research performance progress report (rppr-1)

DE-EE0007166 Commonwealth Edison Company (ComEd)

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Research Performance Progress Report (RPPR-1)

a. Federal Agency Department of Energy

b. Award Number DE-EE0007166

c. Project Title Microgrid-Integrated Solar-Storage Technology (MISST)

d. Principal Investigator

Shay Bahramirad

VP of Engineering and Smart Grid

[email protected]

e. Business Contact

Jeffrey Simcox

Assistant General Counsel

[email protected]

f. Submission Date 1/15/2020

g. DUNS Number 006929509

h. Recipient Organization Commonwealth Edison Company (ComEd)

i. Project Period Start: 01/01/2017 End: 6/30/2020

j. Reporting Period Start: 10/01/2019 End: 12/31/2019

k. Report Term or Frequency Quarterly

l. Submitting Official Signature

Exhibit A (PUBLIC)ComEd Phase I ReportPage 1 of 20


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Major Goals & Objectives:

The proposed technology, referred to as Microgrid-Integrated Solar-Storage Technology (MISST), will address availability and variability issues inherent in the solar photovoltaic (PV) technology by utilizing smart inverters for PV/BESS and working synergistically with other components within a community microgrid. MISST represents an enabling technology for the widespread sustainable deployment of low-cost, flexible, and reliable PV generation, and provides for successful integration of PV power plants with the electricity grid.

Project Results and Discussion:

Task 7: Development of the Microgrid Master Controller (MMC)

BP-3 Due M7.1 / Q2-2020 Percent Complete: 75%

Subtask 7.1: Functional specification, design and development • Deliverables: Set of functional, design and interface documents

Subtask 7.2: MMC System configuration, Test plans development and Factory Acceptance Test

• Deliverables: (a) Develop and setup MMC environments for BCM, such as:

Production Main server, Production Redundant Server, Quality Assurance Server; (b)

Factory Acceptance Test (FAT) plan; (c) FAT test results

Subtask 7.3: Field test plan development and Field test (Site Acceptance Test) • Deliverables: (a) MMC field configuration system; (b) Field test plan (SAT) document;

SAT results document

In this quarter, the team continued implementation of various Microgrid Management System (MGMS) functionalities and FAT testing. Several documents were released, and test reports have been created. Details follow.

New product documentation:

a. Spectrum Power 7 Microgrid Management System: Functional Specification, Document FS-MGMS-EN, Revision 2.2.1.0

b. Spectrum Power 7 Microgrid Management System: User Guide, Document UG-MGMS-EN, Revision 2.2.1.0

The Spectrum Power 7 Microgrid Management System provides all essential functionality to conduct energy management and control of a microgrid. The following core MGMS Functional Specifications are described in this document:

• Sequence of Operations (SOO)

• Generation Management (GM)

o Generation Control

o Reserve Monitoring

o Microgrid Optimization



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o Microgrid Clustering

o Solar PV-Energy Storage Coordination

o Automatic VAR Control

• Microgrid scheduler

• Energy tariff module

• Short Term Load Forecast (STLF)

• Generation Forecast Management (GFM)

• Current Operating Plan (COP)

• Weather Forecast Service Interface

• Distribution State Estimator and Power Flow

The User Guide Document addresses all relevant information related to use of BCM MGMS software, including Main Toolbar with icons, Heads up display, MGMS dashboard, Network diagram, alarm summaries, microgrid overview display, microgrid scheduler, microgrid optimization module, current operating plan, historical information system, generation control, microgrid clustering interface, microgrid management system power flow, and weather forecast interface.

Below is an example of the Navigation Menu and MGMS dashboard:

Figure 1. Navigation menu

Design of the BCM MGMS system is described in the updated design document:

a. Bronzeville Community Microgrid Phase-2 MGMS Design Document, Draft V6.1

The MGMS Design Document addresses design requirement for management of the BCM. The product design will be rigorously tested both via Factory Acceptance Testing (FAT) at Siemens, testing in ComEd’s Grid Integration and Technology lab in Control HIL



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environment (SAT RTDS testing, see Task 10 for more details), as well as on the field, as part of BCM commissioning.

