Adaptive controller for forced oscillation suppression in the grid

A control system and method for an inverter-based resource device provided in a synchronous power grid. The control system includes at least one inverter based resource device connected to an electrical power system, and a controller module. The inverter based resource device includes a reference power Pref, a combination module and a transfer function. The inverter based resource device injects modulated power into the power system. The power system (which is represented by a transfer function in the control system) receives an undesirable forced oscillation, which is connected to a measuring device. A controller module processes the measured output and provides a control signal to the inverter based resource device. The controller is arranged to suppress a forced oscillation detected in the power system.

BACKGROUND OF THE INVENTION

The application generally relates to control systems for inverter based resources in a power grid. The application relates more specifically to an adaptive controller for forced oscillation suppression in a power grid.

A forced oscillation, or FO, is a power system's steady-state response to a cyclic input typically caused by malfunctioning generator control equipment, cyclic loads, etc. With the advent of wide-area time-synchronized measurements, recorded forced oscillations are becoming more common with frequencies ranging from 0.1 Hz to 10 Hz. Forced oscillations may cause undesired overuse of equipment. In some cases, the ramifications can be dangerously catastrophic. The typical solution is to automatically detect the existence of the forced oscillation and locate its source so the faulty equipment can be remedied.

Modern grids are rapidly integrating increasing proportions of non-synchronous generation sources such as wind and solar, as well as energy storage devices such as batteries. These emerging devices are typically interconnected to the grid via inverter systems. In many cases, these inverters enable near instantaneous change in the injected power. Emerging standards for an Inverter Based Resource, or IBR, such as IEEE P2800 for transmission connected IBR interconnection, establish requirements for IBR performance. Although this standard may not require the ability to use IBRs to manage wide-area stability, guidelines include IBR related stability issues, which inherently includes transmission responses. In time, IBRs may be expected to contribute to the improvement of overall transmission system stability.

What is needed is a system and/or method that satisfies one or more of these needs or provides other advantageous features. Other features and advantages will be made apparent from the present specification. The teachings disclosed extend to those embodiments that fall within the scope of the claims, regardless of whether they accomplish one or more of the aforementioned needs.

SUMMARY OF THE INVENTION

One embodiment relates to a control system for an inverter based resource device in a power distribution grid. The control system includes at least one inverter based resource device connected to an electrical power system, and a controller module. The inverter based resource device includes a reference power Pref, a combination module and a transfer function. The inverter based resource device injects power into the power system. The power system includes a transfer function, to receive a forced oscillation source. The transfer function is arranged to generate an output value to a measuring device. A controller module processed the measured output and provides supervisor control of the inverter based resource device. The controller is arranged to suppress a forced oscillation detected in the power system transfer function.

Another embodiment relates to a method for controlling an inverter based resource device to suppress forced oscillation in a radial transmission system. The method includes providing an inverter based resource device connected to an electrical power system; suppressing a forced oscillation; detecting the forced oscillation at a predetermined measurement point; setting a tuned frequency of a band-pass filter frequency HF based on the forced oscillation frequency; setting a control compensator value Hc, in response to the detected forced oscillation having the tuned frequency; tuning a control compensator value to cancel a gain and phase of a measured power value; and setting a gain value Kc; generating a feedback signal c with the gain value in response to the band-pass filter frequency HF and the control compensator value Hc; transmitting the feedback signal to the inverter based resource device; and modulating a real-power output of the inverter based resource device in response to the forced oscillation.

Another embodiment relates to a control method for suppressing forced oscillation in a power system. The control method includes detecting a forced oscillation signal; passing the forced oscillation signal thru a band-pass (BP) filter that focuses on the desired bandwidth for an oscillation detection; passing the band-pass filtered signal through a squaring function and squaring the filtered signal; passed the squared signal thru a low-pass filter estimating the moving mean of the squared signal and is matched to the BP filter; generating a square root of the low-pass filtered signal; wherein the output signal is an RMS value of the forced oscillation signal in the bandwidth of the band-pass filter.

Certain advantages of the embodiments described herein are mitigation of the impact of a forced oscillation on the power grid and to suppress the forced oscillation via controlled devices. The solution includes automatically inducing a second oscillation into the power grid which cancels the impact of the forced oscillation without the need for locating the source of the original forced oscillation.

