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CONSULTING-SPECIFYING ENGINEER (ISSN 0892-5046, Vol. 50, No. 10, GST #123397457) is published 11x per year, monthly except in February, by CFE Media, LLC, 1111 W. 22nd Street, Suite #250, Oak Brook, IL 60523. Jim Langhenry, Group Publisher /Co-Founder; Steve Rourke CEO/COO/Co-Founder. CONSULTING-SPECIFYING ENGINEER copyright 2013 by CFE Media, LLC. All rights reserved. CONSULTING-SPECIFYING ENGINEER is a registered trademark of CFE Media, LLC used under license. Periodicals postage paid at Oak Brook, IL 60523 and additional mailing of� ces. Circulation records are maintained at CFE Media, LLC, 1111 W. 22nd Street, Suite #250, Oak Brook, IL 60523. Telephone: 630/571-4070 x2220. E-mail: [email protected]. Postmaster: send address changes to CONSULTING-SPECIFYING ENGINEER, 1111 W. 22nd Street, Suite #250, Oak Brook, IL 60523. Publications Mail Agreement No. 40685520. Return undeliverable Canadian addresses to: 1111 W. 22nd Street, Suite #250, Oak Brook, IL 60523. Email: [email protected]. Rates for nonquali� ed subscriptions, including all issues: USA, $150/yr; Canada/Mexico, $180/yr (includes 7% GST, GST#123397457); International air delivery $325/yr. Except for special issues where price changes are indicated, single copies are available for $30.00 US and $35.00 foreign. Please address all subscription mail to CONSULTING-SPECIFYING ENGINEER, 1111 W. 22nd Street, Suite #250, Oak Brook, IL 60523. Printed in the USA. CFE Media, LLC does not assume and hereby disclaims any liability to any person for any loss or damage caused by errors or omissions in the material contained herein, regardless of whether such errors result from negligence, accident or any other cause whatsoever.

COVER STORY

26 | Data center power strategiesEngineers should take a closer look at the different power strategies being used to distribute power, and how they impact the data center.BY KENNETH KUTSMEDA, PE, LEED AP

FEATURES34 | Case study:Financial call centerAs more industries deem their daily operations to be mission critical, upgrad-ing existing electrical distribution infra-structure will take on a vital role.BY JOHN YOON, PE, LEED AP ID+C

38 | Integration: Power andfire/life safety systemsIntegrating power and life safety sys-tems requires an understanding of the sources of power and the life safety system load requirements.BY BRIAN RENER, PE, AND JOSH MCCONNELL, NICET, SET

44 | Control sequences for HVAC systemsFollow these 10 steps to create a successful sequence of operation, one of the most important design aspects of any HVAC system.BY JASON A. WITTERMAN, PE, LEED AP BD+C,AND ED BUTERA, PE

36 | Case study: Data center retrofitAny time the reliability demand is high and the data cen-ter has to work around pre-existing building contraints, there are significant design challenges. However, creative engineering can turn just about any challenge into a data center with real reliability.BY ADAM J. BRENDAMOUR AND ADDAM FRIEDL, PE

3www.csemag.com Consulting-Specifying Engineer • NOVEMBER 2013

FEATURES

NOVEMBER 2013

AUTOMATION & CONTROLS

COMMUNICATIONS

ELECTRICAL

FIRE, SECURITY & LIFE SAFETY

HVAC

LIGHTING

PLUMBING

ENGINEERING DISCIPLINES

ON THE COVER: This university data center has multiple data halls. This data hall is a Tier III design with fully redundant (2N) UPS systems. Power is distributed to the server cabinets at 415/240 V using overhead plug-in type busway. Courtesy: Jacobs

06 | Apps for Engineers

09 | ViewpointWanted: Female engineers

10 | MEP RoundtablePrescription for hospital, health care facility success

19 | Career SmartHave you written a fanletter lately?

21 | Codes & StandardsDesigning high-performance buildings using 189.1

57 | New Products

63 | Advertiser Index

64 | 2 More MinutesAnd the engineering beat goes on

DEPARTMENTS

CONNELL, NICET, SET

Web exclusivesVisit www.csemag.com/archives for these Web exclusive articles:

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The digital edition of this publication is greatly enhanced and has unique content for digital edition subscrib-ers. It also includes interactive tools, such as videos, Web links, and other items. Update your subscription, and receive the digital edition on a new platform in your e-mail in-box: www.csemag.com/subscribe.

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Industry researchOn a quarterly basis, Consulting-Specifying Engineer conducts research studies on the industries covered in this publication—electrical, fire and life safety, HVAC, lighting, power, and plumbing. To download any of these research reports, visit www.csemag.com/research.

Projects in ProgressSouthland Industries is performing design-build mechanical and plumbing services for the Carl R. Darnall Army Medical Center located in Fort Hood, Texas. Replacing the existing 45-year-old hospital, this new 947,000-sq-ft hospital will provide state-of-the-art health care to service members and their families. The high-efficiency design includes a remote central util-ity plant with a 100% outside air HVAC system that supplies air to all patient care areas. Read about the project as it proceeds: www.csemag.com/Southlandproject. ity plant with a 100% outside air HVAC system that supplies air to all patient care

When engineering systems in hospitals, what’s themost complex issue you face?

Automation and controls

Codes andstandards

HVAC

Energy efficiency, sustainability

Electrical and power

Read the Q&A about hospitals and health care facilities on page 10.To view more poll results, visit www.csemag.com/poll/cse.

es andndards

HVAC

Energy efficiency, Electrical

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6 Consulting-Specifying Engineer • NOVEMBER 2013 www.csemag.com

Featured Apps

HVAC Toolkit UltimateiOS 3.0Cost: $49.99Company: Carmel SoftwareCompany Website: http://www.carmelsoft.com/index.aspxWeb download link: http://bit.ly/psQBAeThis app is a suite/compilation of all of the individual applications offered by Carmel Software plus bonus software (11 total, including: HVAC Residential Load Calcs, HVAC Equipment Locator, HVAC Quick Load, ASHRAE Ventilation Calcs, HVAC Duct Sizer, HVAC Psychrometric Plus, Steam Tables, HVAC Pipe Sizer - Liquid, HVAC Pipe Sizer - Steam, HVAC Pipe Sizer - Gas Low, HVAC Pipe Sizer - Gas High).

NFPA CatalogiOS 4.0Cost: FreeCompany: NFPACompany Website: http://nfpa.orgWeb download link: http://bit.ly/16rIk2D

The National Fire Protection Association’s (NFPA) Catalog app allows you to browse, rate, review, and purchase NFPA codes, standards, handbooks, and other resources. The app allows you to stay up to code and be your source all from your iPhone, iPad, or iPod Touch. From the app you can purchase various products, become a member, register for seminars, and subscribe to necplus and the National Fire Codes.

Wire Ampacity ProAndroid 1.6Cost: $1.00Company: Comoving MagneticsCompany Website: http://comovingmagnetics.com/wp/Web download link: http://bit.ly/1iMQmHBThis app will calculate the minimum wire or max amps based on the inputted ampacity for low voltage wire, equipment and service ground size, residential feeder size, as well as additional related functions. The calculations are based on the 2008 NEC code.

AutoCAD WSiOS 3.0, Android 2.0-2.1Cost: FreeCompany: Autodesk, Inc.Company Website: http://www.autodesk.com/Web download link: http://bit.ly/q2IITn (iOS), http://bit.ly/qAFbmM (Android)AutoCAD WS is a mobile CAD application that gives you the ability to view, edit, and share your DWG � les. AutoCAD WS mobile app offers a simpli� ed set of viewing, editing, and markup tools so you can work on your designs while you are on the go. Open drawings from email attachments, sync your � les from the web, or upload drawings directly from AutoCAD software. Drawings can also be saved locally so you can work in the � eld without an Internet connection.

CFE Media’s Apps for Engineers is an interactive directory of more than 170 engineering-related applications for Android and iOS operating systems, created by various companies. The app helps users do their jobs better and save time, providing a “pre-sort” of relevant mobile engineering applications loaded with various calculators, catalogs, file viewers, measurement tools, and more. www.csemag.com/appsforengineers

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1111 W. 22nd St. Suite 250, Oak Brook, IL 60523630-571-4070 Fax 630-214-4504

At the risk of sounding like a feminist from the 1960s, I’m going to diverge from the

technical topics usually covered here, and discuss women in engineering. If you don’t think this is a business issue worthy of this space, please read on.

An “It’s the Economy” article by Catherine Rampell in the Oct. 27 New York Times made an interesting connec-tion between the growing number of stu-dents wanting to become forensic scien-tists and the TV show “CSI.” Rampell’s example discussed a young girl who liked science and watched “CSI.” One of the girl’s teachers suggested she attend an 8-week computer science program with Girls Who Code. After completing the course, the young lady decided to major in computer science in college, a previously unknown career option.

I’d love to see more engineering programs like this that engage students while they’re young, and excite them about the prospect of being an engi-neer. Right now, women make up only 10.5% of employed engineers in the United States, according to data from the Society of Women Engineers. That number is too low, and youngsters need to be engaged earlier.

A short time after reading the article, I attended The Executives’ Club of Chicago breakfast roundtable, in which five women in high-ranking tech jobs

spoke about the various aspects of being a female scientist or engineer. They cited statistics that—while I knew to be a national issue—I didn’t realize were so startling. For example, science, technology, engineering, and math (STEM) jobs will grow in leaps and bounds over the next sev-eral years. According to a report by myCollegeOptions and STEMconnec-tor, the STEM workforce will grow to an estimated 8.65 million workers by 2018 (up from 7.4 million in 2012). We must encourage more women to get involved in STEM-related careers, many of which have valuable benefits beyond the relatively high compensa-tion levels.

Still, this growth isn’t nearly enough—we need more women in engineering. We need more female role models and mentors, and we need to remove the barriers young girls may face when considering STEM degrees so that they can be the engineering leaders of tomorrow.

Your task? Engage and encourage more women to be engineers, and to be on your team. Looking strictly at the return on investment, data compiled in 2012 by research group Catalyst showed women held 16.6% of board seats at Fortune 500 companies. Companies whose boards are made up of at least one-third women make 42% more.

Editor’s Viewpoint

Send your questions and comments to:[email protected]

Wanted: Female engineers

Amara Rozgus Editor in Chief


1111 W. 22nd St. Suite 250, Oak Brook, IL 60523630-571-4070 Fax 630-214-4504

CONTENT SPECIALISTS/EDITORIAL AMARA ROZGUS, Editor in Chief/Content Manager

630-571-4070 x2211, [email protected]

AMANDA MCLEMAN, Project Manager630-571-4070 x2209, [email protected]

BEN TAYLOR, Project Manager 630-571-4070 x2219, [email protected]

MICHAEL SMITH, Creative Director 630-779-8910, [email protected]

CHRIS VAVRA, Content [email protected]

EDITORIAL ADVISORY BOARDANIL AHUJA, PE, LEED AP, RCDD, President, CCJM Engineers, Chicago

PETER ALSPACH, PE, LEED AP BD+C, Associate Principal, Mechanical Engineer,

Arup, Seattle

J. PATRICK BANSE, PE, LEED AP, Senior Mechanical Engineer,

Smith Seckman Reid Inc., Houston

THOMAS BROWN, PE, Executive Vice President, RJA Group Inc., Laurel, Md.

MICHAEL CHOW, PE, LEED AP BD+C,Principal, Metro CD Engineering LLC, Powell, Ohio

DOUGLAS EVANS, PE, FSFPE, Fire Protection Engineer,

Clark County Building Division, Las Vegas

JASON GERKE, PE, LEED AP BD+C, CXA, Mechanical Engineer, GRAEF, Milwaukee

RAYMOND GRILL, PE, FSFPE, Principal, Arup, Washington, D.C.

DANNA JENSEN, PE, LEED AP BD+C,Associate Principal, ccrd partners, Dallas

WILLIAM KOSIK, PE, CEM, LEED AP BD+C, BEMP,Principal Data Center Energy Technologist,

HP Technology Services, Chicago

KENNETH KUTSMEDA, PE, LEED AP, Engineering Design Principal, KlingStubbins, Philadelphia

KEITH LANE, PE, RCDD, LC, LEED AP, President, Lane Coburn & Assocs., Seattle

KENNETH L. LOVORN, PE, President, Lovorn Engineering Assocs., Pittsburgh

MICHAEL MAR, PE, LEED AP, Senior Associate,

Environmental Systems Design Inc., Chicago

BRIAN MARTIN, PE, Electrical Engineer, CH2M Hill, Portland, Ore.

SYED PEERAN, PE, Ph.D., Senior Engineer, CDM Smith Inc.,

Cambridge, Mass.

BRIAN A. RENER, PE, LEED AP, Electrical Platform Leader and Quality Assurance Manager,

M+W Group, Chicago

RANDY SCHRECENGOST, PE, CEM, Austin Operations Group Manager and

Senior Mechanical Engineer, Stanley Consultants, Austin, Texas

GERALD VERSLUYS, PE, LEED AP, Principal, Senior Electrical Engineer,

TLC Engineering for Architecture, Jacksonville, Fla.

MIKE WALTERS, PE, LEED AP,Principal, Confluenc, Madison, Wis.


CSE: What sorts of challenges do hos-pitals and health care facilities pose that you don’t encounter on other projects?

Michael Chow: Remodeling existing health care facilities and hospitals can be challeng-ing due to the existing conditions and keeping the facility running 24/7 during construction. There may be a lack of record engineering drawings, labeling of HVAC systems, or elec-trical panelboard schedules. Also, there may be tight above-suspended ceiling space for new engineering systems (e.g., ductwork).

George Isherwood: The people who go to health care facilities are under stress. Whether they are the patient or a family member, they are often overcome by worry and concern. I believe this is important to keep in mind when designing systems in health care facilities. Making things easy and comfortable should be our highest priority.

Michael Lentz: The biggest challenges that I see in health care facilities are energy savings, maintenance, pressurization, and operational redundancy. With the current economic situ-ation, health care, just like any other indus-try, has had to cut corners. New projects are demanding tighter budgets, and health care facilities are reducing their maintenance staff. This is a more serious concern in health care due to the nature of the facilities to care for patients. It is very difficult to meet the energy savings that are required by U.S. Green Build-ing Council LEED, or even requested by the owner, and sometimes still meet the need of the patients and the facility. Tighter budgets

also restrict what types of energy-saving mea-sures the project can support. Budgets have also pushed for more maintenance-friendly equipment while trying not to lose quality or redundancy capabilities.

CSE: Looking into the future 2 to 5 years, how will the needs and character-istics of hospitals and health care facili-ties change?

Lentz: More and more health care facili-ties are outsourcing maintenance, which then requires a more maintenance-friendly design. This can greatly increase the cost of the project. Mechanical equipment needs to be more advanced in order to reduce main-tenance. The mechanical equipment needs to communicate with the building manage-ment system (BMS) more so fewer staff members can monitor a larger number of pieces of equipment. The equipment needs more alarm points in order to troubleshoot problems quicker and easier. Also, more and more of the mechanical equipment is either being required to be or requested to be on emergency power. All of this affects the proj-ect budget and contributes to the rising cost of health care.

Isherwood: In my experience, I believe the health care industry is making great strides at changing the public’s perception on what to expect when visiting medical and health care facilities. Health care facilities have always been a place you go when you’re sick or injured. In the near future, that will continue to

MEP Roundtable

PARTICIPANTS

Michael Chow, PE, CxA, LEED AP BD+CMember/Owner

Metro CD Engineering LLCPowell, Ohio

George Isherwood, PEVice President

Peter Basso AssociatesTroy, Mich.

Michael LentzAssociate

RMF EngineeringBaltimore

George Isherwood, PE

Michael Lentz

Prescription for hospital, health care facility successHospital and health care facility projects are especially important due to their sensitive nature. Engineers charged with designing these buildings must take special care when working in these missioncritical facilities.


change. I first noticed this when we went to visit my mother-in-law at our local hospital. She commented that her room was like a nice hotel. My oldest daughter attended a healthy cooking class, and my younger children wanted to go back for dinner after my mother-in-law was dis-charged. Looking at the design of hos-pitals, sometimes we become immune to the effects they have on the general public. My children’s experience going to the hospital was one of excitement and learning, which is day and night to my memory in visiting hospitals as a child and a young adult.

Chow: We anticipate there will be more renovations to existing hospitals and health care facilities. The chal-lenge will be to meet the future codes such as the number of receptacles in critical patient rooms increasing due to changes in NFPA 70: National Electri-cal Code (NEC). The existing electrical infrastructure may not be able to accom-modate these changes without signifi-cant additions that many times are not accounted for in the initial construction budget by the owner of the facility.

CSE: How often are you called on to retro-commission hospitals and health care facilities, as opposed to new construction of a building? What are some key differences between the two?

Isherwood: In our experience, commissioning services are being purchased for new construction in hospitals, but the demand for retro-commissioning services is not as high. We believe this is because of the high monitoring of existing systems from outside review agencies. Even though these reviews are being completed, we believe most health care systems do not fully realize the benefits of retro-commissioning.

