Maintaining the Grid - Electric TodayOnce the EEM system was brought online, the software could...

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Maintaining the Grid:• MAXIMIZING RELIABILITY ON THE AUSTRALIAN GRID

• MANAGING ENERGY TRANSACTIONS ACROSS THE KINGDOM OF JORDAN

• CAN NEGAWATTS COMPETE WITH MEGAWATTS?

and

• TRANSFORMER MAINTENANCE

INTERVAL MANAGEMENT

• LEVERAGE RISK/DEMAND

WITH OUTSOURCED IT SECURITY

Mark Your Calendar

Waterpower XIVJuly 18-22, 2005Austin, Texas USA

Maintaining the Grid:• MAXIMIZING RELIABILITY ON THE AUSTRALIAN GRID

• MANAGING ENERGY TRANSACTIONS ACROSS THE KINGDOM OF JORDAN

• CAN NEGAWATTS COMPETE WITH MEGAWATTS?

and

• TRANSFORMER MAINTENANCE

INTERVAL MANAGEMENT

• LEVERAGE RISK/DEMAND

WITH OUTSOURCED IT SECURITY

ET_issue5-2005 7/8/05 1:02 PM

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CONNECTINGCONNECTING...PROTECTING...PROTECTING

ET_issue5-2005 7/8/05 1:02 PM

Volu

me

17,

Issue

5, 2

005

in this issue

3

6 Maximizing Reliability on the Australian Grid

20 Managing Energy Transactions Across the Kingdom of Jordan

10 Transformer Maintenance Interval Management

22 Leverage Risk/Reward with Outsourced IT Security

24 Meeting Future Demand Hinges on Many Forms of Generation

26 Record Year for Wind Energy Industry

34 Collaborative Agreement with TJ/H2b Signed

35 AREVA Engineer Wins 2005 Uno Lamm Award

28 Can Negawatts Compete with Megawatts?

31 You Said It

37, 38

37

in this issueSUBSTATION AUTOMATION

TRANSFORMERS

INDUSTRY NEWS

READER RESPONSE

AUTOMATION AND SECURITY

ADVERTISERS INDEX

GENERATION AND CONSERVATIONElectricity Today is published 8 times a year by TheCanadian Electricity Forum [a division of The HurstCommunications Group Inc.], the conference manage-ment and publishing company for North America’s elec-tric power and engineering industry. Distribution: free of charge to North American electri-cal industry personnel who fall within our BPA requestcirculation parameters. Paid subscriptions are availableto all others. Subscription Enquiries: all requests for subscriptionsor changes to free subscriptions (i.e. address changes)must be made in writing to:

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PRODUCTS AND SERVICES SHOWCASE

ET_issue5-2005 7/8/05 1:02 PM

Electricity Today Issue 5, 2005 4

editorial board

BRUCE CAMPBELL

BOB FESMIRE

CHARLIE MACALUSO

SCOTT ROUSE

BRUCE CAMPBELL, LL.B., Independent Electricity Market Operator (IMO)Mr. Campbell is responsible for business development, regulatory

affairs, corporate relations and communications, and legal affairs at the IMO.He has extensive background within the industry and, in particular, acted aslegal counsel in electricity planning, facility approval and rate proceedingsthroughout his career in private practice.

BOB FESMIRE, ABBBob Fesmire is a communications manager in ABB's Power

Technologies division. He writes regularly on a range of power industry top-ics including T&D, IT systems, and policy issues. He is based in Santa Clara,California.

CHARLIE MACALUSO, Electricity Distributor's AssociationMr. Macaluso has more than 20 years experience in the electricity indus-

try. As the CEO of the EDA, Mr. Macaluso spearheaded the reform of the EDAto meet the emerging competitive electricity marketplace, and positioned theEDA as the voice of Ontario's local electricity distributors, the publicly andprivately owned companies that safely and reliably deliver electricity to overfour million Ontario homes, businesses, and public institutions.

SCOTT ROUSE, Energy@WorkScott Rouse is a strong advocate for proactive energy solutions. He has

achieved North American recognition for developing an energy efficiency pro-gram that won Canadian and US EPA Climate Protection Awards through prac-tical and proven solutions. As a published author, Scott has been called to be akeynote speaker across the continent for numerous organizations including theACEEE, IEEE, EPRI, and Combustion Canada. Scott is a managing partnerwith Energy@Work and is a professional engineer, holds an M.B.A. and isalso a Certified Energy Manager.

DAVID W. MONCUR, P.ENG., M. Naqvi & Assoc.David W. Moncur has 29 years of electrical maintenance experience

ranging from high voltage installations to CNC computer applications, and hasconducted an analysis of more than 60,000 various electrical failures involv-ing all types and manner of equipment. Mr. Moncur has chaired a CanadianStandards Association committee and the EASA Ontario Chapter CSA LiaisonCommittee, and is a Past President of the Windsor Construction Association.

DAVID W. MONCUR

ET_issue5-2005 7/8/05 1:02 PM

ET_issue5-2005 7/8/05 1:02 PM ET_4_2005 6/3/05 10:41 AM Page 9

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As Victoria’s largest electricity dis-tributor, Powercor Australia devotes con-siderable energy to maintaining anddeveloping the quality and reliability ofthe power it delivers to its customers.Although not an electricity retailer, theyown and operate the distribution networkthat delivers electricity across 76,000 kmof circuits to more than 600,000 premis-es throughout Western Victoria, fromMelbourne’s western suburbs to the bor-ders of South Australia and New SouthWales. Since its start in 1996, the compa-ny has experienced considerable growthand continues to add more than 10,000new connections to its distribution net-work each year. To guarantee its cus-tomers a reliable source of quality power,Powercor Australia invests $100 millionAUD each year on maintenance anddevelopment and, since 2000, has invest-ed almost $10 million more in its distrib-ution network.

Recently, they embarked upon amajor endeavor to upgrade 55 zone sub-stations, plus several strategic customer-related installations, with a network ofintelligent energy meters and software.The goal of this upgrade was to providePowercor engineers with the tools toremotely monitor and control conditionsat each zone substation, and to help opti-mize power quality and reliability acrossan entire distribution network spanningmore than 74,000 distribution substa-tions.

A COMMITMENT TO QUALITYAccording to Joe Thomas, network

planning manager for PowercorAustralia, the decision to upgrade thecompany’s distribution network wasmotivated by several factors, not the leastof which was an industry regulator’srequirement to report any voltage fluctu-ations occurring at the 22kV supplypoints of each zone substation. To alignwith annual network performance targetsset by Victoria’s Essential ServicesCommission, Powercor maintains“Guaranteed Service Levels” as a com-

mitment to provideits customers with aconsistent level ofreliable, high-qualityservice.

To help ensure asafe, reliable andhigh-quality electrici-ty supply, the compa-ny’s NetworkPlanning group iden-tified a need forremote access todetailed energy-metering data fromeach zone substation,plus the tools to helppinpoint potentiallydamaging conditionssuch as excessive harmonic frequencies,sags and swells, transients, and phaseunbalance. “Aside from a few protectionrelays, the zone substations originally

offered very basic equipment for meter-ing, and no capacity for monitoring

SUBSTATION AUTOMATION

MAXIMIZING RELIABILITY ONTHE AUSTRALIAN GRID

By Anthony Tisot

Continued on Page 8

ET_issue5-2005 7/8/05 1:02 PM

ET_issue5-2005 7/8/05 1:02 PM

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power-quality conditions such as tran-sients or sags and swells,” explainsThomas. “We knew that a more compre-hensive system for monitoring energywould provide our Network Planninggroup with the type of detailed meteringdata necessary to make informed system-augmentation decisions.”

According to Thomas, the NetworkPlanning group also needed a way togather accurate consumption data to bet-ter assess customer usage patterns, andproactively prepare for periods ofincreased power consumption.“Although energy consumption is highthroughout Australia’s winter months(June through August), demand increasessignificantly in the summer (Decemberthrough February) mainly due to theincreased use of cooling equipment suchas air conditioning and cooling storageunits,” says Thomas. “We knew that cre-ating a profile of energy consumptionacross the entire distribution network,and using this information for trendingsystem quantities on an ongoingbasis,would be invaluable for supportingdecision making.”

MANAGING ENERGY,ENTERPRISE WIDE

To meet these requirements,Powercor installed an ION® enterpriseenergy management (“EEM”) systemfrom Power Measurement. With theassistance of Eltec Energy Services,Power Measurement’s regional represen-tative, Powercor equipped its zone sub-stations with ION 7600 or ION 7700intelligent energy meters, and connectedthe meters to a centrally located comput-er workstation running ION Enterprise®energy management software. Each ener-gy meter was then configured to collectdetailed power quality and energy data atthe source, and provide it to the IONEnterprise software server located atPowercor’s head office. Once the EEMsystem was brought online, the softwarecould automatically monitor each meterin the network, analyze the data, andnotify personnel of any threats to powerquality or reliability.

Because of the remote locations andconsiderable distances involved, eachmeter was equipped with an expanded

onboard memory to accommodate addi-tional data in the event of a communica-tions interruption. Although the meterscurrently communicate with the head-end software via modem, Powercor is inthe process of upgrading its communica-

tions network to Ethernet over fiber forimproved speed and reliability.

At each zone substation, the IONmeters measure electricity delivered to


Continued on Page 19

AUSTRALIAN GRIDFrom page 6

ET_issue5-2005 7/8/05 1:02 PM

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ET_issue5-2005 7/8/05 12:26 PM

ABSTRACTRecent surveys indicate that the

average age of utility power transformersexceeds 30 years. Managing these criti-cal assets requires monitoring the factorsthat cause transformer damage.Excessive heat and mechanical stressduring through faults on transformers arerecognized as the two major causes ofdamage. New technology in transformerprotection relays provides for both ther-mal and through-fault monitoring.

This paper demonstrates how to usethe transformer thermal damage and loss-of-life information from IEEE Std.C57.91-1995 to schedule proactive main-tenance. It also presents through-faultrecording and accumulated data and dis-cusses how these relate to transformershort-circuit standards.

INTRODUCTIONIn the historical struggle between ac

and dc power transmission, ac is general-ly preferred because it allows easy con-version of voltages to higher levels for

long distance transport. Power trans-formers are a critical link in the ac pathof electricity from the generating stationsto end users. In terms of total investment,electric utilities invest at least as much intransformers as they do in generating sta-tions. In many cases, because of the larg-er installed base, utilities invest more intransformers.

Transformers are expected to lastfrom 20–30 years, and in many cases,even longer. Because regulators andfinancial markets measure a utility’s abil-ity to make efficient use of resources,utilities must maximize asset utilization.Based on transformer design and experi-ence, we know that the amount of servicea transformer “sees” is an indicator ofserviceability. As they say, “it’s not theage — it’s the mileage.”

