Getting Started with Advanced Network Operations

Getting Started with Advanced Network OperationsA fastrack DMS solution for distribution management

Make the most of your energySM

Summary

Executive Summary .................................................................................... p 1

Introduction ................................................................................................ p 2

Why a fastrack DMS? .................................................................................. p 4

Build ........................................................................................................... p 6

Learn .......................................................................................................... p 7

Plan ............................................................................................................ p 8

Execute ....................................................................................................... p 9

Move at the ‘speed of value’ ....................................................................... p 10

Conclusion .................................................................................................. p 11

Executive summary

Getting Started with Advanced Network Operations

White paper | 01

While many utilities look forward to the benefits of deploying smart grid

technology, they need help on where and how to start. A manageable distribution

management system (DMS) pilot implementation is a good kickoff toward the

smart grid goal, because it successfully demonstrates the possibilities while it

builds support from stakeholders across the enterprise. Schneider Electric helps

the utility implement the DMS pilot, using a phased Build — Learn — Plan —

Execute approach.

In such a DMS pilot project, the company works with a small team of utility

personnel knowledgeable of the organization’s network data stores and analytical

functions. They build a fully operational load flow model that represents a subset

of the network and reflects circuit data from the GIS database or other sources

and includes two HV/MV substations and four to eight feeders, ideally with the

switches and enough load profile data to support some switching and basic

optimization functionality.

In the Learn phase of the DMS pilot, team members evaluate functionality of the

model and completeness and accuracy of the data used. Tuning the model builds

team confidence in its understanding of the data needed and the accuracy of the

basic DMS algorithms.

In the Plan phase, the utility identifies current business plan and internal and

external drivers toward grid automation, considering throughout the political and

regulatory environments. A strategy is designed to remove obstacles and achieve

identified goals.

In the final Execute phase, the utility will contract for software and services; train

core team; develop system configuration and convert data; and finally deploy the

system with site acceptance testing and rollout.

This fastrack DMS implementation gets the utility started and moving at the ‘speed

of value’ as it builds confidence in DMS technology. It offers a proof-of-concept of

DMS benefits across the organization — more reliable service, reduction of peak

demand, utility cost savings and more.

Introduction

White paper | 02


Smart Grid technology offers a large and often confusing array of components

and solutions that promise potential benefits for stakeholders. Making the right

choices in this environment isn’t easy. Focusing on critical areas for improving

grid performance is one key to achieving the best results. One emerging trend in

the industry is to develop strategies that better control and optimize distribution

network operations with advanced distribution management systems (DMS) and

to start with a “proof of concept” (POC) approach.

‘Pilot’ projects can pose challenges for many utilities. How to start? How to

avoid the perception of yet another small-scale Smart Grid effort that won’t lead

to tangible benefits? This paper will address the benefits, issues, and internal

buy-ins necessary to start a pilot project, and will provide a project approach

to achieve success and position the utility organization for a full solution

evaluation.


White paper | 04

Why a fastrack DMS?

Many utilities are stymied by the enormity of

implementing a full Smart Grid with the issues of

network reinforcement, device assessment, algorithm

investigation, production or project software,

integration within OT and IT environments, and many

more issues that need to be addressed. To gain

the benefits that are associated with implementing

Smart Grid initiatives, “you have to start somewhere”.

Implementing a manageable pilot can not only

successfully demonstrate the possibilities, but

provide enormous support for building internal

utility momentum with stake holders, managers,

employees, and regulators.

At Schneider Electric, we often work with customers

to implement a DMS pilot over a three to four month

period through a four phase approach (Build —

Learn — Plan — Execute):

• Build —

- Install DMS software on a laptop

- Build the network model utilizing the utility’s GIS

or engineering analysis data

- Add missing electrical data (typical consumer load

profiles, standard transformer characteristics,

other typical equipment data)

• Learn —

- Learn just what specific data is missing in the

currently available network model

- Investigate the location and quality of the missing

data within the current utility data stores

- Assess steps that will be necessary to maintain a

“timely and accurate” network model to support

an operational DMS

- Investigate what can be achieved through

systems integration and what can be acquired

through bulk import or manual data loads

• Plan —

- Develop a ranking of analytic functions and their

benefit to the utility (i.e. switching orders, FLISR,

VVO, Voltage Reduction, Load Shedding, etc.)