CSE: Since the Affordable Care Act passed, what shift in the types of hospitals and health care facili-ties work have you experienced? For example, a bigger workload, more retro work on existing facilities vs. new construction, etc.

Isherwood: I think health care net-works are still figuring out how the Affordable Care Act is going to benefit them and they are holding back resourc-es until the government uncertainty is clarified. We have experienced a shift toward smaller renovations and infra-structure projects.

CSE: How has the economy impacted your work in this area? Have you seen the number of proj-ects decline with the recession, and improve now that the economy is on the uptick?

Isherwood: I believe the economy has not had a significant impact on the large-ly privatized health care design industry. I believe the implementation and shift-ing of resources from the adoption of the Affordable Care Act has overpow-ered any positive effects from the rising economy.

CSE: What factors do you need to take into account when design-ing building automation systems

Peter Basso Associates engineering projects, such as the Brehm Tower at the Kellogg Eye Care Complex at the University of Michigan, Ann Arbor, include specialized features such as laboratory facilities. Courtesy: Peter Basso Associates (Anton Grassl Photography)


MEP Roundtable(BAS) for hospitals and health care facilities?

Lentz: All major building equip-ment needs to be tied into the BAS and alarmed for malfunctions. This is due to the critical nature of the systems to func-tion 24/7 and also due to most health care facilities reducing maintenance staff. Emergency power for the auto-mated control system and local panels also needs to be accomplished. Again,

due to the critical nature of the systems to function 24/7, the systems cannot shut down, and if the controls are not on emergency when power is lost, the units will not automatically restart after the 10-second delay.

Isherwood: Ease of service and the ability to understand the systems is crucial. Building controls are becom-ing more complex and maintenance staffs are being asked to do more with fewer resources. We need to make sure we design building control systems that will not become a burden on the staff, but a benefit.

CSE: How does implementing BAS in an existing building differ from designing controls for a new build-ing?

Isherwood: There are a significant number of small hospital systems that have been using the same BAS for years. Some of these networks will no longer be supported by basic operating com-puter systems, let alone the BAS sys-tem. Also, different manufacturers have opened different control protocols for tying into a BACnet or similar common language. These challenges are huge for

small hospitals, from both a solution and a cost standpoint.

CSE: What’s the one factor most commonly overlooked in electrical systems in hospitals?

Chow: Understanding and incorporat-ing the applicable codes and standards for a hospital is commonly overlooked. A hospital may be certified by The Joint Commission and an engineer designing

a remodel may inadvertently overlook their standards and requirements.

Lentz: What equipment that the owner would like to see on emergency power and what the code actually allows on emergency power. For example, in a patient room, hospitals would like the lighting on emergency power on the life safety branch, but code does not allow lighting on a life safety branch. So in order to provide that, it would then require additional panels and transfer switches to put the equipment on emer-gency power, but results in increased project costs and space requirements.

CSE: Describe a recent project in which you had a complex standby, back-up, or emergency power design.

Lentz: Inova Women’s Hospital has three 2 MW 5 kV generators parallel-ing with the utility system and four distribution sub-stations. Three 2 MW, 4.16 kV enclosed diesel engine electric generators (EGs) and auxiliary systems were provided in a designated outdoor yard, remote from the hospital central plant. The 2 MW emergency generators were paralleled through the emergency

generator 5 kV paralleling switchgear (EGPS). The EGPS was configured with two outgoing main breakers to the normal 5 kV switchgear, one bus tie breaker, two emergency generator auxiliary load breakers, existing plant breaker, and three generator breakers. Although the generators were intended to be used as standby generators only, the use of a selective catalyst reduc-tion (SCR) system was provided in the design. The SCR system reduces engine emissions, specifically NOx up to 90%, and has become a required component in most new generator installations to meet state/U.S. Environmental Protec-tion Agency emissions requirements. The SCR system consists of an injec-tion/mixing pipe, catalyst housing, solution storage tanks, solution transfer pumps, and associated control panels. The generator assemblies were con-tained in pre-engineered sound attenu-ated enclosures. The enclosures achieve a 40 dB(A) reduction of the generator set source noise, as measured at 1 meter from the enclosure.

CSE: What unique NFPA 99: Health Care Facilities Code issues have you encountered, and how have you resolved them?

Chow: The 2014 NEC has a proposed change to increase the minimum number of receptacles for a patient bed in a criti-cal care area from 6 to 14 receptacles. This would coordinate the requirements between the NEC and NFPA 99.

CSE: How might the complexity and scale of fire/life safety systems in hospitals and health care facili-ties vary from other types of struc-tures?

Lentz: Due to the fact that most health care facilities cannot be evacuated and have to be designed to defend a fire, in-place smoke control systems can become very complex. Smoke zones need to be designed so that when a zone

“Understanding and incorporating the applicable codes andstandards for a hospital is commonly overlooked. A hospitalmay be certified by The Joint Commission and an engineer designing a remodel may inadvertently overlook their standards and requirements.” —Michael Chow


is alarmed, that specific zone can be kept at a negative pressure to the adjacent smoke zones in order to contain all of the smoke in the zone under alarm. We have found that the best way to accom-plish this is under the smoke control sequence of operation, we convert the air-handling unit (AHU) that serves the smoke zone under alarm to 100% outside air. We are using the return fan now as a smoke exhaust fan. A modulat-ing smoke control damper is installed on the supply air duct serving the zone, and it modulates to maintain the zone at a negative pressure. The supply air smoke control damper is controlled by a differential pressure sensor located at the doorways between the zone under alarm and all adjacent smoke zones.

CSE: What are some important factors to consider when design-ing a fire and life safety system in hospitals and health care facilities? What things often get overlooked?

Lentz: Smoke control systems are often overlooked, which can require a hospi-tal to shut down critical AHUs during a fire/smoke alarm. Atrium evacuation

systems and stair pressurization systems are also often overlooked, which can be very difficult to install and engineer after construction or even during the design process without a lot of redesign. When designing smoke control systems or atri-um smoke evacuation systems within the building’s normal HVAC system, what is generally overlooked is the fact that the components of the HVAC system now have to be UL listed for that use and now have activation or communication with the fire alarm system.

CSE: What unique requirements do hospitals and health care facili-ties’ HVAC systems have that you wouldn’t encounter on other struc-tures?

Isherwood: Equipment redundancy is more common in health care facilities than in other structures. This is due to the failure events that may occur and endanger patients if redundant systems are not properly designed, installed, and commissioned.

Lentz: Redundancy and reliability are the largest requirements that I see. Most health care facilities require some means

of redundancy in their HVAC systems so they can still adequately serve patient and critical spaces during an equipment malfunction or failure. The amount of redundancy is always something that has to be weighed and measured against the project budget and the type of program space that is being built. For example, 100% redundancy for the HVAC system is more suitable for operating rooms and patient spaces than material holding or administrative offices. How you achieve this type of redundancy is also some-thing that is unique to each facility. Is the redundancy a standby air handling unit, a standby supply fan, a fan wall assembly, or a manifold system that can withstand the loss of partial supply air?

CSE: What HVAC techniques or tools have you used to reduce the possibility of hospital-acquired infections (HAIs)?

Lentz: Strict pressurization require-ments between different program areas within the hospital, and filtration and separation of different program areas within the hospital. For example, apply-ing 100% exhaust to the emergency

eQUEST was designed to allow engineers to perform detailed analysis of today’s state-of-the-art building design technologies using today’s most sophisticated building energy use simulation techniques, but without requiring extensive experience in the “art” of building performance modeling. Courtesy: Consulting-Specifying Engineer

MEP Roundtable

department waiting rooms. Any air-borne infection isolation room exhaust is treated with high-efficiency particulate air (HEPA) filtration. All critical spaces, such as operating rooms, recovery areas,

and sterile processing departments, are equipped with return or exhaust air ter-minal units in order to maintain correct pressurization within the program area, even if there is a loss of supply air to the space.

CSE: What software or systems do you use to model the energy con-sumption of the building?

Lentz: The two programs that we most commonly use are Carrier Hourly Analysis Program (HAP) and the Dept. of Energy’s eQUEST. These programs allow us to model the exterior of the

building and evaluate several different HVAC systems throughout the build-ing at the same time. We can see which system will have the most energy sav-ings, and then evaluate that system from a maintenance perspective as well as evaluate if the system is a prac-tical application for the building. This is especially helpful on existing build-ings when looking to replace the exist-

ing HVAC system that is beyond its useful life. We can evaluate the exist-ing skin and windows of the building and see if a total change in not only the HVAC system, but the type of HVAC system is warranted, cost-effective, and the correct engineering solution for the building.

CSE: ASHRAE has a goal: net-zero energy for all new buildings by 2030. What do other engineers need to know to achieve this goal on their hospital projects?

Chow: Engineers need to know that a net-zero energy hospital project should incorporate integrated project delivery (IPD). Also, extensive energy modeling analysis will need to be performed as well as integrating innovative design strategies and including both on-site and off-site renewable energy sources.

“We can see which system will have the most energy savings, and then evaluate that system from a maintenance perspective as well as evaluate if the system is a practical application forthe building.” —Michael Lentz

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RESPONDENTS:

� Tom Boyle, Southeast regional sales manager, Fike, Blue Springs, Mo.

� Sean Goings, CEM, CHSP, SASHE,Manager, U.S. Healthcare Solutions,

Schneider Electric, Houston

CSE: What types of tools do you recommend

for hospitals and health care facilities? What

should be in every engineer’s “toolbox”?

Fike: From a life safety prospective, a respon-

sive service organization that can support all

aspects of a safety plan. Access to multiple factory-

certified engineered systems distributors with

certified technicians that can quickly respond and

resolve system issues.

Schneider Electric: We provide efficient infra-

structure solutions for the built environment. From

electrical distribution equipment to building automa-

tion, our products and solutions focus on four key

areas of hospital infrastructure: mechanical, electri-

cal, IT, and security. Our solutions lend themselves

to a sustainable cycle of lower operating costs,

improved clinical outcomes, safety and reliability of

facilities, and positive impact to the environment. By

converging core infrastructure systems and relevant

data, facility operators are enabled to automate

cumbersome processes, streamline operations and

maintenance, and use interrelated data to better

operate facilities.

CSE: What’s the one factor most commonly

overlooked when working on electrical system

projects?

Fike: Cost of ownership of the life safety

and fire suppression systems. Often projects are

provided based on lowest installation cost. Provid-

ing the ownership costs at the beginning of the

project will ensure no surprises. Include preventive

maintenance and testing contracts, unit costs for

devices, panels, and expendables; fixed service

rates; travel rates; and other costs to provide a

better picture of the true cost of the project.

Schneider Electric: The most commonly

overlooked factor is connectivity of intelligent

electrical distribution systems to other facility

infrastructure systems. Meters, submeters, and

intelligent trip units are too often not physically

wired to communicate with power management

or other building systems. This severely prohibits

the operator’s capacity to make sound decisions

and limits the ability to monitor power quality and

dynamic consumption data, and streamline com-

pliance reporting.

MEP Roundtable

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Iam a San Francisco Giants fan. I became one when I married a lifelong Giants fan a few years ago. My wedding vows went

something like this: “To have, to hold, and to be a San Francisco Giants fan for the rest of my life.”

To be honest, while I enjoy watching the occasional baseball game, most weeks I don’t even know where the Giants rank in the standings. But something brilliant happened this week that really caught my attention. The president and CEO of the Giants organization sent out one of the best thank-you letters I have ever seen written—EVER to anyone—to the fans. The Giants did not make the playoffs, but the letter Laurence Baer sent out made the disappointed fans in my house feel great about the year. In one short letter, he managed to specifically and personally call attention to all that the Giants orga-nization had observed from the fan base. And, in a very personal way, he thanked them for their support.

This simple fan letter really made me think about how taking the time to com-municate thoughtfully and graciously can go a long way in building relationships with colleagues and customers. So what consti-tutes a thoughtful thank you letter or note?

� It is personal: The best way to make it personal is to hand-write the note—it shows you took extra time and attention to share your thoughts with the recipient. While e-mail may be more convenient or efficient, it looks like every other communication a person receives in a given day. However, if you are uncomfortable with a handwritten note, e-mail can be made personal if you

use the subject box to make your note stand out. Consider using “A Sincere Thank You” or “With Much Appreciation” to catch the recipient’s attention.

� It is specific: Tell the recipient spe-cifically what he or she has done that you value so much. This combines both the power of positive reinforcement and the power of recognition of when an indi-vidual goes the extra mile on your behalf.

� It is timely: This one should be obvi-ous. Make a point of expressing your appreciation to the recipient immediately following the event. If you are looking for a rule of thumb, send the note within a two-week window of the event.

� It is unexpected: Take the time to recognize the contributions of a colleague for what he or she does every day to help you or the firm. It does not always need to be associated with a major event. In fact, choosing an occasion not tied to a major event or project can show that you do not take the colleague for granted.

� It is sincere: Don’t go overboard in your praise or thanks. Keep your remarks simple and genuine.

And who should you consider sending one to?

� Interviewees for a new job or new position within your firm

� Your teammates who covered for you while you were out of the office

� Your business leaders when they have given you a promotion or a bonus

� Your employee or team member who has demonstrated strong performance in a challenging environment or on a dif-ficult project

� Your repeat clients for continuing to trust you with their projects

� Your new clients for either a new project or for final payment on a com-pleted project

� Your mentor or career adviser for helping you navigate your career deci-sions

� Your current employer when you leave to take a new job outside the firm.

In today’s business environment, many of us are just moving from one task or project to the next, just trying to keep up. Deadlines rule our lives. How-ever, taking the time to recognize the efforts of your peers, colleagues, or cli-ents could make all the difference during those times when a frustrated employee is thinking of leaving, a disappointed cli-ent is questioning its decision to work with your firm, or a colleague is annoyed with something you did or did not do that day. A well-thought-through fan letter is not just about being thoughtful, it’s about building and reinforcing strong professional relationships.

What are you waiting for? Let someone know they are on your fan list.

Jane Sidebottom is the owner of AMK LLC, a management and marketing con-sulting firm that provides market develop-ment and growth expertise to small- and medium-size firms. She has 20 years of management and leadership experience in both consulting engineering and For-tune 100 organizations. Sidebottom is a graduate of the University of Maryland.

Career SmartBY JANE SIDEBOTTOM

AMK LLC, Louisville, Ky.

Have you written a fan letter lately?Taking the time to recognize the efforts of your peers, colleagues,or clients could make all the difference.



Industry standards set by ASHRAE and Illumi-nating Engineering Society (IES) have been integrated into the U.S. Green Building Coun-

cil (USGBC) LEED baseline references since the original development of the LEED rating system.

In the 15 years since the USGBC introduced the pilot version of the LEED rating system, these three organizations have continuously worked together to keep the standards moving in the direction of performance and efficiency. At the same time, technology, design, and construc-tion have evolved in response to these changes.

In 2009, when ASHRAE, IES, and USGBC introduced Standard 189.1: Standard for the Design of High-Performance Green Buildings Except Low-Rise Residential Buildings, it was a significant step, marking the first time that high-performance green building characteristics had been developed as code-enforceable language. ASHRAE has since released Standard 189.1-2011, which supersedes the original version and is listed as an alternative compliance path in the 2012 International Green Construction Code (IgCC).

Unless a jurisdiction in which you regularly engineer and design buildings has adopted or is considering adopting Standard 189.1 or IgCC as part of its code requirements for permit and occu-pancy, Standard 189.1 may not have an impact on your current projects. Regardless, the fact that it is now an option for jurisdictions to consider makes it important for building design industry professionals to have a basic understanding of what it entails. It is equally important to monitor the code adoption plans and procedures of the jurisdictions where you provide service to make

sure you have the chance to review and comment on proposed changes.

As a standard, 189.1-2011 provides guidelines and minimum requirements for the design of high-performance green buildings except low-rise residential buildings. For the purposes of this overview, the standard will be reviewed in its native form of ASHRAE Standard 189.1.

It is important to remember that compared to ASHRAE Standard 90.1, 189.1 covers many aspects of construction beyond energy use. Stan-dard 189.1 includes provisions for site sustain-ability, water efficiency, indoor environmental quality, materials and resources, and commis-sioning in addition to energy use. As jurisdic-tions begin to adopt 189.1 either directly or through the IgCC, these sections will have to be considered against existing regional agencies, departments, and regulations. For example, most jurisdictions have zoning laws on the books that may contradict the site development require-ments of 189.1.

Standard 189.1 is divided into 11 sections and is supported by nine appendices. Sections one through four cover the purpose, scope, defini-tions of key terms, and administration of the standard; Section 11 contains a listing of all other standards referenced in the document, detailing the location of the reference and its responsible governing body.

If you have worked with LEED, the remaining sections are broken into categories that will look familiar: Site Sustainability, Water Use Efficiency, Energy Efficiency, Indoor Environmental Quality, Impact on Atmosphere, Materials and Resources, and Construction Plans for Operation.

By Patrick a. kunze, Pe, LeeD aP, GHT Limited, Arlington, Va.

ASHRAE has since released Standard 189.1-2011, which supersedes the original version and is listed as an alternative compliance path in the 2012 International Green Construction Code (IgCC).