Measurable indicators of trans-former serviceability include electricalload; top-oil, hottest-spot, and ambienttemperatures; fault history; and dissolvedgas analysis. Utilities that use these indi-cators can make intelligent profit/risk

decisions and plan optimal transformerloading and maintenance.

MEASUREMENTSThe best way to protect and extend

the life of transformers is to collect infor-mation such as load and fault current aswell as top-oil or hottest-spot tempera-tures, and receive notification when avalue has reached a preset level.Logically combining these quantities canhelp predict or anticipate an alarm condi-tion, and keeping a record of these mea-surements provides a more complete pic-ture of the transformer’s insulation con-dition.

The challenge is providing a meansto collect this information without creat-ing a massive new system requiring itsown maintenance and cost structure.Protective relays that are permanentlyconnected to the transformer current (andpossibly temperature inputs) as shown inFigure 1, have memory and recording


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continued on page 13

ET_issue5-2005 7/8/05 12:39 PM

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ET_issue5-2005 7/8/05 12:39 PM

13Electricity Today Issue 5, 2005

capability and logical decision making capacity, can be thebeginning of a comprehensive “life management” system fortransformers.

Construction and usage standards for transformers providea starting point for applying these measurements to determineoptimal loading at a given ambient temperature and predictwhen it is appropriate to schedule maintenance prior to a life-ending event.

TEMPERATURE MEASUREMENTS AND CALCULATIONSIEEE standards and numerous technical papers have estab-

lished guidelines for loading transformers based on temperaturelimits for oil and conductors. For example, recognizing that a“loss of life” occurs as temperatures increase, IEEE StandardC57.115-1991: Guide for Loading Mineral-Oil-ImmersedPower Transformers Rated in Excess of 100 MVA (65ºCWinding Rise), Table 2, includes temperature limits for differ-ent load conditions. All of the conditions above normal loadinginvolve some degree of an accelerated loss of life of the trans-former [1] [2].

The standard shows that from a managed ownership stand-point, regularly overloading a transformer at high ambient tem-peratures causes accelerated aging. The question is: how shouldmaintenance of the transformer change based on the amountand duration of overloads?

Both operator actions and system events can cause trans-former overloads. Therefore, temperatures should be continu-ously monitored, and accumulated loss of life should be mea-sured and recorded. The most important two values to calculateor measure are hottest-spot temperature and top-oil tempera-ture. IEEE Std. C57.91-1995 provides formulas for performingthese calculations. We have programmed these formulas in pro-tective relays to calculate temperatures. The user inputs thetransformer constants required (see Appendix A), such as ther-mal time constants, ratio of no-load to load losses, and totallosses at rated output. If these constants are unknown, the stan-dards provide reasonable default values for approximate calcu-lations.

Using the entered constants, the relay provides instanta-neous and accumulated loss-of-life and aging acceleration fac-tor alarm points. Calculations are based on what information isavailable. Temperature devices on the transformers, such asResistance Temperature Detectors (RTDs), may or may not beavailable, so different calculations are made depending on thisavailability [3].

THERMAL CALCULATIONS USING AMBIENT AND TOP-OILTEMPERATURES

In this case, the relay receives measured ambient and top-oil temperature inputs and uses the top oil temperature to cal-culate the hottest-spot temperature.

A single-tank, three-phase transformer can have as manyas two thermal inputs: the ambient temperature input and thetop-oil temperature input. Independent, single-phase transform-ers normally have as many as four thermal inputs: an ambienttemperature input and a top-oil temperature input for each oneof the three tanks. During a fixed time interval, ∆t = 1 minute,the relay calculates the winding hottest-spot temperature at theend of the interval, according to the following expression:

ΘH = ΘTO + ∆ΘH

where:ΘH = winding hottest-spot temperature, °CΘTO = top-oil temperature, °C∆ΘH = winding hottest-spot rise over top-oil temperature,

°CThe relay calculates winding hottest-spot rise over top-oil

temperature, ∆ΘH, according to the following:-∆t

∆ΘH = (∆ΘH,U - ∆ΘH,i) • (1 - e 60•τw) + ∆ΘH,i

where:

∆ΘH,U = the ultimate hottest-spot rise over top-oil tem-perature for any load, °C

∆ΘH,i = initial hottest-spot rise over top-oil temperature atthe start time of the interval, °C

τw = winding time constant of hot spot, in hours∆t = one-minute temperature data acquisition interval∆ΘH,U = ∆ΘH,RK2m

Figure 1 Transformer Relay With Connected RTDs for ThermalMonitoring

INTERVAL MANAGEMENTcontinued from page 10

Figure 2 Iterative Real-Time Hottest-Spot Calculation


ET_issue5-2005 7/8/05 12:39 PM


where:K = load expressed in per unit of transformer nameplate

rating according to the cooling system in service (phase currentdivided by the nominal current)

m = winding exponent∆ΘH,R = rated winding hottest-spot rise over top-oil at

rated load, °CThe implementation of this equation over time is shown in

Figure 2.

THERMAL CALCULATIONS WITH ONLYAMBIENT TEMPERATURE INPUTS

If only ambient temperature is available, the relay calcu-lates both top-oil temperature and hottest spot temperature.Typical variances in ambient temperature for the same loadcould result in a difference in aging of transformer insulation by100 times, so it is critical that ambient temperature is available.

Where the relay has a measured ambient temperature inputwithout a top-oil temperature input, you have one thermal input(for ambient temperature) regardless of whether you have a sin-gle three-phase transformer or independent single-phase trans-formers. The relay calculates winding hottest-spot temperature,ΘH, according to the equation in the earlier case:

ΘH = ΘTO + ∆ΘH

and calculates top-oil temperature, ΘTO, according to thefollowing:

ΘTO = ΘA + ∆ΘTO

where:ΘA = ambient temperature, °C∆ΘTO = top-oil rise over ambient temperature, °C

The relay calculates top-oil rise over ambient temperatureaccording to the following:

-∆t

∆ΘTO = (∆ΘTO,U - ∆ΘTO,i) • (1 - e 60•tTO ) +∆ΘTO,i

where:

∆ΘTO,U = the ultimate top-oil rise over ambient tempera-ture for any load, °C, and is a function of load

∆ΘTO,i = initial top-oil rise over ambient temperature atthe start time of the interval, °C

τTO = top-oil time constant of transformer, in hoursThe relay calculates the ultimate top-oil rise over ambient

temperature, ∆ΘTO,U, according to the following expression:

∆ΘTO,U = K2 •R+1 n • ∆ΘTO,R( R+1 ) where:R = ratio of load loss at rated load to no-load lossn = oil exponent

∆ΘTO,R = top-oil rise over ambient temperature at ratedload, °C

For any n (oil exponent) value and any load value, the relaycalculates the thermal top-oil time constant according to thefollowing expression:

∆ΘTO,U - ∆ΘTO,i∆ΘTO,R ∆ΘTO,R

τTO = τTO,R •[ ]∆ΘTO,U - ∆ΘTO,i(∆ΘTO,R) (∆ΘTO,R )where:τTO,R = thermal time constant in hours at rated load with

initial top-oil temperature equal to ambient temperatureReal-time values include calculated temperatures as well

as loss-of-life accumulations.Instantaneous values are useful to operators in making dis-

patch decisions.Transformer standards provide guidelines for operating at

“damaging” thermal levels. For example, Table 1 from IEEEStd. C57.115-1991 provides what can be considered reasonableloading times for given hottest-spot temperatures [1]. Operatorsor relays should act to limit the time at higher-than-rated tem-peratures. Relay contacts or alarms sent via SCADA can alsoinitiate control actions to reduce load.

INSULATION AGINGHottest-spot temperature above 90–105ºC causes irre-

versible degradation of the cellulose insulation structure of atransformer [4] [5]. This degradation accumulates over timeuntil the insulation material fails. The mode of the insulationfailure in these cases is typically of a mechanical nature, e.g.,cracking and flaking caused by the heavy carbonization of theinsulation material. This mechanical degradation of the insula-tion material eventually results in an electrical failure of thedevice.

Insulation Aging Acceleration FactorBased on transformer standards, we calculate an insulation

aging acceleration factor, FAA, which indicates how fast thetransformer insulation is aging.

We calculate the insulation aging acceleration factor, FAA,for each time interval, ∆t, as follows:

B - BFAA = e [ ](ΘH,R+273) (ΘΗ+273)where:FAA = insulation aging acceleration factorB = is a design constant, typically 15000, °CΘH,R = winding hottest-spot temperature at rated load

(95°C if ∆ΘW/A,R = 55°C110°C if ∆ΘW/A,R = 65°C)

∆ΘW/A,R = average winding rise over ambientat rated load (setting)

Daily Rate of Loss of LifeNow we calculate daily rate of loss of life (RLOL, percent

loss of life per day) for a 24-hour period as follows:

RLOL =FEQA • 24 • 100

ILIFE

where:RLOL = rate of loss of life in percent per dayILIFE = expected normal insulation life in hoursTo provide the user with trend information on the loss of

insulation, the RLOL value should be automatically recorded.The equivalent life at the reference hottest-spot tempera-


1n

1n

ET_issue5-2005 7/8/05 12:39 PM

Accumulated loss of life provides an indicator of theimpact of operational overloads on the transformer. Simply, itis the integral over time of the accumulated aging, taking intoaccount the effect of accelerated aging caused by elevatedtemperatures.

Moisture content in the cellulose insulation has a signifi-cant impact on insulation aging [4] [6]. If the moisture contentincreases from 0.5% to 1.0%, the rate of aging of the celluloseinsulation at least doubles for a given temperature. Moisture inthe insulation can be estimated by applying an appropriatealgorithm [7] to the measured water content in the oil. Becauseit is important to know the amount of water in the transformeroil, even an advanced temperature monitoring system cannotcompletely predict the perfect time to perform maintenance.Using the calculated moisture content to adjust the thermalaging of the insulation improves the ability to predict mainte-nance.

