Compressed air injection system method and apparatus for gas turbine engines.

(54) Title: SYSTEM, METHOD AND APPARATUS FOR INJECTION OF COMPRESSED AIR FOR INTERNAL COMBUSTION TURBINE ENGINES.

(54) Title: COMPRESSED AIR INJECTION SYSTEM METHOD AND APPARATUS FOR GAS TURBINE ENGINES.

(57) Summary

The present invention provides several options, depending on the specific needs of the plant, to improve the efficiency and power output of a plant at low loads, and to reduce the lower limit of output power capacity of an internal combustion turbine while at the same time increases the upper limit of the output power of the internal combustion turbine, thus increasing the capacity and regulation capacity of a new or existing internal combustion turbine system. One aspect of the present invention relates to methods and systems that allow internal combustion turbine systems to run to quickly provide additional power during periods of peak demand.

(57) Abstract

The current invention provides several options, depending on specific plant needs, to improve the efficiency and power output of a plant at low loads, and to reduce the lower limit of power output capability of a gas turbine while at the same time increasing the upper limit of the power output of the gas turbine, thus increasing the capacity and regulation capability of a new or existing gas turbine system. One aspect of the present invention relates to methods and systems that allow running gas turbine systems to provide additional power quickly during periods of peak demand.

PATENT TITLE No. 358183

Headlines): POWERPHASE LLC

Address: 1061 E. Indianatown Road, Suite 206, Jupiter, Florida, 33477, USA

Name: COMPRESSED AIR INJECTION SYSTEM, METHOD AND APPARATUS FOR INTERNAL COMBUSTION TURBINE ENGINES.

Classification: CIP: F01K23 / 02; F01K23 / 10

CPC: F01K23 / 02; F01K23 / 10

Inventor (s): ROBERT J. KRAFT

Number:

MX / a / 2014/011923

REQUEST '

Facha dé Pr6 »« rt $ a <s «ón Internacional:

March 2013

PRIORI

Country:

US '*' áéeftaí April 2012

Number:

61/686,222

Validity: Twenty years

Expiration Date: March 31, 2033 Issue Date: August 8, 2018

The reference patent is granted based on articles Γ, 2 “fraction V, β 'fraction

W, y59dela

Industrial Property Law.

Conf ormidad with Article 23 of the Law ta Property Ind 'ustrtat, ta this mat subject i patented í has a term of twenty non - extendable Antja, counted from the date of filing of the application nternaoicnal and will be subject * I pay the fee to keep valid rights.

Whoever signs this title is born based on the provisions of articles 6 fractions III and 7a bis 2 of the Industrial Property Law (Official Gazette of the Federation (D OF) 27/06/1991, amended on 02 / 08/1994, 10/26/199 «, 12/26/1997, lY / 05/1999, 01/26/2004, 06/16/2005, 01/25/2006, 06/05/2009, 05/05 / 01/2010 06-18-2010,28 / 06/2010, 01/27/2012 and 09/04/20L2), articles 1^to 3'fraction V iricfso a), 4 'and 12' sections I and III of the Regulation of the Mexican Institute of Industrial Property (D OF.14 / 12/1999, amended on 07/01/2002, 07/15/2004, 07/28/2004 and 09/07/2007); articles 1, 3 », 4^to, 5 »section V subsection a) 1« fraecjones 1 and MI y 30 faithful Organic Statute of the Mexican Industrial Property Institute (DOF 12/27/1999, amended on 10/10/2002. 07/29/2004, 04/08 / 2004 and j8 / 09 / 26®), 4 », g.mcraqjó.'of the Agreement that delegates powers to the Deputy Directors General, Coordinator, Divisional Directors, Titulaos of the 'Regional Offices, Divisional Deputy Directors, Departmental Coordinators and others subordinates of the Mexican Institute of the Pmptedhd Irtdustnal. (DOY 12/15/1999, amended on 04/0272000, 07/29/2004, 08/04/2004 and 09/13/2007). '<

This letter is signed with an advanced electronic signature (FIEL), based on articles 7 BIS 2 of the Industrial Property Law; 3 of its Regulations, and 1 fraction III, 2 fraction V, 26 BIS and 26 TER of the Agreement establishing the guidelines for the use of the Electronic Payment and Services Portal (PASE) of the Mexican Institute of Industrial Property, in the procedures indicated.

THE DIVISIONAL DIRECTOR OF PATENTS

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NAHANNY CANAL REYES

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NAHANNY MARISOL CANAL REYES | 00001000000403252793 | Tax Administration Service | 1695 || MX / 2018/66418 | MX / a / 2014/011923 | Patent title PCT | 1027 | RGZ | Pág (s) | afn 11IK1j86HtNZ6eZfqhFCICQ =

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IMPI

MEXICAN INSTITUTE OF THE PROPUDAD industrial

-SYSTEM, METHOD AND APPARATUS FOR AIR INJECTION

TABLET FOR COMBUSTION TURBINE ENGINES

INTERNAL

Related Request

This application claims the priority of United States of America Provisional Application No. 61 / 686,222, filed on April 2, 2012, which is incorporated herein by reference in its entirety.

Field of the Invention

The invention relates generally to gas turbine power systems, including supplementing the generating capacity of such gas turbines, as well as energy storage, which is useful for providing additional electrical power during peak demand periods of electrical energy while self-consuming energy generated by the gas turbine during times of reduced energy demand.

Background of the Invention

Currently marginal energy, or peak energy, is produced primarily by gas turbines, which operate in single-cycle or combined-cycle configurations. As a result of a load demand pfl, gas turbine based systems are recycled during high demand periods and recycled downstream

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or turn off during periods of low * demand. This temperature or temperature is carried out by the grid operator under a program called “grid active program or AGC. Unfortunately, because industrial gas turbines, which account for the majority of the installed power generation base, were primarily designed for base-load operation, a severe fine is associated with the cost of maintaining that particular unit when is recycled. For example, a gas turbine running on base load may undergo a normal maintenance cycle once every three years or 24,000 hours of operation, at a cost of between two million dollars and three million dollars ($ 2,000,000 to $ 3,000,000 ). The same cost may be incurred in one year for labor that is forced to turn on and off daily due to a severe fine associated with the cost of maintaining the recycling of that particular gas turbine. Also, even aero-derived engines, which are designed for quick start capability, will take even ten (10) minutes or more to supply the required power when requested. This need to recycle gas turbine fleets is a major event and is becoming increasingly problematic with the increased use of intermittent renewable energy sources on the grid.