Codes & Standards

Designing high-performance buildings using 189.1ASHRAE Standard 189.1 sets the standard for the total building sustainability package.

Each section has a collection of man-datory provisions that must be met in order to comply, and with the exception of Construction and Plans for Operation, each section offers both prescriptive and performance options for compliance. Construction and Plans for Operation includes only mandatory provisions.

SECTION 5 - Site Sustainability: This section covers preferred building sites (greenfield versus brownfield), roofs and site hardscape, light pollution, and plant species located on the project site with the intent of improving site selection and development, minimiz-ing heat island impact, and reducinglight pollution.

SECTION 6 - Water Use Reduction: All site and building-related potable and non-potable water consumption, includ-ing outdoor water use for irrigation and irrigation system design and controls, is covered in this section. Maximum allow-able flow rates are provided for various types of plumbing fixtures. In addition, water-consuming appliances, mechanical systems, medical systems, and roof irriga-tion are addressed.

SECTION 7 - Energy Efficiency: This section outlines requirements for build-ing energy efficiency, on-site renewable energy systems, and energy monitoring, and largely defers to the requirements of ASHRAE Standard 90.1. Provisions that go beyond the performance requirements of 90.1 include exterior wall and roof performance; fenestration performance, area, and orientation; HVAC system effi-ciency; and lighting power density. In addition to the systems covered by Stan-dard 90.1, this section includes require-ments for energy consumption metering, provisions for on-site renewable energy, and horizontal and vertical projections on the exterior. When using the perfor-mance option, an energy cost comparison alone is not allowed. The engineer must also demonstrate that the CO2 produced by operating the model building will not exceed that of a baseline model.

SECTION 8 - Indoor Environmental Quality: In this section, you will find requirements for eliminating environ-mental tobacco smoke, preventing par-ticulate contamination from entering the building (through walk-off mats and mechanical filtration), monitoring ven-tilation rates, reducing material volatile organic compound (VOC) levels, and daylighting provisions. The section also contains acoustical control requirements

that focus on limiting sound transmission between different areas. The first acous-tical control requires sound attenuation between the inside of the building and the outdoors when located near high-noise sources (e.g., expressways and airports). This is mandated in the form of wall, roof, and fenestration sound transmis-sion class (STC) ratings. Interior sound (between spaces) is controlled through STC-rated partitions between dwelling units, and between assembly areas, such as conference rooms, and other use areas.

SECTION 9 - Impact on the Atmosphere, Materials, and Resources: Provisions for the handling of materials range from sourcing (location, biobased, and wood certification) to end of life (waste diver-sion, recycling, and total waste amount for a construction project). Ozone-deplet-ing characteristics of components such as refrigerants are addressed in this sec-tion. As an alternative to the prescriptive path for materials, a lifecycle assessment

(LCA) can be performed comparing at least two alternative constructions cover-ing the material components addressed by the prescriptive path and compliant with Sections 6, 7, and 8 and the mandatory requirements of Section 9. Performing an LCA for Atmosphere, Materials, and Resources is analogous to performing an energy model for the building energy effi-ciency. That is, the LCA provides design-ers with more freedom to exceed the per-formance requirements of the standard by not being limited to the prescriptive path. In the LCA, the accepted alternative must demonstrate a 5% improvement over the prescriptive building alternate in at least two of the impact categories: land use, resource use, climate change, ozone layer depletion, human health effects, ecotoxic-ity, smog, acidification, and eutrophica-tion. The section references ISO Standard 14044 for performing the LCA.

SECTION 10 - Construction and Plans for Operation: All provisions listed in this section are mandatory. Construction pri-marily covers construction activities and the commissioning effort and includes controlling moisture on the construction site, limiting vehicle idling, erosion and sediment control, and indoor air qual-ity control. The commissioning portion outlines the commissioning process and identifies what systems must be commis-sioned. Plans for Operation tackles post-occupancy activities required to keep the building operating as it was designed throughout the building life. There are six main systems that are identified to be commissioned: mechanical systems, lighting systems, fenestration control systems (automatic shades and dynam-ic glazing), renewable energy systems, water measurement devices, and energy measurement devices.

Plans for Operation starts with devel-oping a high-performance building operation plan. In addition to tracking and recording energy and water use, site sustainability must be maintained through preservation of site vegetation. Indoor environmental quality is to be maintained through outdoor airflow measurement

Codes & Standards


that focus on limiting sound transmission

IgCC’s originsThe International Code Council (ICC) first intro-duced the public version of the International Green Construction Code (IgCC) in 2010. After undergoing two rounds of public comment, a full cycle of code development was held in 2011, which was followed by the official release of the 2012 IgCC to provide “model code regulations that contain clear and specific requirements with provisions that promote safe and sustainable construction in an inte-grated fashion with the ICC Family of Codes.” The code is currently slated to be formally updated and re-released every three years.

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and indoor air quality maintenance. Finally, a maintenance plan must be developed and implemented that cov-ers the building mechanical, electrical, and plumbing systems. This section is important because as the building sys-tems become more complex to reduce energy use and improve indoor envi-ronmental quality, it is necessary that these systems function as they were designed. Otherwise, system perfor-

mance will suffer and with it the energy use will increase, indoor environmental quality will decrease, and there will be a negative impact on the surrounding environment.

Standard 189.1 and LEEDThe value systems of 189.1 and the

LEED rating systems are intrinsically connected. This is obvious in the shared categories that they address. Simply put, LEED raised the level of conversation about sustainable building design and established it as a common practice in the building industry. Now, ASHRAE Standard 189.1 translates those prin-ciples into a design standard ready for code adoption. Taking a deeper look, there are several important distinctions to understand:

1. LEED was developed as a volun-tary program, and organizations made a choice to participate as a way to show a commitment to sustainability. Though mandates to obtain LEED certification for some government facilities do now exist, LEED is still optional for most commercial and institutional projects. 189.1 is a tool that allows jurisdictions to adopt these high-performance build-ing characteristics through enforceable building codes.

2. The distinction of 189.1 as a code-enforceable document is important in understanding its relationship to LEED. Building codes provide a minimum standard of care and safety for buildings and their occupants. Their enforcement affects the ability to obtain permits to begin construction and for occupancy after construction is complete. This is in stark contrast to projects voluntarily pursuing LEED certification, which must

submit preliminary information during design, but do not undergo a final review until after the design and construction is completed, and are not prevented from being occupied if they are not awarded certification.

3. The LEED rating system provides the flexibility to pursue a variety of cred-its to achieve certification but, other than prerequisites, does not dictate which sus-tainable design principles a project must emphasize. 189.1 is not a credit system; it is a complete model standard. To fully comply with the 189.1 standard, the design needs to address every element through both mandatory requirements and either a prescriptive or performance path.

4. A governing jurisdiction can elect whether to implement 189.1 language as-is into code or customize elements to create its own standards. Project teams pursuing LEED certification do not have the opportunity to make wholesale chang-es to the language or process.

Standard 189.1 and IgCC In addition to Standard 189.1, jurisdic-

tions have the option to adopt the Inter-national Code Council’s (ICC) IgCC to enforce minimum green building standards. The IgCC follows a LEED-

inspired outline similar to 189.1 and follows the format of other ICC codes. That familiar format—combined with the fact that the IgCC, in section 301.2, allows 189.1 as an alternative compliance path—makes it an appealing option for jurisdictions already using the ICC based code templates.

What’s nextAlthough ASHRAE Standard 189.1

may not immediately impact your proj-ects, it is important to be aware of its requirements and intent and pay close attention to whether or not local code officials are considering its (or the IgCC’s) adoption. Be sure to under-stand how code changes are adopted and implemented in your jurisdiction. Staying ahead of the implementation of potentially significant changes such as these will provide time both to internally adjust to the new requirements and to educate clients on how future projects may be affected.

Get involved in the process if possi-ble, whether providing comments during public review periods, attending public meetings, or applying to serve as a vol-unteer member of a local code advisory board. The more you know about the change, the more prepared you will be to minimize the impact on your firm and your clients.

Patrick A. Kunze is a senior principal and mechanical section head of the interiors studio with GHT Limited. Kunze has pro-vided mechanical engineering design for more than 20 projects that have achieved U.S. Green Building Council LEED cer-tification, including the USGBC’s head-quarters; contributed to the development of questions for the current LEED AP exam; and currently sits on the Green Technical Advisory Group subcommit-tee of Washington, D.C.’s Construction Codes Coordinating Board.

Codes & Standards

Building codes provide a minimum standard of care and safety for buildings and their occupants. Their enforcement affects the ability to obtain permits to begin construction and for occupancy after construction is complete.

Learn how the District of Columbia turned ASHRAE Standard 189.1 into code.

Read the longer version of this online at: www.csemag.com/archives.

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Nikola Tesla’s alternate current (ac) versus Thomas Edison’s direct current (dc) is a battle that has

been going on for more than a century and continues today in the data center industry. Although ac power is the stan-dard, based on its potential for eliminat-ing conversion losses and improving efficiency, many believe that dc power is the future of data center distribution. Still others believe that the same level of effi-ciency can be achieved with ac by using more efficient equipment with higher voltage distribution such as 415/230 V and 480/277 V.

So how do you know what power strat-egy is best for your data center applica-tion? What are the advantages and chal-lenges of each type of power distribution technique? These are important questions

that need to be evaluated when planning a data center. The goal of this article is to take a closer look at the different power strategies being used to distribute power and how they impact the data center.

Electrical efficiencyOne of the most common metrics for

measuring efficiency in data centers is power usage effectiveness (PUE) created by The Green Grid. It compares the total data center facility power to the power used to run the IT equipment. The opti-mum data center would have a PUE value of 1.0, where all the power going into the data center is being directly used to power the IT equipment. Any value above 1.0 means that a portion of the total facil-ity power is being diverted to data center support systems such as cooling, lighting,

Engineers should take a closer look at the different power strategies being used to distribute power, and how they impact the data center.

BY KENNETH KUTSMEDA, PE, LEED AP, Jacobs, Philadelphia

Data centerpower strategies

Learning objectives� Understand the different strategies used to distribute power in a data center.

� Learn how to measure power efficiency in data centers.

� Know which distribution variation is most appropriate for the application.

Figure 1: This university data center has multiple data halls. This data hall is a Tier III design with fully redundant (2N) UPS systems. Power is distributed to the server cabinets at 415/240 V using over-head plug-in type busway. All graphics courtesy: Jacobs


and the power system. The higher the PUE number, the larger portion of power is con-sumed by the support systems relative to the IT equipment itself, resulting in a less efficient data center.

In the recent past, the primary focus with lowering the PUE and increasing efficiency has been on the mechanical systems and the ability to use free cool-ing. As data center owners strive to fur-ther reduce cost, the focus has shifted toward electrical systems. Electrical sys-tems waste energy in the form of losses due to inefficiencies in the electrical equipment and distribution system. On average, the electrical distribution system losses account for 12% of the total energy consumed by the data center. For a data center with 2000 kW of IT load (2700 kW total load), that equates to an annual cost of $280,000 (see Figure 2).

Typical electrical distribution systems

The typical legacy data center electri-cal distribution system is made up of five major components. Power is supplied to the data center at medium voltage from a utility/generator power source. The power is stepped down from medium voltage to distribution voltage (480 V) by a substa-tion transformer. The power then goes through an uninterruptible power supply

(UPS) system that conditions the power and provides ride-through capability dur-ing an outage until the generator starts. The power is then stepped down to sub-station voltage (208/120 V) by a power distribution unit (PDU). The PDU supplies power to the IT power supply where it is rectified and stepped down to 12 Vdc, which is the internal operating voltage of the IT equipment (see Figure 3).

The four components in the legacy elec-trical distribution system with the highest losses are:

� Substation transformer: Transformer no-load and core losses � UPS: Rectifier and inverter losses � PDU transformer: Transformer no-load and core losses � IT power supply: Rectifier and transformer losses.

One method for increasing efficiency is to replace those pieces of equipment with more efficient equipment. Prior to 2005, when the NEMA TP1 Guide for Deter-mining Energy Efficiency for Distribution Transformers was adopted, transformer efficiencies were around 97%. Today with ultra-high-efficient transformers that efficiency is above 99.5%. Conventional double conversion UPS systems range from 84% efficient at 25% load to 94% at 100% load. Using flywheel or passive

standby UPS topology can increase that range to 94% efficient at 25% load and 99% at 100% load.

Another method for increasing effi-ciency is to eliminate partial loading of the data center. Eliminating partial loading reduces losses by allowing the equipment to operate at its peak operat-ing efficiency. This can be performed by designing a power system that is modu-lar and scalable, one that grows with the load, or by designing a power system that uses flexible tiers, and matches the reli-ability and redundancy to the different programs within the data center.

A third method is to eliminate the inef-ficient electrical equipment altogether. Increasing efficiency by eliminating the equipment that has the most losses is the reason why different power strategies are being investigated for data center distri-bution.

Figure 2: In this data center power consumption example, the IT load makes up the bulk of the electrical load.

Figure 3: The typical legacy data center electrical distribution system is made up of five major components.

Figure 2: In this data center power consumption example, the IT load makes up the

Figure 3: The typical legacy data center electrical distribution system is made up of five major components.

Power systemdesign tips

Review these six key items when planning a data center power distribution system:

� Install or replace existing power and IT equipment with energy-efficient equipment

� Review the proposed IT equipment to deter-mine if the systems can operate on 240 Vac or 380 Vdc

� Review all the advantages and challenges of the different power systems

� Determine how much of the existing infra-structure would need to be replaced to change power systems

� Design flexibility into the power system that will allow the data center to adapt in the future

� Design a power system that is modular and scalable to eliminate partial loading.

Similar to the mechanical systems, modifica-tions can be made to the electrical system to make it more efficient and save energy. The key to a good mission critical facility design is not to degrade the reliability of the facility in the process.


415/240 Vac distributionA power distribution strategy that is

becoming more widely used in the data center is 415/240 Vac. This strategy elimi-nates the PDU and distributes power at the higher voltage form the UPS straight to the server cabinet. The primary goal is to gain efficiency by eliminating the transformer losses associated with the PDU and by allowing the IT loads to operate more effi-ciently at a higher voltage (see Figure 4).

In North America, the standard power

distribution system is set up in a “wye” configuration with a phase-to-phase voltage of 208 V and a phase-to-neutral voltage of 120 V. In Europe the standard power distribution system is set up in the same “wye” configuration but with a high-er voltage distribution. The phase-to-phase voltage is 415 V and the phase-to-neutral voltage is 240 V.

In an effort to standardize between North America and Europe, IT power supplies were developed to accommodate

a range of voltages of 100 to 240 V. The concept behind this power strategy is to push the IT power supply to the high side of its voltage range (240 V) and use an established European voltage.

Advantages:� Energy efficiency (5% to 7% reduction in losses) � Reduced load on the cooling systems� Increased reliability � Smaller feeder and branch circuit conductor sizes to deliver the same amount of power� Gain white space in the data center (two cabinets per PDU eliminated)� Reduced maintenance costs (PDU and mechanical systems)� Power distribution equipment is readily available.

Challenges:� Higher levels of available fault current� Potential for arc flash requires higher levels of personal protective equipment (PPE) to work on equipment� Full neutral conductor required throughout the system� Harmonic influences on the rest of the system.

The main challenge with a 415/240 Vac distribution system is the high lev-els of available fault current. Removing the PDU from the system also removes the transformer impedance that limits the available fault current downstream in the data center.

Therefore, it is recommended that a short circuit analysis be performed early in the design to determine the available interrupt-ing current (AIC) rating of all electrical equipment and to ensure the equipment is capable of withstanding the higher inter-rupting current. One option to consider when designing a 415/240 Vac system is breaking up the distribution system into smaller, more modular pieces. By using smaller high-impedance substation trans-

Data center power strategies

Figure 4: In a 415/240 Vac power distribution system configuration (top), the primary goal is to gain efficiency by eliminating the transformer losses associated with the PDU and by allowing the IT loads to operate more efficiently at a higher voltage. In a 600 Vac power distribution system configuration (middle), power is stepped down to 600 Vac at the substation transformer and distributed to the UPS system. Power then is distributed from the UPS system at 600 Vac to a PDU located near the data center. In a 380 Vdc power distribution system configuration (bottom), the 380 Vdc power distribution strategy distributes dc power from the UPS (dc rectifier) straight to the IT power supply.

Figure 5: The primary goal, advantages, and challenges of the 480/277 Vac power dis-tribution configuration (shown here) are exactly the same as the 415/230 Vac power distribution strategy.

Figure 4: In a 415/240 Vac power distribution system configuration (top), the primary

Figure 5: The primary goal, advantages, and challenges of the 480/277 Vac power dis-

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formers, the engineer can reduce the overall fault current on the entire system. Another option to consider is the use of current lim-iting devices. Since current limiting devices tend to have quick reaction time, it is also recommended that a coordination study be performed to verify that reliability of the system has not been affected.

480/277 Vac distributionThe 480/277 Vac power distribution

strategy is similar to the 415/240 Vac in that it eliminates the PDU and distributes power at a higher voltage straight to the server cabinet. The primary goal, advan-tages, and challenges of the 480/277 Vac power distribution strategy are exactly the same as the 415/230 Vac power distribu-tion strategy (see Figure 5).