COMPARING CALCULATED AND MEASURED VALUESWhile it is advantageous to have top-oil and hottest-spot

temperatures available from direct measurements, calculatedvalues are also useful. Obviously, for a transformer withouttop-oil or hottest-spot RTDs, a calculated value is the only onepossible. The calculated values for top-oil and hottest-spottemperatures can be derived using load currents and eithermeasured or fixed (manually entered setpoint) values forambient temperature. When based on assumed ambient tem-

ture (95ºC or 110ºC) that will be consumed in a given timeperiod for a given temperature cycle is:

FEQA = equivalent insulation aging factor for a total time period

n = index of the time interval, ∆tN = total number of time intervals for the time periodFAAn = insulation aging acceleration factor

for the time interval, ∆tn∆t = time intervalDuring 24 hours, the total number of time intervals is:

where:∆t = time intervalBecause the time intervals and the total time period used

in the thermal model will be constant, we can simplify the cal-culation of FEQA to the following:

= (equivalent life in days)

Total Accumulated Loss of LifeAn estimate of the total accumulated loss-of-insulation

life in percentage of normal insulation life can be made bysumming all of the daily RLOL values:

TLOLd = RLOLd + TLOLd-1where:TLOLd = total accumulated loss of life, TLOLRLOLd = most recent daily calculationTLOLd-1 = previous TLOLDamage, or aging of insulation, roughly doubles with

every 6–8ºC of temperature above 90ºC [5]. We can plot theapproximate effects of hottest-spot temperature on insulationaging as shown in Figure 3.


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Figure 3 Relative Aging vs. Hottest-Spot Temperature

ET_issue5-2005 7/8/05 12:39 PM


peratures, the calculated values will be very unreliable.If measured oil temperatures are available, then it is possi-

ble to compare the calculated values with the measured values.This gives an indication of the effectiveness of the cooling sys-tem. An alarm can be issued if the difference between measuredand calculated temperatures exceeds a preset value. Failedpumps, birds nests in the fans, or any number of other problemscan be detected and corrected this way, before they cause a cat-astrophic transformer failure. Comparing calculated and mea-sured values can also be used to correct setting constants.

THROUGH-FAULT MONITORING AND ALARMSAccording to insurance industry studies [8], through faults

are the number one cause of transformer failure today. Initiationof a through fault can be seen in Figure 4 below.

As fault duty and feeder exposure increase, the incidenceand severity of through faults experienced by a transformer willtend to go up over time. IEEE Std. C57.12 [9] provides con-struction guidelines for short-circuit withstand for transform-ers. The standard states that a transformer shall withstand 2 sec-onds of a bolted fault at the transformer terminals. Testing toverify through-fault withstand capability is normally performedon a design basis, with the length of the test limited to 0.5 sec-onds for up to 30 MVA three-phase transformers.

When evaluating how to assess possible damage or loss oflife to an installed transformer subjected to a through fault, it isinteresting to consider testing standards and their implications.The test standards are “intended for use as a basis for perfor-mance [10]”. Test standards are established only for new units,to some degree in recognition that normal service life of a trans-former will cause it to have an unpredictable response to short-circuit tests; yet those tests are a simulation of what the trans-former may experience with the next through fault.

Following short-circuit tests, a careful set of visual andelectrical tests is performed to verify there has been no, or min-imal, movement of the coils as a result of the forces incident toa short circuit. In an installed transformer, it is generally notpractical to perform even minimal visual and electrical testsfollowing every through fault. So the question is: what is a rea-sonable expectation of length of life of a transformer, built toaccepted standards, following normal through faults that everysystem will experience?

Plotting a comparison of the stresses a transformer experi-

ences and its withstand capability against time could produce agraph such as Figure 5 [6].

The stress withstand capability of a transformer is reducedgradually by degradation caused by overheating of the insula-tion components. The stresses the transformer are subjected tomay increase over time due to increasing loads and an increasein short-circuit duty from additional system interconnectionsand sources.

If we were to modify Figure 5 to include more detail, alsoshown by Reference [6], we could create a graph such as Figure6.

In this case, the transformer experiences three severethrough faults. The first two faults reduce the transformer’swithstand capability to the point where it cannot withstand theforces of the third fault.

While not explicitly stated in IEEE standards (see [9]) thisdegradation in capability is predicted by the following equation[11]:

I2t = k (1)

where:k generally equals a constant where t equals 2 seconds and

I equals maximum fault current in per unit times normal basecurrent. This matches the construction characteristics defined inIEEE Std. C57.12.

For example, for a transformer rated 40 MVA base rating,230/69 kV and a 4% impedance connected to an infinite bus,


Figure 4 One-Line Diagram of a Typical Through-Fault Event

Figure 5 Stress Withstand Capability Over Transformer’s Lifetime

Figure 6 Stress Withstand Capability Over Transformer’s ReducedLifetime

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relays, thermal imaging, and dissolved gas analysis.Sudden pressure relays have been reported to have occa-

sional problems with misoperation on external faults. For thisreason, they are sometimes used for alarm only and not trip-ping [12]. An alarm from a sudden pressure relay may havemore consequence as a maintenance predictor if coupled withan accumulated loss of life due to overload. Within a digitalrelay, it is a simple matter to either logically or electricallycombine the output of the sudden pressure relay with the accu-mulated loss-of-life alarm. This allows recognition of degra-dation in insulation, making small movements of the core andcoil assembly more significant, and possibly, events worthy ofinitiating an inspection.

Thermal imaging can be used to compare calculated top-oil temperatures with measured values, as suggested in thethermal monitoring section above. Cooling effectiveness, orthe lack thereof, can then be evaluated prior to damage.

Dissolved gas analysis is more suited to be an interim stepbetween an accumulation of events and a complete inspectionthan as a frequent diagnostic action, except on the largesttransformers.

TURNING DATA INTO INFORMATIONIt is not enough that data on overall loss of life exist inside

a relay. It must be transmitted to a person who can use theinformation to improve decision-making and better managethe transformer asset. The simplest way to send data is toassign an alarm contact to a certain loss-of-life level. The

we would have:Base load current = 40 = 0.335 kA

3 • 69Equation 1 with maximum fault current then becomes:

40 2 • 2 sec 140 kA2 sec(3 • 69 • 0.04)

While this curve as presented in the IEEE standards [9][11] is used for setting and coordinating protective devices fortransformers, it can have practical applications to ongoingtransformer service. In IEEE Std. C57.12, the transformer isconstructed to be able to withstand this fault. This fault is thelimit of what the transformer was designed to withstand; thetesting standard provides for a design test of the transformer,when new, at a short-circuit duration of 1/4 of this time.Following the short-circuit test, the transformer is untankedand inspected visually for winding displacement or other dam-age. Electrical tests are performed to ensure insulation integri-ty and verify that parameters such as excitation current andimpedance have not changed.

Users can measure and record the fault duty seen by atransformer on the same basis as the design tests performed inthe factory. This gives the user a basis for evaluating the ser-vice life remaining in the transformer before inspection andtesting are required.

COMBINED MEASUREMENTSTemperature loss-of-life calculations are based on a grad-

ual and continual aging process similar to that shown in Figure5. While sudden and severe overloading at high ambient tem-perature could cause a temporary increase in the aging “slope,”as long as the overload is not so severe as to burn up the trans-former, the process is akin to sliding down a hill and not fallingoff a cliff.

On the other hand, a through fault is a sudden and severeevent by its very nature. As shown in Figure 6, the mechanicalforces incident to the through fault can cause an insulationstructure that is already aged by years of loading to fail.

The problem is that overloading guidelines do not takeinto account the short-circuit stresses that a transformer mayhave or may yet experience. Likewise, short-circuit design andtesting standards are made for new units that have not experi-enced any aging of the insulation structure. The advantage ofhaving one device perform both the thermal recording andloss-of-life calculation, as well as the through-fault monitoringand accumulated fault duty recording, is that now these twofactors can be combined for an effective maintenance indica-tor.

For example, if we define TLOLL = Total Loss-of-LifeLimit and ISQT = Accumulated I2t of fault duty, we can writea logic equation to initiate alarm for a transformer similar tothat in the through-fault monitoring example:

Alarm = (TLOLL > 70%) AND (ISQT > 98 kA2 seconds)This alarm can be a sign that because the transformer has

an accumulated thermal loss of life of 70% as well as an accu-mulated through-fault duty of 70% of its nominal withstandcapability, it is time for at least a thorough inspection and pos-sibly an overhaul to reblock or even rewind.

A possibly greater application is to use the outputs fromthe monitoring associated with electrical quantities with othertransformer information that may be available. These othermonitoring devices or methods can include sudden pressure


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problem is that this takes away the addi-tional intelligence that may be available,as discussed in previous sections. Usinga communications processor to send acomplete report to a responsible engineeris a way to send more useful information(Figure 7).

With more complete information,the engineer can assess the degree of riskassociated with continuing with thetransformer in service under the sameconditions or performing maintenance.Combining multiple reports — such asthermal, through-fault, and online dis-solved gas analysis — can give the bestview of the conditions within the trans-former.

CONCLUSIONSWhile using the alarm point as a

maintenance indicator may sound likeadditional work, doing so can actuallyprevent maintenance work. If a unit hasnot experienced an accumulated life dutyto indicate that maintenance is necessary,then without some other indicator, main-tenance is not necessary.

Transformers need to be utilized totheir maximum capabilities, which man-dates that maintenance actions and oper-ating procedures take the consequencesof maximum usage into account. Utilitiesthat use all of the information availablecan postpone maintenance on units thathave not seen excessive stress and accel-erate maintenance schedules for unitsthat have seen possibly damaging stress.

As transformer design toolsimprove, they not only provide fordesigns that are more assured of meetingstandards, but they also allow trans-former designers to avoid safety marginsthat may have existed in prior designs.This makes it more important to recog-nize what these design standards provideand how to measure when the limitsdefined by standards are approached.

1. A comprehensive transformermanagement plan continuously monitorsand records thermal loading.

2. Comparing measured top-oil tem-peratures with calculated top-oil temper-ature provides a measure of coolingeffectiveness that can be used to notifymaintenance personnel of problems withfans or pumps.

3. Accumulated through-fault moni-toring can be an indicator of necessarymaintenance, just as accumulated ther-

mal loading can.4. Combining through-fault, temper-

ature, and other factors can optimizemaintenance practices for an overallreduction in total ownership costs.

REFERENCES[1] Guide for Loading Mineral-Oil-

Immersed Power Transformers Rated inExcess of 100 MVA (65ºC WindingRise), IEEE Std. C57.115-1991.

[2] S. E. Zocholl and A. Guzman,“Thermal Models in Power SystemProtection,” proceedings of the WesternProtective Relay Conference, 1999.

[3] SEL-387-0, -5, -6 CurrentDifferential Relay, Overcurrent Relay,Data Recorder Instruction Manual,Schweitzer Engineering Laboratories,Inc., 2004.

[4] R. Sanghi, “Chemistry Behindthe Life of a Transformer,” Resonance,June 2003.

[5] H. J. Sim and S. H. Digby, “TheMaking of a Transformer,” presented atDoble The Life of a TransformerSeminar, 2004.

[6] M. A. Franchek and D. J.Woodcock, “Life-Cycle Considerationsof Loading Transformers AboveNameplate Rating,” presented at the 65thAnnual International Conference ofDoble Clients, 1998.