Figure 2. MGMS dashboard

In addition, an updated draft of Interface design document has been prepared:

b. Bronzeville Community Microgrid Phase-2 MGMS Interface Design Document, Draft v3

Figure 3. Laboratory test setup

This document describes MGMS interface with numerous components of the BCM system, including BESS, Solar PV, Weather Station, Controllable Generation, Intellirupter (IR) devices, Protection Relays and VISTA switches, ABB EMS NNR4 system,



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SolarAnywhere, OSISoft PI Historian, IIT MMC controller, and Voltage Optimization (VO) system.

Also, a test plan for interface testing was described in this document, including the Grid Integration and Technology lab testing (see Figure 9)

In this reporting period the team completed testing of Distribution Power Flow and State Estimator functionality and it is described in the following document:

c. Spectrum Power 7 MGMS - DNA Distribution Power Flow and State Estimator, Test Book, Document TB-MGMS-DNA-DSSE-EN, V2.21

The test book is accompanied with three use cases and the corresponding test results that can be provided upon request.

d. Three test scenarios and test results for the Distribution Power Flow and State Estimator

In addition, a range of functionalities of the MGMS software has been tested and documented, as part of FAT. This information is also available upon request.

A very large portion of SAT testing is planned to be done in the Grid Integration and Technology RTDS lab in Maywood. The test plan draft has been prepared and is being finalized based on the feedback from the project stakeholders. More details about this are provided as part of Task 10.

Other aspects of the Task 7 were provided in the Q3 status report.

Task 8: Electrical System integration (ESI)


Subtask 8.1: System Integration plan and requirements. Set of activities to ensure proper interface of all microgrid assets (such as DERs, switches, load, and microgrid controller). The communication system architecture and characteristics in terms of the speed of response, possible latency requirements to accommodate needed amount of critical data needed for realization of microgrid control and protection. • Deliverables: System integration plan

Subtask 8.2: System Engineering. Addressing various aspects of engineering design for the equipment installation, system protection settings, controls and interconnection of the DERs to the microgrid. Preparation of user documentation and training of ComEd personnel • Deliverables: Design documents, drawings, procedures, user documentation

Subtask 8.3: System modeling and Studies needed to be performed at each interconnection point with the area electric power system (EPS), as well as at interconnection point with IIT and interconnection points of local DER units with the microgrid to the area EPS.

• Deliverables: List of study requirements and study results



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Subtask 8.4: Test and commissioning – developing end-to-end integration testing and commissioning requirements and its execution. It includes integration and validation of MG controller functionalities and interface with MG controllable assets, dispatching schemes of DERs and controllable load, MG controller interfaces with ComEd SCADA and operations monitoring and controls.

• Deliverables: Operation sequences, commissioning plans for integration of MMC,

DER assets, generation

The project team has been working on the subtasks 8.1 – 8.3 for system integration, engineering and studies. Large volume of documents has been created or planned to be created for the purpose of BCM System Integration. Figure 4 shows the mapping between document numbers and different components of the BCM system. The documents are working in progress and will be shared with DOE once completed.

Figure 4. Mapping between the BCM System components and document numbers

The status of the documentation is shown in the table below:



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Table 1. List of project documentation and readiness status.

Documentation is available to DOE upon request.