Today, gas turbine engines used in power plants can be shut down at approximately 50% of their rated capacity. This is achieved by closing the compressor inlet guide llts, which reduces the air flow for the gas turbine and in turn,

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reduces fuel flow as a constant fuel air ratio is desirable in the combustion process under all engine operating conditions. The goal of maintaining safe compressor operation and exhaust emissions from the gas turbine typically limits the level of shutdown that can be practically achieved.

One way to safely lower the compressor operating limit on current gas turbines is by introducing hot air into the gas turbine inlet, which is typically drawn from a mid stage bleed point at the compressor. Sometimes this hot air is drawn into the inlet to prevent freezing. In any case, when this is done, the work is done for the air by the compressor being sacrificed in the process with the benefit of having the ability to safely operate the compressor with a lower air flow, which produces increased shutdown capacity. Unfortunately, the air purged from the compressor has a negative Impact on the overall efficiency of the gas turbine system, as the work done on the air being purged is lost. In general, for every 1% of air that is purged out of the compressor since its shutdown upgrade, approximately 2% of the total energy output of the gas turbine is lost. In addition, the combustion system also presents a limit for the system.

The combustion system usually limits the number of times the system can be shut down, because less fuel is added, the flame temperature is reduced, which increases the amount of

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carbon monoxide emissions produced (“CO). The relationship between flame temperature and CO emissions is exponential with the reduced temperature, and consequently, as the gas turbine system approaches the shutdown limit, CO emissions soar, so it is important maintain a healthy margin beyond this limit. This feature limits all gas turbine systems to approximately 50% shutdown capacity or for a 100MW gas turbine, the minimum achievable power shutdown is 50% or 50MW. Because the mass flow of the gas turbine shuts down, the compressor and turbine efficiency also decrease, causing an increase in the heat index of the machine. Some operators face this situation on a daily basis and as a result, as the demand for cg decreases, the gas turbine plants reach this lower operating limit and the gas turbines will have shut down, causing the power plant to incur too high a maintenance cost.

Another characteristic of a typical gas turbine is that the ambient temperature increases, the energy output falls proportionally due to the linear effect of the reduced density as the air temperature increases. The nt output can drop more than 10% from the nominal power on hot days, which is typically when the peak gas turbines are requested most frequently to supply power.

Another feature of typical gas turbines is that the air is compressed and heated in the ντπυτο MEXICANI turbine compressor section.

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gas, it is conducted to different portions of the Id section of the gas turbine where they are used to cool various components. This air is typically called turbine leak and cooling air (hereinafter "TCLA") a term that is well known in the art with respect to gas turbines. Although heated from the compression process, TCLA air is much colder than turbine temperatures and is therefore effective in cooling those components in the turbine downstream of the compressor. Typically, 10% to 15% of the air entering through the compressor inlet is diverted to the combustor and used for this process. In this way, TCLA can greatly affect the operation of the gas turbine system.

Other energy boosting systems, such as inlet freezing, for example, provide cooler inlet conditions, resulting in increased air flow through the gas turbine compressor, and gas turbine outlet. it increases proportionally. For example, when inlet freezing reduces inlet conditions on a hot day, such as the gas turbine compressor has 5% more air flow, the output of the gas turbine will also increase by 5 %. As ambient temperatures drop, inlet freezing becomes less effective since the air is already cold. Therefore, the increase in input freezing energy is optimized on hot days and degrades to zero on days with a temperature of approximately 7.2^andC.

In energy enhancement systems such as those described in Makhamkin United States Patent No. 6,305,158

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INSTITUTO MÜUCANO DC THE INDUSTRIAL PROPERTY

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(the "158" patent), there are three defined basic modes of operation, a normal mode, a cg mode, and an air injection mode, but are limited by the need for an electric generator that has the ability to supply power "Exceeding the total nominal energy" that the gas turbine system can supply. The fact that this patent has been in force for more than ten (10) years and that to date there are no known applications to increase energy costs is proof that market requirements have not been met.

First, it is very expensive to replace and renew an electric generator so that it can supply power "that exceeds the total nominal power" that the gas turbine system can deliver today. Also, the injection option as described in the '158 patent, provides a power boost, which takes a long time to turn on and come online with the power grid. This renders the '158 patent impractical in certain markets such as connected standby capacity, where power increase must occur in a matter of seconds, and due to the need for a large auxiliary compressor in these types of systems, this which takes a long time to start.

Another disadvantage is that this system cannot be implemented in a combined cycle plant without a significant negative impact on fuel consumption and therefore on efficiency. Most of the implementations outlined in the '158 patent use a recuperator to heat the air in a single cycle operation, which mitigates the increase in energy consumption, however, adds cost and

IMPI

MEXICAN INSTITUTE OF PROPERTY

INDUSTRIAL

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complexity. The proposed invention, described below,¹ Suluciuiid falls both in cost and in performance of the invention described in the '158 patent.

Also as noted in the related Nakhamkin United States Patent No. 5,934,063 (the "063" patent) there is a valve structure that "selectively allows one of the following modes of operation: there is a normal mode of operation of the gas turbine, a mode where air is supplied from the storage system and mixed with air in the gas turbine, and then a cg mode. " The '063 patent was also issued for more than ten (10) years and there are no known applications anywhere in the world. The reason for this are the costs and disadvantages of operation, similar to those associated with the '158 patent. Although this system can be applied without fines in a single cycle gas turbine, single cycle gas turbines do not start up as many times so they do not compensate for the time-related capital investment, making the technology for power plant operators. In the same way, when this system is applied in a combined cycle gas turbine, there may be a lack in the heat index and again the technology does not meet the needs of the market. The proposed invention described below solves both the cost and operational problems of the '063 patent.

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MEXICAN INSTITUTE OE LA PROFIE1? * P ιηγμ XT5 r¿_t

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Brief Description of the Invention

The present invention, which can be called as TurboPHASE ™, provides several options, depending on the specific needs of the plant, to improve efficiency and power output at low loads, and to reduce the lower limit of output capacity of energy of a gas turbine, while increasing the upper limit of the energy output of the gas turbine, which increases the capacity and regulation capacity of a new or existing gas turbine system.