[7] M. Bélanger, “Techniques forDrying Out Oil-Filled TransformersWhile Still In-Service,” ElectricityToday, Issue 7, 2001.

[8] W. H. Bartley, “An Analysis of

Transformer Failures—1988 through1997,” The Locomotive, Hartford SteamBoiler Inspection and InsuranceCompany.

[9] IEEE Standard GeneralRequirements for Liquid-ImmersedDistribution, Power, and RegulatingTransformers, IEEE Std. C57.12.00-1993.

[10] IEEE Standard Test Code forLiquid Immersed Distribution, Power,and Regulating Transformers and IEEEGuide for Short-Circuit Testing ofDistribution and Power Transformers,IEEE Std. C57.12.90-1993.

[11] Guide for Liquid-ImmersedTransformer Through-Fault-CurrentDuration, IEEE Std. C57.109-1993.

[12] “Transformer Protection,Sudden Pressure Relays,” WSCC RelayWork Group, October 21, 1991.

BIOGRAPHIESRoy Moxley has a B.S. in ElectricalEngineering from the University ofColorado. He joined SchweitzerEngineering Laboratories in 2000 asmarket manager for transmission systemproducts. He is now a senior productmanager. Armando Guzmán (M ‘95, SM ‘01)received his BSEE with honors fromGuadalajara Autonomous University(UAG), Mexico, in 1979. Since 1993 hehas been with Schweitzer EngineeringLaboratories in Pullman, Washington,where he is presently a Fellow ResearchEngineer.


Figure 7 Using a Communications Processor to Send a Formatted Report

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Additionally, the meters’ high sam-pling rate supports an increasedlevel of power quality analysis thathelps staff identify geographicalareas that may be more susceptibleto transient events. This capabilityalso allows Powercor’s networkplanning team to view actual net-work voltages as a result of chang-ing system conditions, and to devel-op a profile for each zone substationsupply point. With this combinedinformation on transients, sags andswells, personnel can better under-stand plant capability requirementsacross each segment of the network.

By upgrading its zone substations with advanced powermonitoring and control technology, Powercor Australia nowhas the tools to track energy consumption, analyze power-quality conditions, and maximize reliability throughout itsextensive distribution network. This initiative is just the latestin a series of strategies and programs that guarantee PowercorAustralia customers a safe, reliable and affordable supply ofhigh-quality electricity.

Anthony Tisot is a professional writer with PowerMeasurement, specializing in energy-management strategiesand communications technology.

the substation at 66kV, andleaving the substation at 22kV.Additionally, they monitorpower quality parameters suchas sags and swells, transients,harmonics, flicker, voltageunbalance and current unbal-ance. To monitor consumptionacross the entire distributionnetwork, the system automati-cally records total kWh asinterval data logs, and presentsthis information as monthlyreports. In the near future, the company plans to install addi-tional meters at the terminal stations that supply power to thePowercor network.

CONTROLLING POWER QUALITY AND RELIABILITY The end result is an enterprise-wide energy management

system that provides real-time power monitoring and controlcapability across the entire distribution network. With 24-houraccess to each zone substation, energy managers can nowreview real-time conditions and logged system data from mul-tiple metering points to help determine effective maintenancestrategies, or assess potential trouble spots. The system canalso deliver alarm notifications to alert staff of any conditionsrequiring an immediate response. For example, the ability totrend harmonics is considered to be a key benefit of the sys-tem. If left unchecked, harmonics can cause severe damage toelectrical equipment, overheating transformers, conductors,capacitors, and motors. “Due to the many new and varied tech-nologies used by our customers, harmonics are an ever-increasing challenge,” confirms Thomas. “But with ourimproved power-quality monitoring capabilities, we canquickly identify potential trouble spots and take correctiveaction before reliability can be affected.”

The ability to remotely identify potential trouble spots hasalso helped Powercor improve reliability through enhancedawareness, increased efficiency, and reduced response time.Although Powercor employs comprehensive mitigation strate-gies to help minimize supply interruptions caused by bushfires,pole fires and wildlife, occasional damage or disruption alonga line may occur, resulting in potentially damaging variationsin voltage levels. By pinpointing the source of a problem andalerting staff, Powercor’s energy management network canhelp maintenance crews respond quickly and efficiently tominimize damage and correct any threats to reliability.

Powercor recently used its enhanced metering capabilityto monitor the effect of a hot water peak load which existed ona very weak network. “Our data illustrated how the distributionsystem tended towards voltage instability,” explains Thomas.“Using the system, we identified voltage regulators that wereunable to coordinate or respond fast enough, and were able toquickly address the situation.” Although Powercor’s NetworkPlanning engineers are among the EEM system’s primaryusers, the detailed energy information it provides has alsoproven useful to protection engineers, operations engineers,and regional managers throughout the organization.


AUSTRALIAN GRIDFrom page 8

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Whether producing and deliveringpower in North America or around theworld, many utilities are finding the keyto staying profitable in today’s competi-tive energy market is the ability toacquire and process information fasterand more efficiently than ever before.

This is especially true in deregulatedmarkets, where the success of indepen-dent generation, transmission and distrib-ution companies hinges upon the timelyand reliable exchange of accurate trans-action and billing data between partners.In the Middle East, where the HashemiteKingdom of Jordan is upgrading andrestructuring the country’s electricitytransmission grid, Jordan’s NationalElectric Power Company has constructeda synchronized, countrywide enterpriseenergy management network to provideenergy companies with independentaccess to metering data from sharedinter-tie points across the grid.

This advanced energy monitoringand communications infrastructure isexpected to play a key role in helping tosupport business processes between mar-ket participants, while providing thetools to maintain a secure and reliablesource of affordable energy for the coun-try’s five million residents.

CREATING A SUSTAINABLE ENERGYSECTOR

Located in the heart of the MiddleEast, the Hashemite Kingdom of Jordanis a country in the midst of some very bigchanges. Limited access to naturalresources such as water and oil have tra-ditionally placed significant constraintson the region, but for decades Jordan hasfaced these challenges with a steadycommitment to increasing growth andimproving living standards.

This initiative has grown into acountrywide goal to upgrade, and mostrecently, deregulate the region’s electric-ity transmission grid. To accomplish thissignificant undertaking, the governmentof Jordan recently split the state-ownedNational Electric Power Company

(NEPCO) into three distinct organiza-tions, and embarked on the next chal-lenge: building a countrywide energy-information infrastructure to monitorenergy transactions and billing betweenthe newly independent power generation,transmission and distribution companies.

This represents a critical steptowards Jordan’s goal of creating a sus-tainable energy sector, characterized byefficiency, quality and growth.

JORDAN’S COMMITMENTTO QUALITY

The promise to improve Jordan’senergy infrastructure dates back to 1967,when the government established theJordan Electricity Authority (JEA). TheJEA was entrusted with developing a sys-tem of modern power plants and a reli-able high-voltage network that woulddeliver electricity to every village andrural community in the country. Onceestablished, the JEA saw Jordan’sinstalled capacity grow steadily to meet

demand and provide sufficient reserve.By the early 1990s, nearly 100% ofJordan’s population was supplied withelectricity.

By this time however, falling oilprices had presented a new challenge tothe national economy by reducingJordan’s levels of trade with oil-produc-ing Arab countries. Faced with a falteringeconomy, Jordan looked for new ways tospur growth. In 1992, the country intro-duced an aggressive reform programintended to promote economic growththrough the development of a market-based system.

For the power sector, this meantincreasing the involvement of privateconcerns to help create a sustainablebusiness and regulatory environment thatwould encourage investment and compe-tition. In 1996, JEA was recast as theNational Electric Power Company(NEPCO), a publicly held governmententity. Then in 1999, the Cabinet split thestate-owned NEPCO into three legally


MANAGING ENERGY TRANSACTIONS ACROSSTHE KINGDOM OF JORDAN

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feed,” explains Khuraishi. “But to verify the consistency andaccuracy of the metered data, we also needed to build in a net-work of redundant meters — a parallel network — to act as acheck to the main meters.”

To do this, NEPCO equipped eight of its substations witha pair of revenue-accurate ION 7500 meters on each feed: one

and financially independent operating compa-nies: the Central Electricity GenerationCompany (CEGCO), the National ElectricPower Company (NEPCO), and theElectricity Distribution Company (EDCO).

PRIVATIZING THE ENERGY SECTORAs a state-owned utility, NEPCO

remains at the center of Jordan’s restructuredenergy sector, responsible for the manage-ment, operation and development of the coun-try’s high-voltage transmission network.NEPCO maintains ownership of Jordan’stransmission assets, but buys power fromgeneration companies such as CEGCO, andsells it to distributors such as EDCO.Eventually, CEGCO and EDCO will be pri-vatized, but NEPCO is expected to remain astate-owned monopoly to manage transmis-sion and load-dispatching services across thecountry.

By splitting the country’s energy assets into independentbusinesses, Jordan effectively divided the responsibilities intotwo parts, with policymaking and supervision on one side, andoperation management on the other.

Most of Jordan’s generation is provided by two mainpower plants: the 650 MW Aqaba power plant in the south, andthe 400 MW Hussein power plant in the north. The country’stransmission system runs along the north-south axis of Jordan,with distribution lines served from this 132 kV radial system.In addition to EDCO, other private firms providing distributionservices include the Jordan Electric Power Company (JEPCO)in Amman, and the Irbid District Electricity Company(IDECO).

To further support the business processes of an expandingenergy market, each of the newly independent companiesneeded a way to efficiently and accurately communicate andverify energy and financial transactions. Everything from thequantity and quality of power produced and delivered, to up-to-the-minute billing and time-of-use data had to be availableto all market participants. As the administrator of this develop-ing marketplace, NEPCO began evaluating ways to monitormetering points across the grid — every inter-tie where elec-tricity is transferred from one business to another.

The first priority was to monitor settlement billingbetween NEPCO’s transmission system and the generationassets of CEGCO. To do this, NEPCO installed an ION®enterprise energy management system from PowerMeasurement of Victoria, Canada. The Internet-based systemuses a network of 150 ION 7500™ intelligent energy meterslinked to four software servers to track and verify energy trans-actions between Jordan’s generation and transmission compa-nies.

ENTERPRISE ENERGY MANAGEMENT OVERPARALLEL NETWORKS

According to Faten Khuraishi, project manager forNEPCO, a key requirement of this system was to create a par-allel communications structure that could provide each com-pany with independent access to metering data from eachshared inter-tie point. “Instead of NEPCO providing informa-tion to CEGCO, we wanted to give each company its owndirect, independent access to metering information from each


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Mundane IT processing of informa-tion security should be outsourced to athird party. Outsourcing raw processingsuch as analysis and correlation of hugeamounts of SCADA or SOX relatedsecurity data can generate considerablecost savings for clients, while also mini-mizing risk and arduous implementation.Some outsourcers further reduce risk forclients by offering control points for theclient, such as proof of concept phasesand clearly enforceable SLA terms.

