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IEEE San Francisco Power Engineering Society

DG Fundamentals Workshop October 18, 2003

Registration 8:00 AM

1. Introductory Remarks 8:15 AM

2. DG Principles –Mechanical systems Brian Sekula (Altran) 8:30 AM • Renewable types

• PV module orientation, shading & insolation level • Wind turbine • Small hydro

• Fuel types • Fuel Cell • Combustion Turbines

• Conventional gas turbine • Micro-turbine

• Steam turbines • Reciprocating Engine

3. DG Principles – Electrical systems Prof. Liou (SFSU) 9:00 AM

• PV cell & module • Induction Generator • Synchronous Generator • Inverters • Electrical characteristics of the above devices

• Fault duty • Voltage and frequency regulation capability

4. Distribution System Characteristics – Willie Chew (PG&E Dist. Planning) 9:30 AM

• Radial Configuration • Protection • Voltage Regulation

• Network Configuration • Protection • Voltage Regulation

• Typical Load Profile • Typical distribution system load and fault capabilities

Break 10:30 AM

IEEE San Francisco Power Engineering Society DG Fundamentals Workshop

October 18, 2003 (continued)

5. Typical DG systems & DG applications – Gary Olson (Cummins) 10:45 AM • Typical sizes/configurations/costs

• $/kW installed • $/kWH

• Emission level & air quality restrictions • Stand-alone/Standby/Parallel/utility-interactive/certified/load management • Generator/facility Protection • Considerations for one or more generator operations

• Voltage Regulation • Frequency Regulation • Load Sharing/following/shedding

Lunch 12:15 PM

6. System Impact Review/Interconnection Study 1:15 PM – Mohammad Vaziri (PG&E System Protection)

• DG compatibility with existing distribution system design at the point of interconnection • Potential system modifications • Interconnection study example

Break 2:15 PM

7. Standards and references - Chuck Whitaker (Endecon) 2:30 PM • CPUC Rule 21 and supplementary review guideline for low and moderate penetration systems • IEEE-929 for utility interactive PV inverter systems • UL-1741 for certifying utility interactive systems • IEEE-1547 and sister standards

8. Bonus presentation on DG interconnection - Anthony Mazy (CPUC/ORA) 3:30 PM

On the way to a Plug and Play DG 9. Q&A 3:40 PM Adjourn 4:00 PM

Distributed Generation CourseIntroductory Remarks

Chase Sun

PG&E

October 18, 2003

San Francisco Power Engineering Society

October 18, 2003Distributed Generation Course

San Francisco Power Engineering Society 2 of 7

Concerns that spurred interest in DG & interconnection areas

• Cost– California Energy Crisis– Interconnection cost

• Environmental– Emissions from fuel fired plants– Green House Gases

• Reliability– Aging infrastructure– Power generation capacity did not keep pace with load

growth and led to inadequate reserve margin



Major factors for power system design

• Safety

• Required Capacity Level

• Required Reliability Level

• Required Power Quality Level

• Minimum Cost



Transmission System Characteristics

• Multiple paths to load

• Spare capacity in each path

• Potential bi-directional power flow in each path

• Ability to clear line fault with no interruption to load. Designed for one or more contingencies

• Traditional method to interconnect generator

• Complex to operate

• High cost & high reliability



Distribution System Characteristics

• Radial – unidirectional power flow but may have backtie

• Moderate reliability• Line fault will interrupt downstream load • Designed to provide acceptable voltage and

frequency from zero load to maximum load in the load direction.

• Low cost• Simple to operate



Existing System• Existing distribution system is engineered to

safely serve a given level of load at a given level of reliability with minimal cost.

• The distribution system is dynamic and changes to meet the requirements of load growth and other customer needs.

• The radial distribution system is configured similar to a tree, with the feeder outlet being the trunk and the leaves/fruits being the loads, supported by branches of progressively smaller sizes. So, no two circuit are exactly alike.



• We have an interconnected system where disturbance at one location can propagate to other locations. We have seen this demonstrated in the 8/14/03 NE Blackout.

• It is very important that the utilities and DG developers work together to reduce the DG interconnection costs while preserving the power system integrity.

Existing System (Continued)

October 18, 2003 Distributed Generation Course1 of 42


DISTRIBUTED GENERATIONDISTRIBUTED GENERATION

MECHANICAL SYSTEM OVERVIEWMECHANICAL SYSTEM OVERVIEWBrianBrian SekulaSekula

AltranAltran

IEEE San Francisco PES DG Fundamentals WorkshopIEEE San Francisco PES DG Fundamentals WorkshopSan Francisco State UniversitySan Francisco State University

October 18, 2003October 18, 2003



INTRODUCTIONINTRODUCTION



What is a Distributed Energy System?What is a Distributed Energy System?

A power source close to the end user of electricity (at a home, business or industrial site)

Typically less than 10MW in size



HistoryHistory

Early power plants were distributed since the transmission and distribution system were not well developed and many users had to provide the power themselves.

Before WWII, many industries had on-site generation

After WWII, utilities developed large power stations to take advantage of the economics of scale and the improved efficiency of larger power plants



Why is Distributed Energy Attractive Why is Distributed Energy Attractive Today?Today?

ReliabilityThe end user can have a higher reliability source of power.

Can Reduce Electrical Grid ExpendituresLocal energy production can reduce the load on the transmission and distribution grid if done properly and properlycoordinated with the utility.

EfficiencyDistributed energy systems that utilize cogeneration can have a higher efficiency than central power plants that only produce electricity.

Low EmissionsFossil fuel powered, distributed energy systems are now available with very low emissions and alternative energy systems may have zero emissions.



PhotovoltaicsPhotovoltaics

Principles of OperationDirect conversion of sunlight to DC electric power



PhotovoltaicsPhotovoltaics(cont’d)(cont’d)

Efficiency100’s of watts to MW sizeDepends on efficiency, insolation, orientation and shading

Insolation varies throughout the day. Peak is about 1000 watts/square meter. Daily average is about 250 watts/ square meter.A fixed panel is cheaper than a tracking system but power output is reduced.A typical system will produce about 100 peak watts/square meter and about 200kwh/year per square meter.

Special RequirementsRequires an inverter to produce 60Hz AC power of sufficient voltage.




AdvantagesNo emissionsNo moving partsLow maintenanceLong life Potential

DisadvantagesInitial CostLow utilization factorLow energy density, a large surface is requiredPV output will decrease if shaded by adjacent buildings or trees




Good ApplicationsLow power remote applications away from the gridLarge flat roofed warehouses and stores are an ideal location



Wind TurbineWind Turbine



Wind TurbineWind Turbine(cont’d)(cont’d)

Principle of OperationConvert the kinetic energy of the wind to rotational motion of ageneratorUse of variable speed generators and inverters allows variable speed operation

Increases efficiencyReduces blade loads and weight

The most successful designs are horizontal axis with 3 blades.

EfficiencyApproximately 20 –40%




Power Output100s of watts to 5MWPower is proportional to wind speed cubed and diameter squaredA 25ft diameter wind turbine produces about 10KW at 25mph wind speedTypical capacity factor approximately 25%

Special RequirementsNeed to be in areas of consistent high wind speeds




AdvantagesRelatively low costNo emissions

DisadvantagesThe end user of electricity rarely is in a high wind area and there are restrictions on installation of towers.Weather dependent

Good ApplicationsLimited use by individuals in remote areasPrincipal use is in large wind farms

Not a typically distributed generator



Small HydroSmall Hydro

Principle of OperationConverts the potential energy of falling water into rotation of a generator.Typically use Pelton wheels



Small HydroSmall Hydro(cont’d)(cont’d)

EfficiencyAbout 80%

Power Output100’s of watts to MW’sA function of available head and water flow

Special RequirementsRequire penstocks and sometimes dams

AdvantagesLow cost

DisadvantagesLimited sitesPermitting is difficult



Small HydroSmall Hydro(cont’d)(cont’d)

Good ApplicationsRemote sites



Conventional Gas TurbineConventional Gas Turbine



Conventional Gas TurbineConventional Gas Turbine(cont’d)(cont’d)

Principles of Operation

COMBUSTOR

COMPRESSOR TURBINE ~

GENERATOR

AIR

POWER

FUEL





Efficiency20-40% (size dependent)Up to 80% when used for cogeneration

FuelsNatural gas, liquid fuels

Power Output500 KW – 100 MWDependent on ambient conditions




Special RequirementsHigh pressure gas or gas compressor requiredTo meet California emissions limits

Use only natural gas andSteam injection orSelective catalytic reduction

In hot areas inlet air chillers or evaporative cooling helps maintain power output




AdvantagesLow capital costProven technology

DisadvantagesAir permitting requiredRelatively skilled operating and maintenance personal required

Good ApplicationsMW size cogeneration at industrial facilities



MicroturbineMicroturbine

Principles of OperationSimilar to conventional gas turbines but typically use single stage compressor and turbine.



MicroturbineMicroturbine(cont’d)(cont’d)

Efficiency20-28%Up to 80% when used for cogeneration

Power Output25-500KW

FuelsNatural gas, liquid fuels, landfill gas (down to 350 BTU/scf)

Special RequirementsRequire 100psi gas or compressorCogeneration works best when providing hot water




AdvantagesPhysically small, packaged systems available with all controls and electrical protective functionsRelatively low capital costMeet California emissions requirementsIf used base loaded, yearly maintenance is limited to air filterreplacement

Disadvantages5 year lifeLife will be reduced by frequent starts and stops and cycling




Good ApplicationsCogeneration at commercial and industrial sitesLandfill power



Internal Combustion EnginesInternal Combustion Engines

Principles of OperationUse either Otto cycle (similar to automotive engines) or diesel

Efficiency25-45%

FuelsNatural gas, diesel, landfill gas, digester gas

Power Output5KW - 7MW



Internal Combustion EnginesInternal Combustion Engines(cont’d)(cont’d)

Special RequirementsTo meet California emissions requirements require SCR and use of natural gas

AdvantagesTechnically mature, widely used technology

DisadvantagesHigh noiseEmissionsMaintenance



Internal Combustion EnginesInternal Combustion Engines((cont’d)cont’d)

Good ApplicationsCogeneration (using jacket water) at commercial and industrial sites



Steam TurbineSteam Turbine

Principles of OperationExpand steam to produce rotation of a generator

EfficiencyApproximately 20-40% cycle efficiency

FuelsBoiler required

Can burn a variety of fuels



Steam TurbineSteam Turbine(cont’d)(cont’d)

Power OutputKW – MW size

Special RequirementsRequires a boiler with sufficient pressure and temperature steamRequires overspeed protection



Steam TurbineSteam Turbine(cont’d)(cont’d)

AdvantagesLow cost if boiler exists

DisadvantagesTypical commercial and industrial boilers do not provide high pressure steam

Good ApplicationsLimited uses for distributed generationMay be part of a combined cycle plant in which gas turbine waste heat is recovered in a heat exchanger to run a steam turbine.



Fuel CellsFuel Cells

Principles of OperationFour types under development

Phosphoric Acid (PAFC)Molton Carbonate (MCFC)Solid Oxide (SOFC)Proton Exchange Membrane (PEMFC)

Similar to a battery (chemical reaction)



Fuel CellsFuel Cells(cont’d)(cont’d)

Hydrogen mixes with air, is broken down into protons and electrons, and positively charged ions move through the electrolyte across a voltage to produce electric power



Efficiency30-60%

FuelsNatural gas, hydrogen. Some can use landfill gas, propane, and diesel

Power Output1 KW-10MW

Special RequirementsNon hydrogen fuels must be reformed into hydrogen (e.g., steam reformer for methane)





AdvantagesHigh efficiencyPotentially 0 emissions

DisadvantagesComplexStill experimentalHigh cost

Good ApplicationsOnce perfected could have very wide application



Hybrid Fuel Cell/MicroturbineHybrid Fuel Cell/Microturbine


COMBUSTOR

COMPRESSOR TURBINE ~

GENERATOR

POWER

FUEL CELL

POWER

FUEL FUEL

AIR

O Fuel cell efficiency is improved at high pressure

O Combines a solidoxide fuel cell with a microturbine



Hybrid Fuel Cell/MicroturbineHybrid Fuel Cell/Microturbine(cont’d)(cont’d)

Efficiency60-70%

FuelsNatural gas, hydrogen



Hybrid Fuel Cell/MicroturbineHybrid Fuel Cell/Microturbine(cont’d)(cont’d)

Power OutputKW – MW

AdvantagesExtremely high fuel to electric conversion efficiencyLow emissions

DisadvantagesVery high costInfant technology

Good ApplicationsIf perfected will have very wide applicability



Installed CostsInstalled Costs



CONCLUSIONSCONCLUSIONS



Many technologies are available and proven

Distributed generation has barely made inroads in a potentially massive market

Distributed generation has huge potential to reduce fossil fuel consumption via the high efficiency of cogeneration v.s. centralized power plants

For more information, see: www.energy.ca.gov/distgen

Distributed Generation Principles Electrical Systems

Presented by Dr. ShyShenq Liou San Francisco State University


DG Fundamentals WorkshopSan Francisco State University

October 18, 2003

Solar Power

•Fundamentals•Electrical Characteristics•Cell, Module, and Array•Maximum Power Tracker•Power Electronics Circuits



p-type mateiral

n-type material

EHP

Electron

Hole

IncomingPhoton

Basic Operation of Solar pn Junction



−−= 1kT

qV

ol eIII

V-I Characteristics of Solar Cell

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FF is the cell fill factor



Cell Voltage

Cel

l Cur

rent

I-V Characteristics of Solar Cell

Illumination Level



V

ICell

Module

Array



Blocking Diode

Bypass Diode



Cell Voltage

Cel

l Cur

rent

Illumination Level

Load Line

Load Line

Load Line

Concept of Maximum Power Tracker



MOSFET

CellModule

Indu

ctor

Diode

Cap

acito

r

Res

isto

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Buck-Boost DC to DC Converter

inout VD

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Overview of Fuel Cell

•Brief Introduction•Fundamentals•Electrical Characteristics

Brief Introduction

• Fuel Cell was invented by William R. Grove in 1839. It was called “Gaseous Voltaic Battery

• Fuel Cell is an electrochemical “device” that continuously converts chemical energy into electric energy (and some heat) for as long as fuel and oxidant are supplied.