Status Name Version

MGMS_RTDS_Testing_Procedures Draft 3.2

MGMS sequence of switching Draft 2.1

BCM LM BESS Grid Forming Test Plan (field) V1.2

Ph1-Planned Island-Test-procedure Draft 2.1

Draft 2.2

DER transformer neutral grounding design Draft 2.0

BCM-Protection Studies Draft 5

Draft 6

Sequence of Operations Draft 4.1

Draft 4.2

BCM Requirements Design and Operation Guide V0.4

BESS Grid Forming Test Plan (lab) V1.4

SMA Inverter Lab Testing Draft 2

Estimate of effort to complete project As of 06-27

Grid Forming (grounding of BESS) Draft 1

Renewable Firming Result Draft 2.1

BCM LM BESS Grid Forming Test Plan (field) V1.1

PV Cabinet Design As of 07-12


Ph1-Planned Island-Test-procedure Draft 2.1

BCM-Implementation Guide Outline Initial response

SCADA Points List As of 08-27

BCM Trip Event & BESS Protection Settings Review Draft 1


MGMS sequence of switching (renamed from BCM

protection SOO)Draft 1.0

MGMS sequence of switching (renamed from BCM

protection SOO)Draft 1.1


MGMS sequence of switching Draft 2

BCM_MGMS_Design V6 Draft

BCM device to device communication paths

BCM_MGMS_Design V2 Draft

BCM_MGMS_interface_Design V2 Draft

Design doc – Solar PV – BESS Coordination V3

Design doc – Microgrid Clustering V4

Design doc – Distribution power flow and state

estimation in MGMSV2

BCM IT-TR Design Review Document V12

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Task 9: IT System Integration (ITSI) – communications and cybersecurity


Subtask 9.1: Develop and manage IT schedule for the application system integration and network communication scopes. • Deliverables: (a) IT System Integration (SI) & network communication workstream

project plan; (b) (Scope) change management plan; (c) SI & network communication

workstream project schedule; (d) Risk management plan; (e) Cut-over / Go-live plan

Subtask 9.2: IT system requirements development. Prepare Microgrid IT networking infrastructure requirements and communication network requirements, including:

- Network communications requirements

- Real Time systems requirements

- Security requirements (network and system)

• Deliverable: Network communications requirements; Infrastructure requirements document; System overview document; IT Communications Requirements Document.

Subtask 9.3: IT Integration design specifications development. Development of additional 3rd party software and hardware specifications. Develop detailed system integration, network and data-flow diagrams. Develop and deliver detailed software, system integration functional and technical design. Design end user application access mechanism.

• Deliverables: SI, network and data-flow diagrams; Detailed SI technical design; End-

user application access design

Subtask 9.4: Cybersecurity planning and execution. Adhering to ComEd cybersecurity guidelines, complete the following: - Lead, design and deliver ComEd access scheme to 3rd party owned microgrid components (PV, controllable generation). - Lead, design and deliver ComEd access scheme to 3rd party owned microgrid components (PV, controllable generation). - Implementing network connectivity to microgrid components making sure that the network implementation complies with ComEd cyber security guidelines

• Deliverables: Cybersecurity test plan with test criteria

The team prepared an IT test strategy document draft that is being reviewed by the stakeholders:

a. Bronzeville Community Microgrid IT Test Strategy, Version 1.0

This IT Test Strategy outlines key elements of the Bronzeville Community Microgrid (BCM) IT testing methodology to help guide the BCM testing team through each phase of testing. The goal of the Test Strategy is to ensure that the MGMS, supporting



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applications and field devices are delivered per design specifications, meet established quality criteria and perform as expected.

The Test Strategy describes the testing portion of the software development lifecycle (SDLC). It informs the project team about the testing process, which includes the testing objective, methods of testing new functions, high-level timelines, resources requirements, and policies and processes for conducting various testing activities.

This Test Strategy covers testing policies and processes to support the various BCM project test types and phases. It primarily addresses BCM testing that involves IT Real Time (IT RT) testing, and also captures other BCM testing to provide a complete picture of BCM end-to-end testing.

The BCM testing process is designed to ensure all BCM hardware and software systems operate as intended, including interfaces to field devices and enterprise systems. Given the need for BCM systems to island specific loads within the BCM footprint and serve those loads during a primary grid outage, the testing approach must provide a capability to evaluate all functional capabilities that cannot be tested with traditional real-time testing environments and processes. Specifically, typical system and integration testing methods cannot support the need to test Microgrid Management System (MGMS) functionalities and use cases that would actuate grid devices. Therefore, ComEd is leveraging a hardware-in-the-loop (HIL) system at its Grid Integration and Technology lab to simulate grid conditions and test MGMS functional capabilities that cannot be tested elsewhere without impacting grid operations.

The figure below depicts the schedule of expected system patches and how that impacts the testing schedule:

Figure 5. Test execution process

The BCM Testing phases are orchestrated to begin with discrete functionality testing and progress through to end-to-end business scenario testing. Progression of BCM testing phases is depicted in the figure below:



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Figure 6. Testing Phases

In addition, the following two documents have been created from the last reporting period:

b. Bronzeville Community Microgrid IT-Network Communication Design, v1.0 (Baseline)

This document defines the high-level and detailed design of the Exelon BSC IT-Utility of the Future / UCOMM solutions in support of ComEd’s Bronzeville Community Microgrid (BCM). Current and future high-level network architecture from this document are shown in Figure 7 and Figure 8 below.