A major disadvantage of the 480/277 Vac power distribution strategy is that 277 V exceeds the 240 V rating of most IT equipment power supplies. Implemen-tation of this strategy requires the purchase of custom-made servers with power sup-plies designed to operate at 277 V. For this reason, the 480/277 Vac power distribution strategy is not as prevalent as the 415/240 Vac power distribution strategy. Currently it is only used in very large facilities where the energy savings outweigh the cost of custom servers due to the high volume of servers that are purchased.

600 Vac distributionThe 600 Vac power distribution strategy

is based on using the standard Canadian voltage of 575/347 Vac. Power is stepped down to 600 Vac at the substation trans-former and distributed to the UPS system. Power then is distributed from the UPS system at 600 Vac to a PDU located near the data center. At the PDU the voltage is stepped down to either 415/240 V or 208/120 V and distributed to the IT equip-ment (see Figure 4 on p. 28). Advantages:

� Reduction in copper cost (smaller equipment buses and smaller feed

Figure 7: The 380 Vdc power distribution system single line diagram shows the redundant UPS (dc rectifier) as the bypass and did not include a separate bypass on each of the UPS (dc rectifier) systems.

Theoretical case study

T he two power strategies for distributing power to the data center that seem to be gaining the most popularity include the 415/240 V higher ac architecture and the 380

Vdc architecture. A theoretical case study was performed by Jacobs-KlingStubbins to compare the capital expenditure (CAPEX) and operating expenditure (OPEX) of these two power distribution strategies against the typical 208/120 V data center. The case study was based on a theoretical simplified data center with 2 MW IT load, 2 N redundancy (Tier IV), six 750 kVA UPS modules, and 30 5 kW cabinets per row.

The 415/240 Vac system had a 12% CAPEX savings and a 20% OPEX savings when compared to the legacy 208/120 V data center. The 380 Vdc system had a 14% CAPEX savings and a 28% OPEX savings when compared to the legacy 208/120 V data center. It should be noted that unlike the legacy and the 415 Vac systems, the 380 Vdc used the redundant UPS (dc rectifier) as the bypass and did not include a separate bypass on each of the UPS (dc rectifier) systems.

Figure 6: This shows the legacy 208/120 Vac power distribution system in a single line diagram.



Figure 8: This building information modeling (BIM) rendering is of a high-density data center floor. The data center was configured with isolated redundant UPS systems and used 415/240 V distribution to the cabinets.

ers to deliver the same amount of power)nUse the full rating of 600 V electrical equipmentnLower available fault current (PDU transformer impedance).

Challenges:n No gain in efficiency (PDU transformer losses)n No gain of white space in data centernNo reduction in maintenance costs.

Although the 600 Vac distri-bution strategy does not eliminate PDU transformer losses or reduce maintenance costs, it can lower initial capital expenditure costs. A 600 Vac system takes advantage of the reduced current at higher voltages resulting in smaller or less conductors. Using smaller or fewer con-ductors will decrease that amount of cop-per and reduces cost. Higher voltage also allows for larger substations. Depending on the size of the data center, using larger substations may result in a reduction in the total number of substations required.

380 Vdc powerContrary to common belief, dc power

is very common in the world today. The telecom and transportation industries have been using dc power for years. Alternative and renewable energy generation sources such as solar power, wind power, and fuel cells are dc-based power sources. Most electronic devices in residential homes and in offices internally operate on dc power. And, most importantly, energy storage devices such as batteries and UPS systems operate on dc power.

When you look at a typical traditional data center distribution system, the power gets rectified from ac to dc, inverted from dc to ac, transformed from 480 Vac to 208 Vac, rectified again from ac to dc, and then transformed down to 12 Vdc before power-ing the IT equipment. Every time the power

is converted, losses occur in the form of heat resulting in a decrease in energy efficiency.

The 380 Vdc power distribution strat-egy distributes dc power from the UPS (dc rectifier) straight to the IT power supply. The primary goal is to gain efficiency by eliminating the inverter losses in the UPS,

the rectifier losses in the IT power supply, and the transformer losses associated with the PDU (see Figure 4).

Advantages:nEnergy efficiency (8% to 10% reduc-tion in losses)n Reduced load on the cooling systemsnIncreased reliabilitynSmaller physical footprintn Integrates with alternate energy sourcesnReduced maintenance costs.

Challenges:n Limited knowledge and difficult to find electricians with experience on dc systemsn dc current does not have a zero crossing, difficult to extinguish the arcnHave to account for voltage drop on

the positive and negative feedersndc arc flash hazards (NFPA 70E provides guidelines for dc arc flash protection).

In addition to the limited number of electricians with dc power experience, the main challenge with dc power in the past has been the lack of standards. This, how-ever, is starting to change. Both the Euro-

pean Telecommunications Standards Institute (ETSI) and the EMerge

Alliance have standardized on 380 Vdc and produced guidelines for dc power

distribution. Unless the data center is

completely powered by an alter-nate source of power, it is most

likely being provided ac power from the utility. In a dc power system the UPS

is used to rectify the power from ac to dc. Because the distribution to the data cen-ter is dc, any bypass of the UPS system will also need a rectifier. Consequently, dc systems are more cost effective in a fully redundant (Tier IV) system where a second UPS (dc rectifier) is used as the bypass. Additional things to be aware of when designing a dc power distribution system include using proper protection devices rated for use in dc systems and following the specific requirements for a dc grounding system.

In an effort to increase efficiency and reduce cost, different power strategies for distributing power are starting to be used. Whether you are planning to update, expand, or build a new data center, design-ing the power distribution system is a criti-cal part of the plan and one that must be evaluated to determine which system is the correct system for the application.

Kenneth Kutsmeda is an engineering design principal at Jacobs (KlingStub-bins) in Philadelphia. For more than 18 years, he has been responsible for engi-neering, designing, and commissioning power distribution systems for mission critical facilities.


Case Study

For today’s customer service-oriented industries, securing data isn’t the only mission critical objective—maintaining

the ability to interact with the customer is now mission critical as well.

At one national financial institution’s 150,000-sq-ft call center located in a west-ern suburb of Chicago, supporting five floors full of responders is just as crucial to its operations as maintaining its computers. So, when severe power quality issues stemming from the local electrical utility led to a series of brownouts and blackouts that were deemed unac-ceptable by the financial institu-tion, an electrical distribution sys-tem upgrade was in order.

McGuire Engineers cre-ated a basis of design docu-ment for the call center to determine what it would take to keep this line of business in opera-tion if the utility would fail. This required a broad understanding the facility’s load profile, much of which was derived from historical data from existing half-hour interval demand meters installed by the utility, to determine the amount of uninterruptible power sup-ply (UPS) and generator

capacity that would be needed to support that load.

Beyond gathering the hard data, the engi-neering team also considered the fact that while ensuring power reliability on a typical day is crucial to the call center, ensuring it during a natural disaster may not be. This is because the function of the facility requires responders to be present for operations, and in the event of a significant natural disaster, responders likely wouldn’t be able to access the facility either.

This led to the abandon-ment of a design that speci-fied 2 MW generators with paral lel ing switchgear. Instead, a second, redundant medium-voltage (MV) sub-station utility feed and an automatic throw-over (ATO) switch were incorporated into the design, allowing the facility to automatically switch from one utility feed to another as needed. Func-tioning similarly to an auto-matic transfer switch (ATS) but on the utility side, the ATO turned out to be both more economical and appro-priate for the call center’s required level of reliability.

Once the backup power source was in place, it was determined that five (one for each floor) 160 kVA UPS systems would be needed to create an uninterrupted power supply when tran-

Financial call centerAs more industries deem their daily operations to be mission critical, upgrading existing electrical distribution infrastructure will take on a vital role.

By John yoon, PE, LEED AP ID+C, McGuire Engineers Inc., Chicago

Figure 1: Five 160 kVA UPS systems were installed at the call center. This inside view shows a 160 kVA UPS system. All graphics courtesy: Eaton


Figure 2: The LCD panel of the 160 kVA UPS system can be used on-site. Building personnel at this financial call center can access all UPS systems remotely and after hours.

sitioning from one utility feed to the next. This would help the call center maintain the desired customer experience, creating no opportunities for a loss of data or dropped calls during a power source transfer.

Because the established call center was already fully functional and has long hours of operation (early morning to late eve-ning), the biggest challenge was conducting the upgrade without disrupting the line of business. While in an ideal world McGuire Engineers would have right-sized the UPS, segregating the most critical equipment only for backup, this would have required a rewiring and rerouting of the facility, which would have necessitated a complete system shut-down. Instead, to minimize the level of interruption to the facility, each floor in its entirety, including the lighting, was put on the floor’s local UPS.

Because it wasn’t feasible to provide a N+1 or 2N redundant UPS design, each UPS became a single point of failure. Therefore, the engineers specified an external mainte-nance bypass cabinet (MBC) for each UPS, which typically gets value-engineered out of projects. However, at the call center, it allows maintenance personnel to take the UPS off line for routine maintenance or even at the end of its life, for replacement, while still maintaining power to the critical load. Note the external MBC was specified as opposed to a dual-input UPS because the latter often provides a false sense of security, as a cata-strophic failure within the dual-input UPS still acts as a single point of failure.

Each floor’s UPS and external MBC are housed in dedicated rooms away from call center responders and can be accessed only

by maintenance personnel. Finding these rooms was a challenge, as it’s common for a UPS system to weigh 200 lbs/sq ft or more, while most areas within a building are struc-turally designed to hold only up to 100 lbs/sq ft. Typically, the places that are most able to accommodate such heavy weights are where the building has structural steel, right at the column lines. The design team worked with a structural engineer to identify key locations for UPS system so as to ensure safety and not disrupt the function of the facility. While this seclusion is crucial to maintaining the UPS systems, it also presents a challenge for the facilities operator: How will a UPS failure be recognized?

Two levels of remote monitoring were established. The first, a remote point moni-toring system with simple dry contact alarms, sends an e-mail to the facility manager letting him know that something is wrong with one of the UPS systems, without any further details. Once the facility manager gets the initial alert, he can log onto the second level of monitor-ing, a network interface card that hosts a Web page for each UPS on the building’s intranet. This will allow the facility manager to drill down through all the parameters on the UPS to figure out exactly what’s wrong. Building personnel can therefore access all UPS sys-tems remotely and after hours, without having to be in the building itself.

John Yoon is a senior electrical engineer with Chicago-based McGuire Engineers and has been designing and implementing electri-cal distribution infrastructure solutions for higher education, hospitality, and Fortune 500 corporate clients for 19 years.

Figure 3: At this financial call center, 160 kVA UPS systems were needed to create an uninterrupted power supply when transitioning from one utility feed to the next.


Case Study

With approximately 120,000 sq ft of white space divided into eight Tier III, 2 MW power data

halls, the 20 MW data center for a confi-dential client in Illinois met a number of design challenges before construction even began.

Designed in Autodesk Revit 2013, the two-story data center was originally the site of an old manufacturing facility. Cou-pled with the owner’s building require-ments, this created a few challenges to the data center’s electrical distribution system

design. Here’s a look at how Environmen-tal Systems Design, working together with the other members of the building team, was able to solve them.

Challenge No. 1: The transformer In an effort to maintain consistency across

its U.S. data centers, the undisclosed cor-poration likes to specify company-standard mechanical, electrical, plumbing (MEP), and fire protection equipment for all of its mission critical facilities. However, much of this equipment is designed for outdoor use, and because this particular facility has very limited outdoor space, significant adjust-ments had to be made for the transformer and switchgear equipment to work indoors.

For example, the heavy transformer couldn’t be placed on the raised floor designed for the data hall and electrical room space and wouldn’t be able to be removed from the building at the end of its useful life, as the 2500 kVA transformers each weigh approximately 16,000 lbs. Instead, the facil-ity was designed with the intent of moving in the transformer prior to the raised floor construction. Coordinating with the archi-tect, saw cuts were designed into the pre-cast panels on the side of the building to make it easier for the contractor to remove/replace the exterior wall to get the transformer out for future installations or replacement.

Additionally, because the liquid-filled transformers specified are typically used outdoors, special design considerations

Data center retrofit

Figure 1: This shows the vista switchgear conduit entry detail, with medium-voltage systems routed under the slab. All graphics courtesy: ESD

Any time the reliability demand is high and the data center has to work around pre-existing building constraints, there are significant design challenges. However, creative engineering can turn just about any challenge into a data center with real reliability.

BY ADAM J. BRENDAMOUR and ADDAM FRIEDL, PE, Environmental Systems Design Inc., Chicago


were needed for the electrical room to con-tain the fluid in the event of a leak. A 4-in. metal dam was constructed along the perim-eter of the room to contain the liquid, while perforated raised-floor tiles were installed around the transformer to facilitate the flow of liquid to under the floor.

Challenge No. 2: Uniform designThe owner wanted a repeatable, scalable

design for each of the eight data halls to both create uniformity across the facility and provide the ability to build out data halls as needed over time. However, due to existing building conditions, including the different quantity and compact nature of the structural columns on the building’s first and second floors, an offsite modular construction design was eliminated.

Instead, the solution was to bring each component of the mechanical and electri-cal systems into the facility individually and build out the data halls one at a time as identically as possible.

Challenge No. 3: Medium-voltage equipment Because the switchgear and transformers

were located inside the building, medium-voltage (MV) feeders were routed through-out. The MV system itself was daisy-chained so it had to be installed and commissioned in its entirety when the first of the eight data halls were installed.

The active MV system presents a poten-tial risk to workers during construction.

Therefore, the MV feeders and conduit were routed through the ceiling of the first floor for safety, stubbing back up through the second floor slab and directly into the equipment. The feeders for the first floor equipment were routed similarly under the first floor slab. Because the eight data halls will be built out over time, this tech-nique permits construction on the floor without subjecting workers to the active feeders.

Challenge No. 4: Switchgear and metering equipment

With very limited space for outdoor equip-ment, there wasn’t enough room for the util-ity’s 34.5 kV ground-level switchgear and metering. In addition, this equipment has not been fully vetted for the application and was seen as a risk by the owner. The only option was for the utility’s switchgear and metering to be pole mounted. This meant that the site’s 20 poles had to be spaced 20 ft from each other, taking up 400 ft of linear space on a site with little outdoor area.

Adam Brendamour is an associate and electrical engineer with experience in data center, low-voltage technology, and tenant office design. Addam Friedl is senior vice president and mission critical facilities practice leader, and has experience in data center strategy, design, implementation, and operations. They are both in Environmental Systems Design’s Chicago office.

Figure 2: The utility metering was pole-mounted on the site of the corporate data center.

Utility service: 2N, or two sepa-rate utility sources/feeders, one general source and the second as backup. The switchgear is daisy-chained together, creating a con-nection from one switchgear to another down the line so that the power can feed into one switch-gear, back out and into the other, rather than having multiple con-nections to the site.

Backup generators: N+1 redun-dant swing generator. While each of the eight data halls has its own backup generator, another redun-dant swing generator for every two to three halls was designed as well, providing additional backup (a total of four swing generators in all). This provides an extra level of redundancy without the cost of providing an additional backup for each generator.

UPS system and distribution (2N): Two sides to the electrical system were designed, where each side is a mirror of the other. The benefit of the 2N system topology allows for maintenance or a fault to occur on one of the sides, while still maintaining a completely active data center.

Data centervital stats


The integration of power and life safety systems requires an under-standing of both the sources of

power and the specific requirements of the life safety loads. It also requires a team approach of various types of con-sulting engineers including electrical, life safety, mechanical, and fire protection.

It becomes confusing when the terms “emergency life safety power” or “stand-by power” are used incorrectly or inter-changeably to refer to either the power sources or the load. The following codes have very specific definitions for these sources and loads:

� NFPA 70: National Electrical Code (NEC), Articles 700 and 701� NFPA 101: Life Safety Code� NFPA 110: Standard for Emergency and Standby Power Systems� NFPA 72: National Fire Alarm and Signaling Code� NFPA 20: Standard for the Instal- lation of Stationary Pumps for Fire Protection.

These codes break things down into two types or levels of systems: one is emer-gency/life safety and the other is standby.

Emergency systems are covered under NEC Article 700, which classifies these systems as “those systems legally required

and classified as emergency by munici-pal, state, federal or other codes, or by any governmental agency having jurisdic-tion.” The NEC further states that “these systems ... automatically supply illumina-tion, power or both … essential for safety to human life.”

In practical terms this normally includes providing power to egress lighting, fire detection and alarms, fire pumps, selected elevators, public safety communications, smoke or toxic exhaust systems, or any system where loss of power would cause serious endangerment to life or health within 10 seconds of normal power loss. Under NFPA 110, these are referred to as Level 1 systems. NFPA 101 Level 2 systems would be equivalent to the NEC Article 701 for legally required standby systems.

The NEC also contains requirements for legally required standby systems in Article 701. Code-required standby systems may include communications, selected ventila-tion or smoke removal systems, lighting, or certain types of industrial processes that may create hazards or hamper firefight-ing operations if power was not available. The code-required standby systems must be available within 60 seconds and may be routed in the same raceway as normal power systems.