Three Major Applications

• Transportation–Automobiles

• Stationary Power Generation–Low CO2 emission–CHP

• Portable Applications–Camping–Yachting



Type of Fuel Cell

2 kW to MW

>50%H2, CO, CH2, and others

~1000 CSolid OxideSOFC

200 kW to MW

> 50%H2, CO, CH2, and others

~650 CLithium & Potassium Carbonate

MCFC

200 kW(CHP)

40%Pure H2~220 CPhosphoric acid

PAFC

5-250 kW35-45%Pure H250-100 CSolid Polymer

PEMFC

< 5 kW35-55%Pure H260-120 CKOHAFC

Power Range

Electric Efficiency

FuelOperating Temp.

ElectrolyteFC Type

AFC: Alkaline FC PEMFC: Proton Exchange Membrane FCPAFC: Phosphoric Acid FC MCFC: Molten CarbonateSOFC: Solid Oxide FC



Membrane Electrode Assembly of PEMFC

inH 2 inO2

−e

Ano

de

Cat

hode

+H+H

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Catalyst LayerGas D iffusion

Layer/Substrate

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r =→++

+→

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−+outOH 2



V-I Characteristic of Fuel CellC

ell P

oten

tial i

n vo

lt

C ell C urrent in A/(cm square)

Power C urve

Effic iency of FC ~ to C ell Voltage



Wind Power

• Major components• Typical Wind Turbine Power Curve• Possible choices of generator• Power Electronics



Major Components of a Wind Turbine

Rotor

Hub

Control

Drive Train Generator

Main Frame/Yaw System

Tower

Foundation

Balance ofElectrical System



Typical Wind Turbine Power Curve

W ind S peed, m /s

Pow

er

C u t-in(~7 m/s)

R ated

C ut-ou t(~20 m /s)



Possible Generators

• Synchronous Machine• Induction Machine• Permanent Magnet Synchronous Machine• Direct Drive Generator• Switched Reluctance Generator• DC Machine

– DC Shunt Machine

– High Maintenance and high cost



Induction Machine

• Motoring when speed is less than synchronous speed– 2-pole: 3600 RPM– 4-pole:1800 RPM– 6-pole: 1200 RPM

• Generating when speed is above the synchronous

• Slip is usually 2% to 3%• Self starting using wind!• Run as induction motor to start!



Torque/Power Speed Curve for Induction Generator/Motor



Synchronous Machine

• Usually started by the wind• Synchronization is needed to connect to

existing AC power system• Active rotor speed control maybe needed



Permanent Magnet Machine

• Generator of choice for <10 kW unit• Permanent magnets mounted on rotor

provides field excitation• Armature on stator is stationary! No need

to have commutator, slip rings, brushes!• AC output has variable frequency and

magnitude. • Rectified to DC, inverted to AC, then

connected to grid.



Direct Drive Generator

• Synchronous Generator of special design• Large no. of poles so it can be coupled to

the wind turbine rotor. No gearbox is needed.

• Diameter is large!• Power Converters are needed to cope with

varying magnitude and frequency!



Switched Reluctance Machine

• a.k.a. Variable Reluctance Machine• A huge stepper motor or generator• Popular in traction applications• Electrical characteristics are similar to

those of series DC machines• Made possible because of power

electronics and digital control• Difficult to compete against Induction

Machines economically



Power Converter

• Block diagram of a motor drive where the power flow is unidirectional



Diode-Rectifier with a Capacitor Filter

• Power electronics load is represented by an equivalent load resistance



Three-Phase, Full-Bridge Rectifier

• Commonly used



Three-Phase Inverter

• Three inverter legs; capacitor mid-point is fictitious



Switch-Mode DC-AC Inverter

• Block diagram of a motor drive where the power flow can be bi-directional



Vdc A B

Single-Phase DC-AC Inverter

ABV



PWM to Synthesize Sinusoidal Output

• The dotted curve is the desired output; also the fundamental frequency



Three-Phase PWM

Waveforms



Vdc A B

Single-Phase DC-AC Inverter

ABV



AC AC

SourceV

ABV

Current I

IjIX

ABV

SourceV

X

pf = 0, leading



AC AC

SourceV

ABV

Current I

I

jIX

ABV

SourceV

X

pf = 0, lagging



Vdc A B

Three-Phase DC-AC Inverter

C

Distribution System CharacteristicsDistribution System Characteristics

Presented by Willie Chew Pacific Gas & Electric Company


DG Fundamentals Workshop

San Francisco State University

October 18, 2003

October 18, 2003 Distributed Generation CourseSan Francisco Power Engineering Society 2 of 21

Most Common Type Used by most Utilities

• Single Path of Supply – One primary source, one transformer, one secondary source

• Main Line Usually Connected at various points to Adjacent Circuits by Switches

Radial Distribution


Mainly used for overhead distribution systems

• Customers exposed to outages when equipment fails

• Easy to locate trouble and faults

• Cost effective to install

Radial Primary Feeder


Radial Primary – Overhead


• Fuses

• Line Reclosers

• Circuit breaker at substation has automatic reclosing

-- Typical 3 shots to lockout

Overhead Line Protection


• Mainly for Underground Distribution Systems

• Provides 2 Supply Paths for Loads

• Usually installed where there is a concentration of Commercial or Industrial Customers

Radial Loop Primary


Radial Loop - Primary


Subsurface Fused Switches

• Interrupters

• Circuit breaker at substation has no automatic reclosing

Underground Protection


• Wind and Trees (46%)

• Equipment Failure (12%)

• Human Error ( 9%)

• Weather (26%)

• Foreign Objects (1.5%)

Most Common Causes of Faults


• Load Tap Changers (LTC) on substation banks

• Station Capacitor Banks

• Field Capacitor Banks

• Autoboosters

Voltage Regulation


Low Voltage AC Network Distribution Systems

Uses Redundant Facilities to Provide almost 100% Service Reliability

Intended to serve Commercial Loads in a High Density Areas

Design for Underground Installations

Two Types – Grid & Spot Networks


Grid or Dispersed Network

Used for Small to Medium Commercial Loads

Transformers dispersed over a Large Area

Has a “Grid” of Interconnected Cables energized at 120/208 Volt, 3 phase

Grid energized at multiple points by Transformers

Multiple Primary Circuits operate in parallel to supply power to Grid Transformers


Dispersed Network


Spot Networks

For Large Concentrated, Commercial Loads

Has Same Reliability and Operating Features as a Grid

Secondary Voltage is usually 277/480 Volt

Usually Serves only one Customer

Types of Customers: High Rise Office Bldgs and Hotels, Computer Facilities, Communication Centers, & Retail Centers


Spot Network


Disadvantages

High Secondary Fault Currents – Up to 200,000 Amp. In Certain Areas

Large Space Requirement for Transformer Vaults

Cost of Purchasing Multiple Transformers and Extension of Multiple Primary Circuits

Reliability affected by Bulk Power Source


Distribution Systems

RADIAL

One source

One transformer

One sec path.

Reliability: ~95% for some rural areas~99.85-99.95 % for urban areas

NETWORK

Multiple sources

Multiple transformers

Multiple sec paths

Reliability: >99.999%


Measured Reliability of Distribution Systems

Type of System RadialOverhead

Loop Radial System

Underground Loop Radial

System

Automatic Transfer Scheme

Grid Network

Spot Network

Outages Per Year 0.3 - 1.3 0.4 - 0.7 0.4 - 0.7 0.1 - 0.5 0.005 - 0.020 0.02 - 0.10

Average Outage Duration (min)

90 65 60 180 135 180

Momentary Interruptions Per Year

5 - 10 10 - 15 4 - 8 4 - 8 ~ 0 0 - 1

Table extracted from ELECTRICAL WORLD, May 1992

Based on information supplied by Consolidated Edison


Fault Capabilities(3 phase RMS symmetrical)

36,000 to 175,000 Amp

18,000 to 52,000 Amp

Secondary(460 & 480 V)

3,000 to 200,000 Amp

10,000 to 42,000 Amp

Secondary (208 & 240 V)

8600 to 21,000 A. 13,500 t0 12,000 A.

600 to 21,000 Amp.

Primary (4 to 34.5 KV)

NetworkRadial Voltage

Assymmetry Factor : 1.0 to 1.6


Commercial Load Pattern


Residential Load Pattern

DG Fundamentals WorkshopOctober 2003

San Francisco Power Engineering SocietyDG Systems and Applications

1 of 55

Commercially AvailableDG Systems & Applications –

Gary Olson Cummins Power Generation

October 18, 2003



2 of 55

DG Concept Changing load dynamicsMove to service economyFlexible manufacturing (automation)DeregulationAvailable technology is more flexible

US market size13GW new load per year*Peaking and shoulder = 7.5GW new load

Targeted Generation delivers lowest cost energy

Use base load assets to supply base loadEfficient Intermediate assets remove need for true “peak” assets

Market uncertainty creates a premium for flexible assets

100

7,000Peak•Capacity… 25% to 20%•Energy… 2.5% to 2.5%

Shoulder•Capacity… 30% to 30%•Energy… 12.5% to 17.5%

Base•Capacity… 45% to 50% •Energy… 85% to 80%

$/M

Wh

Annual Running Hours

*Source: EIA/DOE Annual Energy Outlook 2002 -2020

8,7604,8003,000

20



3 of 55

Drivers for New Technology

–Lower total cost• Equipment• Fuel efficiency

–Lower emissions–Power quality



4 of 55

Technologies Reviewed• Recip Diesel Engines

• Advanced Recip Gaseous Fuel Engines

• Gas Turbines• Microturbines• Fuel cells

• Wind/Solar



5 of 55

Diesel RecipLow $/kWHigh efficiencyNOx/PM Issues

Natural Gas RecipLow emissionsLow $/kWCogen optionsSize IssuesFuel issues

Fuel CellUltra low emissionsHigh efficiencyCogen optionsVery high $/kWSize Issues

MicroturbineFuel tolerantVery low emissionsCompact sizeCogen optionsHigh $/kW

Application needsHours operation?

Capital availability?

Permitting requirements?

Fuel availability?

How do the Technologies andMarkets Fit Together?



6 of 55

Distributed GenerationGrowth rate of DG is highly dependent on assumptions and variables.

FactorsRatio of avg utility rates togas fuel prices

ExpectationsDOE Short term estimate = regionalDOE Long term estimate. =declining

ImpactTBDNegative

Peak utility rates in highservice cost areas (< 5% ofservice)

- Utility generatingreserve capacitydiminishing

- Utility transmissioncapacity diminishing

Political pressure to hold retailpricing, utility rebates are apossibility (to promote getting off thegrid)

New gas plant additions

More capacity with efficientmanagement

Positive if utilities rebate

Positive

Positive

Utility support of dist. gen. Improving due to growingderegulation

Positive

Energy service companies Entrepreneurial adoption of newtechnology

Positive



7 of 55

Market Trends• Standby

– Significant growth in IT and Telecom

• Interruptible and Peak shaving– Growth

• Distributed Generation– Potential for Growth



8 of 55

• Equipment cost• Operating costs

– Fuel (consumption and price)– Maintenance

• Emissions regulations• Utility interconnection issues• Utility Rate Structure

– Demand, energy, backup– Evaluate based on site conditions

Distributed Generation Application Issues



9 of 55

Pros and Cons for DG• Pro:

– Low risk venture– Returns can be very good– Improves Facility Power

System Reliability• “Free” Standby

– Test/Exercise Benefits

• Con:– Most Customers are not in the

power generation business– Return may not be as high as

other projects competing for capital

– More complex power system• less reliable?