Figure 7. High-level Network Architecture

Key properties of current state (pre-BCM) network architecture:

• MPLS Network running over various types of cabling infrastructure (

).

• Routers installed in substation and data centers.

• serving as Interior Gateway Protocol (IGP)

• .

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•

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• .

•

.

•

Figure 8. BCM network architecture – future state

Key properties of BCM network architecture:

• Extension of Smart Grid network, including Fiber and DWDM resources, into

Chicago’s Bronzeville Area.

• Goal is to connect Field Area Network (FAN) devices to fiber network to improve

reliability and performance metrics.

• Will leverage Routers installed in FAN network and designation

enclosed sites (Battery Energy Storage Site (BESS), Photovoltaic site (PV)

• Currently used and supporting protocols extended into

Bronzeville area in support of these performance and reliability objective.

This document also provides other network architecture aspects, including Physical design, Logical design, and Fiber optic design. It updates the document provided in the Q3 period:

c. Bronzeville Community Microgrid IT Design

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Task 10: Hardware-in-The-Loop (HIL) testing of the MMC and Microgrid


• Deliverable: (a) A detailed BCM RTDS model; (b) RTDS test plan document.

• Milestone: Finalized tests as per the test plan.

The MMC RTDS lab testing for Bronzeville Community Microgrid (BCM) aims to achieve a comprehensive testing of the functionalities of the Siemens MGMS microgrid controller together with different hardware through hardware in the loop test via RTDS. Work includes designing and integrating different components of the testbed and test plan. The RTDS models of BCM have been developed to emulate different operational scenarios of the microgrid for testing purposes.

The tests are designed to verify: A. MGMS interface with the field control devices, including DER controllers,

protection and control (P&C) devices, DA switches, circuit breakers, and capacitor controllers on the BCM feeder.

B. Interface between MGMS and a representative of OCC control and monitoring (SCADA Emulator).

C. Execution of the microgrid sequence of operation by MGMS.

A detailed model of the BCM and draft RTDS Test Plan have been developed and reviewed internally by the project team and other relevant stakeholders.

While the complete power circuit of the BCM is modeled in RTDS, a selected number of control hardware devices are proposed to be integrated and used as part of the test setup in a hardware-in-the-loop manner. This testing approach is referred to as Controller Hardware-in-Loop (CHIL) in the literature and standards. The rest of Protection & Control devices and distribution switchgears are simulated inside the RTDS model. Models of Distributed Energy Resources (DERs) of the BCM along with load profiles and solar radiation profiles are also included in the RTDS real-time simulation model.

Figure 9 illustrates hardware control devices in the MGMS test setup, as well as the MGMS itself, which is being tested in the laboratory environment before field commissioning. Designed to emulate the real field setup as closely as possible, the laboratory setup includes multiple control devices that representing devices that will communicate and interact with MGMS in BCM. Other components are simulated in RTDS along with the power system network model to complete the setup. MGMS talks with all the devices downstream using . These downstream devices include site controller for BESS, PV and DER, breaker controllers, capacitor bank controllers as well as SCADA emulator.

CEII - Critical Energy/Electric Infrastructure Information



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Figure 9. MGMS RTDS Test System Setup Components and Connections

The BCM will be operated by Siemens MGMS as described in the sequence of operations (SOO) document. We are developing different operational scenarios and implementing them into sequence of operations. The BCM sequence of operations document details the checks and actions to be performed as the system transits from grid-connected to islanded mode of operation and vice versa.

The test set up and testing procedure are detailed in the “BCM_MGMS_RTDS_Testing_Procedures_Draft” document. The document has been updated and has been reviewed with the project stakeholders. It is expected that the RTDS tests will start in Q1 2020.