- Develop a plan for identifying data sources and

methods for accurately maintaining those sources

- Develop an organizational communications

plan utilizing the POC laptop for “show and tell”

meetings


White paper | 05

• Execute —

- Contract for software and services

> Specify requirements

> Identify delivery and support services

- Design

> Train core team

> Review requirements

- Develop

> Data conversion

> System configuration

- Deploy

> Site acceptance testing

> Production roll out

To successfully achieve the benefits of a DMS POC,

we recommend putting together a small team of key

personnel within the organization that can address

the three main areas of emphasis; assessing data,

evaluating engineering analytics, and gaining internal

management support. To assess the data needs, we

recommend a high energy, self-starter individual that

can diligently dig deep into the internal data stores

of the utility and find those “nuggets” of information.

An innovative engineer thoroughly schooled in

distribution planning and operations should be able

to analyze the appropriateness of various analytical

functions and their benefit to the organization. And of

course, there is the need to have a mid-level or higher

manager that can champion the project to upper

management, various stake holder organizations, and

the regulators.

Build

Design

Develop

Deploy

Learn

Execute

Plan


White paper | 06

Build

At the heart of all DMS implementations is a

sufficiently accurate load flow model. To achieve this

goal, data must not only be complete, but “timely

and accurate.” Electrical network data for distribution

planning and analysis is usually updated only yearly

and includes only peak load information. To properly

build an operational DMS model, the “current”

state of the distribution network must be accurately

modeled. In an operational DMS, the network

model is usually imported from the GIS (keeper of

the “as-built” model) into the DMS (keeper of the

“as-operated” model. Electrical catalog information

not maintained within the GIS is added from other

data sources to complete the DMS electrical network

model. Typical consumer load curves are usually

obtained from regulator rate filing information;

however, with the advent of AMI/MDM systems, finer

granularity of consumer load profile data may be

available.

For the POC, it is not possible to obtain all of the

aforementioned data; therefore, a subset of the

network is used with typical electrical catalog and

typical consumer data added.

• POC Scope

- Two HV/MV substations

- Four to eight feeders

- Ideally sum of the feeders connect with tie

switches

- Does not have to be “end state” data sources (i.e.

no automated integration)

• Build phase

- Draw substation 1-line connectivity model

- Import feeders from electrical connectivity model

data source

- Add several typical consumer load profiles (i.e.

residential, small commercial, large commercial,

industrial)

• Data Sources

- Substations — CAR files, SCADA 1-lines, paper

drawings, equipment records

- Feeders — GIS, SynerGEE, CYME, WindMill,

paper maps, equipment records

- Load profiles — AMI/MDM histories, load survey

data, engineering judgment

Figure above. Typical Consumer Load Profile Curves


White paper | 07

Learn

The purpose this phase is to capture the lessons

learned during the Build phase. With the DMS

installed on a laptop and the small portion of the

network verified and now a working electrical model,

the team can begin to compare load flow results

against field measurements. Where distribution

SCADA exists, the team can input telemetered values

from the SCADA 1-line displays and compare the

load flow results. Immediate verification of model

accuracy will become evident. If an electrical element

is modeled in error, load flow results will not match.

This is where the electrical engineering and utility

experience comes into play. Since the DMS provides

all electrical quantities (i.e. volts, amps, real/reactive

power, etc.) for every element in the network, it

should be fairly easy to investigate the circuit and

find the offending element. If errors exist, there is one

of two possible problems — bad field measurements,

or bad modeling. Tuning the model will build

confidence within the team of their understanding of

the data required and the accuracy of the basic DMS

algorithms. Accumulating results of this investigative

effort will be useful input to any planning for

implementing an operational network model.