PROOF OF CONCEPT: LOW RISK,SHORT TIME TO DEPLOY

A clearly delineated proof of con-cept initial phase for an outsourced secu-rity service provides the client with sev-eral benefits including:

1. An assessment period as towhether the deliverable meets the busi-ness requirements of the project, such ascompliance with a particular securitystandard or making more time availablefor in-house security operations andarchitecture groups to focus on their corebusiness goals.

2. Capped, fixed price for the entiredeployment, including both monthly ser-vice costs and one time implementationcost.

3. Time for the client to evaluate allaspects of the deliverable against theSLA, plus evaluate such intangibles asease of use and quality of knowledgetransfer from outsourcer to client.

4. Time for the client to plan a fullproduction deployment of the service,including making modifications to opti-mize the service for the specific andnewly discovered business needs of theclient.

BREATHING TIME TO CONTEMPLATEIN-HOUSE DEPLOYMENT

Once deployed into full production,an outsourced service provides the clientwith otherwise unavailable planning andassessment opportunities, including:

1. Knowledge transfer to theirsecurity operations and planning depart-ments. This helps to prepare these groups

to better assess whether the outsourcedsecurity service should eventually bedeployed in-house, or remain outsourced.

2. Time to evaluate precisely whatmodifications if any would be beneficialwith respect to scope or features of thesecurity service, and the ability to incor-porate these modifications into the pricemodel for a potential in-house deploy-ment.

3. The opportunity to furtherdecrease security costs by levering theability of the outsourced serviceprovider to take on further operations.

CLIENT MAINTAINS CONTROL ANDMANAGEMENT

Key to the client maintaining controlis to find an outsourced service that sendsonly a data stream of security informa-tion to their service bureau for process-ing, but also leaves the data available atthe client site for redundancy, for otheruses, and for the retention of control.

A trivial but conceptually simpleexample is an outsourced email filteringservice, where data can be redirected tothe service outsourcer simply by redirect-ing email to them, but keeping a separatecopy on the client site. Control of theprocess remains with the client, who hasthe last word on accepting questionableemail, modifying the stringency of emailfilter parameters, and keeping a copy ofall email on the client site.

In this process model where data isrerouted, the control benefit to the clientis that data exporting can be shut downquickly.

For more sophisticated outsourcedsecurity services, such as IDS analysisand remedial recommendations or eventlog correlation and remedial recommen-dations, some outsourcers will providethe back-end processing. This frees moretime for the client to more effectivelymanage their IDS and host securityrespectively. Thus a client retains controlover the final process, such as IDS, hostsecurity, and firewall management, butthe “heavy lifting” analytical work, andback end data base for data mining is

done by the outsourcer.

ROI BENEFITS OF OUTSOURCING ITSECURITY SERVICES

Sophisticated IT security processes,such as analysis and recommendationservices for IDS, IPS, event log correla-tion, security dashboards, and data min-ing capability for all of the above, allrequire considerable investment in:

1. Capital expenditures for soft-ware licensing and hardware.

2. Ongoing expenses for CISSP /CISA certified security analysts andsecurity technology operations staff.

3. Ongoing expenses for softwareand hardware annual maintenance.

4. Extensive time and costs neededfor ongoing training, and repeat trainingfor staff turnover.

5. Expenses for all of the above inthe cases of modification(s) to the initialprocess or replacement of the process if itdoes not operate as planned.

Outsourced services can and do pro-vide substantial savings in both dollarsand time, such as:

1. Savings of 25- 40% over thelifecycle of a project.

2. Equivalent costs to in-housedeployment over the lifecycle of a pro-ject, but with no risk or budget con-straints with regard to capital expendi-tures.

Savings are readily calculated overthe lifecycle of a deployment. Some out-sourcers will provide a prospective clientwith a simple, impartial spread sheet toolfor this very purpose.

A more detailed financial analysis ofcost savings may be found in an articletitled IT Security Costs: Outsource vs.Self-Deploy, by the same author.

HOW DO THEY DO IT?Outsourcers can afford to keep costs

low for clients by sharing capital infra-structure costs and ongoing CISSP oper-ations / support costs over all theirclients.

AUTOMATION & SECURITY

LEVERAGE RISK / REWARD WITH OUTSOURCEDIT SECURITY

By Ron Lepofsky


ET_issue5-2005 7/8/05 1:06 PM

main meter and one check meter. Thesemeters monitor the electricity deliveredfrom CEGCO to NEPCO, and send thedata up to a pair of ION RTU data log-gers. Each substation is equipped withtwo data loggers: a main data loggerreceives data from all main meters in thestation, and a check data logger receivesdata from all check meters in the station.

To oversee the data loggers, a pair ofservers — a main server and a checkserver — was installed at each compa-ny’s headquarters and configured toreceive information from all meteringpoints. Each main server monitors allmain data loggers, and each check servermonitors all check data loggers. Bothservers are equipped with identical ener-gy management and billing software, andboth servers collect revenue and eventinformation from the meters on the mainfeeds. With this arrangement, CEGCOand NEPCO maintain two completelyidentical — yet independent — meteringnetworks, accessible from each compa-ny’s corporate headquarters.

With “main” and “check” meters,RTUs, and servers, CEGCO and NEPCOeach use two identical, yet independent,metering networks to monitor energytransactions from each company’s corpo-rate headquarters.

To supplement the main and checkservers located at each headquarters,NEPCO installed additional workstationterminals at each substation so CEGCOand NEPCO engineers could access thesystem locally for onsite troubleshootingor research. Security safeguards such asa segmented network infrastructure, datavalidation, and multilevel user authenti-cation ensure all billing and operationaldata is secure — accessible only toauthorized users at each organization.

NEPCO’s metering system useshigh-quality Rittal electrical cabinets,equipped with humidity and temperaturecontrols, to accommodate up to sixmeters each. The meters and serverscommunicate over NEPCO’s existingfibre optic network — a dedicatedEthernet wide area network (WAN). Inremote areas, substations can connect tothe Ethernet network via modem over thepublic telephone network.

Every meter is also equipped with abuilt-in GPS (global positioning satel-lite) time-sync capability to ensure theaccuracy and consistency of all time-sen-

sitive data across the entire network.

HIGH ACCURACY METERINGIn selecting an energy management

system, NEPCO identified revenueaccuracy as a key requirement, accord-ing to Dr. Abdallah Abdulrahim, manag-ing director of AMPS, a Middle East-based energy consulting business thatassisted with the implementation of thenew system. “With a synchronized net-work of intelligent revenue meters, both

CEGCO and NEPCO can verify theamount of energy produced and deliv-ered,” says Abdulrahim, “and the high-accuracy of these meters ensure thatenergy can be measured against thehighest revenue-metering standards,such as IEC 60687, Class 0.2S. Also,each meter can help evaluate factorssuch as active and reactive energy, volt-age and current levels, and power-quali-



JORDANcontinued from page 21

ET_issue5-2005 7/8/05 1:06 PM


The second annual EnergyRoundtable CERT Conference inToronto focused on European investmentin Canadian power markets, and includedseveral speakers like AMEC’s BrianBentz.

Speaking on a comparison of windfarm projects in the United Kingdom andCanada, the President of ProjectInvestments, Americas sees wind powerworking in co-operation with the otherforms of generation as being the key tomeeting future demand.

“My feeling, and that of the panel, isthat the answer is going to be a mix ofpower - hydro, nuclear, coal, wind andsolar - to meet generation targets andthose of the Kyoto Protocol,” says Mr.Bentz. “You can’t get a consistent loadwith just wind or solar - you need themix.”

Comparing renewable projects in theUK with Canada, Great Britain needssome 5,000 gigawatt hours annually overthe next five years to meet their targets.“In Canada with similar requirements(and target dates), the country wouldneed to generate 7,000 gigawatt hoursannually.”

However, some of the greatest chal-lenges in the UK market are the morestringent approval processes that stresspublic input.

“The environmental and planning

approval process (for new wind powerplants), some can be quite long (in theUK),” Mr. Bentz points out. “There canbe considerable delays, as they ensurethat these projects are well-approvedthrough much public input.”

This public input (for projects above

50MW) can include community consul-tation at the local level and statutoryauthority consultation from the centralgovernment, with no set time limit for theentire process.

In comparison, Canadian projectshave enjoyed smooth sailing.

“The wind projects here have been

holding to their time frames, usually 6 to12 months.”

The opportunities for investment inCanada’s power sector are significant(see sidebar story, Record Year for WindEnergy Sector). In Ontario alone, it isprojected that by the year 2020, $40 bil-

lion investment in energyinfrastructure construc-tion costs will berequired. Growing pri-vate-power productionand natural gas networksin British Columbia, acompetitive electricitymarket in Alberta, renew-able power generation inQuebec and the expan-sion of hydro power gen-eration in Newfoundlandand Labrador are amongthe array of other invest-ment opportunities thatexist. “Climate change and theKyoto Protocol are dri-

ving this,” points out Mr. Bentz. “Thesecurity of the supply (oil and gas) willnecessitate a broad mix of powersources, and the price of oil and naturalgas - not to mention the cost and risk offuel delivery - makes wind a more viableoption. There is no cost and no risk towind power generation.” ET

INDUSTRY NEWS

MEETING FUTURE DEMAND HINGES ON MANYFORMS OF GENERATION

By Don Horne

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provide their clients a truly end-to-end energy management system.

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MY FEELING, ANDTHAT OF THE PANEL, ISTHAT THE ANSWER ISGOING TO BE A MIXOF POWER - HYDRO,

NUCLEAR, COAL,WIND AND SOLAR -

TO MEET GENERATIONTARGETS AND THOSE

OF THE KYOTOPROTOCO

ET_issue5-2005 7/8/05 1:06 PM

ty concerns like sags and swells, and har-monics.

“With both companies sharing thesame meters at the same time, there’s novariation in the data,” explainsAbdulrahim, “and with every meter inthe network synchronized to the millisec-ond using a standard GPS signal, time-of-use data is absolutely accurate.Overall, this arrangement provides theshared monitoring, reporting and billingcapabilities needed to help accommodatethe needs of this growing market.”

As part of Jordan’s efforts to attractprivate investment to the country’s devel-oping energy sector, a reliable meteringand communications infrastructure ishelping to support the business processesbetween market participants.

Through the adoption of a synchro-nized, countrywide enterprise energymanagement system, NEPCO has set thestage for a competitive, financially viableenvironment for the production and saleof electricity.

The author Anthony Tisot is a profession-al writer with Power Measurement, spe-

cializing in energy-management strate-gies and communications technology.