Other advantages include a robust tuned feedback-control suppression method; expansion of the method to multiple IBR devices; and development of a supervisory system to automate the application of the feedback controller. Another advantage is the ability of the control method to identify and adapt to changing forced oscillation frequency and continue suppression as the suppression frequency changes with time.

Another advantage is a novel suppression control method which modulates controllable devices to automatically cancel the impact of a forced oscillation without the need for locating the source of the original forced oscillation. The method is based upon a tuned feedback controller and is applicable to multiple devices. Once a forced oscillation is detected and its frequency is estimated, a tuned filter and compensator are automatically inserted to modulate controllable devices such as inverter-based resources to cancel the impact of the forced oscillation.

An advantage of using a feedback method for suppression is to avoid a condition where unwanted oscillations are induced into the system if the forced oscillation detection fails, such as might occur with an open-loop design. Another advantage of the feedback method is that the control method can be automated as demonstrated in this paper.

DETAILED DESCRIPTION OF THE INVENTION

The disclosure relates to a control system for an inverter based resource device or devices in a power distribution grid. The control system includes inverter based resource devices connected to an electrical power system, and a controller module. The control system includes a controller module that obtains feedback from the power grid, and modulates an existing inverter based resource that is connected to the electrical power system. The inverter based resource device includes a reference power Pref, a combination module and a transfer function. The inverter based resource device injects power into the power system. The power system is described by transfer functions G1and G2, and is modulated by an undesirable forced oscillation source r. The power system is sampled, sending an output value to a measuring device Hpmu. A Supervisory controller module processes the measured power system output and provides supervisory control of the inverter based resource device. The supervisory controller is arranged with other control elements (Hc, Hf, and Kc) to generate a control signal that will suppress a forced oscillation detected in the power system.

Referring toFIG.1, a control loop diagram for a tuned feedback controller10is shown. The control loop10begins at an IBR device12which is to be modulated. A modulation feedback signal c is added to the reference power Prefof the IBR Device at combination module13and the output of module13is forwarded to a transfer function15representing the real-power injection device, e.g., IBR, dynamic brake, or energy storage device. IBR Device12modulates power into a power system described by transfer functions14which includes a rogue forced oscillation source r. The output of a first transfer function G1of the synchronous power system14is added with r to generate the input to transfer function G2representing an arbitrary division of the synchronous power system14, or G1G2. The rogue forced oscillation r is injected at an unknown location somewhere into the power system. The forced oscillation induced by r is measured by a measurement device16at output18representing a measured value y in system10. Measurement device16has a transfer function HPMUof a measurement device, potentially a phasor measurement unit, or PMU (not shown). The measured signal is then passed from measurement device16thru a switching unit22to a compensator filter24characterized by a control compensator transfer function Hc. Hcforwards the compensated signal to a bandpass filter26, having a transfer function HF, and the filtered signal is input to gain Kc30resulting in the modulation signal c. The measurement point selection for y represents a critical point in system10that is selected to suppress the oscillation. Selection of measurement point y depends on the power system's topology. An adaptive method which utilizes the inherent robustness advantages of feedback control is described below. Adaptive refers to the ability of the controller to follow the forced oscillation and continue suppression if/as it changes with time.

The control method may be implemented through feedback controller10via an automated supervisor module20. The process starts with the detection of a forced oscillation. Supervisor module20sets the feedback control parameters for suppressing the forced oscillation and generates a control gain Kcat gain module30. Supervisor module20also determines the frequency, wc, at which the forced oscillation is occurring, as well as whether an oscillation is occurring. The output of feedback controller10modulates the real-power output of the participating IBRs. Supervisor module20monitors performance of feedback controller10continuously and shuts down the control loop25when a forced oscillation is no longer detected. Supervisor module20continuously operates oscillation detection and control logic. Module20includes control logic in response to oscillation detection, control settings, trigger logic and weight assignment parameters. Control loop is shut down automatically by operation of switching units22,28which disconnect control loop25when in an open state as determined by supervisor module20. Supervisor module20receives real-time wide-area time-synchronized measurements such as a PMU network from measurement device16. Measurement device16is configured with sufficient bandwidth to detect the oscillatory behavior of forced oscillation.