RTDS Model

The model of Bronzeville Community Microgrid (BCM) is developed in RTDS to simulate and capture the dynamic response of the grid under various operating scenarios. BCM model includes two ComEd feeders within BCM boundary and are termed subsystem 1 (SS1) and subsystem 2 (SS2) and are separated by three inter-tie switches. SS1 serves 2.5 MW of total load and SS2 serves 4.5 MW of total load. SS1 also includes 0.5MW 2 MWh battery energy storage system (BESS), 0.75 MW solar photovoltaics (PV). A controllable DER will be installed in the feeder to enable operation of the feeder in different modes of operation even when the main grid is not available.

Figure 10 shows the snapshot of feeder SS2 in BCM. A snapshot of feeder SS1 is shown in Figure 11. POI of the switch can be opened to isolate this feeder from the main grid and operate in islanded microgrid mode.

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Figure 10. Snapshot of SS2 of BCM model in RTDS

Figure 11. Snapshot of SS1 of BCM model in RTDS

Control Hardware and Interfacing with RTDS

The control or power hardware can be interfaced with the rest of the system simulated in RTDS by appropriately interfacing the RTDS simulator and the hardware under test

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(HUT). Control hardware can vary from a low-level monitoring and control devices, such as an automation controller and protective relays to high level supervisory controllers including SCADA and MGMS. RTDS provides interfaces to exchange signals with these control devices via conventional analogue and digital I/O as well as communication-based I/O . Figure 12 shows the interface for ModbusTCP communication developed in RTDS to communicate with BESS RTAC. It shows inputs and outputs in both binary and analog form.

Figure 12. ModbusTCP interface in RTDS for BESS RTAC

The individual control hardware interfaces have been developed and tested. The RTDS model and interfaces are ready for testing with MGMS in the next quarter.

Task 11: Preliminary testing of BCM Islanding


Subtask 11.1: Planned Islanding testing

• Milestone: Successful Planned Islanding Test.

As mentioned in the previous Q3 period report, planned island test is aimed to demonstrate the Microgrid-Integrated Solar Storage Technology (MISST) in a standalone island mode to ensure that a seamless planned island transition to a stable islanded area can be achieved. There will be two parts to the test. A dry run of the test (preparation tests) will be performed at the Maywood facility to verify control schemes of the site Real-Time Automatic Controller (RTAC) and those of a diesel genset, and to ensure the selected diesel genset has the proper controls to regulate voltage and frequency to follow the load changes, when the main grid is isolated. The final test execution will be performed on feeder.

The proposed tests are planned to be performed using an RTAC at the BESS site located in the BESS control and monitoring cabinet, as shown in Figure 13.

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Figure 13. Schematic diagram of the Phase 1 test system

In preparation for this activity, Emulated Planned Islanding was completed earlier this year and the results were provided in the Q2 report. The team developed a draft of Planned Islanding Test Plan that has been circulated to various stakeholders for review and feedback. The test plan will be updated before the start of the tests.

In this quarter, main activities included those related to preparation and setup of the Grid Integration and Technology lab in Maywood, where the first part of the testing will be done. Further Planned Islanding Testing activities are scheduled to resume in Q1 2020.

Task 12: Collect Data and Conduct Analyses (Operation)

BP-3 Due M12 / Q2-2020 Percent Complete: 55%

• Deliverable: Collect operational data.

• Deliverable: Measured and/or calculated performance metrics of the MISST solution.

• Deliverable: One submitted technical report and paper documenting lessons learned and recommended methodologies, processes and considerations for practical implementation and scaling up for high power applications of similar solutions.

• Milestone: Performance metrics are quantified for at least one year after deployment of MISST solution, lessons learned and scaling up methodologies,

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processes and considerations are documented and disseminated via conference presentations and online publication of technical report and paper.

Subtask 12.1: Collect operational data

Subtask 12.2: Analyze operational data and report results

Based on the new operational data collected, the project team is conducting data analysis for selected metrics related to the PV and BESS. A portion of the analysis has been completed and is presented here to verify that the metrics requirements are being met. More results from the data analysis will be reported in the future quarterly report.

Solar PV power level

The success value for this metric is solar capacity ≥ 0.58 MW. BCM hosts 0.734 MW of solar PV.