– Environmental Issues• Exhaust• Noise



10 of 55

Equipment Costs Vs Technology

0

500

1000

1500

2000

2500

3000

1 10 100 1000 10000 100000

Power (Kw)

Pric

e ($

/kW

e)

Fuel Cells Near Term

Natural Gas Recip

Gas Turbine(Non-recuperated)

Diesel Recip

Microturbine(Recuperated)

DOE Fuel Cell Program Targets Long Term

FY03 TQG

Be t

ter



11 of 55

Thermal Efficiency Vs. Technology

0.10

0.15

0.20

0.25

0.30

0.35

0.40

0.45

0.50

0.55

1 10 100 1000 10000

Power (kWe)

Ele

ctri

cal E

ffic

ienc

y (f

ull l

oad)

Gas Turbine(Non-recuperated)

Gas TurbineRecuperated

Fuel Cells Diesel Recip

Natural Gas Recip(Stoichiometric)

Natural Gas Recip(Lean Burn)

Fuel Cell/ Microturbine Target 60-70%

DOE Fuel Cell Target

Bet

ter

Hydrocarbon Fuels

Stationary

Mobile



12 of 55

CHP = Cogeneration

Mechanical

Thermal

Electrical output 42%

HT circuit (90-100°C)16%

Lube Oil circuit (75-90°C) 5%

Exhaust gas (120° + unburnt HC.) 8%

Generator losses 1%

Cooling circuit CAC 2%

Exhaust gas ( -> 120°C) 24%

Engine radiation 3%

Total efficiency

87 %

Losses 14 %



13 of 55

Market Segment Drivers

Market Operation Low Low low Low Segment Hours per Initial Fuel Maint. Emissions

Year Cost Use ($/hr)

Standby <200

Interruptible 100-500

Peaking 1000-2000

Distributed >2000Generation

Importance: High = greenMedium = yellowLow = red



14 of 55

Economic Evaluation

Cost Benefit

Initial/Leased Costvs.

Lower Cost Power

Operating Cost Business Doesn’tfail with the power



15 of 55

Emission level & air quality restrictions



16 of 55

Emissions Requirements• There are no federal genset emissions standards for

stationary gensets• Local state or county regulations exist in air quality non-

attainment areas.– Often federal Mobile Off Highway (MOH) regulations

are adapted for diesel generators in non emergency standby applications >200 hr/yr.

• Many states have no specific genset emissions regulations– General site emissions permitting requirements apply– Typical solutions to issues are increasing exhaust

stack to increase dispersion



17 of 55

Some Emissions Basics

• NOx (NO & NO2) is a function of combustion when N2 and O2 react under high temperatures– Reacts with hydrocarbons in the presence of sunlight to form ozone, a

component of photochemical smog• CO is a function of combustion completeness

– Excess air, and stratified charge helps• CO2 is a function of engine thermal efficiency• Particulate matter is a function of fuel type and delivery system

(mainly a diesel engine issue with incomplete combustion of carbon)• Low emissions can be attained by

– Fuel selection– Engine technology– Exhaust aftertreatment

Cx Hy Sz + O2 + N2 CO2 + H2O + N2 + O2 + NOx + HC + CO + SOx + C

Dieselfuel

Air Major exhaustconstituents

Exhaust components foundin trace concentrations



18 of 55

Emissions Standards and ControlsTechnology Options

0.76

0.40

0.01

0.45

0.42

0.27

0.16

0.03

0.02

13.6

20.9

8.2

3.4

1.5

0.00 0.20 0.40 0.60 0.80 1.00

Tier 1 Diesel

Tier 2 Diesel

Tier 3 Diesel

US Utility Average

Lean burn gas recip

Gas Turbine

Microturbine

Fuel Cell

Rich burn gas recip + TWC

Tier 1 Diesel+ SCR

Tier 2 Diesel + SCR

Tier 3 Diesel+ SCR

Lean burn gas recip + SCR

Gas Turbine+ SCR

NOx (lb/MWe-hr)

MOH Federal Regulations

Base Plant

AftertreatmentMOH - Mobile Off-Highway

SCR - Selective Catalytic Reduction

TWC - Three-Way Catalyst



19 of 55

SCR Systems

• Effective, Rapidly Developing Technology• High Cost

– Initial cost– Operating cost

• Risks

2 MW Diesel DG Module with SCR



20 of 55

Noise dBA

8584838281807978777675747372717069686766656463626160595857

Noise Level vs. Technology

60 KW @ 7 Meters - Uninstalled

Microturbine or custom GenSet73 dBA

63 dBA w/silencer option

Attenuated modular GenSetStage I 71 dBA

Stage II 67 dBA

Open GenSet

85 dBA

Fuel Cell

59 dBA est..

Ref., commercial air conditioner is 61 dBA

Common Property Line Requirement:50 dBA

Common Property Line Requirement:50 dBA



21 of 55

Hythane• Potential to introduce H2 using existing distribution and minorengine modifications

• 20% H2 and 80% NG can provide a 50% reduction in NOx emissions at equivalent efficiencies

Hydrogen

• Easily used in turbines and fuel cells

• Advance reciprocating engines can provide low emissions and good fuel economy

• Fuel cells provide an incremental improvement in fuel efficiency and emissions over turbines and reciprocating engines

•A challenge is to produce and distribute hydrogen at a commercially viable cost



22 of 55

Fuel Storage Capacity Required gal/kW-hr

0.130.25

1.54

0.00

0.20

0.40

0.60

0.80

1.00

1.20

1.40

1.60

1.80

#2 Diesel Fuel(Genset 1/2

Load)

LPG(Genset 1/2

Load)

H2 @ 3600 PSI(PEM Cell)

Fu

el S

tora

ge

Vo

lum

e R

eq'd

gal

/kW

-hr

Fuel Cost Comparison for <10kW Generation

$0.11$0.28

$4.38

$-

$0.50

$1.00

$1.50

$2.00

$2.50

$3.00

$3.50

$4.00

$4.50

$5.00

Diesel Genset(1/2 load)

no tax

LPG Genset(1/2 load)

no tax

PEM Cell on H2

Fu

el C

ost

$/k

W-h

r

Industrial"A"Cylinder

IndustrialBulk GasPricing

DOE-GTINGReformingStudy

$1.63

$0.29

Fuel Storage Volume and Cost Comparison



23 of 55

Fuel Cell Technologies

Germanischer Lloyd



24 of 55

Attributes of fuel cell technologies

Technology Size Eff. Operating Maturity COST FEATURES ISSUESN gas fuel Temp C 5-8 yr

PEM < 100KW 36% 20 - 120 C medium high fast response

complex3M, Ballard 28% sm. reformer

Phosphoric >100KW 40% 160 - 650 C high very mature expensiveFuel Cells Int'l. highCarbonate >100KW 50% 600 - 650 C medium high efficient •low density

FuelCell Energy •therm.cycle

Solid Oxide 5-1000KW 50% 900 - 1,000 C low high efficient •maturity

30% sm.

Highest potential for broad applications

WestinghouseSOFCo •start time



25 of 55

Gaseous Recip Fuel Engines• Stoichiometric Engines

– Carburated, spark plug ignition

• Lean Burn Engines– Close fuel/air ratio control, spark ignited

• Fumigation Techniques– Diesel start and pilot ignition, gas induction– 5% diesel in operation = lower maintenance

• High Pressure Injection – Higher power (+30%), efficiency (+2%)– Lower emissions (1/2 g/bhp-hr NOx w/o aftertreat)



26 of 55

Natural Gas Jet

Direct Gas Injection Technology

• Gas is compressed on the engine and Injected in the cylinder at 3600psi

• Diesel fuel is injected to initiate combustion (approx.. 5% of fuel)

• The lean gas/air mixture burns to completion

A



27 of 55

Microturbine Manufactures

Elliott 45 kW SystemNREC 80 kW System

Cummins Power Generation

30KW and 60 KW Systems



28 of 55

What Makes Up a Microturbine System?

Compressor Turbine Generator

Combustor

Recuperator

FUEL

AIR

EXHAUST

Power Inverter

AC POWER

Fuel Compressor

60 Hz, 480 VAC



29 of 55

Block Diagram: Microturbine system with CHP



30 of 55

Integrating DG into a SiteNew Systems:

– Traditional Practical Limit for Synchronous Generator Sets: >600A

• New breaker and control technologies make “electrically” practical down to approx. 200A

– NO DISTURBANCE• Soft Transfer Systems

» Hard closed transition doesn’t work• Paralleling/Soft Transfer Systems

» To stay connected, or not: that is the question...– Cogen/Renewable any size

• Retrofit Systems– Paralleling and Large Generator Sets



31 of 55

New Installations

GenSet

52 52

Utility

R

52

52 52 52

52 = CIRCUIT BREAKER

R = UTILITY PROTECTION



32 of 55

New Multiple Unit Installations

52

52 52 52

52 52

Utility

R

GenSet

52

GenSet

52

GenSet

52





33 of 55

Typical Small DG or CHP

GenSet52

Utility

R

52

52 52 52





34 of 55

Retrofit: Single Generator Set

GenSet

52 52 52

52

52 52 52

ATS

ATS

ATS

52R

Utility

52

CRITICAL LOADS

CRITICAL LOADS

CRITICAL LOADS

52



35 of 55

Retrofit: Multiple Gensets

GenSet

52 52 52

52

52 52 52

ATS

ATS

ATS

52R

Utility

52

CRITICAL LOADS

CRITICAL LOADS

CRITICAL LOADS

GenSet

52



36 of 55

Closed Transition TransferClosed Transition

Transfer Equipment IS

UTILITY PARALLELING

EQUIPMENT

Watch For:• Compliance to Rule 21

– Fail to disconnect• Compliance to NEC

– Labeling– Protection– Load Control (?)

• Performance you NEED– Fast transfer = sudden load

change– Transient Performance of

Genset



37 of 55

Standby Standby

Utility Power Utility Power

Power to Loads Power to Loads

Standby

Stand-alone/Standby/Parallel/utility-interactive/certified/load management

Stand-Alone (Prime) Stand-Alone (Prime)

(No Utility Service or Standby Only)


Standby Standby

Utility Power Utility Power


time

PRIME

STANDBY

STANDBYAND UTILITYINTERACTIVE

SYSTEM DOWN

SYSTEM DOWN ON NORMAL FAILURE

SYSTEM DOWN ON NORMAL FAILURE

LOAD SHARE



38 of 55

System ProtectionGG G

12470 V

480 V

40004000

2000(TYP 3)

GENERATORPROTECTION

SWITCHGEAR &FEEDER PROTECTION

UTILITYPROTECTION



39 of 55

Generator Protection• I/O availability in digital controls

makes anything possible• Difficulty of:

Protection vs. Reliability• Protection Tuned for the Generator

– Overcurrent– Over/Under Voltage– Over/Under Frequency– Loss of Field/Reverse Power– Differential

POWERTO

LOAD

EN

GIN

E

GEN

EC

GOV

AVR

CB

REMOTE



40 of 55

Control and Protective FunctionsGENSET

AM SW

VM SW

KW KWH PF 40 32 65 90 51V

HZ 27 81U 59

SU

RG

E S

UP

PR

ES

SO

RS

VM SW HZ 47 SYNC 2586

SSDIGITAL CONTROL

SWITCHGEAR TRIP

CLOSE



41 of 55

Utility Protection• Design Depends

on:– Local conditions

– Codes and Standards

– Utility Practice

– More Variety than Generator

• Common Protective Devices:– Over/Under Volts,

Hz

– Reverse Power– Directional Current

• Distribution Changes



42 of 55

Voltage Regulation/Frequency Regulation

• To the generator guy:– The difference between steady state no load

and full load voltage or frequency, as a percentage of nominal level

– Describes how well the machine can maintain nominal levels over time

– Typical: +1% for voltage, +0.25% for Hz

• To a utility:– An attempt by a device to change the voltage

or frequency of the utility service



43 of 55

Synchronous Generator Control

• Active Controls include:– Governor

• Measures speed • Controls fuel rate

– AVR• Measures voltage• Controls excitation (field strength)

• Both work like a cruise control

POWERTO

LOAD

EN

GIN

E

GEN

EC

GOV

AVR

CB

REMOTE



44 of 55

The Need for Load Sharing

RED: PhasesRED: PhasesBlue: NeutralBlue: NeutralGreen: GroundGreen: Ground

A

B

C

N

G



45 of 55

Intertied Synchronous Generator Control System

POWERTO

LOAD

EN

GIN

E

GEN

EC

GOV

AVR

CB

REMOTE

ILSSYNCPROTMETER

ALARMLOAD SHARE

DATA

I/E VAR/PF

UTILITY/MAINS

CB

25

PROT

SENSELOGIC



46 of 55

Load Sharing/Following/Shedding

GenSet

52 52

Utility

R

52

52 52 52

Sharing/Following: • 2 or more Sources• Equal load share • Base load DG• Track Utility