In Victoria, Canada, representatives from Jordan inspect ION 7500 energy meters destinedfor the region’s electricity supply network. (From left: Engr. Munir Najjar, project manager,CEGCO; Dr. Abdallah Abdulrahim, managing director, AMPS; Engr. Faten Khuraishi, pro-ject manager, NEPCO; Michael Gillis, project manager, Power Measurement.)

JORDANcontinued from page 23

ET_issue5-2005 7/8/05 1:06 PM


INDUSTRY NEWS

RECORD YEAR FOR WIND ENERGY INDUSTRY

Canada’s wind energy industry has already bro-ken its annual growth record in 2005 and isset to shatter it before the year is out. As ofJune 2005, Canada had installed 126 MWof new wind energy capacity, breaking theexisting record of 122 MW established in2004. Close to 200 additional MW of newwind energy capacity is expected to be installed inCanada before the end of 2005. Canada currently has570 MW of installed wind energy capacity, enoughto power more than 200,000 homes.

“With Canada’s installed wind energy capacityexpected to grow by close to 70% this year, 2005will be remembered as the start of Canada’s windenergy boom”, says Robert Hornung, President ofthe Canadian Wind Energy Association.

“Over the next five years, federal and provincialgovernment policies and targets are on track to facil-itate a ten-fold increase in the size of Canada’s windenergy industry.”

Projects already installed this year include thePubnico Point Windfarm in Nova Scotia and theMont Copper and Mont Miller Windfarms inQuebec. In addition, wind energy projects are eitherunder construction, or will begin construction thisyear, in Alberta, Saskatchewan, Manitoba, Ontarioand New Brunswick.

“In addition to their environmental benefits,wind energy develop-ments are also provid-

ing lease income to landowners, tax revenues tomunicipal governments, and creating investment andjobs in rural communities across Canada”, saysHornung. “For example, three new facilities are cur-rently under construction in Quebec alone to manu-facture wind turbine towers and blades and to assem-ble wind turbine components.”

The Canadian Wind Energy Association(CanWEA) represents more than 180 companies

involved in Canada’s wind energy industry,including wind turbine and component man-ufacturers, wind energy project developers,

electric utilities and service providersto the wind energy industry.CanWEA’s goal is to see 10,000 MWof installed wind energy capacity inplace in Canada by 2010.

“While the growth we are seeing is signif-icant, wind energy continues to developmore quickly in other countries”, says

Hornung. “With Canada’s unparal-leled wind resource, we can still domore to maximize the environmen-tal, economic and industrial devel-

opment benefits associatedwith wind energy.” ETPhoto of a wind generation station in the U.K.

ET_issue5-2005 7/8/05 1:06 PM


AUTOMATION

Automation is a fine tool, butautomation plus remote control is evenbetter. Just ask the team at Kansas CityPower & Light, where engineers tappedinto an automatic meter reading systemto better manage the capacitors on theirdistribution system. The project demon-strates how much utilities can gain whenthey harness the power of fixed-networkcommunication for operational improve-ments. Following is a brief account ofthis award-winning approach to capacitorbank management.

TAKING CHARGEIn August of 1991, KCP&L was

studying AMR capabilities and examin-ing business case justifications for thetechnology. It turns out that weather hada big impact on whether the utility wouldchoose CellNet’s fixed network system,which it did.

“On August 29, we had a stormmove in at the end of a hot spell,” recallsCarl Goeckeler, lead distribution automa-tion engineer at KCP&L. “The tempera-ture plummeted 25 degrees in a three-hour period, but all of the buildings werestill hot, so air conditioners kept run-ning.”

Air conditioner motors draw reac-tive power (VAr or MVAr*), whichincreases the amount of power utilitiesmust generate. Reactive power often islikened to the foam atop a glass of rootbeer: It’s there and must be produced, butit doesn’t add billable or usable value.Reactive power can, however, addheadaches for electric utility engineers.

This was certainly the case thatstormy afternoon in the Kansas City areabecause simple thermostats controlledmost of the utility’s capacitors that stabi-lize voltage and minimize the amount ofreactive power that the utility needs toproduce. “As temperatures got hot, thecapacitors turned on. As it cooled down,they’d turn off,” Goeckeler says.Consequently, the capacitors shut downwhile the air conditioners kept runningand calling for MVArs.

All of this occurred when KCP&L’s

large generating station, located in theutility’s metropolitan area, was out ofservice due to an unscheduled outage.“We had too much reactive power on thesystem, which caused a lot of problems,”Goeckeler adds. Generators were over-burdened. Voltage sagged. And utilityexecutives called for innovations to pre-vent a repeat of the troublesome event.

ENGINEERING ADVANCESAt the same time KCP&L’s engi-

neering group put a task force to workseeking ways to bettercontrol capacitors, themetering group wasalready eyeing CellNet’sAMR. “We put the twoconcepts together,”Goeckeler says. “Wedecided we could lever-age the same communi-cation system for capaci-tor bank control andmonitoring as well asAMR.”

Working withCellNet, KCP&L engi-neers guided applicationof radio controls thatcould be installed in the capacitor con-trols themselves. Such special engineer-ing was necessary because CellNet’s sys-tem offered only two-way communica-tion to CellNet communicationCellMasters that aggregated informationfrom multiple communications collectorsthat collect readings from various metersand relayed it onto the system’s head end.“We implemented a two-way radio in thecapacitor control that is similar to theradio used in the CellNet CellMaster,”Goeckeler explains. “The radio is moreexpensive to deploy than the devices inmeters, but it’s much more sophisticat-ed.”

After testing and proving the con-cept, KCP&L began strategically retro-fitting existing capacitors with the newradio technology. About 30 percent of theutility’s 1,600 capacitors are on constant-ly, but the remaining capacitors are

switched to go on and off as needed.Today, the utility has about 800 capaci-tors automated for on-demand switchingvia the CellNet system. But from thestart, KCP&L knew that control was onlypart of the value the communicationdelivered. It also delivered informationand savings.

ZAPPING THE BUGSAlthough the automated communi-

cation with capacitors gave KCP&Lengineers data every five minutes, the

utility quickly realizedthat data is only valuablewhen you have the abili-ty to use it to help man-age your system. “It waslike having all kinds ofinformation on theInternet, and no way tosearch for it,” Goeckelersays. “We had to devel-op a query tool.” With the query tool, thecapacitor automationsystem became far morepowerful. Engineersworked out a program toallow on-demand reads,

which permits KCP&L to do trouble-shooting, voltage profiles and currentprofiles, and examine power outages. Inaddition, engineers can view historicaldata. “If we have a low-voltage com-plaint, we can see if the capacitor was onwhen it should have been,” Goeckelersays.

REMARKABLE RESULTSThe real beauty of KCP&L’s system

is the efficiency that capacitor controlprovides. Engineers quickly discoveredthe utility had more capacitors out in thefield than it needed. “In the past, if weneeded eight capacitors, we’d install 10because they were so difficult to man-age,” Goeckeler says. “Now, if we needeight, we install eight.”

In the early 1990s, when KCP&L

AUTOMATION PLUS REMOTE CONTROLPAYS OFF FOR KCP&L

By Betsy Loeff


IN THE PAST, IFWE NEEDED EIGHTCAPACITORS, WE’D

INSTALL 10 BECAUSETHEY WERE SO

DIFFICULT TOMANAGE,”

GOECKELER SAYS.“NOW, IF WE NEED

EIGHT, WEINSTALL EIGHT.”

ET_issue5-2005 7/8/05 1:06 PM


The question of whether negawatts –energy conservation – could and shouldcompete with megawatts (MW) of gener-ating capacity was debated in the early1990s with the overall result that subsi-dies required for negawatt (NW) pro-grams did not produce sufficient benefitsto justify the cost.

These demand side managementprograms (DSM) were also intended tobe Robin Hood in reverse – they taxedthe poor and subsidized the rich. Theissue of NW competition is arising againas power pools, various states, andCanadian provinces attempt to maintainadequate resources to meet power needsat minimum cost and reduce peak prices.This article is based on a report distrib-uted at the recent Ontario Power Summitand explains that NW can add significanteconomic value, but this value is highlysensitive to the market design.

If NW were able to bid along sideMW in the Ontario wholesale marketfour major benefits would result: (1)average wholesale and retail priceswould decline, (2) critical peak priceswould also decline, (3) the wholesalemarket would become more stable, and(4) locational market power would bereduced. Ontario retail customers, andthe regional economy, would obtain sig-

nificant economic benefits. However, ifNW were allowed to compete with ener-gy suppliers in the PJM energy market(The PJM coordinates the movement ofelectricity through all or parts ofDelaware, Illinois, Indiana, Kentucky,Maryland, Michigan, New Jersey, NorthCarolina, Ohio, Pennsylvania,Tennessee, Virginia, West Virginia andthe District of Columbia), customerswould not see these benefits. The criticaldistinction is that the energy market onlyin Ontario reveals efficient peak prices.In contrast, the separate energy andcapacity markets in PJM, along with theinstalled capacity obligation in PJM, pro-duces flat rate capacity pricing that sub-sidizes high cost peaking MW and dis-criminates against lower costs NW.

The critical characteristics of thenegawatt program considered here are itsdispatchability by the system operator,and that it produces measurable, reliableand verifiable results. The system oper-ator must be able to use NW to meet loadwith the same level of reliability and con-trolability as when dispatching MW tomeet projected load. A negawatt programcould curtail or interrupt power use; butthe program considered here is marketbased and competes in the wholesalemarket without a subsidy.

ILLUSTRATING A NEGAWATTPROGRAM

Table 1 is a simple and hypotheticalillustration of the market effects ofincluding 300 NW of supply alternative.Although the numbers are hypotheticaland illustrative, the MW of capacity andsupply of negawatts are roughly applica-ble to Ontario. We assume first that thesystem operator projects that 27,600 MWof capacity is required to meet projecteddemand. As in the Ontario auction mar-ket, the supply resources in Table 1 (seepage 32) are stacked from the lowestprice bid to the highest price bid. Thelowest price bids of the first 27,600 MWof capacity will be accepted, with themarginal bid price determining the

wholesale price received by all bidders. Meeting peak demand requires a

capacity level above 27,600 MW, whichwe illustrate by bids of capacity incre-ments of 300 MW. This capacity incre-ment is selected to correspond to a plau-sible increment in negawatts. The secondcolumn in Table 1 illustrates bid pricesthat define the supply curve whereincreasing levels of MW of capacity arerequired to meet peak demand. The thirdcolumn depicts the larger price incre-ments that characterize an increasinglyinelastic supply curve. For instance, inthis illustration, the increments in base-load capacity increase in bid price by 0.1,0.2 and 0.3 cents. However, these priceincrements increase as installed capacitylevel is approached and the last two priceincrements are 1.0 cents and 2.0 centsrespectively. The last bid of 300 MW ofcapacity increases the marginal bid pricefrom 7.3¢/kWh to 9.3¢/kWh – an incre-ment of 2.0¢/kWh. The market clears27,600 MW of capacity being supplied ata market spot price of 7.3¢/kWh.Wholesale customers pay 7.3¢/kWh foreach kWh they purchase during this auc-tion period.

