Directional Relay SCADA-Based Upgrade for the Power Management Interface Improvement in Pumped Stored Energy

1. Introduction

The high demand for clean energy in the modern energy power system (EPS) due to fuel prices, laws, and regulations emphasizes the need for alternative power generators [1]. Evolution of the renewable energy use the fact that the hydro system evolution until 2050 is quite constant, because the water reserves and new specific implementations are not variating significantly, so the improvements are its optimization and/or use ameliorations. Renewable energy sources (RES), or called sustainable energy sources, like wind, solar, hydropower, geothermal, and biomass energy are now gradually starting to dominate the energy generation mix, re-placing traditional generation sources, such as coal and nuclear. The global installation of only wind and photovoltaic generation exceeded 400 GW and 200 GW, respectively, by the end of 2015 [2].

In such a circumstance, the application of any technology, including energy management techniques, has an impact on how society views energy and energy-related issues. In terms of accepting or rejecting them, society is acting in a way that is consistent with the commitment made. In order to anticipate how society will interact with technology related to electrical energy management, various training and optimization simulation scenarios should be developed.

1.1. Demanding Functions Review

Developing countries from Central and Eastern Europe have significant energy potential from RES determined by mixed environmental conditions (relief and climate). In the 2018 report of Central Europe Energy Partners (CEEP) is presented that overall RES use for 2014 in Romania and Bulgaria (26% and 18% respectively) already exceeded their targets for 2020. According to this report, the power from RES in Romania have their biggest use in electricity production (44%), followed by heating & cooling (28%) and the lowest use in transportation (4.5% in 2014) [2]. In this example, hydropower alone can meet 40% of the country’s instantaneous electricity demand, which is the highest among all the countries in the region.

It is well known that most of the modern RES are interfaced through inverters. Although this is advantageous from the point-of-view of harvesting RES, the inverter-based generation does not provide any mechanical inertial response, and hence compromises frequency stability [3,4,5,6].

In a more detailed manner, a typical load profile can be figure out on a limited period of time, where t.u. represents the time unit (according with the process, time unit can be one hour), and p.u. is power unit according with the process.

Depending by the application, the load is connected to the energy power system, through a bus bar, where more power feeders could be interconnected and managed based on management algorithms.

The profile of load current (I_L) extracted from grid is described by the load demand. In such situation, without taking any corrective measures, the grid reacts with significant fall of the generator’s frequency (up to 2-5 Hz) [7]. The literature describes methods to improve the frequency stability, one well known method being virtual inertia system. Whatever the case, using or not frequency corrective system, the falling event normally is expanded up to 10 seconds, then the stabilization process is done in two steps: the grid response, which should happen in 10÷30 seconds, and the automatic generation control response must expand in 10÷30 minutes. Therefore, not only the fall’s magnitude but also the timing of its various events is significant.

A comparable occurrence is depicted in simulation models for small-scale local generators, that are impacted by abrupt variations in load. In both cases (without/with dumped bars for improving the transient response) the frequency is variating for a significant period, inducing high number of oscillations of the generator’s rotor [8].

The use of local power generator, for the same load profile requires similar “protective measures”. The authors of [9] designed a model of small-scale generator (comparable with most local power generators used in microgrid systems). A simplified interconnected system (main electrical grid and local power generator) is represented in Figure 1.

In [7,8] a rigorous analysis of the torque variation at the generator’s rotor is presented. The typical step response shows important transient variation of the torque - more than 100% of the step amplitude, with the time to stabilization more than 2.

According with IEEE 1547 all necessary measures for re-synchronization and reconnection for health work of the system must be taken. If we consider a power balance at bus bar level, according with load profile, the Figure 2 shows the possible situations (if the local generator’s power is 50 p.u. [kW] continuously for 12 hours).

Above the horizontal axes there is demand from the grid in a variation profile like shown in previous situation (in first 12 hours there are four power peaks required from grid). Then there are hour’s moments when there is available power, that will be injected into the grid. Figure 1 shows currents direction variation according with the load profile.

The standard structure of a pumped hydro storage (PHS) can be represented as in Figure 3. The core point is the distribution busbar when main grid (G), local generator (LG) is connected for load supplying.

To simplify the representation, the figure does not show the load. In practice, the distribution busbar is insulated by the system/local generator with the use of insulation transformers (with step up/down functions).