Shedding: Utility Only Source • Peak Shave • Drop Part Load• Discontinue Operations



47 of 55

Mechanical Considerations• Where are you going to put it?• Mechanical Issues

– Getting waste heat out– Using as much as practical

– Exhaust– Vibration/Noise

– Fuel Storage and System Design



48 of 55

No Problem, we have PLENTY of room…



49 of 55

GenSet Energy Balance• Recip Engine Burns Fuel--creates:

– Rotating mechanical energy/electrical power– Heat

Fuel (BTU) In

Mechanical Energy

Radiated Heat 10%Cooling System 25%

Exhaust 30%

Power Out 35%



50 of 55

Wind Effects on HVAC



51 of 55

Noise Concerns130 Pneumatic Riveter (130)

120 110

100 Jet @ 1000ft (103)

90 Power Mower (96)80 Heavy Street Traffic (85)

70

60 Normal Conversation (65)

50 Light Traffic @ 100ft (55)40 Library (40)

30

20 Broadcast Studio (20)

2000KWGenset Range

50KW

• Noise Ordinances Strict

• Noise Levels of Many DG High

• Cost of Noise Treatment is High– Particularly if you screw up

• Uncertain Enforcement



52 of 55

Fuel Storage…



53 of 55

Big Things to Remember…• Best technology for a site depends on:

– Fuel availability, cost– Emissions Restrictions– Efficiency– Mechanical Concerns

• There is no one best technology that will work for every site

• Technology is driving costs down, so owners need to keep watching for opportunities



54 of 55

Prognosis• DG will grow

– Big Incentives Nationally– Economic viability to User

• Risk needs to be reduced

• Success depends on – Planning – Cooperative Venture between:

• User• Developer/Supplier• Utility• Regulators



55 of 55

Questions?

Gary OlsonCummins Power Generation

[email protected]

Effects of Generation on Radial Distribution Feeders

An IEEE PresentationOctober 18, 2003

San Francisco State University

By

Mohammad Vaziri, Ph.D., P.E.

October 18, 2003 Distributed Generation CourseSan Francisco Power Engineering Society

2 of 21

Generation Effects on:

A) Planning & Design

• Feeder Loading• Voltage Regulators (Steady State)• Voltage Flicker (Transient)

• Capacitor Controls• Stability concerns


3 of 21

B) System Protection

• Overstress on equipment• Protective equipment desensitization

• Islanding Conditions• Ferro-resonance

• Nuisance Tripping


4 of 21

"Comparison of "Open Delta" and "Closed Delta" Distribution Line Regulators.

1 - Phasor Diagram for the "Open-Delta" regulators shows the Neutral Shift associated with Open Delta

regulators under "Full 10% Boost" condition.

2 - Phasor Diagram for the Closed Delta regulators shows the derivation of the 15% regulation capability (

under full boost condition) when the 10% regulators are connected in a Closed Delta configuration.


5 of 21

A

A’

B

B’

100%

110%

C C’

1) A,B,C & N are source side phase & neutral references

2) A’,B’C & N’ are load side phase & neutral references.

3) Matched regular steps assumed.

BA = 100% AA’ = 10% Regulation

KVLL = BA’ = 110% of BANN’ = 5.8%(of line to line value = 10% of line to neutral value) = Neutral Shift

N N’

1) Phasor Diagram – Open Delta Regulators

Source: M. Vaziri, “Effects of Co-Generation on Distribution System”, Thesis, CSUS 1991


6 of 21

A

A’

B

B’

100%

115%

C C’

0.1

1.0

N, °N’X°

C’

c = 1.15

a = 1.1

A

A’b = 0.1

120°

BA = 100% AA’ = 10%

KVLL = B’A’ = 115%NN’ = 0 Neutral Shift

Consider the triangle AA’C, where angle A=120° and the sides AC’=a=1.1p.u. and AA’=b=0.1p.u. (assuming 10% boost for the regulators).


2) A’,B’C & N’ are load side phase & neutral references.


Calculating the maximum possible shift;

Using the law of sines,

sin 120° = sin X°

1.15 .1

solving for X;

X = 4.3°

Then; c2 = a2 + b2 - 2ab Cos(A)= 1.12 +0.12 -2(0.1)(1.1) Cos(120°)

Then; c = √ 1.33 = 1.153

That is; 10% regulators are capable of 15% regulation in a closed delta configuration. To limit the regulation to a maximum of 10%, then each regulator must be blocked at 87%.

2) Phasor Diagram – Closed Delta Regulation



7 of 21


2) A’,B’C’ & N’ are load side phase & neutral references.


NA = 100% AA’ = 10% L-N Regulation

KVLL = NA’ = 110% NN’ = 0

1) Phasor Diagram – WYE Connected Regulators


100

%110

%

100 %

110 %

B’

A’

C’

B

A

C

N, N’


8 of 21


9 of 21


10 of 21

Thevenin Equivalent of sequence networks at resonance neglecting resistance


11 of 21Connection of sequence networks for a single phase-to-ground fault

on the 12.47 feeder


12 of 21

Line Drop Compensator Circuitry in Voltage Regulators


13 of 21

I2t for a 3-phase fault on a 12.47 Kv feeder with a dispersed synchronous generator


14 of 21

I2t for a phase-to-ground fault on a 12.47 Kv feeder with a dispersed synchronous generator connected through grounded wye-

delta transformer of equal capacity


15 of 21

Open Delta Regulation:

• Usually installed on 3 wire systems

•Generates the same % neutral shift (of the line to neutral value) as the regulator contacts move away from their neutral points. This neutral shift translates into E0 voltage, which means each stage of open delta regulation can produce a maximum of 10% E0.


16 of 21

fault

~ 10%

As it can be seen from the above sequence network, E0 seen by the relay can be effected by the E0 generated by open delta regulators.


17 of 21

Coordination Against Nuisance Tripping

Single Line, Positive, Negative, and Zero Sequence Diagram


18 of 21

Coordination Against Nuisance Tripping Using Xd’

Three Phases and Three Io Currents for Faults at F2


19 of 21

Desensetization of Recloser R1 after Interconnection of SDG

Three Phases Io Currents for Faults at F1

Grounded Y- Connection for SDG Main Transformer is assumed


20 of 21

References

1) Mohamad Y. Vaziri P.E., “Effects of GO Generation on Distribution System”, M.S.EE Thesis CSUS 1991

2) Richard M. Moffatt, Customer Generation on the Distribution System. Presented at the 34th Annual Conference for Protective Relay Engineers, Texas A&M University, Collage Station, Texas. April 13-18, 1981.

3) Roger C. Dugan and Dwight T. Rizy, “Electric Distribution Protection Problems Associated with the Interconnection of Small, Dispersed Generation Devices”. IEEE Transactions on Power Apparatus and Systems, PAS-103 No. 6 June 1984


21 of 21

4) N.H. Malik, and A.A. Mazi, “Capacitance Requirements for Isolated Self-Excited Induction Generators”, IEEE Transactions on Power Systems 86 WM 219-0 pp. 62-69, March 1987

5) Robert H. Jones, Measuring the Effects of Dispersed Generation, Rochester Gas and Electric Company. Published by Transmission & Distribution, a Cleworth Publication, pp. 50-54, August 1987.

EENNDDEE CCOONNEE NN GG II NN EE EE RR II NN GG

Distributed Generation Distributed Generation Interconnection Interconnection

Standards & GuidelinesStandards & GuidelinesChuck WhitakerChuck Whitaker

Endecon EngineeringEndecon Engineering

IEEE San Francisco PES DG Fundamentals WorkshopIEEE San Francisco PES DG Fundamentals WorkshopSan Francisco State UniversitySan Francisco State University

October 18, 2003October 18, 2003


2 of 97San Francisco Power Engineering SocietyEENNDDEE CCOONN

EE NN GG II NN EE EE RR II NN GG

Interconnection Standards & GuidelinesInterconnection Standards & Guidelines

•• Regulatory Agency Interconnection Rules Regulatory Agency Interconnection Rules –– MuniMuni Boards, State Boards, State PUCsPUCs (i.e.(i.e. Rule 21Rule 21), FERC ), FERC

•• Equipment and Facility Requirement Standards Equipment and Facility Requirement Standards –– IEEE 929, IEEE 1547, IEEE 1547.2IEEE 929, IEEE 1547, IEEE 1547.2

•• Product Testing StandardsProduct Testing Standards–– UL1741UL1741, UL2200, IEEE C37.X , , UL2200, IEEE C37.X , IEEE P1547.1,IEEE P1547.1, NEMA, NEMA,

etc.etc.




Presentation OverviewPresentation Overview

•• California Electric Rule 21California Electric Rule 21

•• IEEE 929IEEE 929

•• IEEE 1547 FamilyIEEE 1547 Family–– 15471547

–– 1547.11547.1

–– 1547.21547.2

•• UL 1741UL 1741




California Electric Rule 21California Electric Rule 21

Standard for Interconnecting Standard for Interconnecting Distributed Resources with Electric Distributed Resources with Electric

Power Systems Power Systems

(Thanks to Scott Tomashefsky)(Thanks to Scott Tomashefsky)




•• A term commonly referred to as interconnection A term commonly referred to as interconnection rules.rules.

•• Specific rule contained in the electricity tariff Specific rule contained in the electricity tariff booklets of the utilities under CPUC jurisdiction.booklets of the utilities under CPUC jurisdiction.

•• Documentation of technical and procedural criteria Documentation of technical and procedural criteria for connecting generation equipment to the utility for connecting generation equipment to the utility systems.systems.

•• Technology and size neutral. Technology and size neutral.

What Is Rule 21?What Is Rule 21?




•• Rule was not designed for smallRule was not designed for small--scale scale DG interconnections.DG interconnections.

•• It did not address the benefits of It did not address the benefits of having a standardized rule in place.having a standardized rule in place.–– Increased cost to DG manufacturers.Increased cost to DG manufacturers.

–– Larger degree of customization Larger degree of customization required.required.

•• It did not obligate utilities to review It did not obligate utilities to review applications within a particular applications within a particular timeframe or provide any detailed timeframe or provide any detailed cost estimate to applicant.cost estimate to applicant.

Why Did Rule 21 Need Refinement?Why Did Rule 21 Need Refinement?




•• Rules, protocols and processes should be clear and Rules, protocols and processes should be clear and transparent.transparent.

•• Rules should be technology neutral, except when Rules should be technology neutral, except when differences are fully justified.differences are fully justified.

•• A level playing field should be established for all DG A level playing field should be established for all DG providers.providers.

•• Rules should be uniform throughout California.Rules should be uniform throughout California.

•• Utilities should be fairly compensated for Utilities should be fairly compensated for distribution services that support DG installations distribution services that support DG installations and customers. and customers.

What Were the Guiding Principles?What Were the Guiding Principles?




Rule 21 Rule 21 -- HighlightsHighlights

CPUC Jurisdictional Projects OnlyCPUC Jurisdictional Projects Only

Application ProcessApplication Process

▲▲ Standard CPUC FormStandard CPUC Form

▲▲ Application Fee:Application Fee:

➤➤ $800: Initial Review Only$800: Initial Review Only

➤➤ $600 Additional: Supplemental Review$600 Additional: Supplemental Review

➤➤ Cost Estimate for IC StudyCost Estimate for IC Study

▲▲ Utilities to Complete Within 10/20 DaysUtilities to Complete Within 10/20 Days

(Initial/Supplemental Reviews Only)(Initial/Supplemental Reviews Only)




•• Interconnection FeesInterconnection Fees

•• Testing and Certification Testing and Certification ProceduresProcedures

•• Clear Engineering Review ProcessClear Engineering Review Process

•• Interconnection AgreementsInterconnection Agreements

•• Application Forms (Paper and Application Forms (Paper and Electronic)Electronic)

•• Process for Continuing Process for Continuing RefinementRefinement

Issues Addressed by the Rule 21 Working Issues Addressed by the Rule 21 Working GroupGroup




Technical Basis for Rule 21Technical Basis for Rule 21

Safety Is Safety Is FirstFirst PriorityPriority

PerformancePerformance--BasedBasedTechnical RequirementsTechnical Requirements

Identify Review Time and PotentialIdentify Review Time and PotentialCostsCosts

TechnologyTechnology--NeutralNeutral




Rule 21 Technical Requirements Rule 21 Technical Requirements

Section D Section D -- Design & OperatingDesign & OperatingRequirementsRequirements

1. 1. GeneralGeneral

•• Protective FunctionsProtective Functions

•• Momentary ParallelingMomentary Paralleling

•• Equipment RequirementsEquipment Requirements

•• Visible DisconnectVisible Disconnect

•• DrawingsDrawings RequiredRequired DG Section D




Rule 21 Technical Requirements Rule 21 Technical Requirements (cont.)(cont.)