One aspect of the present invention relates to methods and systems that allow gas turbine systems to be commissioned to provide additional power quickly during peak demand periods.

Another aspect of the present invention relates to energy storage and a recovery system for obtaining useful work from an existing source of a gas turbine power plant.

Another aspect of the present invention relates to methods and systems that allow gas turbine systems to be shut down more efficiently during periods of low demand.

An embodiment of the invention relates to a system comprising at least one existing gas turbine comprising a first compressor, at least one electric generator, at least one

<img file="MX358183B_D0011.tif" />

turbine connected to the generator and to the compressor, a comhuatnry a box of the combustor (which is the discharge manifold for the compressor, and also comprises a complementary compressor that is not the same as the first compressor.

An advantage of other preferred embodiments is the ability to increase the shutdown capacity of the gas turbine system during periods of low demand and improve the efficiency and output of the gas turbine system during periods of high demand.

Another advantage of the modalities of the present invention is the ability to increase the shutdown capacity of a gas turbine system during periods of low demand with the use of a complementary compressor powered by a fuel engine, whose operation is independent of the electrical network.

Another advantage of the embodiments of the present invention is the ability to increase the shutdown capacity of a gas turbine system during periods of low demand with the use of a supplemental compressor driven by a fuel engine that produces heat that can be added compressed air flowing into the combustion box, from the supplemental compressor, an air storage system, or both, Or heat can be added to the steam cycle in a combined cycle power plant.

Another advantage of the embodiments of the present invention is the ability to increase the output of the gas turbine system during periods of high demand with the use of a complementary compressor that is not powered by the energy produced by the gas turbine system.

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INSTITUTO McXICAN · DE LA PROPIEPaO tNDU «T'4 | At

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Another advantage of some modalities has been pracan ^ invention I? Ability to increase the output of the gas turbine system during periods of high demand with the use of a complementary compressor that is powered by steam produced by a heat recovery steam generator from a combined cycle power plant.

Another advantage of the present invention is the ability to incorporate selective portions of the modalities into existing gas turbines to achieve the specific objectives of the plant.

Another advantage of an embodiment of the present invention is the ability to inject compressed air into a turbine cooling circuit without heating the air prior to such injection, and because cold cooling air can reach the same desired metal temperatures. By using less compressed air (compared to hot compressed air), efficiency is improved.

Another advantage of another embodiment of the present invention is that because an increased amount of compressed air can be added at a relatively constant rate over a wide variety of ambient temperatures, the increase in energy achieved by the gas turbine is also relatively constant. over a wide range of ambient temperatures. Also, because supplemental compressed air is supplied without a significant increase in energy from the gas turbine compressor, (because compressed air comes from a separate fuel compressor or compressed air storage system) , for every 1% of air injected (by mass flow), there is a 2% increase in energy.

<img file="MX358183B_D0013.tif" />

This is important because other UteeriUlogias, ”'vouchers · wmo input freezers, to complement the energy production closer to a 1% increase in energy for every 1% increase in Injected air, therefore, the double the energy start with the same increased air flow through the turbine and the cbr, resulting in a complementary, lower cost and smaller energy system.

A preferred embodiment of the present invention includes an intercooled compression circuit with the use of a combustor to produce the compressed air that is stored in one or more high pressure air storage tanks, where the process heat Inter-cooled absorbed compressed air during compression is transferred to the cpr cycle of a combined cycle power plant.

Optionally, when integrated with a combined cycle gas turbine plant with a steam cycle, steam from the steam cycle can be used to drive a secondary steam turbine, which, in turn, drives the supplemental compressor. The use of high pressure air storage tanks together with the dsr of this air directly in the gas turbine gives the gas turbine the ability to supply much more energy than could otherwise be produced, because The maximum mass of air flow that is supplied by the compressor of the gas turbine system to the turbine is supplemented by air from the air tanks. In existing gas turbines, this can increase the output of a gas turbine system to the generator limit on a hot day, which can be as much as a

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20% additional energy output, while i π cr in reTrt'j ~ l^,a ~ c^,ap'a CI dad “off for 25-30% more than in the current state of the art.

In new gas turbines, the generator and turbine can be larger in size to supply this additional energy at any time, which increases the system's main foot energy ratio by 20%, to a total cost increase by system that is much less than 20%, like 25-30% more of the shutdown capacity than in the current state of the art.

Other features and advantages of the present invention, as well as the methods of operation and functions of the related elements of the structure and the combination of parts will become more apparent after considering the following detailed description and the appended claims with reference to the accompanying drawings. They are all part of this specification.

Brief Description of Drawings

FIG. 1 is a schematic drawing of an embodiment of the present invention having a complementary power system with a recovered motor that drives the complementary compressor.

Figure 2 is a schematic drawing of an embodiment of the present invention having a complementary power system with a recovered motor that powers communications and power storage.

Figure 3 is a schematic drawing of one embodiment of the

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present invention incorporating a system of continuous energy increase.

Figure 4 is a schematic drawing of an embodiment of the present invention where an auxiliary steam turbine drives the complementary compressor.

Figure 5 is a schematic drawing of an embodiment of the present invention including the auxiliary steam turbine that drives the supplemental compressor and energy storage.

Figure 6 is a schematic drawing of an embodiment of the present invention installed together with two gas turbines and a steam turbine.

Figure 7 is a schematic drawing of an embodiment of the present invention together with a gas turbine and a steam turbine.

Figure 8 is a schematic drawing of an embodiment of the present invention installed in conjunction with a gas turbine.