Another important part of this structure is the reversible turbine, that is specially designed to be used as hydro plant turbine or pump turbine. This reversible turbine is mechanically connected to a synchronous machine via a proper gearbox. In this way, the obtained chain can use potential energy of the water from upstream hydro storage basin to produce electrical energy in local generator to be injected into the grid, or to be used by the load. If there is available energy from solar/wind systems or energy price is low, the working chain can be switched: the synchronous machine, now working as motor, drives the turbine in the way that pumps up the water from down-stream basin to be stored as potential energy, in upstream basin.

1.2. Research Contribution

Taking into considerations the above listed functions requirement, the general approach of our research is represented in Figure 4, where we will point out our contribution, as a main response to the interoperability demand formulated in IEEE 1457 [10].

Because we are implied to different levels of the research, the above figure is explained as top-down modem of the involved components. We proposed this kind of architecture to add an educational value to the Smart Grid implementations when some up-dates are taken. The lowest level (1) is the process level, which is linked with hardware and SCADA software through communication (2) support layer, in our laboratory we are using Modbus (2.a) over RS 485 (2b) protocol. In the same time the two layers are linked each-other through concepts (example: we measure phase voltage; we validate the synchronization operation). The concept is “visible” up to the highest level, where the user must decide operations. At this level our contribution was to adapt the communication protocol to the above levels, and we have validated the designed response to the Smart Grid requirements, like in [4,5,10].

Considering that we are adding to our research a new operational function by integrating a directional relay in PHS structure, our major concern was always interoperability. It was the reason why we checked the possibility for the user to interact with both, software (SCADA) and hardware (laboratory model); if fact we have replicated the real situations, where, for instance, the final decision is always taken by the user. At highest level of architecture representation (3).

The SCADA software has been designed entirely following typical SCADA functions, adapted to the lab model of a PHS implementation. In our implementation, we designed a laboratory model that is using industrial devices (synchronization and directional relays) working together with devices that are replicating major functions (grid component, power distribution breakers), as a response research focused hardware and software upgrade.

On the other hand, according with Figure 1, not only momentary response problems appear, but also direction variations changes happen (time periods 3-4, 4-5, 5-6, 7-8, 8-9, there is a need to “prepare” the generators to react properly to the load profile and, if possible, to apply some load profiles optimization. In the revision process of the IEEE 1457 [10] is formulated an improvement also in terms of process interfaces, as illustrated in Figure 5.

We agree with the structure formulated in [10], the only differences we propose are related to the structure: a top-down architecture defines more clearly in our opinion the relationships between entities. We agree with the electricity adequacy [11] because it respond to the commitment of security and local constrains, and because of this reason, a part of our “interface optimization” work is dedicated to the way we interconnect devices, and how they are “visible” at the information level.

If we accept that protocols for communication also mean information, we also agree with the authors of [10] structure. This level is responsible for exchanging information between all entities (horizontal and vertical directions).

A bit more complex level is the information level we are proposing, where we identify meanings (data, facts, knowledge [10]), and where processing functions are implemented for fulfilling security constrained unit commitments to the formulated purpose, clearly described in the flowchart designed by the authors of [12], called imperialist competitive algorithm. Our understanding from the algorithm question “is there a colony which has better objective function than that of imperialist” force us to always focus on “better objective function”- electricity price at load busbar is our laboratory criteria we should consider. Then we can add or not different constrains. We can only implement such algorithms in an information level integrated into a software, and eventually working as a part of smart grid, as [10] also suggests.

Our approach intends to improve the “interface” between communication and information entity by using a directional relay (67 ANSI Code) controlled by a supervisory control and data acquisition (SCADA) designed software, which allows improvement of interoperability (the capability of two or more networks, systems, devices, applications, or components to externally exchange and readily use information securely & effectively [10]).

Our approach responds also to the revision proposal for IEEE 2030.2-2015 (which should regulate the interoperability between storage systems with electric power grid) [11] - chapter 3. It will contain two parts: directional supervision/protection, and coordinate (readily use information securely and effectively) the energy storage process into an interconnected system.

In summary, the goal of this study is to provide a visible improvement of a security constrained electrical energy management solution as an add-on to the operation of the Smart Grid Systems. The SCADA-Based update is modernized and applied to a pumped stored energy solution simulated by an industrial device-filled lab model.

