-corrosion coating also strengthens bonds in the metal or metal alloy substrate of gas turbine engine system <NUM>. In another aspect of the embodiments, significant thermal decomposition of anti-corrosion coating may be avoided at temperatures below <NUM>° C. In yet another aspect, successive anti-corrosion treatment cycles can be applied to the gas turbine engine system <NUM> using the wash system <NUM> described herein, resulting in a multi-layer anti-corrosion coating.

Anti-corrosion mixtures can include water and an anti-corrosion agent in a particularly selected, predetermined ratio. Any anti-corrosion agent/inhibitor that is suitable to impart an anti-corrosion coating may be employed. In an embodiment, the anti-corrosion agent is an organic amine. Amine as a corrosion agent/inhibitor by absorbing at the metal/metal oxide surface of components in gas turbine engine system <NUM>, thereby restricting access of potentially corrosive species (e.g., dissolved oxygen, carbonic acid, chloride/sulfate anions, etc.) at a metal or metal alloy substrate surface of the gas turbine engine system <NUM> component. In another embodiment, the anti-corrosion agent/inhibitor can be two or more organic amines. In yet another embodiment, anti-corrosion agent/inhibitor may be a polyamine. As used herein, the term "polyamine" refers to an organic compound having two or more primary amino groups, NH<NUM>. In still another embodiment, the anti-corrosion agent/inhibitor further includes a volatile neutralizing amine, which can neutralize acidic contaminants and elevate pH into an alkaline range, and with which protective metal oxide coatings are particularly stable and adherent.

In another aspect of the embodiments, non-limiting examples of the anti-corrosion agent/inhibitor include, but are not limited to, cycloheaxylamine, morpholine, monoethanolamine, N-<NUM>-Octadecenyl-<NUM>,<NUM>-propanediamine, <NUM>-octadecen-<NUM>-amine, (Z)-<NUM>-<NUM>, dimethylaminepropylamine (DMPA), diethylaminoethanol (DEAE), and the like, and combinations thereof. In a further embodiment, an amount of the anti-corrosion agent/inhibitor in the anti-corrosion mixture is from <NUM> parts per million (ppm) to <NUM> ppm. In another embodiment, an amount of the anti-corrosion agent/inhibitor in the anti-corrosion mixture is provided in a range from about <NUM> ppm to about <NUM> ppm. In yet another embodiment, the amount of the anti-corrosion agent/inhibitor in the anti-corrosion mixture is provided in a range from about <NUM> ppm to about <NUM> ppm.

In a particular aspect of the embodiments, the amount of the anti-corrosion agent/inhibitor in a first anti-corrosion mixture supplied to late lean injection valves <NUM> of combustor <NUM> is from <NUM> ppm to <NUM> ppm.

Anti-corrosion mixtures including water and anti-corrosion agent/inhibitor are introduced into gas turbine engine system <NUM> via the LLI valves <NUM>, as discussed above, are in an aqueous solution. As used herein, "aqueous solution" refers to a liquid phase medium. In an embodiment of the disclosure, the aqueous solution is a liquid phase medium, which is devoid of polyamine gas, water vapor (such as steam), and/or air. Water acts as a liquid carrier for anti-corrosion agent/inhibitor, which is also in a liquid phase. Water thus carries anti-corrosion agent/inhibitor through piping <NUM> and into selected regions of combustor <NUM> and gas turbine <NUM>, coating the components therein with the anti-corrosion coating.

As will be appreciated by one skilled in the art, controller <NUM> and controller <NUM>, as embodied by the disclosure, may be embodied as a system, method or computer program product. Accordingly, controller <NUM> and controller <NUM>, as embodied by the disclosure, may take the form of an entirely hardware embodiment, an entirely software embodiment (including firmware, resident software, micro-code, etc.) or an embodiment combining software and hardware aspects that may all generally be referred to herein as a "circuit," "module" or "system. " Furthermore, controller <NUM> and controller <NUM>, as embodied by the disclosure, may take the form of a computer program product embodied in any tangible medium of expression having computer-usable program code embodied in the medium. Additionally, controller <NUM> and controller <NUM>, as embodied by the disclosure, may take the form of a non-transitory computer readable storage medium storing code representative of a component according to embodiments of the disclosure.