Integrating power and life safety systems requires an understanding ofthe sources of power and the life safety system load requirements.

BY BRIAN RENER, PE, M+W U.S. Inc., Chicago; and JOSH MCCONNELL, NICET, SET, M+W U.S. Inc., Albuquerque

Integration:

Power andfire/life safety systems

Learningobjectives� Learn which codes and standards pertain to power system integration.

� Understand the codes and standards that pertain to life safety.

� Determine which power sources are correct for life safety applications.


Having clearly separated emergency/life safety from standby loads, let’s look at the most common emergency power systems and associated life safety loads.

Emergency power sourcesThe term “emergency generator” is

often used mistakenly as a description of any type of engine generator used to pro-vide power in a facility. However, not all generator types will meet NEC or NFPA requirements to power life safety loads. First, the emergency power from a gen-erator is required to be available within 10 seconds or less. Second, the source of fuel to a generator must be reliable; this typically eliminates natural gas generators from consideration unless on-site liquefied petroleum (LP) storage is provided. Tra-ditionally, this has meant a diesel engine generator set.

NFPA 110 has additional requirements for emergency generators:

� A certified 0.8 power factor, full load factory test. Test report must be furnished to owner for proof and kept on record by manufacturer for 5 years.

� Requires certified NFPA 110 gen-erator controller which includes all pre-alarms and a 16-light annunciator.

� Requires a certified NFPA 110 battery charger that has the following

alarms: low volt-age, high voltage, and common fault.

� A four-hour full load test is required to be com-pleted annually.

Beyond tradi-tional diesel engine generators, newer forms of power sources including motor generator flywheels, and fuel cells may be con-sidered by local authorities having jurisdiction (AHJ) a s e m e rg e n c y power sources.

B a t t e r i e s , including invert-ers and uninter-rupt ible power supply (UPS) sys-tems, may also be used as an emergency power source for buildings of a limited type and size, and for certain systems like egress lighting and fire detection and alarm systems.

This standard also includes two other power source terms:

Class: Refers to the time, in hours, for the energy source to provide power. For example, Class 2 means 2 hours of power at full load (see Table 1).

Type: Refers to the maximum time for the emergency power source to be unavailable or restored. Type is commonly

Figure 3: Emergency circuit wiring must be routed separately from legally required or optional standby circuits.

Figure 3: Emergency circuit wiring must be routed

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Figure 2: A computer-based model of the Massachusetts Green High Performance Computing Center shows the top level high-performance computing space with overhead utilities.

Figure 1: The new Massachusetts Green High Performance Computing Center was developed on a brownfield site in Holyoke, Mass. All graphics courtesy: M+W U.S. Inc.

referred to by seconds; for example, Class 10 would be a power source that is online in 10 seconds or less (see Table 1).

Two final points on emergency power sources should be kept in mind. First, in most electrical system sizing, demand or diversity is applied to the electrical loads. However, for life safety loads the entire load must be fully applied, without demand factors. This also includes the starting currents of motors on emergency systems. This is particularly important with loads like fire pumps.

Secondly under NEC, emergency cir-cuit wiring must be routed separately from legally required or optional standby circuits. An example of emergency power distribution is shown in Figure 3.

After examining the types of emer-gency power sources available, the engi-neer should focus on the specific types

of life safety loads. The most common ones encountered in buildings include egress lighting, fire alarm systems, and fire pumps.

Power distribution requirements Under NEC, emergency circuit wiring

must be routed separately from legally required or optional standby circuits (see Figure 3). However, legally required standby circuiting may be combined with optional and other loads.

Emergency generator power distribu-tion systems must also have fire protection when installed in buildings with occupan-cies of 1000 or more people, or in certain types of buildings that are taller than 75 ft. This fire protection shall be accomplished by installing the distribution in spaces protected by sprinklers, or by providing a 2-hour rated enclosure for the circuit wir-

ing. The fire protection requirements also apply to the physical feeder circuit equip-ment itself (panels, transfer switches, etc.), which must be in 2-hour rated rooms, or rooms with fire protection.

Emergency and legally required stand-by generator power distribution systems also are required under the NEC to be selectively coordinated. This will require a protective device coordination study, looking at fault levels, and overcurrent devices to ensure that faults are isolated by opening the protective device nearest the fault, allowing the rest of the system to function. Optional standby systems are not required to be selectively coordinated. Another notable protection requirement is that emergency and legally required stand-by power systems do not have to include ground fault protection, but rather must have ground fault alarms.

Life safety loads: LightingWhile the NEC designates that lighting

is an emergency load, NFPA 101 covers specific requirements for that lighting. The requirements are focused on paths of egress and exiting from certain types of buildings and structures. When required in these buildings, this includes designat-ed stairs, aisles, corridors, ramps, escala-tors, and passageways leading to an exit.

The source of emergency power (NFPA 110 Level 1) must come on line with 10 seconds after loss of primary power (NFPA 110 Type 10) and must provide power for a minimum of 1.5 hours (NFPA 110 Class 1.5).

Various power sources may be con-sidered for typical buildings including a central UPS or inverter system, localized internal battery packs, or diesel genera-tors. However, in certain types of build-ings such as high-rises or high-occupancy buildings, the larger loads and a require-ment for a fire pump and/or one or more elevators will require a diesel generator.

The illumination levels for egress light-ing are very specific. Lighting should be provided to achieve an initial level of not less than an average of 1 foot-candle (fc). The level is permitted to decline to not less


Integrating power and fire/life safety

Table 1: This shows the secondary power supply requirements for typical life safety systems. Requirements are based on the 2010 edition of NFPA 72: National Fire Alarm and Signaling Code.

Table 1: Secondary power supply requirements

System type Standby (hours) Alarm (minutes) Comments

Protected premises fire alarm 24 5

Fire emergancy voice/alarm communications

24 15

Supervising station

Capable of supporting operations for a minimum of 24 hours

High-power speaker arrays used for wide-area mass notification systems

168 (7 days) 60

Textual visible appliances 120

Shall have sufficient secondary power to operate a minimum of 2 hours of continuous display time during an emergency event

Central control station—wide area mass notification system

Capable of supporting operations for a minimum of 24 hours

In-building mass notification system 24 15

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than 0.6 fc at the end of the 1.5 hours. In addition a maximum-to-minimum illumi-nation uniformity ratio of 40:1 shall not be exceeded.

NFPA 101 requires regular testing of emergency lighting systems every 30 days.

Life safety loads: Fire detection and alarm systems

NFPA 72: National Fire Alarm and Signaling Code, contains requirements for emergency power to fire alarm and detection systems. NFPA 72 specifies the need for two independent power supplies with adequate capacity to serve the con-nected loads.

The primary source may be either a commercial utility source or an engine generator. The secondary source maybe either a storage battery or an engine gen-erator.

A dedicated branch circuit for the pri-mary power supply must be provided. It is

not acceptable for the fire detection/alarm system to share power with any other load. The branch circuit connections must be mechanically protected against physical damage, have suitable overcurrent protec-tion capable of interrupting the maximum short-circuit current they may be subject-ed to, and be clearly marked as a “FIRE ALARM CIRCUIT.”

Typical operating voltage for fire detec-tion and alarm systems in the United States is 120 Vac supplied to the primary side of the system power supply, which is then rectified and stepped down to 24 Vdc (system operating voltage). The most typi-cal configuration for the primary power is a dedicated branch circuit fed from a commercial utility source.

The most typical configuration of the secondary power supply is battery backup, usually two 12 Vdc batteries connected in series. The battery amp/hour rating (size)

is calculated by the system designer based on the maximum load conditions of the system and the time period the system will need to receive the secondary power upon loss of the system primary power. NFPA 72 also requires that the battery calcula-tions include a 20% safety margin added to the calculated amp-hour rating.

The intent of providing secondary power to the fire detection/alarm sys-tem is to allow the system to operate in a “standby” or normal mode for a period of time (typically 24 hours) in a scenario where the primary power has been entirely or partially lost, and also to provide suffi-cient operating power to the system at the end of this supervisory period to perform evacuation functions (alarm mode) for a sufficient period of time (typically 5 min-utes) to allow occupants of the protected premise to evacuate safely.

Therefore, the battery calculation meth-od is as follows:

Required standby time (hours) x total system standby current (amps) = Required standby capacity (amp/hours) + required alarm time (hours) x required alarm cur-rent (amps) x 120% (20% safety factor) = adjusted battery capacity (amp/hours)

NFPA 72 also requires that the second-ary power supply shall automatically pro-vide power to the protected premises’ fire detection/alarm system within 10 seconds whenever the primary power supply fails to provide the minimum voltage required for proper operation.

Further, any required signals shall not be lost, interrupted, or delayed by more than 10 seconds as a result of the primary power failure.

It is important to understand that there are several types of protective signaling systems that are also addressed in NFPA 72 that may have differing requirements relat-ed to secondary power supply capacity.

Table 1 summarizes some of these systems and the associated capacity requirements for secondary power.

Life safety loads: Fire pumpsThe major electrical power require-

ments for fire pumps are found in NEC Article 695. The intent of the requirements is to provide uninterrupted power to the fire pump and to protect all power equip-ment and wiring from fire. Other major requirements for the installation of fire pumps are found in NFPA 20.

The following four items are major elec-trical power requirements for fire pumps per NEC 695:

1. Electric motor-driven fire pumps shall have a “reliable” source of power. Typically the “reliable” power source is an electrical utility service connection. The service connection is located to minimize damage from a fire. Many times the power connection is found remotely located from the building or major fire load area. An electrical tap used for the fire pump power connection can be located ahead of the ser-vice disconnecting means when installed in accordance with NEC 230. Alternate feeders can also supply power to the fire pump if those feeders are supplied from separate utility service connections.

2. Circuits that supply electric motor-driven fire pumps shall be supervised from inadvertent disconnection. One can mini-mize the opportunity for disconnection by directly connecting the supply conductors to the power source of the listed fire pump controller, or listed combination fire pump controller/power transfer switch. The dis-connecting means is typically supervised by a central monitoring station so that the operation of the disconnect is reported to a constantly attended location. A local supervisory alarm signal may also be installed to alert local service personnel.

3. All power supplies shall be located and arranged to protect damage against fire from within the premises and expos-ing hazards, and multiple power sources shall be arranged so that a fire at one source does not cause an interruption at the other source. Physical location(s) of

Integrating power and fire/life safety

Typical operating voltage for fire detection and alarm systems in the United States is 120 Vac supplied to the primary side of the system power supply, which is then rectified and stepped down to 24 Vdc.

fire pump power sources in relation to the specific fire hazards at those location(s) must be carefully considered during the electrical power design phase of a proj-ect to accommodate the requirements of Article 695.

4. Power circuits and wiring methods shall comply with the requirements of Article 695. The power conductors feed-ing the fire pump must be physically protected from the fire hazard, structural failure, or operational accident. This is typically accomplished by physically rout-ing the conductors outside of the build-ing, encasing the conductors/raceways in a minimum of 2 in. of concrete, or installing them in a minimum 2-hour fire- rated assembly.

Life safety loads: Special facilitiesSpecific requirements for emergency

power and life safety loads will vary based on building occupancy type, facility

use, and critical function. Various codes such as the International Building Code (IBC), NFPA 5000: Building Construc-tion and Safety Code, NFPA 99: Health Care Facilities Code, and others will have specific requirements. Facilities with special requirements include hospitals, high-rises, large places of assembly, and hospitals.

One interesting example of a special building type is semiconductor manu-facturing facilities (H4/H5 occupancies). Continuous gas detection and emergency alarm systems are commonly used in these facilities. In this type of facility, emergency power is provided following NFPA 110 requirements for both continu-ous gas detection and emergency alarm systems.

Lastly, recent versions of the NEC have added Article 708: Critical Operations Power Systems (COPS). These are sys-tems, operations, or facilities designated

by local, state, or federal government as “mission critical”; examples can include police or fire stations or other facilities for reasons of public safety, national security, or business continuity. This new section (introduced in 2008) has some notable requirements for things like commission-ing, which has long been practiced in data centers and other previously unclas-sified mission critical facilities.

Brian Rener is electrical engineering discipline platform leader and qual-ity assurance manager at M+W U.S. He has more than 20 years of experience in management and engineering for new and existing facilities, and is a member of the Consulting-Specifying Engineer editorial advisory board. Josh McConnell is the life safety systems discipline platform leader at M+W U.S. He has 27 years of experi-ence in engineering and construction of life safety systems.

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The sequence of operation is one of the most important design aspects of any HVAC system.

Without a proper sequence, the system is left to operate wildly—or not at all. When approached methodically, the process can be broken into smaller seg-ments. We’ll look at the steps required to create a successful sequence of oper-ation using a single-zone variable air volume (VAV) air handling unit serving a convention space. These same steps can be applied to any piece of equip-ment.

Some information must be gathered before the designer can begin actually creating the sequence of operation. This data gathering and brainstorming process can be broken down into the following major steps:

STEP 1: Create a flow diagram of the system. Creating a flow diagram allows the designer to identify the components of the system. These are the compo-nents that must be controlled to achieve the desired operational results. The sequence can generally be written with a subsection for each of the major air handling unit components. Fan control may be addressed in one section, tem-perature control in another, and various safety devices and accessories detailed separately.

Figure 1 shows the main components of the air handling unit (AHU) being considered for our example. The unit has an exhaust fan, outside and supply airflow measuring stations, mixing box, pre-filter, final filter, heating hot water coil, chilled water coil, and supply fan. The flow diagram should also identify the airflow pathway and piping connections. Airflow and water flow rates do not need to be included as this information should be included on equipment schedules. The flow rates could be included if desired, or diagrams can be left more generic. The latter permits use of the same diagram for multiple units with similar configura-tions. Include all inputs and variables that

Figure 1: A schematic diagram shows the control components of the example air han-dling unit (AHU). Courtesy: JBA Consulting EngineersFigure 1: A schematic diagram shows the control components of the example air han-

BY JASON A. WITTERMAN, PE, LEED AP BD+C, and ED BUTERA, PE, JBA Consulting Engineers, Las Vegas

Control sequencesfor HVAC systems

Learningobjectives� Learn how to create a suc-cessful sequence of operation.

� Recognize the importance of the sequence of operation as it relates to design, specification, and construction.

� Understand how the sequence of operation carries forward through commission-ing and into the long-term operation of the building.

Follow these 10 steps to create a successful sequence of operation,one of the most important design aspects of any HVAC system.


must be controlled. Components that are not inputs or controlled variables should be left out to maintain a simple diagram that is easy to read.

STEP 2: Categorize the purpose of the equipment. One of the first questions to ask before moving forward is: “What is the purpose of the system?” Often the purpose is comfort heating or cooling for human occupants. Sometimes the purpose is maintaining acceptable temperatures for a process (e.g., a data center). Per-haps the system needs to maintain pres-sure relationships for a particular space or group of spaces. The designer should also identify any other equipment that is affected by the sequence. A makeup air unit, for example, needs to be inter-locked with the exhaust fan(s) that create the need for the makeup air unit. Keep in mind that a system may have multiple purposes. An AHU may be designed for space conditioning during normal opera-tion and also function as a smoke control system during a fire event.

STEP 3: Identify the required inputs and outputs. It was noted above that the flow diagram should include the inputs for the controlled variables. Inputs are those readings coming into the build-ing management system (BMS). These include items such as space sensors, air temperature sensors, static or differen-tial pressure sensors, and so on. When developing this list of input devices, the designer should note what inputs are already available for use in the control system. Are any of the required input devices included as a part of the equip-ment or already specified for other pur-poses? Additional devices should be indi-cated in the construction documents and specified at this time. Outputs should also be considered at this time in preparation for developing the full list of points. Out-puts are those signals originating from the BMS to the controlled variable.

STEP 4: List any code required func-tions of the system. Energy codes (such as ASHRAE Standard 90.1) continue to become more stringent and demand ever more efficient systems. Identifying these requirements ahead of time helps

Figure 2: Deadband is a setpoint differential to avoid simultaneous heating and cool-ing. Energy codes and efficiency standards specify setpoint overlap restrictions. Courtesy: JBA Consulting Engineers

Figure 2: Deadband is a setpoint differential to avoid simultaneous heating and cool-

Table 1: AHU points

Point descriptionType

NotesDI AI DO AO

ENABLE / DISABLE X

SUPPLY FAN VFD SPEED COMMAND X

SUPPLY FAN VFD SPEED STATUS X

EXHAUST FAN VFD SPEED COMMAND X

EXHAUST FAN VFD SPEED STATUS X

OUTDOOR AIR DRY BULB TEMPERATURE X

OUTDOOR AIR WET BULB TEMPERATURE X

RETURN AIR DRY BULB TEMPERATURE X

RETURN AIR WET BULB TEMPERATURE X

MIXED AIR TEMPERATURE X ALARM BELOW 40 F

SUPPLY AIR TEMPERATURE X

SPACE TEMEPRATURE SENSOR X

SPACE RELATIVE HUMIDITY SENSOR X

RELIEF AIR DAMPER COMMAND X

RELIEF AIR DAMPER POSITION X MONITOR FOR OPEN POSITION

OUTDOOR AIR DAMPER COMMAND X

RETURN AIR DAMPER COMMAND X

CARBON DIOXIDE SENSOR X ALARM ABOVE 1200 PPM

SUPPLY DUCT SMOKE DETECTOR X

RETURN DUCT SMOKE DETECTOR X

CHILLED WATER VALVE COMMAND X

HEATING HOT WATER VALVE COMMAND X

OUTDOOR AIRFLOW MEASURING STATION X

FILTER DIFFERENTIAL PRESSURE SWITCH X ALARM AT 1.5 IN. WC OR

SUPPLY AIR STATIC PRESSURE SENSOR X ALARM INVALID READING

Table 1: A list of points for the air handling unit (AHU) example is shown. All desired inputs and outputs should be listed and classified. Courtesy: JBA Consulting Engi-neers


to ensure the system complies with the applicable energy conservation code. Setback requirements, isolation dampers, demand controlled ventilation (DCV), economizers, reheat limitations, dead-band, and supply air temperature reset are all examples of airside energy code requirements that, when required, need to be incorporated into the sequence. It is important to rec-ognize the require-ments and excep-t ions for your particular project location.