2. Fundamentals of Directional Analysis

According with IEEE 315-1975 symbol library, the analysis has begun from a typical representation of an IEEE-3 bus electric power network configuration, as a basic configuration for integration of a local power supply to the main grid system (as in Figure 6).

The load (L) is connected to the electric grid through the busbar c, which is then linked to the main grid source (G) and local generator (LG) through the busbars (a) and (b). The typical IEEE- three bus network configuration uses parallel lines (Figure 6i), and for simplified analysis (when local generator is sensible les powerful that the grid capacity) we are using the second configuration (Figure 6ii).

The basic operating characteristic of any protection relay (we include here the overcurrent protection, directional protection) depends on the energizing values of the currents, or voltage, or various combinations of these two quantities (especially the phase between two parameters).

To start protection or power flow analysis, it is usually necessary to know the mathematic representation of the current and voltage, in momentary values and phases. Then, according with networks configurations there is a requirement of system analysis, in fault conditions, with the reference to the various points within the analyzed system.

The analysis considers the power system as a network of circuit elements contained in branches (closed loops or meshes), described by impedance and admittance.

We resume here the well know mathematical parameters for currents- i(t) and voltage- v(t)- in a sinusoidal system. Thus, if the line is supplied by the voltage:

v(t) = V_m sin(ωt),

(1)

Then, if the line parameters are composed by resistances (R), capacitances (C), and inductances (L) connected serially, the current established in this circuit is:

i(t) = I_m sin(ωt-φ),

(2)

where φ is the phasor between voltage and current.

In this context, for a three phases power system, there is a convention related to vector representation. In a system built by three phases, from the generator (G), the voltage phases (U_U, U_V, U_W) supply the three phases load (L), being established three phase currents (I_L1, I_L2, I_L3).

If the system is symmetrical the representation of the power network and associate vector representation is shown in Figure 7.

However, the controlled parameter, where the technical literature gives it a particular name as zero-sequence variable as:

$$\overrightarrow{I_h}=\frac{1}{3}\left(\overrightarrow{I_{L1}}+\overrightarrow{I_{L2}}+\overrightarrow{I_{L3}}\right),$$

(3)

is very simple to evaluate by using three current transformers for measuring phases currents, or by a coil (ring CT) around the three phases.

The estimation of the direction of the current (not only in fault situation but also in the situation of changing the direction of the power) requires also to consider the voltage vector (U_u). In both situations, by measuring the angle between the specific electrical parameters (the voltage flux ϕ_U and current flux ϕ_Ih, responsible for creating the torque T) allows to create a zone of protection (b), and non-sensitive area (a), like in Figure 8-a. For practical reasons, the torque direction will be considered as reference (ref) while the angle between torque direction and the voltage vector is the directional protection angle (φ_x).

If is established a reference angle of the electrical parameters related to φ_x, and if we consider a threshold (r) of the parameter that must be controlled (in our case zero-sequence variable I_h), according with the phase angle of the controlled parameter, the z axes define not protected zone (a) and protected zone (b) [13,14].

The direction of the power flow is detected by establish the controlled parameter:

$$\overrightarrow{I_h}=\frac{1}{3}\left(\overrightarrow{I_{L1}}+\overrightarrow{I_{L2}}+\overrightarrow{I_{L3}}\right),$$

(4)

related to the phase voltage U_U, to avoid dead protection zone when earth fault occurs. Furthermore, the protection is adjusted according with the angle between U_h and I_U, and by setup the relay measuring the current I_U and the voltage U_h has a 90° relay connection [15]. A possible situation of the protection can be represented as in Figure 8-b (retaining the meanings of notations as in Figure 8-a).

By checking the angle and amplitude of the controlled parameter with the help of an appropriate relay, it is possible to monitor both the direction of the power flow and the overcurrent fault.

Figure 8. a) the vectorial representation of the I_h current; b) the vectorial representation of the U_h voltage- particularized from [15].

Figure 8. a) the vectorial representation of the I_h current; b) the vectorial representation of the U_h voltage- particularized from [15].

The directional relay (ANSI 67) in Figure 9, is collecting information about the power line’s voltages (through the vector V_h), and the power line’s currents (through I_x) for estimating the amplitude and phase ϕ_x which has been defined above. The user enters in this relay the working and supervising parameters: rated current (I_n), trip overcurrent (I_s), and protection angle (a) - notations are referring to relay’s technical documentation [15].