Detailed description of the invention

The components of an embodiment of the present invention are shown in Figure 1, as used with an existing gas turbine system 1. The existing gas turbine system 1, which compresses the ambient air 2, includes a compressor 10, a combustor 12, a combustion box 14, a turbine 16, and a generator 18. A fuel engine 20 is used to drive a compressor Complementary 22 Multi-stage intercooling, which compresses the ambient air 24 and

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discharges the compressed air 26. As used herein, the term "fuel engine" means a reciprocal internal combustion engine, a gas turbine (in addition to the gas turbine in an existing gas turbine system 1, or a similar machine that converts fuel into energy through an exothermic reaction, such as combustion (eg, gasoline, diesel, natural gas, or a biofuel or similar fuel). The fuel engine entrains ambient air 42 and as a result of the combustion process produces hot exhaust gas 32. As will be appreciated by those skilled in the art, as the air in the complementary compressor 22 passes from one stage of the compressor to the next, the air is intercooled with the use of an intercooled exchanger 28, such as a tower cooling to reduce the work required to compress the air in the compressor downstream stage. As used herein, the term "intercooler exchanger" means an exchanger that receives compressed air from the upstream stage of the compressor, and cools that air before supplying it to the other compressor stage downstream of the upstream stage of the compressor. compressor. The use of the intercooler exchanger 28 increases the efficiency of the complementary compressor 22, which makes it more efficient than the compressor 10 of the efficient gas turbine system 1. As will be appreciated by those skilled in the art, although referred to herein as "intercooler", intercooler exchanger 28 actually includes an intercooler and postcooler, as described in more detail below.

This modality also includes a recuperator 30, which is a

INSTITUTO MRXICAN. '· I DE LA PROHFDAI-,

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exchanger receiving exhaust gas 32 from fuel engine 20 and compressed air 26 from supplemental compressor 22. The flow of compressed air from supplemental compressor 22 to reclaimer 30 is controlled by a flow control valve 44 of the recuperator. Inside the reclaimer 30, the hot exhaust gas 32 heats the compressed air 26 and then exits the reclaimer 30, as essentially cooler exhaust gas 34. At the same time in the reclaimer 30, the compressed air 26 absorbs the heat from the exhaust gas 32 and then exits the reclaimer 30 as essentially hotter compressed air 36 than when it entered the reclaimer 30. The substantially hotter compressed air 36 is then discharge from the recuperator 30 into the combustion box 14 of the gas turbine system 1, where it becomes an addition for the mass flow through the turbine 16.

The colder exhaust gas 34 is then discharged into the atmosphere. A catalytic reduction device ("SCR) (not shown) of the type known in the art, can be inserted before, in the middle, or after the retriever 30 to achieve the most desirable condition for SCR function. Alternatively, after the SCR device, the colder exhaust gas 34 can be injected into the exhaust gas 38 of the turbine 16, as shown in Figure 1, and then the mixed flow exhaust 38 will be discharged to the atmosphere (in the case of a single cycle gas turbine) or directed to the heat recovery steam generator ("HRSG") of a steam turbine of the type known in the art (not shown) in cycle power plants combined. When the escape 38

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flow mix is ​​to be discharged into the HRSG, this used medium must ensure that the exhaust gas 38 flows from the turbine 16 into the HRSG and the SCR device is not interrupted. In class “F” engines, such as the General Electric Frame 9FA industrial gas turbine, there are large compressor bleed lines that, for starting purposes, bypass around the turbine section and air is discharged into the exhaust plenum. turbine 16. These purge lines are not in use when the gas turbine system 1 is loaded, and therefore they are a good place to discharge the cooler exhaust gas 34 after it leaves the reclaimer 30, since these lines of Compressor bleed are already designed to minimize Impact on HRSG and SCR device. By injecting the exhaust 32 of the fuel engine 20 into the exhaust 38 of the gas turbine system 1, the SCR of the gas turbine system 1 can be used to clean the exhaust 32, which eliminates the costly system of the fuel engine 20 .

It turns out that gasoline, diesel, natural gas or biofuel and similar reciprocating engines are not sensitive to back pressure, so that putting the recuperator 30 in the fuel engine 20 does not have a measurable effect on the operation of the engine 20 made out of fuel. This is important because other heat recovery systems, such as the HRSG used in the exhaust from typical gas turbine power plants, create an energy loss at all times, regardless of whether the power boost system is in use or not.

The energy from the fuel engine 20 is used to drive

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the Inter-cooled compressor 22. When the installation includes an HSRG and a steam turbine, the auxiliary heat from the engine jacket, the cooler oil and the turbocharger in the fuel engine 20 can be transferred into the steam cycle of the steam turbine through HSRG (typically low pressure line and temperature condensate). In the same way, the heat removed by the intercooler 28 from the air cooler as it is compressed in the multi-stage complementary compressor 22, can be transferred to the value cycle in a similar way, before the compressed air is cooled. through the cooling tower, to lower the temperature of the compressed air to the desired temperature before entering the subsequent compression stage of the complementary compressor 22. When the auxiliary gas turbine is used as the fuel engine 20 instead of a reciprocating engine, lower emission rates can be achieved, allowing emission even in the most stringent environmental areas. Also, when the auxiliary gas turbine is used as a fuel engine 20, the exhaust gas from the auxiliary gas turbine can be led directly to the exhaust pipes of the existing gas turbine system 1, described above, which avoids the cost and maintenance of an additional SCR device.

When the highest demand is carried out with this system, the gas turbine system 1 will probably shut down at the power outlet and flow (assuming the highest demand is needed in summer when ambient air temperatures higher reduce the total mass flow through the gas turbine system 1, which in turn

<img file="MX358183B_D0019.tif" />

Once, it reduces the power output of the gas turbine system 1, as a whole, and the complementary compressor 22 will only carry the mass air flow through the gas turbine system 1 back to where the flow would have been at a coldest day (that is, a day when the total nominal energy of the gas turbine system 1 is reached).

Figure 2 shows the embodiment of Figure 1 with the addition of compressed air storage. The compressed air storage system includes an air storage tank 50, a hydraulic fluid tank 52, and a pump 54 for transferring hydraulic fluid, such as water, between hydraulic fluid tank 52 and storage tank 50 of air. In accordance with preferred embodiments, during periods when an increased power supply is needed, the air outlet valve 46 opens, the air bypass valve 48 opens, the air inlet valve 56 closes, and the compressor Complementary 22 operates, powered by the fuel engine 20. As will be appreciated by those skilled in the art, when the compressed air is to be stored for future use, it is likely that it will need to be stored at a higher pressure, whereby on the wall the supplemental compressor 22 will have additional steps of compression, compared to the complementary compressor 22 in the modality shown in Figure 1. These additional stages will be driven by the fuel engine 20 at all times or may have the ability to be intermittently actuated by installing a clutch type mechanism that only engages the additional stages when the fuel engine 20

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it operates to store compressed air in the air storage tank 50 (where the desired storage pressure is essentially higher to minimize the required vlm of the air storage tank 50). Alternatively, the additional stages can be decoupled from the fuel engine 20 and driven by a separate fuel engine (not shown) or other means, such as an electric motor.