<FIG> are flow diagrams or flow charts for processes, as embodied by the disclosure. Like steps in each flow chart are represented by like reference step numbers.

With respect to <FIG>, the wash process <NUM> is an off-line process <NUM>. In step <NUM>, gas turbine engine system <NUM> is off-line. Optional process <NUM> is to wash compressor <NUM>, where the compressor wash can be accomplished through known systems, either separate from wash system <NUM> as embodied by the disclosure, or in conjunction with wash system <NUM>, as embodied by the disclosure. In off-line process <NUM>, water and the particular cleansing agent are applied to internal components of gas turbine <NUM> through late lean injectors <NUM> of combustor <NUM>. In process <NUM>, water and an anti-oxidation agent are applied at step <NUM> and are applied to internal components of gas turbine <NUM> through late lean injectors <NUM> of combustor <NUM>.

Process <NUM> is optional and can apply a rinse and apply detergent to remove contaminants, such as but not limited to slag, ash, oils, and the like, as needed, and can be applied to internal components of gas turbine <NUM> through late lean injectors <NUM> of combustor <NUM>. Process <NUM> is also optional and can apply a rinse, if needed, are applied to internal components of gas turbine <NUM> through late lean injectors <NUM> of combustor <NUM>. In process <NUM>, another optional process <NUM> can apply a passivation treatment (similar to that applied in process <NUM> described hereinafter), to internal components of gas turbine <NUM> through late lean injectors <NUM> of combustor <NUM>. Drying at process <NUM> of gas turbine engine system <NUM> components can occur for one embodiment of process <NUM>.

As shown in <FIG>, process <NUM> is an on-line wash process. In process <NUM>, the gas turbine engine system <NUM> (<FIG>) is on-line, and an optional step of washing compressor <NUM> may occur in process <NUM>. In process <NUM>, water and anti-corrosion agent(s) can be applied to internal components of gas turbine <NUM> through LLI(s) <NUM> of combustor <NUM>. As embodied by the disclosure, magnesium or yttrium can be included as the anti-corrosion agent to remove vanadium. Moreover, in process <NUM> the water and anti-corrosion agent can be applied as a homogeneous liquid blend or a foam. In process <NUM>, a rinse and detergent can be optionally applied to remove contaminants, such as but not limited to slag, ash, oils, and the like, as needed, and can be applied to internal components of gas turbine <NUM> through late lean injectors <NUM> of combustor <NUM>. Process <NUM> is an optional application of a rinse, if needed, applied to internal components of gas turbine <NUM> through late lean injectors <NUM> of combustor <NUM>. Process <NUM> is also an optional application of an anti-corrosive or passivation treatment.

Referring to <FIG>, in off-line wash process <NUM>, water and the particular agent are applied to internal components of gas turbine <NUM> through late lean injectors <NUM> of combustor <NUM>. In process <NUM>, gas turbine engine system <NUM> is off-line. Optional process <NUM> is to wash compressor <NUM>, where the compressor wash can be accomplished through known systems, either separate from wash system <NUM> as embodied by the disclosure, or in conjunction with wash system <NUM>, as embodied by the disclosure. In process <NUM>, water and an anti-corrosive/passivation treatment-agent are added at process <NUM> and are applied to internal components of gas turbine <NUM> through late lean injectors <NUM> of combustor <NUM>. Process <NUM> is optional and can apply a rinse and apply detergent to remove contaminants, such as but not limited to slag, ash, oils, and the like, as needed, and can be applied to internal components of gas turbine <NUM> through late lean injectors <NUM> of combustor <NUM>. Process <NUM> is optional and can apply a rinse, if needed, applied to internal components of gas turbine <NUM> through LLI(s) <NUM> of combustor <NUM>. Drying at process <NUM> of gas turbine engine system <NUM> components can occur for offline process <NUM>.