According with implemented method (example: f(a)=supervision), the relay compares the amplitude of the current first, and then changes of angle ϕx. When both conditions are fulfilled, the relay sends command to the power breaker from the beginning of the power network (52), for disconnecting the segment of protected power network.

The typical integration of such relay in a network supplied by two sources, is shown in Figure 6 configurations at the beginning of this section, and according with regulations stipulated by [10], and based on quality requirements from [11], we propose to integrate the directional relay into the protected network, as in Figure 10.

Following the IEEE representation [10], this analysis resumes the main algorithm of the energy management when a load (Z) is supplied by two sides power supplies (algorithm available also when a local generator is added). For operational reason, each feeder line is controlled by a power breaker (52) located at the beginning of the line (CB1 and CB2). They are required also for controlling the synchronization sequence executed by a specific relay (ANSI 25), when the synchronization conditions are fitted the relay [16] commands the breaker CB3 (with the same role - 52) to add the second generator to contribute with its added energy.

The working principle of the used industrial directional relay (ANSI 67), preserve the stability and dependability of the electrical grid. The power system is continuously monitored, current directional faults are identified, the fault parameters are quantitatively assessed, and suitable protective measures are implemented. The relay supervises the direction of the current when the input voltage is above 1-2% of the rated input value, input currents are above the set level: Ix > [Is] and the phase displacement “ϕx” is within ±90° from the reference direction “a”.

It is important to use/push correctly the energy from the power system. The directional relay is protecting the network, by using two functions: by correctly allowing the power flow circulation and by controlling (signalling) the sequence of power transfer. Particularly, in above figure, the relay allows to send the power into the grid according with the agreement or commitment (case 1) or to protect against reverse power fault (case 2). The protection has the ability to detect the direction of a short-circuit current for a well-established range of angle φ_x.

3. Laboratory Model Design for the Concept Validation

3.1. The Laboratory Setup

The laboratory setup is shown in Figure 11 and for the experimental purpose, the local generator is simulated, in Figure 11 (i), by using a synchronous machine (G/M) driven by a prime mover implemented with a brushless machine (PM/B), controlled through an electronic driver, as in Figure 11 (ii).

This implementation allows to create reversible chain (if the synchronous machine is generator, the brushless is prime mover; if the synchronous machine is running as motor, the brushless will become brake, simulating a process - like pumping system).

According with the three entities architecture proposed in [10], and following the designed simplified control wiring diagrams, the grid power supply is replicated consisting model components, as in Figure 12 (for reasons of simplicity and clarity the components are represented in a symbolic way - for instance instead of showing wirings, arrows are used that indicate the concept of energy transmission.).

The three-phase power supply from the lab represents the main grid (G). It is supplying the distribution transformer which is also playing the role of insulation transformer. The output of the transformer is connected to a transmission line (we are using a distributed parameters model for a long line: 13 Ω/km, 290 mH/km, 0.5μF/km and phase) until the distribution busbar of the load.

The local generator (LG) has the structure presented in Figure 13. It is consisting of a synchronous generator (SG) mechanically connected to a brushless motor (PM/B) controlled by its electronic driver (ED). According with proposed objective, when LG works as generator, the brushless motor is a prime mover (PM) simulating the developed energy at turbine level by the upstream water. From the ED we control the amount of produced mechanical energy, at the terminals of SG we obtain three phases electrical energy. When LG works as pump, from the main grid we supply the SG as motor, and the PM/B works as a brake (B) for the SG rotor, representing the mechanical resistant torque at the reversible turbine when it pumps water into upstream basin.

The three-phase load (Z) is represented by static variable resistance, inductance, and capacity, as in Figure 14.

For running the laboratory model, a SCADA software is designed and implemented which will control the system through a RS485 Modbus protocol. The software supervises and control the different steps, like in real energetic system. First step will supervise the automatic synchronization of the local generator with the electric grid.

The synchronization relay [16] (25 is the ANSII IEEE code for this specific function) will control the synchronization conditions regarding the voltages - from the main grid (U_G) and from the local generator (U_LG), and when they are fulfilled, the relay command the main breaker (CB1) to connect the local generator to the grid, as in Figure 15.