2. Prevention of Interference2. Prevention of Interference

•• Normal Voltage Operating RangeNormal Voltage Operating Range

•• FlickerFlicker

•• FrequencyFrequency

•• HarmonicsHarmonics

•• Power FactorPower Factor






3. Control & Protective Functions3. Control & Protective Functions

•• Technology Specific RequirementsTechnology Specific Requirements

•• Mitigation of Unintended IslandingMitigation of Unintended Islanding

•• Fault DetectionFault Detection





Section I Section I -- Review ProcessReview Process

Determines:Determines:

•• Simplified Interconnection (via InitialSimplified Interconnection (via InitialReview)Review)

•• Supplemental Review Determines If ThereSupplemental Review Determines If ThereAre Additional Requirements forAre Additional Requirements forInterconnection or...Interconnection or...

•• If an Interconnection Study Is RequiredIf an Interconnection Study Is Required




“The Review/Screening Process”

Networked Secondary System?

Equipment Certified?

Starting Voltage Drop Screen Met?

11 kVA Or Less?

Meets Short Circuit Current Contribution Screen?

Meets LineConfiguration Screen?

Qualifies for Simplified

Interconnection

Yes

No

Yes

No

Yes

Power Exported?

No

Aggregate Capacity < 15% ofLine Section Peak Load?

Yes

SupplementalReview

No

No

No

No

No

Qualifiesfor

Interconnection

Yes

Yes

Yes

Yes

Utility ProvidesCost &

Schedule forInterconnection

Study

$800

$600

“or”





Section I Section I -- Supplemental ReviewSupplemental Review

–– Guideline Developed in 2002 Through Guideline Developed in 2002 Through Rule 21 Working Group ProcessRule 21 Working Group Process

–– Goals: Identify Review Criteria and Goals: Identify Review Criteria and Study Requirements Study Requirements

–– Draft Issued in JanuaryDraft Issued in January20032003





Section J Section J -- Testing and CertificationTesting and Certification

–– Certification CriteriaCertification Criteria

–– Type TestingType Testing

•• Individual Tests Individual Tests -- By Technology TypeBy Technology Type

•• UL 1741 ReferencedUL 1741 Referenced

•• Surge Withstand TestSurge Withstand Test

CERTIFICATION





Section J Section J -- Testing/CertificationTesting/Certification

-- Production TestingProduction Testing

-- Commissioning TestingCommissioning Testing

•• General RequirementsGeneral Requirements

•• Protective Functions to Be Protective Functions to Be TestedTested

•• Impact of CertificationImpact of Certification

•• Verification of SettingsVerification of Settings

•• Trip TestTrip Test




For More Information...For More Information...

Scott TomashefskyScott Tomashefsky

California Energy CommissionCalifornia Energy Commission

[email protected]@energy.state.ca.uswww.energy.ca.www.energy.ca.govgov//distgendistgen/interconnection/interconnection.html/interconnection/interconnection.html




Other State RequirementsOther State Requirements

•• NY SIR NY SIR http://www.dps.state.ny.us/distgen.htmhttp://www.dps.state.ny.us/distgen.htm

•• Texas: Texas: http://www.puc.state.tx.us/electric/projects/21965/21965.cfmhttp://www.puc.state.tx.us/electric/projects/21965/21965.cfmhttp://www.puc.state.tx.us/rules/subrules/electric/25.211/25.211http://www.puc.state.tx.us/rules/subrules/electric/25.211/25.211ei.cfmei.cfm

•• Good resource: Good resource: www.irecusa.orgwww.irecusa.org–– Sign up for Steve Sign up for Steve Kalland’sKalland’s newsletter newsletter




1.1. StandardsStandards: documents with : documents with mandatory requirements mandatory requirements (shall)(shall)

2.2. Recommended PracticesRecommended Practices: documents in which : documents in which procedures and positions preferred procedures and positions preferred by the IEEE are presented by the IEEE are presented (should)(should)

3.3. GuidesGuides: documents in which alternative approaches: documents in which alternative approachesto good practice are suggested but to good practice are suggested but no clearno clear--cut recommendations are made cut recommendations are made (may)(may)

IEEE Standards areIEEE Standards are Voluntary.Voluntary.

IEEE Standards ClassificationsIEEE Standards Classifications




P929Recommended Practice forUtility Interface ofPhotovoltaic (PV) Systems

Prepared by the Utility Working Group ofStandards Coordinating Committee 21, on Photovoltaics

Copyright © 1998 by the Institute of Electrical and Electronic Engineers, Inc.345 East 47th StreetNew York, NY 10017, USAAll Rights Reserved

This is an IEEE Standards Project, subject to change. Permission is hereby granted forIEEE Standards committee participants to reproduce this document for purposes ofIEEE standardization activities, including balloting and coordination. If this documentis to be submitted to ISO or IEC, notification shall be given to the IEEE CopyrightsAdministrator. Permission is also granted for member bodies and technical committeesof ISO and IEC to reproduce this document for purposes of developing a nationalposition. Other entities seeking permission to reproduce portions of this document forthese or other uses must contact the IEEE Standards Department for the appropriatelicense. Use of information contained in the unapproved draft is at your own risk.

IEEE Standards DepartmentCopyrights and Permissions445 Hoes Lane, P.O. Box 1331Piscataway, NJ 08855-1331, USA

IEEE 929IEEE 929--20002000

•• Passed by IEEE Passed by IEEE Standards Board Standards Board in January, 2000.in January, 2000.

•• Provides an Provides an excellent primer excellent primer on PV inverter on PV inverter interconnection interconnection issues.issues.




The Need for PV Interconnection The Need for PV Interconnection StandardsStandards

●● Many utilities were using rotating machinery Many utilities were using rotating machinery requirements for PV systemsrequirements for PV systems

●● Many of the Interconnection Requirements Many of the Interconnection Requirements were established in early were established in early ““PURPAPURPA”” daysdays•• too many requirementstoo many requirements

•• telemeterytelemetery and and ““Utility GradeUtility Grade”” relaysrelays

•• special (and costly) engineering was needed for special (and costly) engineering was needed for each specific utility requirementeach specific utility requirement




Purpose of IEEE 929Purpose of IEEE 929

““This recommended practice contains guidance This recommended practice contains guidance regarding equipment and functions necessary to regarding equipment and functions necessary to ensure compatible operation of photovoltaic ensure compatible operation of photovoltaic systems which are connected in parallel with systems which are connected in parallel with the electric utility. This includes factors the electric utility. This includes factors relating to relating to personnel safetypersonnel safety, , equipment equipment protectionprotection, , power qualitypower quality and and utility system utility system operationoperation..””




IEEE 929 Working Group IEEE 929 Working Group Consisted of Utilities and IndustryConsisted of Utilities and Industry

John Stevens, ChairSandia National Labs

D. Lane GarrettSouthern Co. Services

Miles Russell, Secr.Ascension Technology

Mike Behnke Trace Technology

Steve Hester, UPVG

John Moriarty Raytheon

Bill Brooks N. Carolina Sol. Center

John Hoffner, Planergy (ex Austin Electric)

Chet Napikoski Arizona Public Service

John Bzura New England Electric

Barry Hornberger PECO Energy

Jean Posbic Solarex

Steve Chalmers (Ret.) Salt River Project

Bob Jones Rochester G&E

Jodi Smythe Underwriters Labs

Joe Chau Florida Power & Light

Greg Kern Ascension Technology

Chase Sun Pacific Gas and Electric

Doug Dawson (Ret.) Southern Cal Edison

Leslie Libby Austin Electric

Rick West UPG

Dick DeBlasio Chair – IEEE SCC 21

Don Loweberg IPP

Chuck Whitaker Endecon

Tom Duffy Central Hudson G&E

Tron Melzl Omnion

Robert Wills Advanced Energy Sys.

Chris Freitas Trace Engineering

Tim Zgonena Underwriters Labs




What Does IEEE 929 Really Impact?What Does IEEE 929 Really Impact?

PV ArrayInverterMUtilitySystem




IEEE 929 OutlineIEEE 929 Outline

•• IntroductionIntroduction

•• 1. Overview (scope & purpose)1. Overview (scope & purpose)

•• 2. References2. References

•• 3. Definitions (inverter, islanding, PCC, 3. Definitions (inverter, islanding, PCC, quality factor, etc.)quality factor, etc.)

•• 4. Power quality4. Power quality

•• 5. Safety and protection functions5. Safety and protection functions

•• AnnexesAnnexes




IEEE 929IEEE 929--2000 2000 Power QualityPower Quality

•• Power quality problems in general are rising Power quality problems in general are rising because of proliferation of nonbecause of proliferation of non--linear loads on linear loads on utility systems utility systems ---- all customers sufferall customers suffer

•• PV should not add to that problemPV should not add to that problem




IEEE 929IEEE 929--2000 Power Quality2000 Power Quality

•• Power QualityPower Quality–– 1. Service Voltage1. Service Voltage

•• Inverters inject current, donInverters inject current, don’’t regulate voltaget regulate voltage•• Voltage operating range is a protective functionVoltage operating range is a protective function

–– 2. Voltage Flicker2. Voltage Flicker•• IEEE 519IEEE 519--19921992

–– 3. Frequency3. Frequency•• Frequency operating range is a protective functionFrequency operating range is a protective function

–– 4. Waveform Distortion4. Waveform Distortion•• IEEE 519IEEE 519--19921992

–– 5. Power Factor5. Power Factor•• >0.85 at >10% of rated output power>0.85 at >10% of rated output power




IEEE 929IEEE 929--2000 2000 Safety and Protection FunctionsSafety and Protection Functions

•• Response to Abnormal Utility ConditionsResponse to Abnormal Utility Conditions–– Voltage DisturbancesVoltage Disturbances–– Frequency DisturbancesFrequency Disturbances–– Islanding ProtectionIslanding Protection

•• Annex A AntiAnnex A Anti--Islanding TestIslanding Test

–– Reconnect After a Utility DisturbanceReconnect After a Utility Disturbance•• 5 min delay5 min delay

•• Direct Current IsolationDirect Current Isolation–– <0.5% of rated output current<0.5% of rated output current

•• GroundingGrounding–– Meet local codesMeet local codes

•• Manual DisconnectManual Disconnect–– Not required for nonNot required for non--islanding invertersislanding inverters




IEEE 929IEEE 929--2000 Response to 2000 Response to Abnormal Utility ConditionsAbnormal Utility Conditions

Voltage (at PCC) Maximum Trip Time* V< 60 (V<50%) 6 cycles 60≤V<106 (50%≤V<88%) 120 cycles

106≤V≤132 (88%≤V≤110%) Normal Operation 132<V<165 (110%<V<137%) 120 cycles

165≤V (137%≤V) 2 cycles Frequency (at PCC) Maximum Trip Time*

<59.3 Hz 6 cycles 59.3 - 60.5 Hz (normal) --

>60.5 Hz 6 cycles

*”Trip time” refers to the time between the abnormal condition being applied and the inverter ceasing to energize the utility line. The inverter will actually remain connected to the utility to allow sensing of utility electrical conditions for use by the “reconnect” feature.