After the model is producing good results, the DMS

analytical functions can be used to demonstrate the

positive effects that implementation of the DMS could

bring the utility. Learn what it takes to construct a

useful DMS model and:

• Identify data deficiencies

• Perform DMS functions and rank analytic

functions

• Topology/Connectivity Analysis

• State Estimation

• Voltage Reduction (VVO/VVC)

• Improve efficiency of the distribution network

• Define requirements and validate business needs

• Build organization confidence and consensus

Figure above. Geographic and Schematic Views of Network


White paper | 08

Plan

The key to any successful Smart Grid implementation

project is having a well thought out and tested

plan. Using the lessons learned from the previous

phase as a micro implementation, areas needing

further investigation can be identified. Stake holder

feedback from taking the POC laptop throughout

the organization should provide valuable insight into

obstacles that will need to be overcome before any

project implementation can begin.

Analyzing the current business situation is a must.

Internal and external drivers toward a Smart Grid

along with the political and regulatory environment

must be considered. A good plan will identify all of

these elements and provide a strategy for removing

obstacles and achieving goals.

One key item often overlooked is developing a

strategic vision of utility operations in the next five

to 10 years. Forgetting to plan long range can

result in solutions being implemented that meet

current targets, but are inadequate for future

utility operations. One particular area of emphasis

should be on having a robust, secure, and scalable

distribution SCADA infrastructure. Current utility

SCADA systems can adequately handle present

telemetry needs for several hundred substation

RTUs, but they cannot handle the demands of a

fully automated and telemetered smart distribution

network with tens of thousands of field devices (i.e.

switches, controllers, and sensors).

“As-is” and “to-be” processes should also

be mapped out at a very high level to identify

opportunities for improvement. A gap analysis of

current state versus future state will reveal areas

that need further investigation. Business process

re-engineering will be critical to ensuring all of the

identified benefits are achieved and the return on

investment maximized. Also of consideration is the

development of a strategy to ensure the organization

can achieve future goals.

Plan for executing Smart Grid projects• Assess internal and external drivers for grid

automation

- Balance of supply and load

- System efficiency

- Operations reliability

• Evaluate internal resources

• Develop business case metrics for a DMS system

• Plan for complete DMS deployment, including

change management


White paper | 09

Execute

The last stage is Execute. At this point the Utility is

now positioned to act on the information gathered

from the Build - Learn - Plan phases. Typically an

Execution plan looks like the following:

• Contract for software and services

- Specify requirements

- Identify delivery and support services

• Design

- Train core team

- Review requirements

• Develop

- Data conversion

- System configuration

• Deploy

- Site acceptance testing

- Production roll out

Build

Design

Develop

Deploy

Learn

Execute

Plan


White paper | 10

Move at the ‘speed of value’

Schneider Electric is an industry leader in open-

architecture solutions that allow full integration

with existing and future standardized information

systems, ‘future-proofing’ its deliverables. Utilizing

the existing GIS connectivity model, the fastrack

DMS can leverage existing investments and help

validate network model accuracy. The more accurate

the network model, the better your utility identifies

operational and economic goals and develops a

realistic and effective Smart Grid strategy to realize

those goals.

Conclusion

White paper | 11


Utilities can take the first step toward achieving the benefits of DMS by

implementing a proof-of-concept DMS pilot project. This pilot will help the

utility identify data requirements and resources needed, as well as demonstrate

operational and economic benefits and build ‘buy-in’ from stakeholders.

A four-phased approach to carrying out this pilot — including creation of an ‘as

operated’ model of a subset of the network — has shown to help utilities put

network data and analysis functions to work to realize automated control and

performance optimization. Schneider Electric has helped utilities worldwide get

started with DMS technology to deliver better service to their customers and

improve overall operations efficiency and reliability.

Schneider Electric USA, Inc.

4701 Royal Vista CircleFort Collins, CO 80528Phone: 1-866-537-1091 + (34) 9-17-14-70-02Fax: 1-970-223-5577www.schneider-electric.com/us

June 2012

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Getting Started with Advanced Network Operations

Technology

Transcript of Getting Started with Advanced Network Operations