Feedback controller10is tuned to suppress steady-state forced oscillation where the following parameters are defined for IBR device12:D=A real-power injection device (e.g., IBR, dynamic brake, or energy storage device).G1and G2=Arbitrary division of the synchronous power system, G1G2.r=A “rogue” forced oscillation being injected at an unknown location somewhere into the power system.ωc=Fundamental frequency of r in radians per second (rad/s) (note fc=2π/ωcHz)HPMU=A measurement device (a PMU is assumed).y=A measurement point in the power system.HF=Band-pass filter tuned to frequency ωc+10%.Hc=Control compensator.Kc=Control gain.c=controller output control signal.

Supervisor module20provides a first control layer. Communication link23controls switching unit22and communication link21controls gain value Kcat gain module30. The real-time feedback control loop25is indicated by solid lines. Supervisor module20detects the oscillation at y, automatically sets the parameters for HFand Hc, switches the feedback control switches22,28to the “On” state, and then ramps in the control gain Kc. The output signal generated at gain module30is signal c, in response to control settings received from communication link21Supervisor module20then monitors the feedback controller's performance and shuts down the feedback control loop when the oscillation disappears. If the oscillation is detected and quantified at frequency wc, HFband-bass filter26is automatically tuned to wc. Compensator Hcis automatically tuned to cancel the gain and phase of (DG1G2HPMU) at frequency wc. Supervisor module20also adapts to changing FO frequency and changes wc(t) accordingly. Gain Kcis automatically set to a maximum safe value. Feedback control loop25is then turned on and the gain Kcis slowly increased to this design value determined by supervisor module20. The forced oscillation is then suppressed. Once oscillation FO suppression input c goes below a pre-determined threshold for an extended time, supervisor module20switches the feedback control loop to the Off state at switching units22,28.

A. The Feedback Method

The feedback control method is based upon adaptive gain scheduling and the internal model principal. With (DG1G2HPMU) and wcknown, the compensator and gain (Hcand Kc) are automatically calculated based on loop-shaping theory. The total loop gain is set as high as possible at frequency wcwith the phase at 0° while maintaining a minimum gain margin of 6 dB and a minimum phase margin of 45°.

Equations 1, 2(a) and 2(b) generate the foundation parameters for band-pass filter26, compensator24, and control gain30, assuming the frequency wcis known. The equations are in the Laplace transform, or frequency, domain. Variable s is the Laplace operator. Letting s=jwctransforms the equation to the frequency domain at frequency wc. In the following equations, a capital letter denotes a signal in the frequency domain and lower-case letters indicate time domain (e.g., R vs r).

Referring toFIG.1, an open-loop y is calculated from
Y(s)=YR(s)+YP(s)  EQ. (1);
YR(s)=G2(s)R(s)  EQ. (2a)
YP(s)=D(s)G1(s)G2(s)PREFEQ. (2b)
where EQ. (2a) is the component of y due to rogue input r, and EQ. (2b) is the component of y due to Pref. of IBR device12. We are interested in yR. In closed-loop, yRis calculated from

YR(s)=G2(s)⁢R⁡(s)1+L⁡(s)EQ.(3)
where L(s) is the loop transfer function of:
L(s)=D(s)G1(s)G2(s)HPMU(s)Hc(s)HF(s)KcEQ.4

Clearly from (3), the larger |L(jωC)|, the more yRis suppressed. Hcis tuned to cancel the gain and phase of (DG1G2HPMU) at frequency ωcresulting in

Band-pass filter HFis defined by the 2nd-order transfer function with damping ratio ç:

Because the band-pass filter's gain peaks at ωc, Kccan be large. A suppression gain Gsis defined as the amount the FO is suppressed from open-loop to closed-loop. Comparing EQ. (2a) and EQ. (3), the suppression gain at a general frequency ω is

Using EQ. (7), suppression gain at the FO frequency is

Therefore, the larger Kc, the higher the suppression.

Referring toFIG.1, if the controller is operating correctly, an oscillation will be induced at u that cancels the rogue oscillation from r. That is, the closed-loop transfer function from r to u will ideally be 1∠180° at frequency ωc. Assuming pref=0 inFIG.1, this transfer function is

To study the properties at frequency ωc, we let s=jωcand apply (7) to get

Therefore, from EQ. (10b), the larger Kcthe closer we get to the ideal gain and phase of 1∠180°.