IEEE 929IEEE 929--2000 2000 Manual Disconnect SwitchManual Disconnect Switch

PV Array

InverterM

LocalLoads

UtilitySystem




IEEE 929IEEE 929--2000 2000 -- AnnexesAnnexes

•• Annex Annex A (Normative)A (Normative) –– Minimum Test Procedure for Minimum Test Procedure for a Nona Non--Islanding PV InverterIslanding PV Inverter

•• Annex Annex B (Informative)B (Informative) -- BibliographyBibliography•• Annex Annex CC -- PV Inverters and the Utility InterfacePV Inverters and the Utility Interface

(Terminology)(Terminology)•• Annex Annex DD -- Disconnect Switches & Utility ProceduresDisconnect Switches & Utility Procedures•• Annex Annex EE -- Islanding as it Applies to PV SystemsIslanding as it Applies to PV Systems•• Annex Annex FF -- The PV Inverter Under Utility Fault The PV Inverter Under Utility Fault

ConditionsConditions•• Annex Annex GG -- Dedicated Distribution TransformerDedicated Distribution Transformer




IEEE 1547IEEE 1547--20032003

Standard for Interconnecting Standard for Interconnecting Distributed Resources with Electric Distributed Resources with Electric

Power Systems Power Systems

(Thanks to Richard DeBlasio and Tom Basso)(Thanks to Richard DeBlasio and Tom Basso)




1547 Standard for Interconnecting Distributed Resources with Electric Power Systems

P1547.1Draft Standard for Conformance Test Procedures for Equipment Interconnecting Distributed Resources with Electric Power Systems

P1547.2Draft Application Guide for IEEE P1547 Draft Standard for Interconnecting Distributed Resources with Electric Power Systems

Guide for Networks Guide for Impacts

Guide for Islanding & Anti-Islanding

DR Specifications and Performance

Guide For

Interconnection System

Certification

P1547.3Draft Guide for Monitoring, Information Exchange and Control of DR Interconnected with EPS

IEEE 1547 Body of StandardsIEEE 1547 Body of Standards




Round 1Round 1---- Draft 7Draft 7•• Balloting completed 4/1/01Balloting completed 4/1/01•• 91% ballot returns91% ballot returns•• 66% affirmative66% affirmative•• Addressed negative commentsAddressed negative comments

Voter Category Affirm Negative Voter Category Affirm Negative -- User User 30 2330 23-- Producer Producer 35 12 35 12 -- General Interest 28 15General Interest 28 15

Requirements for adoption: 75% ballot return, 75% affirmativeRequirements for adoption: 75% ballot return, 75% affirmative

Round 2 Round 2 ---- Draft 8Draft 8•• Recirculation completed 10/2/01Recirculation completed 10/2/01•• 96% ballot returns96% ballot returns•• 66% affirmative66% affirmative•• New Draft TBDNew Draft TBD

Voter Category Affirm Negative Voter Category Affirm Negative -- User User 25 3325 33-- Producer Producer 43 6 43 6 -- General Interest 35 14General Interest 35 14

IEEE P1547 IEEE P1547 Drafts 7 and 8 Ballot StatusDrafts 7 and 8 Ballot Status




Requirements for adoption: 75% ballot returns, 75% affirmativRequirements for adoption: 75% ballot returns, 75% affirmatives es

Ballot ResultsBallot Results•• Ballot Action August 28 Ballot Action August 28 -- September 26, 2002 September 26, 2002 •• 93% ballot returns (230 in ballot group) 93% ballot returns (230 in ballot group) •• 90% affirmatives 90% affirmatives •• 10% negatives 10% negatives •• 3% abstentions 3% abstentions

Voter Category Affirmatives Negatives Voter Category Affirmatives Negatives -- UserUser 63 63 99-- ProducerProducer 57 57 4 4 -- General InterestGeneral Interest 59 59 6 6 -- GovernmentGovernment 88 1 1

Voting Tally Voting Tally 187187 20 20

IEEE P1547 Draft 10 Ballot StatusIEEE P1547 Draft 10 Ballot Status




Requirements for adoption: 75% ballot returns, 75% affirmativeRequirements for adoption: 75% ballot returns, 75% affirmatives s •• June 2003: IEEE Standards Board Meeting June 2003: IEEE Standards Board Meeting

Ballot ResultsBallot Results•• Ballot Action February 7 Ballot Action February 7 -- 28, 2003 28, 2003 •• 95% ballot returns (230 in ballot group) 95% ballot returns (230 in ballot group) •• 89% affirmatives 89% affirmatives •• 9% negatives 9% negatives •• 2% abstentions 2% abstentions

IEEE P1547 Draft 11 Ballot StatusIEEE P1547 Draft 11 Ballot Status

APPROVED

APPROVED




1547: Interconnection Is The Focus 1547: Interconnection Is The Focus

Distributed Resource

(DR) unit

Area Electric Power

System (EPS)

Interconnection

System




Local EPS 1

Area Electric Power System (EPS)

Local EPS 3

PCC

Point of DR Connection

DR unit

Local EPS 2

Point of DR Connection

Point of Common Coupling (PCC)

Note: There can be any number of Local EPSs.

PCC

DR unit Load Load

1547 Interconnection Terms 1547 Interconnection Terms




INTRODUCTION INTRODUCTION

1.01.0 OVERVIEW OVERVIEW 1.1 1.1 Scope Scope 1.2 1.2 Purpose Purpose 1.3 1.3 Limitations Limitations

2.02.0 REFERENCES REFERENCES

3.03.0 DEFINITIONSDEFINITIONS

IEEE 1547IEEE 1547--2003 2003 ContentsContents




IEEE 1547IEEE 1547--2003 2003 ContentsContents1.1 Scope1.1 Scope

This standard This standard establishes criteria and requirementsestablishes criteria and requirements for interconnection of for interconnection of distributed resources (DR) with electric power systems (EPS).distributed resources (DR) with electric power systems (EPS).

1.2 Purpose1.2 PurposeThis document provides a uniform standard for interconnection ofThis document provides a uniform standard for interconnection of distributed distributed resources with electric power systems. It provides requirements resources with electric power systems. It provides requirements relevant to relevant to the performance, operation, testing, safety considerations, and the performance, operation, testing, safety considerations, and maintenance maintenance of the interconnection.of the interconnection.The requirements shall be The requirements shall be met at the point of common coupling (PCC), met at the point of common coupling (PCC), although the devices used to meet these requirements can be locaalthough the devices used to meet these requirements can be located ted elsewhereelsewhere. This standard applies to interconnection based on the . This standard applies to interconnection based on the aggregate aggregate ratingrating of all the DR units that are within the Local EPS. The of all the DR units that are within the Local EPS. The functionsfunctions of the of the interconnection system hardware and software that affect the Areinterconnection system hardware and software that affect the Area EPS a EPS are are requiredrequired to meet this standard to meet this standard regardless of their locationregardless of their location on the EPS.on the EPS.The The stated specifications and requirementsstated specifications and requirements, both technical and testing, are , both technical and testing, are universally neededuniversally needed for interconnection of DR, including synchronous for interconnection of DR, including synchronous machines, induction machines, or power inverters/converters, andmachines, induction machines, or power inverters/converters, and will be will be sufficient for most installations.sufficient for most installations.11

11 Additional technical requirements and/or tests may be necessary Additional technical requirements and/or tests may be necessary for some limited situationsfor some limited situations..




4.04.0 INTERCONNECTION TECHNICAL SPECIFICATIONS AND INTERCONNECTION TECHNICAL SPECIFICATIONS AND REQUIREMENTSREQUIREMENTS

4.1 General Requirements 4.1 General Requirements 4.2 Response to Area EPS Abnormal Conditions4.2 Response to Area EPS Abnormal Conditions4.3 Power Quality 4.3 Power Quality 4.4 Islanding 4.4 Islanding

5.0 INTERCONNECTION TEST SPECIFICATIONS AND 5.0 INTERCONNECTION TEST SPECIFICATIONS AND REQUIREMENTS REQUIREMENTS

5.15.1 Design Test Design Test 5.25.2 Production Tests Production Tests 5.35.3 Interconnection Installation Evaluation Interconnection Installation Evaluation 5.45.4 Commissioning Tests Commissioning Tests 5.55.5 Periodic Interconnection Tests Periodic Interconnection Tests

ANNEX A (INFORMATIVE) BIBLIOGRAPHYANNEX A (INFORMATIVE) BIBLIOGRAPHY

IEEE 1547IEEE 1547--20032003 ContentsContents




IEEE 1547IEEE 1547--20032003 ContentsContents4.1 General Requirements4.1 General Requirements

4.1.1 Voltage Regulation4.1.1 Voltage Regulation (Don’t!)(Don’t!)4.1.2 Integration with Area EPS Grounding 4.1.2 Integration with Area EPS Grounding (Coordinate)(Coordinate)4.1.3 Synchronization 4.1.3 Synchronization (<5% voltage fluctuation, no flicker)(<5% voltage fluctuation, no flicker)4.1.4 Distributed Resources on Distribution Secondary Grid and S4.1.4 Distributed Resources on Distribution Secondary Grid and Spot pot

NetworksNetworks4.1.4.1 Distribution Secondary Grid Networks4.1.4.1 Distribution Secondary Grid Networks4.1.4.2 Distribution Secondary Spot Networks4.1.4.2 Distribution Secondary Spot Networks

4.1.5 Inadvertent Energization of the Area EPS 4.1.5 Inadvertent Energization of the Area EPS (Don’t!)(Don’t!)4.1.6 Monitoring Provisions4.1.6 Monitoring Provisions4.1.7 Isolation Device4.1.7 Isolation Device (Disconnect Switch)(Disconnect Switch)4.1.8 Interconnect Integrity4.1.8 Interconnect Integrity

4.1.8.1 Protection from Electromagnetic Interference 4.1.8.1 Protection from Electromagnetic Interference (C37.90.2)(C37.90.2)4.1.8.2 Surge Withstand Performance 4.1.8.2 Surge Withstand Performance (C62.41 or C37.90.1)(C62.41 or C37.90.1)4.1.8.3 Paralleling Device 4.1.8.3 Paralleling Device (withstand 220% of rated voltage)(withstand 220% of rated voltage)




IEEE 1547IEEE 1547--20032003 ContentsContents4.2 Response to Area EPS Abnormal Conditions4.2 Response to Area EPS Abnormal Conditions

4.2.1 Area EPS Faults 4.2.1 Area EPS Faults (detect faults, cease to energize)(detect faults, cease to energize)4.2.2 Area EPS Reclosing Coordination4.2.2 Area EPS Reclosing Coordination (coordinate)(coordinate)4.2.3 Voltage 4.2.3 Voltage (<60V,106V (<60V,106V –– 132V, >144V)132V, >144V)4.2.4 Frequency 4.2.4 Frequency (59.3 (59.3 –– 60.5 Hz)60.5 Hz)4.2.5 Loss of Synchronism 4.2.5 Loss of Synchronism (not required unless there is flicker)(not required unless there is flicker)4.2.6 Reconnection To Area EPS 4.2.6 Reconnection To Area EPS (up to 5 min, C84.1 Range B)(up to 5 min, C84.1 Range B)

4.3 Power Quality4.3 Power Quality4.3.1 Limitation of DC Injection 4.3.1 Limitation of DC Injection (>0.5% of rated output current)(>0.5% of rated output current)4.3.2 Limitation of Flicker Induced by the DR 4.3.2 Limitation of Flicker Induced by the DR (Don’t)(Don’t)4.3.3 Harmonics 4.3.3 Harmonics (~IEEE 519)(~IEEE 519)

4.4 Islanding4.4 Islanding4.4.1 Unintentional Islanding 4.4.1 Unintentional Islanding (Don’t)(Don’t)4.4.2 Intentional Islanding 4.4.2 Intentional Islanding (Don’t know)(Don’t know)





55..0 INTERCONNECTION TEST SPECIFICATIONS AND 0 INTERCONNECTION TEST SPECIFICATIONS AND REQUIREMENTSREQUIREMENTS

5.1 Design Test5.1 Design Test5.1.1 Response to Abnormal Voltage and Frequency5.1.1 Response to Abnormal Voltage and Frequency5.1.2 Synchronization5.1.2 Synchronization5.1.3 Interconnect Integrity Test5.1.3 Interconnect Integrity Test5.1.3.1 Protection From Electromagnetic Interference (EMI)5.1.3.1 Protection From Electromagnetic Interference (EMI)

5.1.3.2 Surge Withstand Performance5.1.3.2 Surge Withstand Performance5.1.3.3 Paralleling Device5.1.3.3 Paralleling Device

5.1.4 Unintentional Islanding 5.1.4 Unintentional Islanding 5.1.5 Limitation of DC Injection5.1.5 Limitation of DC Injection5.1.6 Harmonics5.1.6 Harmonics

5.2 Production Tests5.2 Production Tests





5.3 Interconnection Installation Evaluation5.3 Interconnection Installation Evaluation5.3.1 Grounding Integration with Area Electric Power System5.3.1 Grounding Integration with Area Electric Power System5.3.2 Isolation Device5.3.2 Isolation Device5.3.3 Monitoring Provisions5.3.3 Monitoring Provisions5.3.4 Area EPS Faults5.3.4 Area EPS Faults5.3.5 Area EPS Reclosing Coordination.5.3.5 Area EPS Reclosing Coordination.

5.4 Commissioning Tests5.4 Commissioning Tests5.4.1 Unintentional Islanding Functionality Test5.4.1 Unintentional Islanding Functionality Test

5.4.1.1 Reverse5.4.1.1 Reverse--Power or Minimum Power TestPower or Minimum Power Test5.4.1.2 Non5.4.1.2 Non--Islanding Functionality Test7Islanding Functionality Test75.4.1.3 Other Unintentional Islanding Functionality Tests5.4.1.3 Other Unintentional Islanding Functionality Tests

5.4.2 Cease to Energize Functionality Test5.4.2 Cease to Energize Functionality Test

5.5 Periodic Interconnection Tests5.5 Periodic Interconnection Tests




IEEE P1547.1IEEE P1547.1

• Verifies Conformance to IEEE 1547-2003

• Provides Test Procedures and order, but does not define a comprehensive Certification Process

Draft Standard for Conformance Test Procedures Draft Standard for Conformance Test Procedures for Equipment Interconnecting Distributed for Equipment Interconnecting Distributed Resources with Electric Power Systems Resources with Electric Power Systems





Scope:Scope:

This standard specifies the type, production, and commissioning tests that shall be performed to demonstrate that the interconnection functions and equipment of a distributed resource (DR) conform to IEEE Standard P1547.