Other building, mechanical, and fire code require-ments should also be reviewed at this point. For exam-ple, codes may require unit shut-down upon detec-tion of smoke. Additional control requirements may come into play if the equipment serves a smoke control function.

HVAC equipment or features that are required by code must be identified early in the design process. This is one of the reasons it makes sense to develop the controls sequence early in the design process. Doing so allows for a complete and comprehensive coordination effort as the design is developed.

Step 5: Confirm the owner’s opera-tional requirements and expectations. After identifying the minimum code required functions of the unit, the designer should confirm whether the owner has any specific operational requirements and understand how the owner intends to use the equip-ment. These requirements may be identified in the owner’s project requirements (OPR) or a request for proposal that explained the project scope. If an OPR was not devel-oped, the designer should still consult with the owner to verify the intent of the systems.

The team should discuss which desired sys-tem features may conflict with overall suc-cessful operation or code requirements. The system should be reviewed for additional components necessary to suit the owner’s desired operation.

The sequence of operation should be tailored for how the building will be operated, as well as the experience of the

facilities maintenance staff. Sequences developed for a large casino resort with a full-time, highly experienced, on-site maintenance staff may be more complex than those developed for a small office building with no dedicated maintenance staff. Sequences should always be as simple as possible while still meeting the performance requirements. Unnec-essarily complex control sequences can overwhelm even the most experienced operator because they are more difficult to operate and maintain. A lack of opera-tor understanding or need to override often leads to the building operating dif-ferently than the designer intended.

Once this information has been gath-ered, the designer can begin to actually create the sequence of operation. This becomes the baseline upon which the requirements for the sequence of control are further identified and developed.

Step 6: Develop a list of points. The information gathered in the previous steps allows for the creation of a points list. The points list identifies all the inputs and outputs that are controlled or moni-tored by the BMS. A matrix similar to Table 1is often the best method of iden-tifying these points. The matrix should identify all inputs and outputs for the

controlled system. The points can be classified as digital or analog. Digital inputs and out-puts are a simple on or off (0 or 1) condition. Analog inputs and outputs represent a value within a range corresponding to a change in voltage (e.g., 2 to 10 Vdc) or amperage (4 to 20 mA), or in the era of pneumatic controls, a change in air pressure. A dirty filter alarm from a differen-

tial pressure switch is an example of a digital input to the controller. Chilled water valve position is an analog output as it modulates from 0% to 100% open position. The system should be designed to permit expansion and be capable of handling at least 125% of the number of points currently specified. Allowances should also be made for virtual points. These are points that are calculated or passed through the controls system as opposed to hardwired physical points.

It may be necessary to revisit step 3 as the points list is developed. The designer may realize that he or she does not have all of the required input and output devic-es to achieve proper control of the sys-tem. It is better to identify these changes during design so that they do not become costly changes in the field.

Monitoring capability and alarms should also be reviewed at this time.

Control sequences for HVAC systems

Figure 3: This sample building management system (BMS) graphic shows various points. The graphic overview provides a summary of the unit status in a clean, simple appearance. Courtesy: ABS Systems Inc.

xyleminc.com© 2013 Xylem Inc. Bell & Gossett is a trademark of Xylem Inc. or one of its subsidiaries.

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These points provide additional informa-tion to the operator, allowing the opera-tor to monitor the system performance. This can be valuable information, but an excessive number of points can be overwhelming, costly, and of no real benefit to the operator. Controls should be kept simple wherever possible. The operator should have all of the neces-sary information at a glance, but addi-tional information becomes “noise” and distracts the operator from focusing on the important points. It is possible to monitor and trend almost any value within a system. The designer needs to ask whether or not a point is actually needed for the particular system.

The storage capability of the system must also be specified. Identify how long the data should be retained (e.g., 30, 60, or 90 days). The frequency of the trends must also be evaluated. Is it necessary to sample and record the readings every 15 seconds or every 15 minutes? Trending hundreds of points every few seconds may lead to network performance issues.

Consider best practices for the spe-cific region in which you are working. In some areas, control specifications may be performance based where the temperature control contractor will be responsible for providing all hardware components and points necessary to achieve the engineered sequence of operation. Other geographical regions

or particular projects may require the designer to specify the exact details and points list for all system components that the control contractor is to provide.

Step 7: Identify the setpoints. Set-points are values the system tries to main-tain during operation. Space temperature is a common example of a setpoint. The space sensor or thermostat is the input

device that measures the current space temperature. The control system evalu-ates this condition against the setpoint value. Setpoints are not limited to tem-perature. The duct static pressure sensor controlling fan speed will also have a setpoint. Likewise, a setpoint must be identified for the carbon dioxide (CO2) sensor that serves as the input for the demand controlled ventilation strategy.

Step 8: Work through the actions and functional responses. The initiation and functional response are the key aspects of the sequence of operation. It is prob-

ably what comes to mind for most peo-ple when they hear the term “sequence of operation.” It is best to work through these as a numbered list.

Let’s look at the temperature control for our example. The space tempera-ture sensor is the input device. It mea-sures the space temperature and sends the value to the brain of the system. In stand-alone packaged equipment, this will likely be an equipment controller with preset control sequences. In larg-er, more complex systems, the value is reported to a BMS. The BMS acts as the brains of the operation and evaluates whether the measured value is within the operational parameters—at setpoint. Assume the system is operating in the cooling mode with the chilled water con-trol valve partially open and the heating coil valve fully closed. If the value is above setpoint, then the space tempera-ture is higher than desired. The chilled water control valve must modulate open to provide additional cooling and lower the space temperature.

The sequence of operation should con-cisely list these evaluations and how the system needs to respond. Recommended language for the last example may be similar to the following:

In cooling mode, the setpoint shall be 75 F ± 1 F (adjustable). If the space temperature rises above the cooling set-point, the system shall first modulate the

Table 2: Operating modes

DEVICE

MODE

NORMALSMOKE CONTROL

ECONOMIZER RECIRCULATION

SUPPLY FAN VFD SPEED COMMAND

BASED ON SUPPLY DUCT STATIC PRESSURE

BASED ON SUPPLY DUCT STATIC PRESSURE DISABLED

EXHAUST FAN VFD SPEED COMMAND

BASED ON BUILDING DIFFERENTIAL PRESSURE

BASED ON BUILDING DIFFERENTIAL PRESSURE FIRE OVERRIDE FOR 30,000 CFM

RELIEF AIR DAMPER COMMAND 100% OPEN 100% OPEN 100% OPEN

OUTDOOR AIR DAMPER COMMAND

BASED ON MIXED AIR TEMPERATURE

RESET BY CO2 SENSOR, NOT LESS THAN SCHEDULED MINIMUM CLOSED

RETURN AIR DAMPER COMMAND BASED ON MIXED AIR TEMPERATURE 100% OPEN CLOSED

RETURN DUCT SMOKE DETECTOR ENABLED ENABLED DISABLED

Table 2: A matrix can be used to outline the various operating modes during design. The designer can use this brainstorming exercise to help write the actual control sequence. Courtesy: JBA Consulting Engineers

It is possible to monitor and trend almost any value within a system. The designer needs to ask whether or not a

point is actually needed for the particular system.

49Consulting-Specifying Engineer • NOVEMBER 2013

chilled water control valve from 0% to 100% open according to the proportional-integral-derivative (PID) and the supply fan airflow shall remain at the minimum position. The sup-ply fan speed shall be modulated from minimum to 100% design airflow if the control valve position is greater than 70% (adjustable) open. If the space temperature drops below cooling setpoint, the system shall modulate the chilled water control valve closed according to the PID. If the control valve is less than or equal to 50% (adjustable) open, the supply fan speed shall be reset to minimum supply airflow.

The designer needs to systematically work through all of the ways the system may be required to modulate. Consider all of the modes in which the system must operate and what system components need to operate differently in these various modes. Think about the supply and exhaust fans in our system. Our example assumes that the air handling unit exhaust fan also functions as a smoke exhaust fan. The fans and control damp-ers will operate differently in smoke control mode than they will in normal operation. The sequence of operation should specifically identify requirements for each of these modes.

Note that normal operation mode may also have under it several modes. In our example, we have economizer operation and recirculation operation. A matrix like the excerpt shown in Table 2 is an easy way to identify the required parameters for the various operating modes. While this matrix does not necessarily need to be included in the construction documents, it provides the designer with an overview summary that helps develop a written sequence of operation. The various analog and digital inputs and outputs should, in some form, be clearly identified in the construction documents with a corresponding written sequence of control.

Step 9: Identify failure scenarios. At some point, system components will fail. Quality products help reduce the fre-quency of failures, but they are still inevitable. If the designer plans for these failures in the sequence of operation, then he may be able to reduce the resulting operational impact when a failure does in fact take place. Again, be careful to not over specify. Resiliency requirements for a typical office building will be substantially different from those of a data center. Life safety requirements should also be considered.

Failure considerations should look at both the input devices and the controlled system components. The failure of a supply duct static pressure sensor may lead to improper control of the supply fan variable frequency drive (VFD) speed. If the value measured at this sensor varies significantly from the expected value, then a false measurement may be received. The sequence of operation could specify that this reading be ignored if the value is some percentage outside of the expected value. Some input devices may also have an invalid reading function built into the sensor.

Consider a low static pressure sensor reading. A sequence that identifies the failure of this component can reset the sup-

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ply fan to some fixed speed that keeps the system in operation and provides at least partial capacity until the maintenance team can properly address the problem. A system that does not anticipate this failure will continue to control the system using the erroneous static pressure measurement. This system will likely increase the supply fan speed until the system eventually shuts off on high static pressure if a high static pressure setpoint was considered in the original points list. This typically requires a manual restart and the system will have a longer downtime compared to the one that incorporated fail-safe scenarios. This is an important consideration for systems where environmental conditions are criti-cal or safety could be compromised.

Now consider the failure of a con-trolled device such as a control valve actuator. Failure of this device will lead to loss of space temperature control. The importance of a fail-safe position for


Figure 4: Redundant packaged air handling units (AHUs) connect to a common sup-ply and return duct. The sequence defines the control damper positions and how the units are cycled. Courtesy: JBA Consulting Engineers

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this actuator can be debated, but a spring return open actuator may be considered for a chilled water coil in a hot climate. Although the system no longer has accu-rate control, this arrangement errs on the side of caution and will overcool the space until the system can be repaired. This may be more important for cooling equipment that serves telecomm rooms, data centers, or other process loads where a loss of cool-ing has significant consequences.

A supply fan motor failure in a single supply fan system has no real fail-safe position. However, a system with mul-tiple supply fans and motors may be able to respond to this failure scenario with no decrease in supply airflow rate. This is a prime example of how developing a sequence of operation may lead to changes in which hardware components are specified for the system. The impact of the supply fan motor failure may have been overlooked prior to this stage of the design.

Step 10: Review the sequence. At this point, the designer has completed the first pass to developing the sequence of opera-tion. A successful sequence is iterative and often requires revisiting the previ-ous steps. It was mentioned earlier that a designer may begin writing the actual functional responses of the system and realize he does not have all the required input and output devices. This may require an update to the flow diagram initially developed. The process of devel-oping the sequence of operation may also identify features or options that were not originally specified. This is the time to adjust and refine those specifications.

The best way to review the sequence of operation is to step through all of the actions and responses. Try to break the system by identifying scenarios that your sequence of operation cannot prop-erly respond to. Rewrite the sequence as necessary to address these scenarios. A peer review is a great way to ensure the intent of the sequence is clear to others.

In complex systems, consider how individual pieces of equipment inter-act with the sequence of operation of

the other equipment. A multi-zone VAV system will have a sequence of operation for the individual terminal units and the central air handling unit. These sequenc-es must be coordinated to ensure they

work in harmony to provide the most efficient operation. The successful oper-ation of one is dependent on the other.

CommissioningFunctional testing during commission-

ing helps ensure the constructed project operates according to the design intent. The tests are largely based on the design-er’s sequence of operation. The equip-ment should not be expected to perform functions that were not required by the sequence.

Discrepancies noted during the com-missioning phase of the project should be reviewed with the designer. It may be nec-essary to update the sequence of operation based on data gathered during the function-

al testing. Refer to the static pressure sensor example mentioned earlier. Commissioning is the appropriate time to verify the fail-safe strategies function as expected. The intent was to keep the system in operation. The commissioning authority should test the operation of this feature and the team should modify setpoints as required to achieve the desired results.

Commissioning is the last chance to evaluate the sequence before turning over the project to the owner. The designer should be involved in the commission-ing process and review the final commis-sioning report. The sequence may need to be modified based on observations dur-ing the commissioning period. Changes this late in the project schedule may have large cost and schedule impacts. That being said, the designer should not rely on the commissioning process to make up for lack of adequate foresight during the design phase.

OperationThe building operator should fully

understand the sequence of operation. This ensures the facilities maintenance group operates the equipment consis-tent with the design intent to recognize the full benefits of the system they have been provided. The building operator may override the supply air temperature in response to space temperature com-plaints. He or she should understand the consequences of this override as they relate to sacrifices in energy efficiency. Identify root causes of operational defi-ciencies and solve problems at the source.

Although the designer should consider the operational requirements during the design phase, these specific details may not always be available. The sequence may need to be refined as the build-ing operation evolves over time. The sequence of operation should be consid-ered a living document that is continu-ously maintained throughout the life of the system. Doing so allows for seamless transfer of knowledge within the opera-tions group. Understanding the control logic for existing equipment is important


Figure 5: Multiple variable frequency drives (VFDs) are used with a group of exhaust fans. The sequence modulates the fan speeds together to maintain differential pressure within the space. Courtesy: JBA Consulting Engineers


for designers working on building reno-vations or tenant improvements within an existing space. Without this knowledge, the new design may work against the base system instead of in sync with it.

An up-to-date sequence also becomes a benchmark for how the system should be operating. The sequence for existing equipment may be modified to optimize energy efficiency and better suit the evolved building functional and opera-tional requirements. Retro-commission-ing and energy audits are great ways to identify deficiencies in the sequence of control for existing equipment. Exist-ing equipment without a well-defined sequence of operation may be a good target for energy optimization.

HVAC systems use considerable amounts of energy in commercial build-ings. Developing a well-thought-out sequence of operation helps minimize the energy consumption of these systems. In

addition, it allows the system to meet the criteria for which it was designed. The designer must develop the sequence to a level of detail that is appropriate for the project at hand and maximizes the suc-cess of that particular project.

Although it is not uncommon to see sequences included in project speci-fication manuals, the best location for this information is often directly on the construction drawings. Keeping the sequence of operation closely tied to the equipment schedules, plans, and control diagrams increases the transparency of information throughout the project his-tory. This arrangement is advantageous as the project specification manual is not always available in the field and often becomes separated from the drawings.

The steps outlined can be translated to almost any system regardless of size and complexity. The important thing to remember is that the sequence of opera-

tion should not be written in haste as the project is going out the door. An effec-tive sequence of operation begins early in the design process when the systems are being developed and equipment is being selected. Doing so allows the designer to develop the most effective system.

Jason A. Witterman is a mechanical project engineer with JBA Consulting Engineers. He has experience in various market sectors including data centers, commercial office, aviation, medical, and government projects. His expertise is data centers, sustainability, and ener-gy codes. Ed Butera is chairman of the board at JBA Consulting Engineers and has more than 40 years of experience. He specializes in master planning and design of complex systems for health care, high-rise buildings, central utility plants, and large hospitality resort projects.

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In early 2012, the District of Columbia ini-tiated an effort to develop new construc-tion codes. The process has been led by

the Department of Consumer and Regulatory Affairs (DCRA) Construction Codes Coordi-nating Board (CCCB) and its Technical Advi-sory Group (TAG) subcommittees, comprising a diverse group of District officials and design and construction industry professionals.

As a member of D.C.’s Green TAG, I had the opportunity to participate in the process of creating the District of Columbia Green Con-struction Code (DCGCC). The Green TAG met weekly over a period of six months, and while our primarily task focused on reviewing and proposing amendments to the 2012 Interna-tional Green Construction Code (IgCC), we addressed ASHRAE Standard 189.1: Stan-dard for the Design of High-Performance Green Buildings Except Low-Rise Residential Buildings and U.S. Green Building Council (USGBC) LEED standards as well. The model code we delivered completed three rounds of public comments, and as of the writing of this article, its approval is pending a final vote by the D.C. Council.