The feeder relay (67), described in [15], is supervising the phase between parameters I_LK and V_LK, and according with its setup, it will send command (a) to the SCADA when L_G works as generator, and command (b) when L_G works as motor. For security reason, the feeder relay is programmed, if case, to disconnect the local generator with the command C1 for the breaker CB2, of to disconnect the load Z with the command C2 for the breaker CB3.

On the other hand, the SCADA, which is recording the electrical parameter measured by the relay (67), and measuring device M, according with its implemented algorithms, will send command C3 to the higher-level processing software (integrated into the smart grid concept). For an easy understanding purpose, was integrated into the diagram a three-phases measuring device that displays the power transfer with sign.

The second step: working as a local generator by pumping the water to the upstream basin. In this step the main role has the feeder relay, with main function directional supervision and control (67). For this part of the experiment, as in Figure 16, the main devices involved in the experimental setup, are: the circuit breakers involved in connecting the local power generator to the load (CB2, and CB3), the directional relay (67), one measuring device (M) for measuring the voltage/power, and the RS 485 hub required for local control and for integration in Smart grid.

3.2. SCADA Support for Laboratory Model Development

The laboratory software with the function associated to SCADA has been developed using Winlog as open-source development platform [17,18]. When using a dongle license [18] it supports most popular communication protocols (Siemens, Omron, Allen Bradley, Modbus RTU/TCP, KNX, BACnet).

The main architecture of this software is shown as UML (Unified Modelling Language) diagram, in Figure 17. The UML representation is used because, as a standardized modelling language, it contains rules, symbols and concepts comprised in best practice for developing dedicated software. According with the diagram, in Figure 17, into a project manager, by using template builder (as fastest software development automation) the required gates were created (operator windows) together with the control interface. For interacting with external devices, though the RS 485 network interface, and Modbus protocol, the designed SCADA is interrogating our RS485 hub.

The main software interface is presented in Figure 17, were the experimental operations are allowed to be controlled, with measurement details shown in Figure 18 (for generator side) and Figure 19 (for the load).

4. Tests and Experimental Setup Results

As in all double supplied electric power systems, the first step is the coupling in parallel of the generator with the main grid after fulfilling the synchronization conditions (equal voltages, equal frequencies, and phases of the voltages below a standard limit). They are controlled by the synchronization relay (ANSI 25). The laboratory model allows these actions by adjusting speed of the prime mover until it reaches 1450 rotation/min (50 Hz), and by adjusting the excitation of the synchronous generator.

In the separate window the synchronization relay pup-up interface shows with two of the parameters (the frequencies are equal but not yet the voltages), as presented in Figure 21.

In the current situation the excitation voltage was adjusted (INC button) until voltages reached equal values. Then the synchronisation relay followed its procedure to couple the two power systems.

After the synchronization process was ended, the electrical parameters measured by the directional relay 67 are shown in Figure 22. The measured injected power (line three in the opened display) was null. At the same time, the synoptic display didn’t fill any of the Pump/Generator container.

4.1. Experimental Test with the Synchronous Machine as a Motor for the Pump

After synchronization process passed, the torque control was activated and was added brake to the electrical machine’s rotor: it acts as a motor that drives a pump (for storing the water energy in upstream basin).

With connected load, the extracted active power from the grid was 332 W, and the required power by the pump was 117 W. The distribution busbar was at the load connection point to the electric grid, by convention, the positive sign was when the power flow comes to this point, and negative sign was when the power flow goes out from this point. According with this rule, Figure 23 shows that the power is extracted from the grid and used for load and for the pump. The active power of 333W from de grid and 177 W from de local generator are used by the load. In the synoptic representation, the pump tank is filling proportionally with added torque. We might also notice directional relay phases (not equal because also the phases loads are very equal too).

Because the energy consumed by the pump needs to be controlled accurately, the goal was to program the directional relay to supervise this direction of the power flow.

Was supervised the magnitude of the controlled parameter and its angle direction to the reference. If one-line current was established as reference, and the vectoral difference was controlled of the other two phases (Uh), measured with 90° relay connection, we can setup the relay operation angle, based on its programming procedure.

The reference value of the tripping current was Is=500mA, the reference angle was a=60°. The relay worked, as shown in Figure 23, because the current was higher than tripping current (Ix=Imax=578 mA) and the phase displacement outside the protected area (“φx” of 170°).

The relay supervises the direction of the current, and the operation conditions are shown in Figure 24:

- Input voltage above 1-2% of the rated input value.