Draft Standard for Conformance Test Procedures Draft Standard for Conformance Test Procedures for Equipment Interconnecting Distributed for Equipment Interconnecting Distributed Resources with Electric Power SystemsResources with Electric Power Systems





Purpose:Interconnection equipment that connects Interconnection equipment that connects distributed resources (DR) to an electric power distributed resources (DR) to an electric power system (EPS) must meet the requirements system (EPS) must meet the requirements specified in IEEE Standard P1547. Standardized specified in IEEE Standard P1547. Standardized test procedures are necessary to test procedures are necessary to establish and establish and verify complianceverify compliance with those requirements. These with those requirements. These test procedures must provide both test procedures must provide both repeatable repeatable resultsresults, independent of test location, and , independent of test location, and flexibilityflexibility to accommodate a variety of DR to accommodate a variety of DR technologies.technologies.




IEEE P1547.1 OutlineIEEE P1547.1 Outline1.0 Overview1.0 Overview2.0 References2.0 References3.0 Definitions3.0 Definitions4.0 General Requirements4.0 General Requirements5.0 Type Tests5.0 Type Tests6.0 Production Tests6.0 Production Tests7.0 Commissioning Tests7.0 Commissioning TestsAnnex A (Normative) Test SignalsAnnex A (Normative) Test SignalsAnnex B (Informative) BibliographyAnnex B (Informative) BibliographyAnnex C (Informative) Sample Data Pages for Annex C (Informative) Sample Data Pages for

Temperature Stability TestTemperature Stability Test




IEEE P1547.1 OutlineIEEE P1547.1 Outline

4.0 General Requirements4.0 General Requirements

4.1 Test result accuracy 4.1 Test result accuracy (verify Mfg stated accuracy)(verify Mfg stated accuracy)

4.2 Testing Environment 4.2 Testing Environment ((--5 to +40°C minimum)5 to +40°C minimum)

4.3 Measurement accuracy and calibration of the 4.3 Measurement accuracy and calibration of the testing equipmenttesting equipment

4.4 Product information4.4 Product information

4.5 Test Reports4.5 Test Reports

4.6 Source requirements4.6 Source requirements





5.1 Test for Response to Abnormal Voltage Conditions5.1 Test for Response to Abnormal Voltage Conditions5.1.1 Test for Overvoltage 5.1.1 Test for Overvoltage (Separate magnitude and timing)(Separate magnitude and timing)

5.1.2 Test for Undervoltage5.1.2 Test for Undervoltage5.2 Test for Response to Abnormal Frequency Conditions5.2 Test for Response to Abnormal Frequency Conditions

5.2.1 Test for 5.2.1 Test for OverfrequencyOverfrequency (Separate magnitude and timing)(Separate magnitude and timing)

5.2.2 Test for Underfrequency5.2.2 Test for Underfrequency5.3 Test for Synchronization5.3 Test for Synchronization

5.3.1 Synchronization Control Function using Simulated 5.3.1 Synchronization Control Function using Simulated Sources (Method 1) Sources (Method 1) (vary V, (vary V, ff, , ΦΦ))

5.3.2 Synchronization Control Function using Actual 5.3.2 Synchronization Control Function using Actual Generator Equipment (Method 1)Generator Equipment (Method 1)

5.3.3 Startup Current Measurement (Method 2) 5.3.3 Startup Current Measurement (Method 2)





5.4 Interconnection Integrity Tests 5.4 Interconnection Integrity Tests

5.4.1 Protection From Electromagnetic Interference 5.4.1 Protection From Electromagnetic Interference (EMI) (EMI) (C37(C37--90.2)90.2)

5.4.2 Surge Withstand Performance 5.4.2 Surge Withstand Performance (C62.41/C37(C62.41/C37--90.1)90.1)

5.4.3 Paralleling Device5.4.3 Paralleling Device (Hi Pot)(Hi Pot)

5.5 Test for Limitation of DC Injection5.5 Test for Limitation of DC Injection

5.5.1 DR with interconnection transformer 5.5.1 DR with interconnection transformer (Saturation)(Saturation)

5.5.2 Inverter5.5.2 Inverter--based DR without interconnection based DR without interconnection transformertransformer

5.6 Unintentional Islanding5.6 Unintentional Islanding




IEEE P1547.1 Draft 2: IslandingIEEE P1547.1 Draft 2: Islanding

•• Unintentional Islanding of exporting DR is a bad thingUnintentional Islanding of exporting DR is a bad thing

•• Inverter/inductionInverter/induction--based DR that is not attempting to based DR that is not attempting to regulate voltage is nearly impossible to make islandregulate voltage is nearly impossible to make island

•• For now, “nearly” is enough of a concernFor now, “nearly” is enough of a concern

•• PV inverter Islanding testing goes back more than 20 yrsPV inverter Islanding testing goes back more than 20 yrs

•• Sandia responsible for development of 929/1741 test Sandia responsible for development of 929/1741 test procedure (procedure (www.www.sandiasandia..govgov//pvpv/docs//docs/InvertesintroInvertesintro..htmhtm ))





•• Resonant Tank circuit used to stabilize island Resonant Tank circuit used to stabilize island voltage and frequencyvoltage and frequency

•• Real load to generation match determines Real load to generation match determines operating voltageoperating voltage

•• Capacitance to Inductance match determines Capacitance to Inductance match determines operating frequencyoperating frequency

•• Quality factor, Q, defines circuit resonance:Quality factor, Q, defines circuit resonance:

kW

kVARkVARQ CL ×

=




AntiAnti--Islanding Test CircuitIslanding Test Circuit

DRDR

S3S3

LR C

S2S2S1S1

SimulatedSimulatedUtilityUtility





•• Test performed over range of output power Test performed over range of output power levels with Q=1.8 (IEEE 929 and current 1741 levels with Q=1.8 (IEEE 929 and current 1741 use Q=2.5)use Q=2.5)

•• Under stable, matched conditions, such as Under stable, matched conditions, such as specified in the procedure, an inverter relying specified in the procedure, an inverter relying only on frequency and voltage trip points will only on frequency and voltage trip points will run on indefinitely run on indefinitely

•• Additional detection methods must be Additional detection methods must be employed to meet 2 second trip requirementemployed to meet 2 second trip requirement





•• Test is intended to be detectionTest is intended to be detection--method method neutralneutral

•• Other methodOther method--specific or less rigorous tests are specific or less rigorous tests are being consideredbeing considered





5.75.7 Reverse Power (for unintentional islanding)Reverse Power (for unintentional islanding)5.7.1 Reverse5.7.1 Reverse--Power Magnitude TestPower Magnitude Test

5.7.2 Reverse5.7.2 Reverse--Power Time TestPower Time Test

5.85.8 Cease to Energize Functionality and Loss of Cease to Energize Functionality and Loss of Phase Test RequirementsPhase Test Requirements

5.95.9 Reconnect Following Abnormal Condition Reconnect Following Abnormal Condition Disconnect Disconnect (restart magnitude and delay)(restart magnitude and delay)

5.105.10 HarmonicsHarmonics

5.115.11 Temperature Stability Test Temperature Stability Test





6.0 Production Tests 6.0 Production Tests (simplified versions of Type (simplified versions of Type Tests)Tests)

6.1 Response to Abnormal Voltage6.1 Response to Abnormal Voltage

6.2 Response to Abnormal Frequency 6.2 Response to Abnormal Frequency

6.3 Synchronization6.3 Synchronization

6.4 Documentation 6.4 Documentation





7 Commissioning Tests7 Commissioning Tests7.1 Verifications and Inspections7.1 Verifications and Inspections

7.2 Field Conducted Type and Production tests7.2 Field Conducted Type and Production tests

7.3 Permission from Area EPS operator to parallel DR7.3 Permission from Area EPS operator to parallel DR

7.4 Unintentional Islanding7.4 Unintentional Islanding7.4.17.4.1 Unintentional Islanding Procedure for Synchronous Unintentional Islanding Procedure for Synchronous

machinemachine7.4.27.4.2 Unintentional Islanding Procedure for InverterUnintentional Islanding Procedure for Inverter




IEEE P1547.1 StatusIEEE P1547.1 Status

•• Writing Committee is preparing Draft 3 for Writing Committee is preparing Draft 3 for review at Nov 12review at Nov 12--14 workgroup meeting14 workgroup meeting

•• Section 5 (Type Tests) is fairly well developedSection 5 (Type Tests) is fairly well developed

•• Section 6 (Production Tests) has first cuts for Section 6 (Production Tests) has first cuts for most elements most elements

•• Section 7 (Commissioning Test) is under initial Section 7 (Commissioning Test) is under initial developmentdevelopment

•• Expect to have document approved by June Expect to have document approved by June 20052005





Thanks to Tom Basso and Richard FriedmanThanks to Tom Basso and Richard Friedman

Draft Application Guide For IEEE Std. 1547, Draft Application Guide For IEEE Std. 1547, Standard For Interconnecting Distributed Standard For Interconnecting Distributed Resources With Electric Power SystemsResources With Electric Power Systems





Scope:Scope:

This guide provides technical background and application details to support the understanding of IEEE 1547, Standard for Interconnecting Distributed Resources with Electric Power Systems.





Purpose:This document facilitates the use of IEEE Std. 1547 by characterizing the various forms of distributed resource technologies and the associated interconnection issues. Additionally, the background and rationale of the technical requirements are discussed in terms of the operation of the distributed resource interconnection with the electric power system. Presented in the document are technical descriptions and schematics, applications guidance and interconnection examples to enhance the use of IEEE 1547.




What P1547.2 is Intended to DoWhat P1547.2 is Intended to Do

• Providing technical background

• Providing application details

• Characterizing various forms of DR technologies

• Characterizing associated interconnection issues

• Discussing background and rationale of the technical requirements in terms of the operation of the interconnection

• Presenting good practice approaches

Support understanding and facilitate use of IEEE 1547 by




What P1547.2 Will What P1547.2 Will NOTNOT DoDo

•• Interpret IEEE 1547Interpret IEEE 1547

•• Introduce new requirements to IEEE 1547Introduce new requirements to IEEE 1547

•• Address issues not covered in IEEE 1547, other Address issues not covered in IEEE 1547, other than as needed to help enhance the user's than as needed to help enhance the user's understanding of IEEE 1547understanding of IEEE 1547

•• Provide a "guarantee" that IEEE 1547 Provide a "guarantee" that IEEE 1547 requirements will be metrequirements will be met



EE NN GG II NN EE EE RR II NN GG 69

Other IEEE SCC21 Other IEEE SCC21 Interconnection ProjectsInterconnection Projects

TTiittllee SSccooppee aanndd PPuurrppoossee PP11554477..33:: DDrraafftt GGuuiiddee ffoorr MMoonniittoorriinngg,, IInnffoorrmmaattiioonn EExxcchhaannggee aanndd CCoonnttrrooll ooff DDiissttrriibbuutteedd RReessoouurrcceess IInntteerrccoonnnneecctteedd wwiitthh EElleeccttrriicc PPoowweerr SSyysstteemmss

•• TThhiiss ddooccuummeenntt pprroovviiddeess gguuiiddeelliinneess ffoorr mmoonniittoorriinngg,, iinnffoorrmmaattiioonn eexxcchhaannggee,, aanndd ccoonnttrrooll ffoorr ddiissttrriibbuutteedd rreessoouurrcceess ((DDRR)) iinntteerrccoonnnneecctteedd wwiitthh eelleeccttrriicc ppoowweerr ssyysstteemmss ((EEPPSS)).. •• TThhiiss ddooccuummeenntt ffaacciilliittaatteess tthhee iinntteerrooppeerraabbiilliittyy ooff oonnee oorr mmoorree ddiissttrriibbuutteedd rreessoouurrcceess iinntteerrccoonnnneecctteedd wwiitthh eelleeccttrriicc ppoowweerr ssyysstteemmss.. IItt ddeessccrriibbeess ffuunnccttiioonnaalliittyy,, ppaarraammeetteerrss aanndd mmeetthhooddoollooggiieess ffoorr mmoonniittoorriinngg,, iinnffoorrmmaattiioonn eexxcchhaannggee aanndd ccoonnttrrooll ffoorr tthhee iinntteerrccoonnnneecctteedd ddiissttrriibbuutteedd rreessoouurrcceess wwiitthh,, oorr aassssoocciiaatteedd wwiitthh,, eelleeccttrriicc ppoowweerr ssyysstteemmss.. DDiissttrriibbuutteedd rreessoouurrcceess iinncclluuddee ssyysstteemmss iinn tthhee aarreeaass ooff ffuueell cceellllss,, pphhoottoovvoollttaaiiccss,, wwiinndd ttuurrbbiinneess,, mmiiccrroottuurrbbiinneess,, ootthheerr ddiissttrriibbuutteedd ggeenneerraattoorrss,, aanndd,, ddiissttrriibbuutteedd eenneerrggyy ssttoorraaggee ssyysstteemmss..