The purpose of the DCGCC is to imple-ment many of the strategies that architects and engineers are already experienced with into enforceable code language. Overall, the proposed code is not intended to create drastic changes to typical methods or represent a far deviation from good practice. Most language encompasses the processes likely followed by many design and construction teams as a mat-ter of course.

On a personal note, acknowledging no code is perfect, I believe the DCGCC has been well-vetted and that the intent of the model code and ASHRAE Standard 189.1 was preserved,

though some requirements were removed or lightened.

Outlining the codeThe fundamentals:

n The DCGCC will apply to all projects larger than 10,000 sq ft that are classified as either New Construction or Substantial Improvement.

n It will apply to small tenant fit-outs, although in order to reduce burden on smaller projects, certain provisions of the DCGCC will not apply. These types of projects make up a large volume of work in the District.

n There are three additional compliance paths if you elect not to follow the DCGCC: the D.C. Green Building Act of 2006 and amendments, LEED Silver certification or better, or ASHRAE Standard 189.1.

n In addition to the primary code language, Appendix A contains options for Elective Credits. Projects must achieve 15 for New Construction and 13 for Level 3 Alterations. There are more than 75 potential options in Appendix A, which only applies to the primary DCGCC compliance path and not the alternative D.C. Green Building, LEED, or Standard 189.1 paths.

n Commissioning will not hold up a certificate of occupancy (COO)—it has been replaced with a final inspection.

Vegetation, soils, and erosion control:n Containment and removal of invasive plant

species will be required.n 75% of land-clearing debris and excavated

soil must be diverted.n For requirements in this domain, thorough

planning and documentation is critical for success. Develop a plan for planting, and make sure the area is clear of debris before you excavate so there is no rubble. Leave 6 in. of topsoil for planting.

By Patrick a. kunze, Pe, LeeD aP, GHT Limited, Arlington, Va.

The DCGCC will apply to all projects larger than 10,000 sq ft that are classified as either New Construction or Substantial Improvement.

Codes & Standards

Turning Standard 189.1 into codeThe District of Columbia has created new construction codes, mirroring ASHRAE Standard 189.1.

DE-2www.csemag.com Consulting-Specifying Engineer • NOVEMBER 2013

Materials and resources:� 50% of construction waste (volume or

weight) must be diverted. This is typically required in contract specs and should be fairly easy to achieve. Many contractors are achieving 75% on a regular basis.

� 40% of materials must be:-Used-Recycled-Recyclable-Bio-based OR-Regional.

Note that materials that have more than one of these features can be counted mul-tiple times toward the 40%—i.e., if a material is used, recy-clable, and regional, its value is tripled.

Energy:First, there are a handful of energy

requirements that will apply to all build-ings covered by the DCGCC.

� Elevators and escalators have effi-ciency and control requirements to reduce energy consumption.

� At least 50% of Energy Star eligible food service equipment shall be Energy Star rated.

� Energy metering and distribution requirements:

- Energy must be metered by sourcetype (e.g., electricity, natural gas, district steam, etc.).

- Energy must be distributed by usetype (HVAC, lighting, plug loads, process loads, and miscellaneous). If not distributed separately, the various uses must be submetered for monitoring purposes. Submetering is only required for larger projects. The intent is to require the separate dis-tribution on all projects so that uses can be measured in the future. Sub-meters can be provided on smaller projects if the design team decides it is more feasible to do that instead of separate distribution paths.

- Projects larger than 50,000 sq ftmust have meters capable of meter-ing each use type in the building.

- Projects that use a building man-agement system must have the capa-bility to use auto-demand response in which HVAC power is reduced by 10% of the design load upon a signal from the utility company that peak power consumption is in effect.

This does not mandate the use of auto-demand response, just that it is available for use.

Next, there are two primary compli-ance paths under the energy section of the code: prescriptive and performance. The prescriptive path is a simplified approach that may be best suited for projects of smaller scale. The perfor-mance path is envisioned for larger, more complex projects that do not want to be constrained by the prescriptive require-ments and will document, through build-ing energy modeling, that the designed building exceeds certain benchmarks. This is not unlike the energy code which currently offers a prescriptive path or an alternative performance path based on ASHRAE Standard 90.1 compliance.

� Prescriptive path: In addition to specific insulation and mechanical efficiency requirements, new electri-cal controls are mandated to facilitate power conservation. Occupancy sensors are required for interior lighting, time clocks are required for non-emergency exterior illumination, and daylight har-vesting controls are required for inte-rior lighting near perimeter windows and under skylights.

� Performance path: In order to pursue the modeled performance path-way, a building energy model must be performed demonstrating a specific level of efficiency in terms of zEPI (Zero Energy Performance Index). Unlike the energy use index used in

ASHRAE 90.1 modeling, the zEPI allows buildings of different use types and different code years to be compared. Currently, the DCGCC requires a build-ing to be designed to use no more than 90% of the source energy of a build-ing designed to the per-formance requirements of ASHRAE 90.1-2010.

Water:The DCGCC sets maximum flow

rates for standard plumbing fixtures. The flow rates are in line with current commercially available products. In most cases, the maximum flow rates are in line with the current plumbing code. Additional water conservation measures include:

� Meters are required to measure water consumption based on a variety of uses outlined in the code.

� Eff iciency and water saving requirements have been mandated for most common water treatment systems including water softeners and reverse osmosis systems.

Patrick A. Kunze is a senior principal and mechanical section head of the inte-riors studio with GHT Limited. Kunze has provided mechanical engineering design for more than 20 projects that have achieved U.S. Green Building Council LEED certification, including the USGBC’s headquarters; contributed to the development of questions for the current LEED AP exam; and currently sits on the Green Technical Advisory Group subcommittee of Washington, D.C.’s Construction Codes Coordinat-ing Board.

This shows the progression of the D.C. Green Construction Code. Courtesy: GHT Limited

DE-3 Consulting-Specifying Engineer • NOVEMBER 2013 www.csemag.com

Government agencies and regulato-ry bodies in the U.S. and around the world are working on regula-

tions to help reduce power consumed by fans in commercial and industrial ven-tilation. As a part of this effort, AMCA International (in support of a request from ASHRAE Standard 90.1) developed an efficiency metric known as fan efficiency grade (FEG) that could be used to estab-lish minimum acceptable fan efficiency.

FEG definition and ratingFEGs, as defined in AMCA 205, are

designed to be a simple system to indi-cate the aerodynamic quality of the fan and are based on the fan’s peak total effi-ciency. The total efficiency is calculated using the traditional airflow, pressure, and input power as measured per AMCA Standard 210. Fan efficiency does not take into effect the efficiency of the drive (belt drive) or the motor. Efficiency is defined as the air power divided by the fan input power. Both static and total efficiency can be calculated from fan performance data as follows:

Where:CFM = Fan flow rate, ft3/minPs = Static pressure, in. wgPt = Total pressure, in. wgBHP = Fan power input, hp

Fan static and total efficiency (Figure 1) can be plotted along with the fan pressure curves. The peak total efficiency occurs at the top of the “bell” shaped efficiency curve. This peak total efficiency is used to determine the FEG value.

Note that the peak efficiency occurs at just one point on the curve and all other points on the curve have a lower efficien-cy. It is important to understand, as the efficiency curves illustrate, that each fan has a large range of efficiencies depending on the airflow and pressure at the operat-ing point. For example, a fan with a peak efficiency of 70% easily can be selected to operate at a point of only 50% efficiency.

Another aspect of AMCA FEGs is that their value depends on the fan size. Smaller fans are inherently less efficient than larger fans. This is because the small-est dimensions—material thicknesses and running clearances between parts—cannot be held as tightly in proportion to other dimensions as they can on larger fans. The AMCA FEG curves have been established such that fans of a given model that are geometrically similar will each have the same, or nearly the same, grade.

Fan efficiency grades (FEG) are a poor metric in determining the mostefficient fan (in terms of actual power consumption) for a given airflow and pressure operating point. The best simple metric to ensure the lowest power consumption is the operating brake horsepower at the specified design point.

BY TIM MATHSON and ANTHONY ROSSI, Greenheck, Schofield, Wis.

Understanding the limitationsof fan efficiency grades

Learningobjectives� Understand the fan effi-ciency grade (FEG) metric.

� Learn about the relationship between peak fan efficiency and actual operating effi-ciency.

� Understand the difference between static efficiency and total efficiency.

� Know that, depending on the actual fan application, the highest efficiency may not yield the greatest energy savings.

DE-4www.csemag.com Consulting-Specifying Engineer • NOVEMBER 2013

Once the peak TE is known, the FEG value can be determined from AMCA Standard 205 (see Figure 2). For example, a 24.5-in. diameter fan with a peak TE of 69% would be classified as an FEG71. Note that a 12-in. diameter fan with a peak TE of 60% is also FEG71.

Selection rangeBecause the efficiency curve of a fan is

bell shaped, specifying a relatively high FEG by itself will not necessarily result in high fan efficiency. To realize the potential efficiency of a fan, the fan must operate near its peak efficiency. AMCA Stan-dard 205 recommends that all selections be made within 15 percentage points of the peak TE. This requirement effectively reduces the allowable selection range (see Figure 3).

Limitations of FEGA significant shortcoming of the FEG

metric is that the highest FEG fan does not necessarily result in the lowest energy consumption. Table 1 illustrates this point. Notice that the 72-in. fan requires the least energy (lowest BHP). Yet, the 48-in. fan has a greater total efficiency (66% vs. 60%) and a higher FEG (71 vs. 63).

Additionally, Table 2 relates the first cost of each fan size, along with the 5-year total cost of ownership (TCO), excluding

maintenance. The size 27 blow-er could be selected for this application, having the lowest first cost but not the lowest power consumption. The larg-est blower, size 36, has the low-est power consumption, but at a 27% premium cost over the size 27. If the application can accommodate the dimension-ally larger blower, the energy savings will pay back the addi-tional cost of the larger blower in 1.4 years. ($0.10/kWh and 2400 hours/year operation) The size 33 blower, however, has the lowest 5-year TCO.

So how can the fan with a higher efficiency consume more than twice the power?

How can the same type of fan, selected for the duty point of operation, have the same FEG value yet consume twice the power of another (see Table 2)?

First, the FEG metric is based on fan total efficiency and fan total pressure. Total pressure is used because it is a measure of the total energy imparted to the air. However, the velocity pressure exiting a fan can only be used when it is contained in a duct—and is lost on non-ducted fans. This makes FEG an inap-propriate and often misleading metric for

many fan applications, such as sidewall propeller fans, powered roof ventilators (PRVs), and plenum fans. For fans with-out a discharge duct, static efficiency will correlate to power consumption.

This is why the fan industry has stan-dardized on selecting fans using static pressure and not total pressure: both ducted and nonducted fans use static pressure, whereas only ducted fans use total pressure.

In the example in Table 1, the 48-in. fan has a much greater discharge velocity than the 72-in. fan. This contributes to the

Figure 1: Fan efficiency is plotted along with a fan curve. Fan performance (measured in cfm) can be plotted as a function of static pressure or total pressure. Respectively, fan efficiency can be plot-ted on the fan curve for either static pressure or total pressure. Because total pressure is the sum of static and velocity pressure, the peak total effi-ciency will always be greater than the peak static efficiency. Courtesy: Greenheck

Figure 2: In this AMCA FEG curve, a 24.5-in. diameter fan with a peak total efficiency of 69% is classified as FEG71. Courtesy: AMCA International

Figure 3: This fan curve shows how the selection range is reduced when following AMCA Standard 205, which recommends all selections be made within 15 percentage points of the peak total effi-ciency and FEG values. Courtesy: Greenheck

Figure 1: Fan efficiency is plotted along with a fan

DE-5 Consulting-Specifying Engineer • NOVEMBER 2013 www.csemag.com

high TE and FEG values, but since this is a nonducted application, the velocity pressure is lost. Notice that the 72-in. fan has the highest static efficiency, which is the proper metric for nonducted applica-tions.

Second, as communicated earlier, the FEG value is based on the peak efficiency of the fan. For a given point of operation (CFM and pressure) an FEG63 fan could consume less power than an FEG75 fan simply because it is selected closer to its peak efficiency point. Fans with higher peak efficiencies do have a greater poten-tial to operate more efficiently. However, the actual fan efficiency selected is the correct measure of actual energy con-sumed.

Another limitation is that while speci-fying a single FEG value for all fan applications would be desirable, it is just not that simple. ASHRAE Standard 90.1-2013 requires a minimum FEG67

for all fans. This is also the direction being taken by the International Energy Conservation Code (IECC). Addition-ally, it is well known that weather guard-ing of PRVs inherently impacts fan efficiency negatively. And as discussed above, PRVs and other fans with a non-ducted discharge should not be held to the same metric that is based on ducted total efficiency. To accommodate these realities, several exemptions have been added to the proposed language so that the industry doesn’t unwittingly elimi-nate economical and efficient fans from existence. Meanwhile, ducted housed airfoil centrifugal fans and ducted vane axial fans already greatly exceed the pro-posed minimum value of FEG67, so this won’t drive greater efficiency for these fans. The end result is that the single FEG value approach as adopted in ASHRAE Standard 90.1 has little ability to actually save energy.

Code languageFEGs are a simple measure of the peak

total efficiency of a fan. Although other alternatives are being considered for code regulation and energy savings, FEG was initially incorporated into proposed code language and has not been replaced (as of the time of this writing). Because of the current state of events on this front, the final code language may use FEGs to establish minimum aerodynamic effi-ciency levels. If this occurs, fans below the mandated FEG value will not be allowed.

Regardless of the outcome of code language, FEG is a poor metric in deter-mining the most efficient fan (in terms of actual power consumption) for a given air-flow and pressure operating point. Clearly the best simple metric to ensure the low-est power consumption is the operating BHP at the specified design point. From a specifying engineer’s perspective, there are three key takeaways regarding fan efficiency:

1. Specify the specific operating BHP in your fan schedule and specify that fans are licensed to bear the AMCA seal for air per-formance. This ensures that your fan applica-tion performance/energy intent is met.

2. Consider total cost of ownership as well as first cost to economically justify fans that use lower brake horsepower.

3. Reputable manufacturers will pro-vide information and tools to help you comply with the minimum code require-ments. And, in many cases, economical products will be available that exceed the code minimum.

Tim Mathson, principal engineer is a member of ASHRAE TC 5.1, AMCA Fan Committee, AMCA Air Movement Engi-neering Standards Committee, and is chairman of the standards writing com-mittees for AMCA 210/ASHRAE 51 and AMCA 301. Anthony (Tony) Rossi, vice president of marketing is a member of the AMCA Marketing Board and ASHRAE TC 9.10 Laboratory Systems, and has served on both ASHRAE and ARI standards development committees as well the Edu-cation Committee Chairman for ASHRAE Central Indiana.

Understanding FEG limitations

Table 1: The highest fan efficiency grade (FEG) fan does not necessarily result in the lowest energy consumption. Courtesy: Greenheck

Table 2: Various size fans of the same type, selected for the same duty point of opera-tion, have the same high fan efficiency grade (FEG) value (85), but significantly differ-ent power consumptions (ranging from 12 to 24.5 BHP). Courtesy: Greenheck

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labels on its life safety dampers, and control and air measuring dampers. Life safety dampers include ceiling radiation dampers, fire dampers, smoke dampers, and combination fire smoke damp-ers. When the QR code is scanned with a smartphone, it links to www.greenheck.com based on the model to provide instant access to product specifications, submittals, instruction manuals, installation videos, and warranty information. Greenheck, www.greenheck.com Input #211 at www.csemag.com/information

General purpose softstarters

Carlo Gavazzi’s RSGD (two-phase controlled) compact Gen-eral Purpose Softstarter handles loads up to 40 hp and is designed to reduce the starting current down to three or four times the rated motor current, resulting in smoother starting and stopping of

motors. This increases the lifetime of the motor and reduces the electrical

disturbances on the supply network. Other features include an auto-adaptive algorithm for optimal inrush current reduction and current balances. Its intelligent algorithm is able to react to stalled mo-tors, and it has an optional relay output. The RSGD series has CE, cULus, and CCC approval and a 45 mm wide housing.Carlo Gavazzi, www.gavazzionline.com Input #209 at www.csemag.com/information

Power monitoring softwareSchneider Electric’s StruxureWare Power Monitoring Expert is designed for integrated energy and electrical distribution power man-agement. Highlights of the new software include cost allocation and bill estimation features that enable customers to analyze the direct fi-nancial impact of energy usage at a departmental or cost center level, through the implementation of user-defined energy consumption hi-erarchies. The robust productivity kit with documentation, productivity tools, libraries, and end-to-end how-to guides helps project execution teams deliver custom solutions in a consistent, efficient, and repeat-able way. Additionally, support is available for an offline configuration mode, and improved maintenance tools empower project teams to be more productive ahead of the commissioning phase and mitigate risk. StruxureWare Power Monitoring Expert also offers extensibility sup-port through Web services. This makes it easier to integrate with other applications, like Schneider Electric’s entire StruxureWare software suite, for energy management information systems (EMIS) and sus-tainability management, to share real-time, historical, power quality, and event data. This software platform also is efficient at managing critical energy data in diverse environments, ranging from industrial plants to data centers.Schneider Electricwww.schneider-electric.com Input #210 at www.csemag.com/information

Product & Literature Digest


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The 3,250 kW Series 4000 diesel generator set from MTU Onsite Energy is designed to respond to transient loads and quickly recover from voltage and fre-quency dips commonly associated with cycling loads and motor starting. In standby applications, the unit’s reserve power capabilities enable the generator to accept its full rated load in a single step in accordance with NFPA 110.