A critical design factor is the damping ratio (ç) of HF. If the forced oscillation frequency is exactly known and is at ωc, then a very small ç is possible which will result in a very large Kc. In reality, the frequency cannot be exactly estimated, and may not be stationary. Therefore, controller10must perform for forced oscillations within a range of ωc. Many oscillation estimation methods are based upon FFT windowing where the window size dictates the accuracy of the frequency estimate with a frequency resolution being 1/z-Hz where z- is the window size in sec. For example, a 20 sec. window has a frequency resolution of 0.05 Hz. Using known filtering and windowing methods, frequency estimation is possible within 10% of the actual frequency. Therefore, a design requirement is for control system10to perform for all oscillations within the 0.9 ωcto 1.1 ωcrange. A ç=0.1 satisfies this requirement.

EQ. (5) represents the key design requirement for compensator Hc. This first requires the frequency response of (DG1G2HPMU) be known which can be obtained via transient stability models using first principles, or Eigen-analysis, or a simple chirp simulation. Another method is to use system ID method within the actual system. For realistic applications, once a model (DG1G2HPMU) is obtained, it will likely not significantly change with operating conditions as its properties will often be dominated by the IBR device D and the topology of the power system.

A relatively simple compensator Hcis preferred which enables an auto-tuning algorithm by the supervisor module20. In realistic applications (DG1G2HPMU) will be a phase-lag system, therefore, Hcwill be phase lead. A simple phase-lead controller is

Hc(s)=K⁡(α⁢Ts+1)Ts+1EQ.(11)
where α>1. Using a standard phase-lead design method, design parameters α and T are automatically set to cancel the phase of (DG1G2HPMU) at frequency ωc. This is achieved by setting the maximum phase point of Hcat co. The gain K is then set to cancel the gain of (DG1G2HPMU) at frequency co. In the following, G=(DG1G2HPMU), then the design equations 12(a), (b) and (c) are represented below:

Equations 12(a), 12(b) and 12(c), are valid if 0≥∠G(jωc)>−90°. If ∠G(jωc)<−90°, then multiple phase lead terms are cascaded.

The gain Kcis selected to the maximum while maintaining the loop's gain and phase margins within the required levels. Conservative stability designs typically require a minimum of 6 dB gain margin and a minimum of 45° of phase margin to assure loop stability.

An exemplary linear system loop transfer function from EQ. (4) is shown inFIGS.2A and2B. wherein L(jω) with fc=1 Hz. Vertical markers106a,106band106cindicate margin points for the gain profile102(FIG.2A) and vertical markers108a,108b, and108cindicate the margin points for the phase profile104(FIG.2B). In the example ofFIGS.2A and2B,

If fc=1 Hz, the resulting controller, gain, and filter are computed by EQ. (13d), (13e) and (13f) as follows:

Markers106a, bandcindicate the key gain margin points and markers108a, bandcindicate the key phase margin points. Note that the design meets the minimum 6 dB gain margin and the 45° phase margin requirements. With the Kcvalue in EQ. (13e), expected suppression is near 90%.

FIG.2Cshows the time domain results of the simulation illustrated byFIGS.2A and2B, wherein
r(t)=sin (2πt)=1.0 Hz FO  EQ. (14)

The detected forced oscillation frequency is assumed to be fc=1.0 Hz. Also, assuming 20 sec. for detection to occur and for controller10to ramp in over 40 seconds. The time-domain results of signals c, r, y, and u, as indicated inFIG.1, are illustrated. As indicated by the graph y, significant suppression of the oscillation in y is shown, and u is 180° out of phase from r.

Referring next toFIG.3, in an alternate embodiment a feedback controller310is shown for controlling multiple IBR devices312a,312bconnected in parallel. For example, a wind farm may comprise multiple turbines, each having an independent inverter.

FIG.3shows an expanded feedback controller310for multiple devices312a,312b. In the example ofFIG.3, two IBR devices are shown but it should be understood that the configuration may include three or more devices. Control signal c is distributed to n devices via weights W1thru Wn. Weights W1, W2are scaled as shown in EQ. (15):
Σi=1nWi=1  EQ. (15)

Weights W1thru W2distribute the required modulation among the devices and can be tailored to the headroom of each device. In this case, D is defined by EQ. (16):
D(s)=Σi=1nWiDi(s)  EQ. (16)

Selection of the weights enables one to dynamically distribute the control action according to the available capacity of the devices. In the example that follows, the weights are distributed according to the rating of the controlled units. Another method would be set the weights based upon available headroom below the current operating point of each device.