Any combination of one or more computer usable or computer readable medium/media may be used for controller(s) <NUM> and <NUM>. The computer-usable or computer-readable medium that may be utilized for controller(s) <NUM> and <NUM> may include, for example but not limited to, an electronic, magnetic, optical, electromagnetic, infrared, or semiconductor system, apparatus, device, or propagation medium. More specific examples (a non-exhaustive list) of the computer-readable medium that may be utilized for one or both of controllers <NUM> and <NUM> would include the following: an electrical connection having one or more wires, a portable computer diskette, a hard disk, a random access memory (RAM), a read-only memory (ROM), an erasable programmable read-only memory (EPROM or Flash memory), an optical fiber, a portable compact disc read-only memory (CD-ROM), an optical storage device, a transmission media such as those supporting the Internet or an intranet, or a magnetic storage device. In the context of this document, a computer-usable or computer-readable medium may be any medium that can contain, store, communicate, propagate, or transport the program for use by or in connection with the instruction execution system, apparatus, or device. The computer-usable medium may include a propagated data signal with the computer-usable program code embodied therewith, either in baseband or as part of a carrier wave. The computer usable program code may be transmitted using any appropriate medium, including but not limited to wireless, wireline, optical fiber cable, RF, etc..

Computer program code for carrying out wash operations, as embodied by the disclosure, may be written in any combination of one or more programming languages, including an object oriented programming language such as Java, Smalltalk, C++ or the like and conventional procedural programming languages, such as the "C" programming language or similar programming languages.

The embodiments are described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems) and computer program products according to embodiments of the disclosure.

These computer program instructions may also be stored in a computer-readable medium that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable medium produce an article of manufacture including instruction means which implement the function/act specified in the flowchart and/or block diagram block or blocks.

The computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide processes for implementing the functions/acts specified in the flowchart and/or block diagram block or blocks.

The foregoing drawings show some of the processing associated according to several embodiments of this disclosure. In this regard, each drawing or block within a flow diagram of the drawings represents a process associated with embodiments of the method described. It should also be noted that in some alternative implementations, the acts noted in the drawings or blocks may occur out of the order noted in the figure or, for example, may in fact be executed substantially concurrently or in the reverse order, depending upon the act involved. Also, one of ordinary skill in the art will recognize that additional blocks that describe the processing may be added.

Claim 1:
A method of washing an off-line gas turbine (<NUM>) engine, the gas turbine (<NUM>) engine including a compressor (<NUM>), a combustor (<NUM>), a gas turbine (<NUM>), the combustor (<NUM>) including a plurality of late lean fuel injectors (<NUM>) supplied with secondary fuel (<NUM>) to an interior of the combustor (<NUM>), the method including:
supplying water (<NUM>) from a water source (<NUM>) to a mixing chamber (<NUM>) of a wash system (<NUM>);
supplying from an anti-corrosion agent fluid source (<NUM>) a supply of an anti-corrosion agent through an anti-corrosion agent supply piping, the anti-corrosion agent supply piping being in fluid communication with the anti-corrosion agent fluid source (<NUM>); the anti-corrosion agent including a polyamine corrosion inhibitor;
supplying the water (<NUM>) and anti-corrosion agent fluid to a mixing chamber (<NUM>) including pumping water (<NUM>) from the water source (<NUM>) and pumping the anti-corrosion agent fluid from the anti-corrosion agent fluid source (<NUM>), the mixing chamber (<NUM>) configured to receive water (<NUM>) from a water (<NUM>) supply piping and the anti-corrosion agent fluid from the anti-corrosion agent supply piping to produce an anti-corrosion mixture including a mixture of the anti-corrosion agent fluid and water (<NUM>); and
injecting fluid from the mixing chamber (<NUM>) to at least one of the plurality of late lean fuel injectors (<NUM>) while the gas turbine (<NUM>) engine is off-line.