BESS power level

The success value for this metric is set to be BESS power capacity ≥ 0.5 MW. The battery installed in the BCM has a capacity of 500 kW/2000 kWh.

BESS frequency control deviation

The success value for this metric is considered to be ±0.5 Hz (frequency between the range 59.5 Hz-60.5 Hz). To evaluate this metric, frequency data from the datalogger from 06/19/2019 to 12/02/2019 is utilized and plotted in a histogram as shown below. The frequency data for datalogger has a resolution of 5s. The frequency was within the success range.

Figure 14. Histogram of datalogger frequency data for BESS datalogger



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BESS voltage control deviation

The success value for this metric is ± 5% of the nominal voltage (277 V). In this case, the allowable limit would be (263.15, 290.85). To evaluate this metric, BESS voltage magnitude with a resolution of 5s from 09/20/2019 to 12/02/2019 is employed. The distribution of data associated with BESS voltage control deviation is shown using a histogram. The voltage was within the success range.

Figure 15. Histogram of datalogger voltage data for BESS voltage

Penetration level

The equation below is utilized to calculate the penetration level.

𝑃𝑒𝑛𝑒𝑡𝑟𝑎𝑡𝑖𝑜𝑛 𝑙𝑒𝑣𝑒𝑙 (%) =𝑃𝑃𝑉,𝑚𝑎𝑥

𝑃𝐿𝑜𝑎𝑑,𝑝𝑒𝑎𝑘∗ 100

Where PPV,max and PLoad,Peak are maximum PV power and peak load power, respectively. The success value for this metric is 20% to 35%.

Considering that the capacity of installed PV is 734 kW AC and peak load at that feeder is 2.5MW, the penetration level is:

734

2500∗ 100 = 29.36%

Subtask 12.3: Documentation and dissemination of lessons learned

The project team is documenting sharing the technology developed as part of the project as well as the testing and analysis results with the industry.

1 project paper has been submitted to the CIGRE Session 2020:



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• S.R. Kothandaraman, N. Gurung, L. Zhang, Using a Real Time Digital Simulator to Test a Microgrid Integrated Solar Storage Technology.

3 project papers were presented at the CIGRE US National Committee 2019 Grid of the Future Symposium:

• M. Bazrafshan, A. Majzoobi, et al., Successful Site Acceptance Tests for Microgrid-Integrated Battery Energy Storage.

• A. Majzoobi, M. Bazrafshan, et al., Site Acceptance Test for Solar PV System of Bronzeville Community Microgrid.

• M. Bazrafshan, A. Majzoobi, et al., Simulated Islanding Test for a Practical Utility-Scale Microgrid.

1 panel presentation at the PowerGen International 2019 conference:

• N. Gurung, H. Chen, The Bronzeville Community Microgrid.

Plans for Next Reporting Period:

Next reporting period will continue addressing the status of the activities related to project PB3 activities, as described in Tasks 7, 8, 9, 10, 11 and 12 of the SOPO.

Task 7: Development of the Microgrid Master Controller (MMC)

Continuation of implementation of MGMS and testing of its components in the factory setup.

Task 8: Electrical System integration (ESI)

Continuation of development of project documentation and studies, and updating the existing documents based on reviews from the team.

Task 9: IT System Integration (ITSI) – communications and cybersecurity

Continuation of development of project documentation and studies, and updating the existing documents based on reviews from the team.

Task 10: Hardware-in-The-Loop (HIL) testing of the MMC and Microgrid

Initial test plan draft has been prepared. The final test plan will be finalized, and the tests will commence in the next reporting period.

Task 11: Preliminary testing of BCM Islanding

Planned Islanding Testing activities are scheduled to resume in Q1 2020.



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Task 12: Collect Data and Conduct Analyses (Operation)

The team will continue collecting and processing the data for the scope of subtask 12.1 and 12.2. The team will start documenting and disseminating lessons learned, recommended processes and methodology to scale up, interconnect and approve the solution (by utilities) from low to high power applications, for the scope of subtask 12.3 and 12.4, via technical conference/journal papers and/or technical reports.

Changes/Problems:

No changes/problems since last report.

Products:

No new products have been developed.

Special Reporting Requirements:

No special reporting requirements are needed at this time.


research performance progress report (rppr-1)

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