Compressed air 26 flowing from supplemental compressor 22 is forced to flow to mixer 58, opposite to intercooler exchanger 28 because air inlet valve 56, which controls air flow exits intercooler 28. cooler, closes. The compressed air 26 flowing from the outlet of the complementary compressor 22 is mixed in the mixer 58 with the compressed air leaving the air storage tank 50 and is introduced into the recuperator 30, where it absorbs the heat of the exhaust gas from the fuel engine 20 before being introduced into the combustion box 14 using the described process. As will be appreciated by those skilled in the art, for the purposes of tea efficiency, the reclaimer 30 will ideally be a counter-flow exchanger, as it will allow the maximum amount of heat to be transferred from exhaust 32 to the compressed air leaving the air storage tank 50. Alternatively, when the reclaimer 30 is formed from one or more cross flow heat exchangers, it may have a first stage, which is a first cross flow heat exchanger, followed by a second stage, which is a second flow exchanger. heat of

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cross flow. In this configuration, when the exhaust 32 ~ enters the first stage of the recuperator, it partially cools, then it flows to the second stage of the recuperator. At the same time, the compressed air leaving the air storage tank 50 first enters the second stage of the reclaimer 30, where additional heat is removed from the partially cooled exhaust 32, which "pre-heats" the compressed air. The compressed air then flows to the first stage of the recuperator 30, where it is heated by the exhaust 32 that has not been partially cooled, before flowing to the mixer 58 to join the air flowing from the complementary compressor 22. In this case, the “two-stage” recuperator acts more like a counter-flow exchanger, which produces greater thermal efficiency in heating the compressed air.

As will be appreciated by those skilled in the art, since the air is compressed in the complementary compressor 22 by bypassing the Intercooler heat exchanger 28 because the bypass valve 48 is open, the compressed air leaving the compressor Complementary 22 retains some compression heat and when mixed with the compressed air flowing from the air storage tank 50, the temperature of the mixed air will increase, so that when the mixed air enters the reclaimer 30, it is hotter than it would be if only the compressed air from the air storage tank 50 were fed into the reclaimer 30. In the same way, when the air leaving the air storage tank 50 is pre-heated first in a "second stage"

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of the reclaimer, as described above; Before entering mixer 58, an even hotter mixture of compressed air will result, which may be desirable under certain conditions.

As the combustion turbine system 1 continues to operate in this way, the pressure of the compressed air in the air storage tank 50 is decreased. When the pressure of the compressed air in the air storage tank 50 reaches the air pressure in the combustion box 14, the compressed air will be stopped from flowing from the air storage tank 50 within the gas turbine system 1. To prevent this from happening, as the pressure of the compressed air in the air storage tank 50 approaches the pressure of the air in the combustion box 14, the fluid control valve 60 remains closed, and the hydraulic pump 54 starts to pump the fluid, such as water, from the hydraulic fluid tank 52 into the air storage tank 50 at a pressure high enough to entrain the compressed air therein out of the air storage tank 50, allowing essentially all of the compressed air in the tank 50 for air storage to be supplied to the combustion box 14.

As will be appreciated by those skilled in the art, when the additional stages of the compressor or the higher pressure stages of the combustor are added separately from the supplemental compressor 22 driven by the fuel engine 20, then, when desired, air from the gas turbine combustion box 14 can be purged and allowed to flow in reverse to the

<img file="MX358183B_D0023.tif" />

air 36 compressed essentially more ^ ni¡rnfl ~~~ Cumu cl turn prrgqflfr from the gas turbine combustion box 14 and takes the place of the air from the separate fuel engine 20 driven by the complementary compressor 22. In this case , the purged air can be cooled in the intercooler exchanger 28, or in a cooling tower, and then supplied to the inlet of the high pressure stages of the complementary compressor 22. This can be especially convenient when low shutdown capacity is desired, since the purged air results in a loss of energy from the gas turbine, and the drive system for the high pressure stages of the supplemental compressor 22 can be driven by an electric motor, which consumes the electrical energy generated by the gas turbine system 1, which also results in a loss of energy from the gas turbine. As will be appreciated by those skilled in the art, this is not an operating mode that is desirable during periods when supplemental energy production by the gas turbine system is desired.

In accordance with the preferred modalities, regardless of whether the hydraulic system is used or not, when the air stops its flow from the air storage tank 50, the complementary compressor 22 can continue to run and offer an increase in energy for the system 1 gas turbine. In accordance with other preferred embodiments, such as that shown in Figure 1, supplemental compressor 22 is started and started without the use of an air storage tank 50. Preferably heat exchanger 28

<img file="MX358183B_D0024.tif" />

<img file="MX358183B_D0025.tif" />

Intercooler is used to cool the air from a low pressure stage to a high pressure stage in the complementary compressor 22, which compresses the ambient air 24 through a multi-stage compressor 22.

The air inlet valve 56, the air outlet valve 46, the bypass valve 48 and the supplemental flow control valve 44 are operated to obtain the desired operating conditions of the gas turbine system 1. For example, when it is desired to load the air storage tank 50 with compressed air, the air outlet valve 46, the bypass valve 48 and the supplemental flow control valve 44 are closed, the air inlet valve 56 opens and the fuel motor 20 is used to drive the complementary compressor 22. As air is compressed in supplemental compressor 22, it is cooled by intercooler heat exchanger 28 because bypass valve 48 is closed, forcing compressed air to flow through intercooler heat exchanger 28 . Air exiting supplemental compressor 22 then flows through air inlet valve 56 and into air storage tank 50. In the same way, when it is desired to discharge the compressed air from the air storage tank 50 and into the combustion box 14, the sire outlet valve 46, the bypass valve 48 and the complementary flow control valve 44 they open, and the air inlet valve 56 can be closed and the fuel motor 20 can be used to drive the complementary compressor 22. As the air is compressed into the

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supplemental compressor 22, heated nohidn ai rai_nr rig mmprAsjón and is not cooled by the Intercooler heat exchanger because the bypass valve 48 is open, which bypasses the intercooler heat exchanger. Compressed air from air storage tank 50 then flows through mixer 58, where it mixes with hot air from supplemental compressor 22, and then flows to reclaimer 30, where it absorbs heat transferred to reclaimer 30 from the exhaust gas 32 from the fuel engine 20 then flows into the combustion box 14. In the event that all the air flow from the complementary compressor 22 is not required by the gas turbine system 1, this mode can be operated in a hybrid mode, wherein some of the air flowing from the supplemental compressor 22 flows to the mixer 58 and some of the air flowing from the supplemental compressor 22 flows through the intercooler heat exchanger 28 and then through the valve 56 of air inlet and into the air storage tank 50.