The illustration thus far assumes thatall market adjustments are supply sideand in the form of adding MW of gener-ation to meet demand. We now allow for300 negawatts to be economically viableat 5.8 ¢/kWh. With 300 negawatts enter-ing the bid order, the 300 MW powerplant that bid 5.9 cents drops down oneplace in the order (col. 4, Table 1). Allhigher price bids also drop down oneplace in the stacked order. The negawattresponse has the effect of moving downthe bid order of all higher priced MWsupplied. The last 300 MW of supplyrequired previously to meet demand is nolonger required; it is displaced by 300negawatts of reduced megawatt use (col.5). As depicted in Table 1, the marketagain clears with 27,600 MW ofresources being used to meet projected

GENERATION & CONSERVATION

CAN NEGAWATTS COMPETE WITH MEGAWATTS?

By Ronald J. Sutherland, Consulting Economist

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has joined Aird & Berlis LLP as an advisor to the firm’s Energy Group.

Les Horswill

ET_issue5-2005 7/8/05 1:06 PM

We are pleased to announce

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ET_issue5-2005 7/8/05 1:06 PM

avoiding the need to patrol capacitorsannually. Periodic patrols are used toverify proper operation of the capacitorbank and control. With the CellNet sys-tem, KCP&L’s engineers are able todetermine all of this remotely.Eliminating the need to check 800capacitors each year shaves close to$100,000 off the utility’s maintenanceexpenses.

System efficiency results, as well.“This morning I looked at the systemand we had only three more MVArs thanwe needed. The load was 1,600Megawatts. That’s virtually unity powerfactor,” Goeckeler says.

Overall, KCP&L is achieving sig-nificant annual savings through reducedcosts for capacitor banks, patrols andline loss. “In addition, our equipment isrunning more efficiently, so we’re get-ting more life out of it,” Goeckeler adds.

And perhaps the greatest contribu-tion this program offered was theresilience it gave KCP&L. In Februaryof 1999, the utility suffered a gruesomesetback when a critical power plant inmidtown Kansas City imploded. “Themulti-story facility blew down to a fewfeet of rubble,” says Goeckeler.“Suddenly, that crucial power plant was-n’t available to produce power and stabi-lize system voltage and VArs.”

Many voltage problems were proac-tively resolved during the two and a halfyears the utility spent rebuilding its lostpower plant. KCP&L engineers usedtheir query tools to find and turn onavailable capacitors by changing theautomatic on/off set points. “What’s neatabout this is that we didn’t need to justturn the capacitors on and worry aboutvoltage getting too high. Ours turn offautomatically when they’re not needed.”

On several occasions, KCP&L engi-neers used capacitors to augment systemvoltage and MVAr flow when the powerplant was out of service for two and halfyears. “Meter reading may be the plat-form, the bread and butter of an AMRsystem,” Goeckeler says, “but this is aclassic example of how much more util-ities can do to leverage that communica-tion infrastructure.”

* VAr or MVAr: Volt Amperes Reactiveor Megavolt Amperes Reactive is the com-mon abbreviation for reactive power, whichis energy produced to accommodate needsof electric motors and other equipment.

AMRA is an abbreviation for theAutomatic Meter Reading Association,of which Betsy Loeff is a news writer.

“By avoiding the need to invest innew capacitors, we saved around $2 mil-lion over a 10-year period,” Goeckelersays. “We still install fewer capacitorseach year than we used to. Now, wemostly add new capacitors to keep upwith system growth of 2 or 3 percent peryear.” KCP&L’s system grew 2 percent ayear during the early 1990s too, butmoving capacitors still took care of theutility’s equipment needs.

The utility also saves money by

first started the capacitor bank controlprogram, the utility routinely installedup to 50 new capacitors to its distribu-tion system each year. Gaining controland data allowed engineers to relocatesome capacitor banks, rather than installadditional ones. And that happy circum-stance lasted for eight years.


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ET_issue5-2005 7/8/05 1:09 PM

For example, much training andcross training is required for CISSPs, andcompanies are reticent to over-train anyindividual, particularly if there is no pro-rated repayment schedule if the trainedemployee leaves within a year of receiv-ing training. Even if there is a form ofrepayment, should the employee leaveearly, there is no ROI on the time spentachieving the designation. Outsourcers,on the other hand, completely eliminatethis problem.

Similarly outsourcers can afford toutilize various security technologies andcan better afford to switch or upgradetechnology compared to their clients.This is due, in part, to the fact that tech-nology manufacturers are willing to pro-vide volume discounts and extra supportto outsourcers, particularly when out-sourcers provide valuable technical feed-back to software developers.

CONCLUSIONA well composed outsourced IT

security service should provide a proofof concept which can be used to bothconfirm and fulfill the client’s businessneeds. It can also be executed at reason-able cost and with a quick time to deploy.As a result, a client’s risks are mini-mized, should the client wish to proceedinto full production. The client can leverthe outsourced service to provide back-end processing and additional CISSPsupport which they could otherwise notafford, while retaining control and fullmanagement of their internal IT securitysubsystems. Everybody wins!

Ron Lepofsky is the President and CEOof ERE Information Security Auditors,who are information security and finan-cial disclosure/privacy compliance audi-tors.

Freddie Whitlock, Crewleader forCenterpoint Energy in Houston, Texas:

“Very informative magazine.”

Marvin Geersen, Metering SystemsEngineer with the Nebraska PublicPower District, Kearney Nebraska:

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LEVERAGE RISKcontinued from page 22

YOU SAID IT...

ET_issue5-2005 7/8/05 1:12 PM

demand, but this resource now consists of 27,300 MW ofcapacity at its margin bid of 6.3 cents and 300 negawatts ofreduced demand, which enters the bid order at a lower price.

The first effect of increasing this supply alternative is toreduce the wholesale price to all customers. The market priceis again determined by the marginal bid price, but with 300

negawatts of market based resources entering the bid order, therequired resources are now brought on line at a reduced mar-ginal cost. Table 1 illustrates that with the negawatt response,the spot market clears with 300 less MW of capacity, and at areduced peak price of 6.3 ¢/kWh instead of 7.3 ¢/kWh.

Wholesale electricity markets, that use spot markets andproduce real time prices, tend to produce a price durationcurve that resembles an inverted hockey stick. Spot prices tendto be relatively flat during much of the year, but increase dur-ing peak periods, and increase very sharply during the fewhours of greatest peak demand. An important feature of theNW resource is that it displaces the marginal or critical peaksupply resource that produces the critical peak prices.Although market-based negawatts compete successfully wellbefore a critical peak is reached, it is the marginal, high-cost,supply resource that customers no longer have to pay for.Negawatts therefore reduce peak prices and add price stabilityto the wholesale market.

From the perspective of the system operator, the negawattprogram looks like a typical MW supply resource, not ademand side response. In fact, the impact of negawatts on thesystem is barely distinguishable from using an additional con-ventional MW technology to meet perceived load. The maineffect of adding a negawatt program to MW supplied is toreduce average prices and peak prices. The same effect onprices would occur from adding a conventional generatingplant to the mix of supply resources. A negawatt program islike a supply side resource, except that it meets projected loadby reducing the use of low value electricity instead of produc-ing more high cost electricity. The market effects on averageprices and price spikes can be identical, customers see no dif-ference, and the system operator sees little difference.

Local markets in Ontario experience price spikes whenpower demanded at one location exceeds that provided byavailable generators. Generating stations come in large dis-crete increments that do not always match locational powerneeds. Negawatts are available in tiny increments, and arewidely dispersed across a market area. Given the dispatchabil-ity requirement of megawatts and negawatts, a system opera-tor would be able to dispatch negawatts in locations experi-


NEGAWATTS / MEGAWATTScontinued from page 28

Total MW Supply Increment in MW Supplied 300 Total Resources Supply Price inSupplied Price in Market with 300 Negawatts Provided with 300 Cents/kWh with

¢/kWh Price in Negawatts at 5.9 Negawatts 300 Negawatts¢/kWh Competition ¢/kWh

Col. 1 Col. 2 Col. 3 Col. 4 Col. 5 Col. 6 Col. 7

20,000 4.8 - - 20,000 0 20,000 4.821,500 4.9 0.1 21,500 0 21,500 4.9 23,000 5.1 0.2 23,000 0 23,000 5.124,500 5.3 0.2 24,500 0 24,500 5.326,000 5.6 0.3 26,000 0 26,000 5.627,000 5.9 0.3 27,000 300 27,000 5.827,300 6.3 0.4 27,000 0 27,300 5.927,600 7.3 1.0 27,300 0 27,600 6.327,900 9.3 2.0 27,600 0 27,900 7.3

Table 1An Illustration of the Effect of 300 Negawatts on Wholesale Spot Prices


ET_issue5-2005 7/8/05 1:17 PM

The program provides a supply side resource, in the formof demand reduction that contributes to meet projected load ata lower cost than a MW only resource. It does so by reducingthe use of low value energy when market prices indicate thatsuch energy is expensive to produce.

FOOTNOTES

1 Paul Joskow and Donald Maron, “What Does a NegawattReally Cost? Evidence From Utility Conservation Programs” TheEnergy Journal, Vol. 13, No. 4, pp. 41-74.

2 Ronald J. Sutherland, “Income Distribution Effects of ElectricUtility Programs” The Energy Journal, Vol. 15, No. 4, pp. 103-118.

3 This report is available from the Electric City Corporation.See www.eleccorp.com

4 Most conservation programs do not have these characterstics,but the “Virtual Negawatt Power Plan” of Electric CityCorporation has these properties.

5 The assumption of 5.8 cents is arbitrary. The only necessaryassumption is that market-based negawatts enter the bid orderbefore the last or marginal supply resource.

6 PJM Market Monitoring Unit, 2002 State of the MarketReport, March 5, 2003, p. 68.

7 Information in this paragraph was obtained from the OntarioIndependent System Operator site, www.ieso.ca.

8 Quoted from the IESO site, www.ieso.ca, “How theWholesale Price is Determined”

Ronald J. Sutherland’s presentation was commissioned byElectric City Corp.

encing high locational marginal costs. The diversification between negawatts and megawatts

reduces supply risk that may provide greatest value in reduc-ing locational price spikes.