Supervisor module320sets the real-time control settings via links321,323, indicate by dotted lines, and automatically implements the feedback control method by conducting the following main steps: a). detect the FO and quantify its fundamental frequency fc; b) Set the feedback control parameters via EQs. (6) and (12); c) set device weights W1thru Wn; d) ramp in the control gain Kc; and e) monitor the controller to shut down when the FO has ceased or its fundamental frequency has changed.

Steps a) through e) indicated above must be automatically conducted. Step b) is set by EQs. (6) and (12) after fcis determined at step a) for ωc=2πfc. Step c) is set by monitoring the available headroom of each device312a,312b. Step d) is completed by linearly ramping the gain over many cycles of the oscillation. In a typical embodiment, 10 or more cycles of oscillation may be the ramp function interval, so as to avoid any significant initialization transients.

Automated methods are well-known for detecting FO and quantifying fundamental frequency fcat step1. In one embodiment shown inFIG.4, a general RMS energy filter410is used to implement step a). A signal of interest y is passed thru a band-pass (BP) filter412that focuses on the desired bandwidth for oscillation detection. After BP filtering by filter412, filtered signal y is then passed to a squaring function414and squared. The squared output signal y is next passed thru a low-pass (LP) filter416, and the square root of output signal y is generated at box418. LP filter416estimates the moving mean of the squared signal y and is matched to the BP filter. The resulting output signal y′ will be the RMS of the input signal in the bandwidth of the BP filter. In a preferred embodiment, multiple parallel RMS energy filters each with a specific BP setting may be employed. If the RMS energy filter output exceeds a predetermined threshold, an oscillation alarm may be set and a Fast Fourier Transform (FFT) operation conducted on y. The maximum FFT bin in the bandwidth of the RMS filter corresponds to the fundamental frequency of the forced oscillation and sets fc. Four parallel RMS energy filters to detect an oscillation wherein:0.01 Hz to 0.15 Hz—the speed governor band;0.15 Hz to 1 Hz—inter-area oscillation band;1 Hz to 5 Hz—local mode and controls band;5 Hz to Nyquist—high-frequency band.

The forced oscillation may not be a pure sinusoid, e.g., a square-wave forced oscillation function. In this case, the estimated frequency will be the fundamental frequency of the wave-form and the controller will address this frequency.

Step e) is executed by monitoring the output c of the suppression controller. Once the amplitude of c stays below a predetermined minimum threshold, the feedback controller is shut down. The frequency of the forced oscillation is monitored by the supervisor module20during the controller operation. If the frequency shifts is greater than 10% from the nominal, supervisor module20will shut down and then re-start at the new frequency.

In an alternate embodiment, supervisor module may also be configured to shut down the controller during major transient events.

The control method success requires that the system define the critical measurement y where suppression is desired. This involves three basic components including a) the measurement location within the grid; b) the type of measurement parameter, e.g., real-power or voltage magnitude; and c) the requirements of the measurement devices and communication system.

With respect to the location selection for measuring y, the power-system example described in greater detail below uses an interconnection point of a radial sub-system into a bulk grid. In such a case, the obvious critical measurement location is the interconnection point as the goal is to avoid inducing any forced oscillations into the bulk system from the radial system. Applying the method to other configurations such as a meshed network is possible; but defining the critical measurement location may be more complex. Any selection method must carefully consider the specific system's topology.

With respect to the type of measurement parameter type, the example focuses on suppressing a real-power oscillation because this case is common and most troublesome. Alternately, the method may also focus on suppressing forced oscillations in other measurable signal types, such as voltage magnitude and system frequency. The measurement system must be configured with a bandwidth, sampling rate, and reliability to accurately measure the forced oscillation in real-time.

Referring next toFIG.5, an exemplary radial sub-system500is shown. It is understood that sub-system500is one of many sub-systems that are interconnected through a bulk grid514which may cover multiple states and/or territories. Bulk grid514includes load buses dispersed throughout the bulk grid radial transmission system. The overall system includes thirty-five synchronous generators each represented using a sub-transient model, a turbine model, and a detailed excitation system. Sub-system500also includes two inverter-based power plants at buses167and169, each consisting of twenty IBR.