As will be appreciated by those skilled in the art, the preheated air mixture can be introduced into the combustion turbine at other locations, depending on the desired objective. For example, the preheated air mixture can be introduced into the turbine 16 to cool the components therein, which reduces or eliminates the need to extract the purged air from the compressor to cool these components. Of course, when this is the proposed use of the preheated air mixture, the desired temperature of the mixture will be lower and the ratio of the mixture within the

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<img file="MX358183B_D0027.tif" />

Mixer 58 will need to be changed accordingly, considering how much heat, if any, must be added to the preheated air mix by reclaimer 30 before introducing the compressed air mix into turbine cooling circuit 16. It should be noted that for this use, the preheated air mixture can be introduced into the turbine 16 at the same temperature at which the cooling air from the compressor 10 is introduced into the TCLA system of the turbine 16 or at a temperature Cooler to improve overall combustion turbine efficiency (since less TCLA cooling air will be required to cool turbine components).

It should be understood that when the air storage tank 50 has hydraulic fluid therein prior to the start of the charging cycle to add compressed air to the air storage tank 50, the fluid control valve 60 is opened so that the compressed air flow into the air storage tank 50, as the hydraulic fluid draws into it, out of the air storage tank 50, through the fluid control valve 60 and back into the hydraulic fluid tank 52. By controlling the pressure and temperature of the air entering the turbine system 1, the turbine 16 of the gas turbine system can operate with increased energy because the mass flow of the gas turbine system 1 is effectively increased, which among other things, allows an increased fuel flow within the combustor 12 of the gas turbine. This increase in fuel flow is similar to an Increase in fuel flow associated with a cold day operation of

<img file="MX358183B_D0028.tif" />

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INSTITUTO MiXICANC DE LA PRORBíiM! NOt b'TSlAf gas turbine, where mass flow occurs iiTC7emeKtTdó ^ l'ráVés3eT ** complete gas turbine system 1, because the density of the ambient air is higher than in a normal hot day.

During periods of high energy demand, the air flowing from the air storage tank 50 and the supplemental compressor 22 can be introduced into the gas turbine system 1 in a similar way that eliminates the need to purge the cooling air from compressor 10, allowing more compressed air to flow into compressor 10 through combustor 12 and turbine 16, which increases the net available energy of gas turbine system 1. The output of the gas turbine 16 is proportional to the mass flow rate through the gas turbine system 1, and the system described above, compared to prior art patents, provides an increase in the flow rate more high to the gas turbine 15 with the same air storage volume and the same size of the complementary compressor, when the two are used simultaneously to provide compressed air, resulting in a hybrid system that costs much less than the price of prior art systems, while providing comparable levels of power boost.

The complementary compressor 22 Increases the pressure of the ambient air 24 through at least one compression stage, which is then cooled by the Intercooler heat exchanger, also compressed in a subsequent stage of the complementary compressor 22, and then cools again in the intercooler heat exchanger 28 (where the compressed air leaves the last stage of the

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<img file="MX358183B_D0029.tif" />

supplemental compressor 22 is then cooled in the same intercooler heat exchanger 28) and then the cooled, compressed, high pressure air is supplied to the air storage tank 50 through the open air inlet valve 56 and inlet manifold 62 and stored in air storage tank 50.

As the pressurized air flowing through the intercooler heat exchanger 28 cools, the heat transferred from it can be used to heat the water in the HRSG to improve the efficiency of the steam turbine. An alternative method of cooling the compressed air in the Intercooler heat exchanger 28 is to use relatively cold water from the steam cycle (not shown) in a combined cycle plant. In this configuration, the water will flow into the intercooler heat exchanger 28 and captures the heat that is drawn from the compressed air from the complementary compressor 22, and then the hotter water exits from the intercooler heat exchanger 28 and flows back to the steam cycle. With this configuration, heat is captured during the storage cycle described in this paragraph and the energy increase cycle described above.

In accordance with preferred embodiments, the air storage tank 50 is above ground, preferably on a raft, skid, trailer, or other mobile platform, and is adapted or configured to be easily installed and transported. The additional components, excluding gas turbine system 1, also add less than 6000 square meters, preferably less than 4500 meters and with more

<img file="MX358183B_D0030.tif" />

Preference, less than 3000 square meters, to the general space of the power plant. A continuous increase system of the present invention takes up to 1% of the space of the combined cycle plant and supplies three to four times the energy per square meter, compared to the rest of the plant, which takes advantage of the space, while The continuous growth system of the present invention with the storage system takes up to 5% of the space of the combined cycle plant and supplies one to two times the energy per square meter of the power plant.

Figure 3 shows another embodiment of the present invention, wherein an auxiliary gas turbine 64 is used to provide the supplemental air flow at times when additional power output from the gas turbine system 1 is needed. Auxiliary gas turbine 64 includes a complementary compressor section 66 and a complementary turbine section 68. In this embodiment, the auxiliary gas turbine is designed so that essentially all the energy produced by the complementary turbine section 68 is used to drive section 66 of the complementary compressor. As used herein, "essentially all" means that over 90% of the energy produced by the complementary turbine section 68 is used to drive the complementary compressor 66, because the main accessories, such as the electric generator used with the gas turbine system 1, does not draw energy from auxiliary gas turbine section 68. Small gas turbine manufacturers, such as Solar Turbines Inc., have the ability to mix and match compressors and combustion / turbines because

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<img file="MX358183B_D0031.tif" />

MÍXICAN INSTITUTE.