- Input current above the set level: Ix > [Is]

- Phase displacement “ϕx” within ±90° from the reference direction “a”.

In this working regime, the directional relay that detect the direction of the power flow, in improving the protection, by controlling the overcurrent limit only when the electrical machine runs as motor for water pumping.

Figure 24. The vectorial representation for the current parameters SCADA diagram snapshot.

Figure 24. The vectorial representation for the current parameters SCADA diagram snapshot.

4.2. Experimental Test with the Local Generator Energy Injection

With the speed control facility from the interface, the synchronous machine was running as generator, as in Figure 25. In this case the local generator is driven by the prime mover (simulating the energy captured at turbine level from the upstream basin water potential energy) and producing 465W power that is used by the load (465 W-140 W), and rest is pushed to the grid (140 W). In the synoptic representation, the generator tank is filling proportionally, with added torque to the prime mover. We might also notice that the directional relay phases are changed.

In the testing experiments the phase current was above 500 mA, which is the tripping value of the directional instantaneous current protection. The relay didn’t trip because in this case the phase displacement was in the protected area.

On the other hand, to validate the response of the relay (for disconnection or for connection/re-connection), was programmed the relay to record instant values for 500 milliseconds before and after command trigger (tripping or connecting command) in order to understand the time response of the relay. The first oscillography shows a tripping evolution, Figure 26.

The significant times are marked: t_t is the tripping moment (reference zero), t_t-500, t_t+500 represents the range of event recording, important for transient analysis. The relay responds according with most general regulations [10], the disconnecting time is around two and half periods of the power frequency (around 50 milliseconds). There are also oscillography records for connecting the line as in Figure 27.

The record is done in similar experimenting conditions (rated current, recording time). The only difference is the meaning of tt: from the relay setup point of view, the reference time is when the power is stabilized in frequency and amplitude. The important observation here is the variation of the voltage at the output of the line until it become “useful”. In our experiments we obtained variations for 150 milliseconds, value that still fits the requirements from [11].

The records are repetitive, which means that the lab setup is stable, and the relay works correctly.

5. Conclusions

A lab model of the pumped storage system evaluation has been set up for the synchronization of two or more power supplies, to realize a smart-grid connected system. For this operation, the synchronization process is implemented. The relay allows states collection for higher level of processing (security constrained unit commitments), or smart grid implementations. The relay offers 4 outputs for integration in hardware networks and send states data via RS 485 communication networks. In this way, the designed lab model replicates real process implementation, coordinated by designed SCADA is proving the concept, and in the same time, the SCADA could be used in real situation (monitoring and controlling the industrial relays).

The objective to present a comprehensive understanding of PHS regarding peak shaving, was described in [19,20,21]. We highlighted that the use of a directional relay between storage systems and the electric power grid is the outcome of our design optimization technique. This relay improves interoperability by automatically identifying and distinguishing between the fault mode and the mode of operation’s switching sequence.

The lab model uses a software controlled brushless motor that plays the role of a brake (similar with the pump turbine). The developed brake torque results in an extracted power from the system (when there is an available power at the distribution point or when the price of the grid energy is low). The preparation of the system for working as the motor-pump system is done automatically by the SCADA software, allowing exercising and knowledge base accumulation for real reverse-controlled turbine control.

The lab model uses also the same software controlled brushless motor that plays the role of a prime mover (similar with the hydro turbine). The developed brake torque results in a produced power for the system (which is consumed locally or injected into the grid as sold energy when its price is high). The preparation of the system for working as the turbine - generator system is done automatically by the SCADA software, considering time delays for working mode and transitory sequences switching.

The lab model, controlled by the SCADA, is able to switch between pumping and generating system passing through the synchronizing speed, managing the possible sleeps of the speed variation when it switches between generator and motor’s regime.

The SCADA software provides for the upper-level processing software (Smart Grid software), automatically, the power flow into the system (values and sign) every 200 milliseconds (at the speed of the Modbus protocol). Starting from the current version, as future work, there are tested Modbus over TCP in multi-clients systems, for remote monitoring and control, and for reducing the data querying time closed to the standard network delays limit.

From the practical point of view, it is underlined the fact that SCADA (designed to be used on both cases: lab model and real system) is controlling all real technological functions from the real system integrated into the lab model, for knowledge base accumulation. Then the SCADA can be installed on the real system, with fast acceptance and implementation.