The portion of sub-system500shown inFIG.5is the radial interconnection point into the bulk system at bus164, The radial interconnect of sub-system500comprises a 400 MW gas-fired-turbine synchronous generator35connected at bus165.

20 IBRs512are connected at bus167. Each IBR in512has a maximum power rating of 3 MW. Another 20 IBR512are shown being connected to sub-system500at bus169. Ten of the IBR have a maximum power rating of 3 MW each and the remaining 10 have a maximum power rating of 1.5 MW each.

The real-power current injection of each IBR12(FIG.1) is represented mathematically inFIG.6by dynamic model600. Dynamic model600is consistent with a grid-following device. The parameters for each IBR12in the exemplary model600are Tpord=0.1 sec. for all units, as indicated in transfer function module602. Module602receives an input reference power PREFwhich is applied to transfer function module602and the output power value applied to a divider module604. At TV=0.05 sec. for all units, and at bus167: Tg=0.05 sec; at bus169: the voltage VTabsolute value is applied to transfer function module606to generate an output voltage value that is input to a second input of divider module604. Divider module604outputs a current command value Ipcmdat transfer function608wherein Tg=0.05 sec. for 3 MW units, 0.1 sec. for 1.5 MW units. Each transfer function module602,606,608equation multiplies the input value by 1/1+sTxwhere x corresponds with the relevant sampling time of the input signal.

A suppression control system is added to the IBR512connected to bus169using the exemplary configuration inFIG.4, having twenty devices wherein for Di, i=1, . . . ,20. The weights W are scaled according to the rating of each unit:
Wi=3/45 fori=1, . . . ,10  EQ. (17a)
Wi=1.5/45 fori=11, . . . ,20  EQ. (17b)

The key forced oscillation measurement location to suppress any forced oscillations is at the interconnection into the bulk system514at bus164. That is, the real-power flowing from bus165to bus164via an interconnecting transformer, therefore:y=P165-164=real power flow from bus165to164.

With fc=1 Hz, the resulting phase-lead controller, gain, and filter are characterized by equations (18a), (18b) and (18c), respectively, as follows:

Note that the exemplary design meets the minimum 6 dB gain margin and the 450 phase margin requirements. For Kc=11.7, a suppression gain of 0.079 (92% suppression) is expected.

While the exemplary embodiments illustrated in the figures and described herein are presently preferred, it should be understood that these embodiments are offered by way of example only. Accordingly, the present application is not limited to a particular embodiment, but extends to various modifications that nevertheless fall within the scope of the appended claims. The order or sequence of any processes or method steps may be varied or re-sequenced according to alternative embodiments.

The present application contemplates methods, systems and program products on any machine-readable media for accomplishing its operations. The embodiments of the present application may be implemented using an existing computer processors, or by a special purpose computer processor for an appropriate system, incorporated for this or another purpose or by a hardwired system.

It is important to note that the construction and arrangement of the adaptive controller for forced oscillation suppression, as shown in the various exemplary embodiments is illustrative only. Although only a few embodiments have been described in detail in this disclosure, those skilled in the art who review this disclosure will readily appreciate that many modifications are possible (e.g., variations in sizes, dimensions, structures, shapes and proportions of the various elements, values of parameters, mounting arrangements, use of materials, colors, orientations, etc.) without materially departing from the novel teachings and advantages of the subject matter recited in the claims. For example, elements shown as integrally formed may be constructed of multiple parts or elements, the position of elements may be reversed or otherwise varied, and the nature or number of discrete elements or positions may be altered or varied. Accordingly, all such modifications are intended to be included within the scope of the present application. The order or sequence of any process or method steps may be varied or re-sequenced according to alternative embodiments. In the claims, any means-plus-function clause is intended to cover the structures described herein as performing the recited function and not only structural equivalents but also equivalent structures. Other substitutions, modifications, changes and omissions may be made in the design, operating conditions and arrangement of the exemplary embodiments without departing from the scope of the present application.

It should be noted that although the figures herein may show a specific order of method steps, it is understood that the order of these steps may differ from what is depicted. Also, two or more steps may be performed concurrently or with partial concurrence. Such variation will depend on the software and hardware systems chosen and on designer choice. It is understood that all such variations are within the scope of the application. Likewise, software implementations could be accomplished with standard programming techniques with rule based logic and other logic to accomplish the various connection steps, processing steps, comparison steps and decision steps.