Say LA FROPUfvr, do you build your systems with multiple supports that support? ^to '= »Section 66 of the complementary compressor and section 68 of the complementary turbine. A specialized turbine, with a large gas turbine compressor 66 and with a regular size turbine combustion system 68 is used to provide additional supplemental air flow to gas turbine system 1 and excess air 70 compressed is emitted from the large compressor 66, which is an excess of what is needed to start the turbine / combustion system 68, flows through the combustion box flow control valve 74, when it is in the open position, and is discharged into the combustion box 14 of the gas turbine system 1 to increase the total mass flow through turbine 16 of the gas turbine system 1 and therefore, increases the total energy output by the gas turbine system 1. For example, a 50 Ib / sec combustor / turbine section 68 that will normally be rated for 4MW may actually generate 8 MW, but the combustor draws 4 MW, so that the net output from the generator is 4 MW. When such a turbine is coupled with a 100 Ib / sec combustor, but only 50 Ibs / sec is fed to section 68 of the combustor / turbine, the other 50 Ib / sec will be supplied to the combustion box of the turbine system 1 gas. The exhaust 72 from the 50 Ib / sec turbine / combustor section 68 can be injected into the exhaust 38 of the main turbine 16, similar to the manner described in the embodiment shown in Figure 1 and sent to the SCR. Optionally, the space can be treated separately, when required.

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It will be apparent that the pressure from the compressor 66 of 100 Ib / sec has to be sufficient to drive the compressed air outlet therefrom within the combustion box 14. Fortunately, many of the smaller gas turbine engines are based on derivatives of aircraft engines and have a much higher pressure ratio than the large industrial gas turbines used in most power plants. As shown in Figure 3, this embodiment of the present invention does not include the recoverer 30, the intercooled compressor 22 or the intercooler heat exchanger 28, shown in Figures 1 and 2. Of course, the modality shown in Figure 3 does not provide the efficiency improvement of the intercooled modalities shown in Figures 1 and 2, however, the Initial cost of the modality shown in Figure 3 is substantially lower, which can be an attractive option for operators of power plants that typically provide power at times of peak demand, and therefore they don't start as much and are less sensitive to fuel efficiency. When the auxiliary gas turbine 64 is not running, the combustion box flow control valve 74 is closed.

The embodiment shown in Figure 4 shows another way to incorporate a complementary compressor 22 within the gas turbine system 1. In some situations, the gas turbine augmentation of the present invention with (i) an additional mass flow for the HRSG and / or (i) the additional heat from the intercooler heat exchanger 28 and the engine 20 fuel (compared to gas turbine system 1^DI

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not incorporating the present invention) may be too much for the steam turbine and / or the steam turbine generator to handle all the additional heat flowing to the steam turbine generator (especially when the power plant has duct to replace missing exhaust power on hot days). In this case, the additional steam generated as a result of adding the compression heat generated by the complementary compressor 22 se4 can be extracted from the HRSG steam cycle. As it happens, when the compressed air is added to the gas turbine system 1, the heat energy extracted from the intercooler heat exchanger 28 generates approximately the same amount of energy that is taken to drive the complementary compressor 22. In other words, when you have a steam turbine that generates 100 MW normally and 108 MW when the complementary compressor 22 was injected with compressed air into the gas turbine system 1, the additional 8 MW is approximately equal to the energy rate for operate the complementary compressor 22 Intercooled. Therefore, when some of the steam is removed from the steam cycle of the power plant, and the steam turbine is maintained at 100 MW, a small auxiliary steam turbine 76 can be used to drive the inter-cooled complementary compressor 22 and there is no additional source of emissions at the power plant.

In Figure 4, the auxiliary steam turbine 76 drives the complementary compressor 22 Intercooled and the steam 78 that is used to drive the steam engine 76, which comes from the HRSG (not shown) of the power plant, is the additional steam produced from the heat is added to the HRSG,

<img file="MX358183B_D0034.tif" />

which was removed by the inter-enfnSttürxhtr-eM® heat exchanger 22 »-. air compression in the supplemental compressor 22. The spc 80 of the steam engine 76 is returned to the HRSG where it is used to produce more steam. This embodiment of the present invention results in an improvement in efficiency because the compression process of the complementary compressor 22 is much more efficient than the compressor 10 of the gas turbine system 1. In this situation, the level of energy increase will of course be reduced, since the steam turbine does not put additional MW, however, there will be no other source of emissions / burning of fuels.

Figure 5 shows the embodiment of Figure 4 with the addition of compressed air storage. This implementation of compressed air energy storage is similar to that described with respect to Figure 2, as well as the operation thereof. Persons skilled in the art will understand that the level of energy increase of the mode shown in Figure 5 is lower than the mode shown in Figure 2, since the steam turbine will not put additional MW, however, it will not there will be another source of emissions / fuel burn.

Figures 6 to 8 show various implementations of the modality shown in Figure 1, referred to as the “TurboPHASE system”. TurboPHASE which is a supplemental power system for gas turbine systems, is a modular, packaged “turbocharger” that can be added to most, if not all, gas turbines and can add up to 20% more output for single cycle plants or

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<img file="MX358183B_D0035.tif" />

improves efficiency (i.e.

The TurboPHASE system is existing combined cycle, as long as "the heat index") by up to 7%.

compatible with all types of inlet freezing or condensation systems and when properly implemented it will leave emission rates (eg ppm of NOx, CO, etc.) unchanged, while specific emission rates should improve as a result of the improvement in the heat index. Because only 4 clean air, at the appropriate temperature, is injected into the turbine, the TurboPHASE system does not have a negative effect on the maintenance requirements of the gas turbine. Due to the factory-assembled and tested modules that make up the TurboPHASE system, installation in an existing power plant is quick, requiring only a few days of the off gas turbine system to complete connections and carry out commissions.

FIG. 6 shows an implementation of the embodiment of the present invention shown in FIG. 1 together with two General Electric Frame 9E 135 MW Industrial gas turbines 82, 84, in a combined cycle configuration with a steam turbine 86 of 135 MW (“ST”). The results of this implementation are shown below in the Table.