THE PJM MARKETThe PJM wholesale market is significantly restructured

from that of traditional regulation. This market includes auc-tion markets for energy, capacity, and others for various ancil-lary services. These markets produce real time and day aheadspot prices. Floating prices are essential to achieve price-demand response. Although PJM wholesale market pricesfloat, these prices do not reflect the actual marginal cost ofsupplying peak electricity demand.

According to the PJM market rules, an installed capacitymargin (ICAP) is set to meet peak demand requirements. In thePJM model, this installed capacity level must also be main-tained throughout the year. The cost of peaking units is there-by averaged throughout the year, just as in the traditional rateof return regulatory model. Capacity market prices vary ran-domly around an annual average price, regardless of capacityutilization. In the absence of peak prices that reflect real peakcosts, price-demand responses, including market basednegawatts, are not feasible. Just as in traditional regulation, inthe PJM market, the high cost peaking units tends to crowd outlower cost negawatts, because these high costs are shifted tonon-peak users.

With relatively flat retail rates, there is little incentive forretail customers to reduce their low value peak power inexchange for negawatts. With relatively flat wholesale pricesthere is limited opportunity for negawatts to reduce peakdemand or peak prices.

THE ONTARIO MARKETThe Ontario electricity market is an energy market only

(no separate capacity market) that includes an “energy reserve”of roughly 1400 MW above actual consumption. Wholesaleprices are determined in a real time auction market. TheIndependent Electricity System Operator (IESO) issues fore-casts of needed energy the following day. Generators andimporters submit offers to supply electricity and the offers arestacked until the highest priced offer just provides the neededpower. As stated by the IESO “All suppliers are paid the sameprice – the market clearing price. This is based on the last offeraccepted” with real time prices.

Ultimate customers are divided into low volume and largevolume customers, where large volume customers are thosewho consume more than 250,000 kWh a year. Large volumecustomers pay the wholesale price of electricity, which is afloating price determined in the auction market. Residentialand small business customers pay an administered price, whichis currently 5.0 ¢/kWh for the first 750 kWh and 5.8 cents forthe additional electricity consumed during the month.

Stable and flat rate retail prices discourage price-demandresponse in this market. At present there is demand response inthe wholesale market from the largest customers, but littleprice-demand response from residential and small businesscustomers. A market-based negawatt program is highly feasi-ble in the Ontario market.


NEGAWATTS / MEGAWATTScontinued from page 32

ET_issue5-2005 7/8/05 1:17 PM

AREVA T&D has entered into a col-laborative agreement with US diagnostictesting company, TJ/H2b to provide on-line monitoring products of T&D equip-ment in exchange for TJ/H2b’s diagnos-tic testing services of oil, gas and otherinsulating materials used in transformers,power circuit breakers and load tap-changers.

Under the agreement, AREVA T&Dwill implement TJ/H2b’s transformercondition assessment tool and provide 24hour, 7 day a week emergency laboratoryservices to its Utility and Industry cus-tomers throughout the United States andCanada. TJ/H2b is based in Sacramento,California.

The combined effort of AREVA’son-line monitoring diagnostic products

and TJ/H2b’s laboratory capabilities willenable both parties’ North American cus-tomers to reduce the occurrence of fail-ures, extend their equipment’s lifeexpectancy and help plan the replace-ment of aging transformers, circuitbreakers and tap changers.

T&D: AREVA WINS 12-MILLION-EURO CONTRACT WITH

EDF ENERGY IN THE UKAREVA T&D has jwon a 12-mil-

lion-euro contract with EDF Energy inthe UK for the supply of gas-insulatedswitchgear.

They will replace and upgrade exist-ing equipment at the Lodge Road substa-tion, located in London. Under the con-tract, they will build, deliver, install and

commission 26 bays of its F35-type145kV gas-insulated switchgear and keyancillary equipment.

EDF Energy UK is the country’slargest distribution network operator. Inrecent years, AREVA T&D has workedclosely with EDF Energy to help mod-ernize, strengthen and expand its electri-cal network to meet current and futureelectricity demands.

“Working together in this way hasenabled us to develop a true understand-ing of the customer’s specific needs.AREVA T&D was awarded this latestcontract because our offer was the mostcompact, economical and adapted to thecustomer’s requirements,” said StephenBurgin, President of AREVA in the UK.

ET


MTE Series A dV/dT filters aredesigned to protect AC motors fromthe destructive effects of peakvoltages facilitated by long cable runsbetween the inverter and motor.Depending on the turn-ontime (risetime) of thepower semiconductorsused in the inverter, andthe size of the motor;cable lengths as short as eight feet

can result in motor peak voltages that exceed the rating ofthe motor’s insulation system.

The MTE dV/dT filter is guaranteed to meet its maximumpeak motor voltage specification (150% of bus voltage)with up to 1,000 feet of cable between the filter and themotor. It is also rated for a maximum dV/dT of 200 voltsper microsecond.

New MTE Series A sine-wave filters provide a sine-waveoutput voltage when driven from PWM inverters withswitching frequencies from 2 kHz to 8 kHz. For driveapplications, these filters eliminate the problem of motorinsulation failures and reduce electromagnetic interference

by eliminating the high dV/dTassociated with inverter outputwaveforms in applications where thedistance between the motor andinverter is up to 15,000 feet.

For alternative energyapplications, such as winddriven generators, where an inverter is used to

return power to the utility distributionsystem through a step-up transformer,these filters meet the requirements of IEEE-519 and permit the use of standard transformers.

Harmonic voltage distortion feeding a transformer at fullload and at 60Hz is 5% maximum. Harmonic voltagedistortion feeding a motor at full load and at 60Hz is 5% typical.

The Sine wave filter is available in 440 – 480 VAC and 550– 600 VAC for motors from 1.5 to 600 HP (440 VAC) and1.5 to 700 HP (550 VAC). For details and our performanceGUARANTEE call:

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COLLABORATIVE AGREEMENT WITHTJ/H2B SIGNED

INDUSTRY NEWS

ET_issue5-2005 7/8/05 1:17 PM

AREVA T&D power electronics engineerMr. Michael L. Woodhouse has been designatedas the recipient of the 2005 Uno Lamm IEEEAward for his contributions in the field of high-voltage direct current (HVDC) technology.

Woodhouse has been involved in the tech-nical design, development and application ofthyristor valves for HVDC Converters, StaticVar Compensators and Flexible ACTransmission Systems for over 40 years. Hereceives the award in recognition of his out-standing contributions in the development ofhigh-voltage direct current (HVDC) technologyand in particular for his technical achievementsin the field of thyristor valves.

He is a technical expert for the AREVAT&D Power Electronic Activities Unit inStafford, UK. He has written 13 technicalpapers and has actively supported the

International HVDC community through mem-bership in numerous technical working groupsranging from the IEE, IEEE, CIGRE and IEC.In 1992, he was awarded the GEC Nelson GoldMedal for his significant technical achieve-ments in the design of thyristor valves.

Woodhouse is the fourth AREVA T&Drecipient of this award. Previous winnersinclude John D. Ainsworth (1983), AleskaGavrilovic (1989) and Tom E. Calverley (1994).

The IEEE Power Engineering Societyaward was named after Dr. Uno Lamm, theSwedish engineer and father of HVDC technol-ogy. His work has allowed HVDC to be devel-oped into an effective power system tool forlong-distance energy transport, AC networkinterconnections, and system stability enhance-ment.

ET


AREVA ENGINEER WINS 2005 UNO LAMM AWARD

INDUSTRY NEWS

Michael L. Woodhouse

ET_issue5-2005 7/8/05 1:17 PM

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ET_issue5-2005 7/8/05 1:17 PM



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ET_issue5-2005 7/8/05 1:18 PM


Publication Date: July 2005Regular Price: $35 Order Now: $24.50The latest techniques and technologies avail-able in extending the life of transformers, alongwith articles on transformer testing, monitor-ing, design, retrofitting and other elementsinvolved in keeping transformers up and run-ning.

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ADVERTISER PAGE CONTACT INFO ELECTRICITYFORUM WEB PAGEAbsopulse 33 www.absopulse.com www.electricityforum.com/products/absopulse_electronics.htmAird & Berlis LLP 29 www.airdberlis.comCable Master Inc. 37 www.cablemasterinc.com www.electricityforum.com/products/cablemas.htmCanadian Electricity Forum 46 www.electricityforum.com www.electricityforum.comCanadian Hydro Power Association 11 www.canhydropower.comThe Delta Group 38 www.delta.xfo.com www.electricityforum.com/products/deltagrp.htmFlex-Core 38 www.flex-core.com www.electricityforum.com/products/flex.htmFLIR Systems Ltd. 40, 17, 37 www.flir.com www.electricityforum.com/products/flir.htmGT Wood Company Ltd. 37 www.gtwood.com www.electricityforum.com/products/gtwood.htmHydro Component Systems 25 www.hydrocomponentsystems.comHigh Voltage Supply 32 www.highvoltagesupply.com www.electricityforum.com/products/High_Voltage_Supply_(HVS).htmlHubbell Power Systems 2,15,35,37 [email protected] www.electricityforum.com/products/hubbell.htmIncon 19 www.incon.com www.electricityforum.com/products/incon.htmInfraRed Imaging Solutions 37 www.iristhermography.comKEMA 7 www.kema.com www.electricityforum.com/products/kema.htmKinetrics 10 www.kinetrics.comLineal 28 www.lineal.com Magna Electric Corp. 12 www.magnaelectric.com www.electricityforum.com/products/magna.htmMikron 9 www.mikroninfrared.com www.electricityforum.com/products/Mikron_Infrared_Inc.htmlMorgan Schaffer 39 www.morganschaffer.com www.electricityforum.com/products/morgan.htmMTE Corporation 34 www.mtecorp.com www.electricityforum.com/products/mte.htmOptimized Devices 37 www.optdev.com www.electricityforum.com/products/optimized_devices.htmPowertech Labs Inc. 30 www.powertechlabs.com www.electricityforum.com/products/powtech.htmPowerTran Company 31 www.powertran.ca www.electricityforum.com/products/powtran.htmRONDAR Inc. 5 www.rondar.com www.electricityforum.com/products/rondar.htmSynergy 23 www.synergyinc.com www.electricityforum.com/products/SYNERGY_ENERGY_INC.htmltechniCAL Systems 2002 24 www.technical-sys.com/ www.electricityforum.com/products/technical_systems2002.htmVelcon Filters 21 http://www.velcon.com www.electricityforum.com/products/velcon_filters.htm

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ET_issue5-2005 7/8/05 1:18 PM

http://www.electricityforum.com/t&d/company.htm





















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ET_issue5-2005 7/8/05 1:18 PM

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ET_issue5-2005 7/8/05 1:18 PM

Maintaining the Grid - Electric TodayOnce the EEM system was brought online, the software could...

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