• Dr. Richard DeBlasio [email protected] (303) 275 - 4333• Mr. Tom S. Basso [email protected] (303) 275 - 3753

• IEEE SCC21 -- IEEE Standards Coordinating Committee 21 on Fuel Cells, Photovoltaics, Dispersed Generation, & Energy Storage http://grouper.ieee.org/groups/scc21/

• 1547 web sites • http://grouper.ieee.org/groups/scc21/1547• http://grouper.ieee.org/groups/scc21/1547.1/1547.1_index.html• http://grouper.ieee.org/groups/scc21/1547.2/1547.2_index.html• http://grouper.ieee.org/groups/scc21/1547.3/1547.3_index.html

70

SCC 21 Contact InformationSCC 21 Contact Information




UL 1741UL 1741

Standard for Inverters, Converters and Standard for Inverters, Converters and Controllers for Use In Independent Controllers for Use In Independent Power SystemsPower Systems

(Thanks to Tim Zgonena of UL)(Thanks to Tim Zgonena of UL)




UL 1741 AddressesUL 1741 Addresses

•• Electric Shock HazardsElectric Shock Hazards•• Fire HazardsFire Hazards•• Mechanical HazardsMechanical Hazards•• Utility Compatibility and Utility Compatibility and

Interconnection for Grid Tied Interconnection for Grid Tied ApplicationsApplications




Electric Shock Hazards (Testing)Electric Shock Hazards (Testing)

•• Testing for prevention of electric shock Testing for prevention of electric shock includes:includes:–– Earth ground paths ability to carry currentEarth ground paths ability to carry current–– Dielectric tests verify insulation systemsDielectric tests verify insulation systems–– Induced faults to verify suitability of electrical Induced faults to verify suitability of electrical

insulation and operation of protective devices such insulation and operation of protective devices such as fuses, circuit breakers and thermal cut offsas fuses, circuit breakers and thermal cut offs




Electric Shock Hazards Electric Shock Hazards (Construction)(Construction)

•• Enclosure and BarriersEnclosure and Barriers

•• Insulate accessible live parts for both Insulate accessible live parts for both end users and service personnelend users and service personnel

•• Insulation between circuits of different Insulation between circuits of different potential or separation of circuitspotential or separation of circuits

•• Markings and labelingMarkings and labeling




Fire HazardsFire Hazards

•• Verification of normal operating temperaturesVerification of normal operating temperatures

•• Acceptable operation of transformers under Acceptable operation of transformers under short circuit and overload conditionsshort circuit and overload conditions

•• Under no circumstances shall a product emit Under no circumstances shall a product emit sparks, flames or molten metal sparks, flames or molten metal




Mechanical HazardsMechanical Hazards–– Sharp EdgesSharp Edges

–– Mounting means Mounting means

–– StabilityStability




•• Many of the performance issues Many of the performance issues associated with the grid interactive associated with the grid interactive operation of DG products are important operation of DG products are important Safety Issues. This is unlike many other Safety Issues. This is unlike many other product categories covered by UL product categories covered by UL Standards.Standards.

UL 1741UL 1741




Utility Compatibility and Utility Compatibility and Interconnection ConcernsInterconnection Concerns

•• The following performance parameters The following performance parameters are safety issuesare safety issues–– Utility operating voltage and frequency Utility operating voltage and frequency

parametersparameters–– Islanding protectionIslanding protection

–– Output Power QualityOutput Power Quality




Utility Voltage and Frequency Utility Voltage and Frequency Operating ParametersOperating Parameters

•• Products ability to detect and cease Products ability to detect and cease exporting power to the utility grid during exporting power to the utility grid during a utility grid over / under voltage or a utility grid over / under voltage or over / under frequency situationsover / under frequency situations–– The normal operating Voltage window is The normal operating Voltage window is

nominal nominal --12% to +10%12% to +10%–– The normal operating Frequency window is The normal operating Frequency window is

nominal nominal --0.7Hz to +0.5Hz0.7Hz to +0.5Hz




Voltage Frequency Variation Test Voltage Frequency Variation Test for 120V Rated Unitfor 120V Rated Unit

SSiimmuullaatteedd UUttiilliittyy SSoouurrccee MMaaxxiimmuumm TTrriipp TTiimmeeCCoonnddiittiioonn VVoollttaaggee,, VV FFrreeqquueennccyy,, HHzz sseeccoonnddss ccyycclleess

AA 6600 RRaatteedd 00..11 66 BB 110055..66 RRaatteedd 22 112200 CC RRaatteedd RRaatteedd NNoorrmmaall CCoonnddiittiioonn DD 113322 RRaatteedd 22 112200 EE 116644..44 RRaatteedd 22//6600 22 FF RRaatteedd 5599..33 00..11 66 GG RRaatteedd 6600..55 00..11 66

CALCULATIONS FROM TABLE 46.1




T1 >

1) Simulated Utility: 50 Volt 20 ms

dX: 100.0 ms X: 0 s

Under-Voltage Test

Scope Readout for Transient by Simulated Utility50% of Rated for 120V Unit




Islanding ProtectionIslanding Protection

•• IslandingIslanding is when a distributed source continues is when a distributed source continues to operate, feeding power into a portion of the to operate, feeding power into a portion of the grid when the utility source is no longer grid when the utility source is no longer present. This situation presents many hazards present. This situation presents many hazards including lethal electric shock to utility service including lethal electric shock to utility service personnel that think that the load side of the personnel that think that the load side of the utility transmission line is “electrically dead.”utility transmission line is “electrically dead.”

•• Utility and DG equipment damage.Utility and DG equipment damage.




AntiAnti--Islanding Test CircuitIslanding Test Circuit

SimulatedSimulatedUtilityUtility DRDR

S3S3

LR C

S2S2S1S1




Power QualityPower Quality

•• These utility interconnected DG products These utility interconnected DG products must meet minimum output power quality must meet minimum output power quality requirements requirements –– Output power Factor 0.85% or higherOutput power Factor 0.85% or higher–– Harmonic Distortion <5% at full output power Harmonic Distortion <5% at full output power –– DC Injection minimized to < 0.5% of rated output DC Injection minimized to < 0.5% of rated output

currentcurrent




UL 1741 Covers UL 1741 Covers Utility Interactive, StandUtility Interactive, Stand--alone, alone,

and Multiand Multi--Mode Products.Mode Products.

•• Utility InteractiveUtility Interactive -- Products that operate in Products that operate in parallel with or backfeed power to the utility parallel with or backfeed power to the utility grid to supply common loads.grid to supply common loads.

•• Stand AloneStand Alone -- Products that supply power to Products that supply power to loads independent of the utility grid.loads independent of the utility grid.

•• MultimodeMultimode -- Products that can operate in both Products that can operate in both utility interactive and standutility interactive and stand--alone modes in case alone modes in case of utility failure. of utility failure.




UL 1741 Expansion to Cover the UL 1741 Expansion to Cover the Interconnect of All Types of DGInterconnect of All Types of DG

•• UL1741 New Title UL1741 New Title -- The Standard For Inverters, The Standard For Inverters, Converters and Controllers For Use In Independent Converters and Controllers For Use In Independent Power Production Systems.Power Production Systems.–– Photovoltaic ModulesPhotovoltaic Modules

–– Fuel CellsFuel Cells

–– MicroMicro--turbinesturbines

–– Wind and Hydro TurbinesWind and Hydro Turbines

–– Engine GenEngine Gen--Set Interconnect ControllersSet Interconnect Controllers




UL 1741 StatusUL 1741 Status

•• Harmonized with IEEE 1547 and IEEE Harmonized with IEEE 1547 and IEEE P1547.1P1547.1

•• Developed as an ANSI StandardDeveloped as an ANSI Standard




•• UL1741 is being harmonized with UL1741 is being harmonized with IEEE 1547 and IEEE P1547.1IEEE 1547 and IEEE P1547.1




Tim Zgonena Tim Zgonena

Underwriters Laboratories Inc.Underwriters Laboratories Inc.333 333 PfingstenPfingsten Rd.Rd.Northbrook, IL 60062Northbrook, IL 60062

847847--272272--8800 ext. 430518800 ext. 43051timothy.p.timothy.p.zgonenazgonena@[email protected]

For More Information...For More Information...

On the Road to On the Road to ‘Plug‘Plug--&&--Play’ Play’ DGDG??

Anthony Mazy, PECALIFORNIA PUBLIC UTILITIES COMMISSION

Office of Ratepayer Advocates

An epilogue . . .An epilogue . . .

. . . about the limits of:

what we knowwhat we agree uponwhat we believe

CPUC CPUC regulates revenues, rates, and rules of serviceregulates revenues, rates, and rules of servicefor investorfor investor--owned electric, gas, telecom, and water utilitiesowned electric, gas, telecom, and water utilities

ORAORA represents the interests of small ratepayersrepresents the interests of small ratepayers

Anthony Mazy, PEAnthony Mazy, PEEnergy Auditor of over 225 Commercial/Industrial facilities, Energy Auditor of over 225 Commercial/Industrial facilities, Utilities Engineer for two major USAF bases, Utilities Engineer for two major USAF bases, Commercial/Industrial Lighting/Power/Controls DesignCommercial/Industrial Lighting/Power/Controls DesignORA Project Coordinator, DG PolicyORA Project Coordinator, DG Policy

DisclaimerDisclaimer

The Opinions Expressed

Are Those of the Individual Speaker

and Do Not Necessarily Represent The Opinions

of the California Public Utilities Commission,

The Office of Ratepayer Advocate,

or Their Managements

We don’t know as much as we We don’t know as much as we like to think we dolike to think we do

Industry (or gov’t) isn’t well documentedUtilities, Developers, Regulators all make decisions without adequate informationExample: Documentation of Unintended Islanding

Example:Example:Documentation of IslandingDocumentation of Islanding

(Unintended Islanding, not Microgrids)(Unintended Islanding, not Microgrids)

Utility Engineers universally aver existence, significance of islandingAcademic researchers universally deride probable significanceAlmost no actual documentation exists

We disagree more than we We disagree more than we really like to talk aboutreally like to talk about

Technical decisions have business implicationsInstitutions are highly risk-averseExample: Utility Discretion

Example:Example:The Problem with “Discretion”The Problem with “Discretion”

How to distinguish between . . .How to distinguish between . . .

“Good” DiscretionResolve problems with

andUndefined situations New situationsUnintended unfairness

“Bad” Discretion(i.e., “Market Power”)

Reward affiliatesPunish competitorsRogue individuals

We have radically divergent We have radically divergent beliefs about what’sbeliefs about what’s

. . . “good,” . . . “good,”

. . . “progress,” and. . . “progress,” and

. . . “the future”. . . “the future”“Well-bred people never discuss their religion, money, or politics”DG as a triple-pointExample: T&D Architecture

Example:Example:

T & D ArchitectureT & D ArchitectureShould It Continue to

“Transmit” & “Distribute” “Public Utility” Power to

Retail Customers or

With:

Hierarchical structure, protectionNominally “predictable” power flow

“Low Cost” Strategy

Should It Evolve into a “Physical Marketplace”

Between “Willing Sellers” and “Willing Buyers” of

Competitive Energy With:

Negotiable structure, protectionExplicitly unpredictable power flow

“High Value” Strategy

The UpshotThe Upshot

Developers and Utilities frequently disagree about . . .– What Rule 21 is trying to accomplish,

– What Rule 21 means, and even

– What Rule 21 says.

Should Not Be Cause for Despair!

Example:Example:How “nonHow “non--exporting”?exporting”?

Rule 21 includes “screens” for Simplified InterconnectionScreen 2: “Will power be exported across the PCC?”If “No,” four options, three implicitly addressing some export.

Bottom LineBottom Line

Only the CPUC sets Rules for utility serviceRule 21 is the only applicable interconnection ruleRule 2, etc., apply just as they apply to all other electric service installations“Interpretations” of Rule 21 must be fair, reasonable, and consistent

Where to Get More InformationWhere to Get More Information

California Attorney General investigates violations of state lawCPUC Consumer Affairs Board, investigates violations of regulatory rules, rates, or utility service standardsCPUC Energy Division investigates noncompliance with Commission policiesCPUC Office of Ratepayer Advocates investigates abusive, unfair, or unreasonable utility policies or practices

For Further Assistance:For Further Assistance:

Write: Anthony Mazy, PEProject Coordinator, DG PolicyOffice of Ratepayer AdvocatesCalifornia Public Utilities Commission505 Van Ness Avenue, 4th FloorSan Francisco, California 94102

E-mail: [email protected]

Or, Call: (415) 703-3036

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