<img file="MX358183B_D0036.tif" />

open 1 ^r.0% additional flow added to a 2x1 9E combined cycle in one day at 5 | C (+71 Ibs / sec per GT))

<td></td><td>Existing plant</td><td>With TurboPHASE ™</td>

<td>Compressor pressure ratio</td><td> 12.7</td><td> 13.6</td>

<td>Compressor discharge temperature</td><td>673 F</td><td>760 F</td>

<td>Compressor discharge pressure</td><td>185 psi</td><td>197 psi</td>

<td>Turbine firing temperature</td><td> 2035</td><td> 2035</td>

<td>Turbine exhaust temperature</td><td> 1000</td><td> 981</td>

<td>9E GT output (each MW)</td><td>135 MW (each base load)</td><td>+ 23MW (+ 17% of departure)</td>

<td>Increased Flow</td><td>N / A</td><td> + 20.7</td>

<td>Increase in PR turbine output (delta)</td><td>N / A</td><td> +5.6</td>

<td>PR compressor load increase (delta)</td><td>N / A</td><td> -3.3</td>

<td>ST output (MW)</td><td>135 MW (base load)</td><td>+ 16 MW (-12%)</td>

<td>Increased Flow</td><td>N / A</td><td> +9.4</td>

<td>Cooler exhaust temperature</td><td>N / A</td><td> 2.9</td>

<td>Jacket Heat and Heat IC in ST</td><td>N / A</td><td> +9.9</td>

<td>9E SC plant output (MW)</td><td>135 MW (base load)</td><td>158 MW (+ 23MW or - 17%)</td>

<td>9E CC plant output (MW)</td><td>405 MW (base load)</td><td>467 MW (+ 52MW or + 15%)</td>

<td>Burned base load fuel by GT</td><td>1397 MMBTU / hr</td><td>1514 MMBTU / hr</td>

<td>Burning auxiliary engine fuel supplying 71lbs / sec.</td><td>N / A</td><td>96 MMBTU / hr (740 Gal / hr - 15,000 HP)</td>

<td>Total additional fuel burn GT</td><td>N / A</td><td>11 MMBTU / hr (+ 1%)</td>

<td>Increased flow</td><td>N / A</td><td>98 MMBTU / hr (+ 7%)</td>

<td>PB increased / CDT more high / mixed temperature</td><td>N / A</td><td>-77 MMBTU / h_r</td>

<td>Burned fuel from DC plant total</td><td>2974 MMBTU / hr</td><td>3028 MMBTU / hr</td>

<td>SC heat index</td><td>10350 BTU / kWh</td><td>5582 BTU / kWh (-767 BTU / kWh or -7%)</td>

<td>DC heat index</td><td>6900 BTU / kWh</td><td>6483 BTU / kWh (-416 BTU / kWh or -6%)</td>

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<img file="MX358183B_D0037.tif" />

As is evident from Table 1, the impipmpntaninn h_p The output Hp increased energy from each of the gas turbines by 23 MW, and an increased energy output from the steam turbine by 6 MW, for a total of 25 MW (2x23 MW + 6 MW = 52 MW). The TurboPHASE system increases air flow for gas turbines by 7%, operates at any ambient temperature, and produces a 5% improvement in heat index. By doing this, the pressure ratio (“PR”) at the gas turbine outlet of each gas turbine increased by 5.6, while the PR of the combustor cg showed a decrease of 3.3. The total energy consumption rate for the combined cycle plant (“CC”) increased by 54 MMBTU / hr, while the heat index for the CC plant decreased by 416 BTU / kWh. For information purposes, Table 1 shows that when the implementation was carried out in a single cycle plant (“SC”), the increased energy output from each of the gas turbines will have added 46 MW, while the index of Heat will have decreased by 767 BTU / kWh. As an option, the intercooler heat exchanger can be removed and the heat from the supplemental compressor and engine heat added to the gas turbine cycle, which increases the ST output from + 6MW to +16 MW (total 62 MW) and improves the heat index by 6%.

Figure 7 shows an implementation of the embodiment shown in Figure 1 in a DC plant comprising a General Electric Frame 9FA industrial gas turbine 82 and a 138 MNW steam turbine. In this implementation, the energy output by the 82 9FA industrial gas turbine is increased by 42 MW from 260 MW, and the output of

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Power from the 88 steam turbine is increased by 8 MVV, for a total increase in power output of 50 MW, along with an improvement in the heat index of 0.25%. As an option, the intercooler heat exchanger 28 can be removed and the compression heat from the supplemental compressor 22 and heat from the fuel engine exhaust 32 can be added to the HRSG in the steam cycle, which increases the ST output from + 8 MW to + 14 MWS (total 56 MW) and improves the heat index to 1.8%.

Figure 8 shows an implementation of the embodiment shown in Figure 1 in a SC plant comprising a General Electric Frame 9B (or 9E) industrial gas turbine 90. In this implementation, the power output by 9B is increased by 23 MW from 135 MW, along with an improvement in the heat index of 7%.

Implementation of the embodiments of the present invention preferably provide the following benefits:

(i) Installation is quick and easy, no further electrical connections are required.

(ii) No changes are made to the firing temperature of the gas turbine, so that the maintenance costs of the gas turbine remain unchanged.

(iii) Uses the existing ports in the combustion box of the gas turbine system to inject the air.

(iv) High efficiency, internal combustion and recovered, engine driven, intercooled supplemental compressor improves SC and DC heat rates.

<img file="MX358183B_D0039.tif" />

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INSTITUTO MEXICANO DE LA TRO REOAO INDUSTRIAL (v) It is compatible with water injection, condensation, inlet freezing, steam injection and duct burners.

(vi) Air is injected into the combustion box of the 5 gas turbine at compatible temperatures and pressures.

(vii) The reciprocating, internal combustion fuel engine can burn natural gas, low BTU bio-fuel, or diesel (also available with a small steam turbine driver and a small gas turbine driver for a fuel engine ).

(viii) The energy storage option is also available, approximately 2 times for the price and 2 times the efficiency improvement. Although particular systems, components, methods, and devices have been described in detail, they have the ability to achieve the objectives and advantages of the invention, it should be understood that these are the preferred embodiments of the invention and therefore are representative of the subject which is contemplated by the present invention, that the scope of the present invention encompasses other modalities that will be apparent to those skilled in the art, and the scope of the present invention is limited only by the appended claims, wherein the region to a singular element means "one or more" and not "only one, unless the claim dictates otherwise. It should be appreciated that modifications and variations of the invention are encompassed by the teachings and are within the appended claims without departing from the spirit and scope of the invention.