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cse201301_eNewslt_QTR.indd 1 1/14/2013 11:27:35 PM

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Kristen Nimmo, Marketing Manager630-571-4070 x2215; [email protected]

Elena Moeller-Younger, Marketing Manager773-815-3795, [email protected]

Michael Smith, Creative Director630-779-8910, [email protected]

Paul Brouch, Director of Operations630-571-4070 x2208, [email protected]

Kate Steel, Production Coordinator,630-571-4070 x2217, [email protected]

Rick Ellis, Audience Management Director303-246-1250, [email protected]

Michael Rotz, Print Production Manager717-766-0211 x4207, Fax [email protected]

Maria Bartell, List Rental Account DirectorInfogroup Targeting Solutions847-378-2275, [email protected]

Claude Marada, List Rental Manager402-836-6274, [email protected]

Letters to the Editor Please e-mail your letters [email protected] Letters should include name, company, and address,and may be edited for space and clarity.

Information For a Media Kit or Editorial Calendar, e-mail Trudy Kelly at: [email protected].

REPRINTSFor custom reprints or electronic usage, contact: Nick Iademarco, Wright’s Media 877-652-5295 x102, [email protected]

PUBLICATION SALESMidwestMatt Waddell [email protected] West 22nd St. Suite 250 312-961-6840Oak Brook, IL 60523 Fax 630-214-4504

ALPatrick Lynch [email protected] W. 22nd St., Suite 250 630-571-4070 x2210Oak Brook, IL 60523 Fax 630-214-4504

West, TX, OKTom Corcoran, [email protected] W. 22nd St., Suite 250 215-275-6420Oak Brook, IL 60523 Fax 484-631-0598

NortheastRichard A. Groth Jr. [email protected] Pine Street 774-277-7266Franklin, MA 02038 Fax 508-590-0432

InternationalStuart Smith [email protected] Global Media Ltd. +44 208 464 5577 Fax +44 208 464 5588

www.csemag.com Consulting-Specifying Engineer • NOVEMBER 2013 63

Advertiser Index

Consulting-Specifying Engineer does not assume and hereby disclaims any liability to any person for any loss or damage caused by errors or omissions in the Advertiser contacts regardless of whether such errors result from negligence, accident, or any other cause whatsoever.

Request more information about products and advertisers in this issue by using thehttp://csemag.com/information link and reader service number located near each item. If you’re reading the digital edition, the link will be live. You may also check the circle adjacent the page reference to indicate which companies you are interested in, then FAX this back to CSE at 630-214-4504 for FREE information. When you contact a company directly, please let them know you read about them in Consulting-Specifying Engineer.

Need More Info? FAX this page to: 630-214-4504or mail to Consulting-Specifying Engineer magazine, 1111 W. 22nd Street, Suite 250, Oak Brook, IL 60523

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Company Address

City State

Phone Fax e-mail

Zip

Reader Company Page Service # Phone # Web site Send Info

Armacell................................................ 14 ...............7 ................888-570-DUCT ............www.armacell.us ....................................... �

Baldor Electric Company ..................... C-2 .............1 ................479-646-4711 ..............www.baldor.com ....................................... �

Berthold Electric Company ................. 16 ...............9 ................800-657-6650 ..............www.GenConCab.com .............................. �

Carrier Corporation ............................. 5 .................4 ................800-227-7437 ..............www.carrier.com

CFE Media, EngineeringIs Personal ............................................ 60 ..................................630-571-4070 ..............www.csemag.com ..................................... �

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Hochiki America Corp .......................... 31 ...............16 ..............714-522-2246 ..............www.hochiki.com ...................................... �

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International Exposition Co ................ 20 ...............12 ..............203-221-9232 ..............www.AHREXPO.COM/ATTEND17 ............. �

Keltech, Inc ........................................... 51 ...............23 ..............800-999-4320 ..............www.keltech-inc.com ................................ �

Kohler ................................................... 2 .................3 ................800-544-2444 ..............www.KOHLERPOWER.COM/INDUSTRIAL .... �

Legrand/Wiremold ............................. C-4 .............25 ..............800-621-0049 ..............www.legrand.us/wiremold....................... �

Let’s Connect Socially,CSE Social Media.................................. 50 ..................................630-571-4070 ..............www.csemag.com/connect/social-media.html .... �

Metra� ex .............................................. 49 ...............22 ..............312-738-3800 ..............www.Metra� ex.com/SeismicGator .......... �

MTU Onsite Energy ............................. 15 ...............8 ................507-625-7973 ..............www.mtu-online.com ............................... �

Mitsubishi ElectricCooling & Heating ............................... 33 ...............17 ..............800-433-4822 ..............www.mitsubishipro.com/new-controllers ....�

Reliable Controls .................................. 8 .................6 ................250-475-2036 ..............www.reliablecontrols.com/contact .......... �

Schneider Electric................................. 17 ...............10 ..............847-397-2600 ..............www.schneider-electric.com ..................... �

SimplexGrinnell .................................. 41 ...............18 ..............800-746-7539 ..............www.simplexgrinnell.com ........................ �

Solutions for Engineers ....................... 58 ..................................630-571-4070 ..............www.csemag.com ..................................... �

The VMC Group ................................... 7 .................5 ................800-569-8423 ..............www.TheVMCGroup.com ......................... �

Trane .................................................... 29 ...............15 ..............651-407-4189 ..............wwwTrane.com/Foundation..................... �

XYLEM GLOBAL HEADQUARTERS...... 47 ...............20 ..............914-323-5700 ..............www.xyleminc.com ................................... �

Yaskawa America, Inc ......................... C-3 .............24 ..............800-927-5292 ..............www.yaskawa.com ................................... �

PUBLICATION SERVICESJim Langhenry,Co-Founder and Publisher, CFE Media630-571-4070 x2203; [email protected]

Steve Rourke, Co-Founder, CFE Media630-571-4070 x2204, [email protected]

Trudy Kelly, Executive Assistant630-571-4070 x2205, [email protected]

Kristen Nimmo, Marketing Manager630-571-4070 x2215; [email protected]

Elena Moeller-Younger, Marketing Manager773-815-3795, [email protected]

Michael Smith, Creative Director630-779-8910, [email protected]

Paul Brouch, Director of Operations630-571-4070 x2208, [email protected]

Kate Steel, Production Coordinator,630-571-4070 x2217, [email protected]

Rick Ellis, Audience Management Director303-246-1250, [email protected]

Michael Rotz, Print Production Manager717-766-0211 x4207, Fax [email protected]

Maria Bartell, List Rental Account DirectorInfogroup Targeting Solutions847-378-2275, [email protected]

Claude Marada, List Rental Manager402-836-6274, [email protected]

Letters to the Editor Please e-mail your letters [email protected] Letters should include name, company, and address,and may be edited for space and clarity.

Information For a Media Kit or Editorial Calendar, e-mail Trudy Kelly at: [email protected].

REPRINTSFor custom reprints or electronic usage, contact: Nick Iademarco, Wright’s Media 877-652-5295 x102, [email protected]

PUBLICATION SALESMidwestMatt Waddell [email protected] West 22nd St. Suite 250 312-961-6840Oak Brook, IL 60523 Fax 630-214-4504

ALPatrick Lynch [email protected] W. 22nd St., Suite 250 630-571-4070 x2210Oak Brook, IL 60523 Fax 630-214-4504

West, TX, OKTom Corcoran, [email protected] W. 22nd St., Suite 250 215-275-6420Oak Brook, IL 60523 Fax 484-631-0598

NortheastRichard A. Groth Jr. [email protected] Pine Street 774-277-7266Franklin, MA 02038 Fax 508-590-0432

InternationalStuart Smith [email protected] Global Media Ltd. +44 208 464 5577 Fax +44 208 464 5588

1111 W. 22nd St., Suite 250, Oak Brook, IL 60523630-571-4070 Fax 630-214-4504


My career in fire protection engi-neering has spanned more than 25 years. The profession has

always given me the opportunity to live a comfortable life. By no means would I consider myself rich in a financial sense, but my wife and three children weren’t left wanting for much. My kids were able to go private school through the 12th grade and my wife enjoys playing tennis at the local country club. It’s a pretty good life.

My oldest two children, ages 26 and 22, are both college graduates who did well in school. My daughter gradu-ated from an honors program with two degrees and many academic honors. My son was a NCAA Division 1 athlete and also received several academic awards.

Both did well in math and science in high school, but after years of encouragement (they might say badgering) from me, neither one wanted to go into engineering. I start-ed the encouragement/badgering of my youngest daughter earlier in hopes that I could get one of my three children to continue our family engineering tradition. I should mention that my father is a retired electrical engineer.

During her last year of high school, like many of her friends and classmates, my youngest was busy applying to a variety of colleges and universities. When she selected the school of her choice, she was accepted as a communi-cations major. I stopped the badgering and resigned myself to having no children in the engineering profession.

But then one day, out of the blue, she asked, “Dad, what do you really do at work?”

I’m pretty sure my kids believed that all I did at work was talk on the phone and entertain clients over lunch. I saw the door of enlightenment open a crack. We sat and talked for a couple of hours. We visited engineer-ing websites of the school she selected and explored online information about engineering professional soci-eties. We reviewed salaries and job opportunities that a graduate engineer could expect to earn upon graduation.

We even discussed intern programs, such as the one our company offers to students studying fire protection engi-neering.

At the end she said, “I might want to do that.” I took the bait and offered to set up a meeting with the head of the engineering department at her soon-to-be school. Fortunately, she had picked my alma mater so we were able to schedule a meeting with the chairman of the engineering department.

After the meeting she immediately changed her major from communications to engineering. Of course, I am thrilled.

I have already warned her that I prob-ably won’t be much help with her home-work. But I’m not sure what to do now:

� Do I pass down my father’s slide rule to my daughter, or do I buy her a new computer?

� Do I give her a copy of Marks’ Standard Handbook for Mechanical Engineers, or calculus CliffsNotes?

� Should I get her a drafting table, triangles, and a French curve, or buy the latest version of AutoCAD and a big computer monitor?

� Should I show her how to operate an IBM key punch machine and teach her how to program in Fortran?

I think I still have my remote computer workstation with an acoustically coupled 300-baud modem and a thermal printer, but I don’t think that would be much help in the new world she’s entering.

Times have definitely changed, but engineering is still an honorable and well-paying profession. I hope my daughter will enjoy it as much as I do. I do know one thing for sure—she’s now on the fast track to becoming my favorite child.

Tom Brown is an executive vice president for The RJA Group Inc., the parent company of Rolf Jensen & Associ-ates Inc. Based in the Baltimore office, Brown heads up the RJA Practice Group that sets the technical standards and best practices for the firm.

2 More Minutes

And the engineering beat goes onFinally—one of the kids sees the engineering light.

THOMAS BROWN, PETHE RJA GROUP, BALTIMORE

on-peakperformanceNOVEMBER 2013

ON-SITE POWER GENERATION FOR A COMPETITIVE FUTURE

A supplement to Consulting-Specifying Engineer,with information from EGSA.

Use withstand current ratingto improve electrical designsPAGE 4

Standby genset emissionrequirementsPAGE 8

Resistive/reactivegenset load testingPAGE 12

Continuing standbypower educationPAGE 16

Critical powermonitoring, controlPAGE 18

Analyzing CHP installation validityPAGE 23

Structured maintenance ensures genset reliabilityPAGE 26

Case Study: Rex Hospital gets a power system upgradePAGE 28

Welcome from the2013 EGSA president

ELISABETH FOLEY SAID, “The most beautiful discovery true friends make is that they can grow separately without growing apart.” There is an applicable message in that quote. For the past 15 years, the Electrical Generating Systems Association (EGSA) has grown up side-by-side with Consulting-SpecifyingEngineer Magazine. Each November, our common goal is to bring the engineering

ever-evolving industry of on-site power. It is always easy to pick up right where we left off.

EGSA is the world’s largest trade association dedicated to on-site power, composed of companies serving many facets of the power generation industry. Our members provide services, technology, equipment, and associated and supporting products, advancing the power generation industry to best serve our customers’ requirements. This equipment is used in many applications domestically and globally, including emergency standby, demand response, prime power, rental, and cogeneration. On-site power also encompasses alternative power sources such as fuel cells, wind, and solar.

Generator sets are among the many components used in reliable on-site power systems. This equipment can be complex, and must be serviced and maintained for reliable operation. For more than 48 years, we have dedicated our efforts, through programs like our EGSA

Advanced Power Schools, to help engineers just like you navigate the industry.

What does this mean to consulting and specifying engineers? Our membership comprises companies that design, manufacture, distribute, install, service, and sell. We hope that you will gain insight from these articles and get to know us. Perhaps one of these articles will energize you to take action. Each has been prepared by

the information useful, engaging, and practical.

If you would like to learn more, we have several opportunities each year for you to get to know us. Please visit www.egsa.org for more information, email us at [email protected], or join us on LinkedIn.

Debra Laurents2013 EGSA PresidentCummins Power Generation

COVER STORY

4 Using withstand current ratingto improve electrical system designsUnderstanding how withstand current rating affects anautomatic transfer switch enables consulting engineers todesign more effective electrical systems.

FEATURE STORIES

8 Understanding emissionrequirements for standby gensetsEngineers should know the current emission regulatoryrequirements to ensure their designs comply.

12 Commissioning, testing gensetsusing resistive/reactive load banksConsulting engineers can help their clients by conveying to themthe importance of including reactive load bank testing duringcommissioning and periodically during normal operations.

16 Continuing standby power educationKnowledge is power when designing standby power systems.

18 Selecting a critical power monitoringand control technologyChoosing a monitoring and control technology should be basedon the power reliability requirements for the application.

23 Analyzing CHP installation validityModern CHP modules can increase a facility’s energyefficiency, reduce environmental impact, and contribute tocorporate sustainability.

26 Structured maintenanceensures genset reliabilityConsulting engineers are in an excellent position torecommend structured maintenance programs to their clients.

28 Case Study: Rex Hospital getsa power system upgradeThe upgrade increased the system’s emergency powergenerating capacity and boosted its fuel storage capacity.

DEPARTMENTS

29 About the Electrical Generating Systems Association29 EGSA 2013 board election results30 Important on-site power industry events

ABOUT THE COVERStandby gensets, such as the unit shown in the photo, provide electrical power whenthe utility fails. The ATS determines which source—utility or genset—provides powerto the distribution circuit breakers. Courtesy: Kohler Power Systems

3N O V E M B E R 2 0 1 3 3

N O V E M B E R 2 0 1 34

The automatic transfer switch (ATS) is a critical part of an electrical power system. Understanding its withstand current rating (WCR) is essential. If

Transfer switch considerationsA transfer switch is typically the last distribution device feeding the critical

1

2 -

here can result in arcing and heat damage that can lead to premature switch failure.

3

system testing.

stress (measured in I2-

Using withstand current rating toimprove electrical system designsUnderstanding how withstand current

rating affects an automatic transfer

switch enables consulting engineers to

design more effective electrical systems.

Figure 1: Standby gensets,such as the unit shown in thephoto, provide electrical powerwhen the utility fails. The ATSdetermines which source—util-ity or genset—provides power tothe distribution circuit breakers.Courtesy: Kohler Power Systems

5N O V E M B E R 2 0 1 3 5

By Steve Ennesser and Allen Frederick,Kohler Power Systems

Specifying a transfer switchTo avoid catastrophic events, protective devices such as circuit breakers and fuses are used to isolate a fault from the power source if a fault oc-curs. A proper WCR rating ensures that a particular transfer switch can withstand the fault current until the immediately upstream protective device opens. The appropriate WCR also demonstrates that the switch will remain operational after the fault current passes.

To minimize fault risk, which is typically caused by load-side cable failures, the transfer switch should be located as close as possible to the pro-tected critical load it serves. After a transfer switch is exposed to a short-circuit fault, it must still be operable to restore power from the alternative power source.

Prior to selecting a transfer switch, detailed knowledge is required about where the switch will be used. An updated power system study can provide this. This type of study shows computed fault currents at each system bus (for normal and

the capability of upstream and downstream de-vices, protective device coordination analysis and recommendations, and other computations such as available arc-fault energies at each bus. The study also allows engineers to select fuses and determine circuit-breaker trip settings.

Proper protective device coordination ensures that an electrical fault is cleared as close to the point of occurrence as practical. Modern power system studies use computer modeling to consider all parameters including conductor sizes, quanti-ties, and lengths; transformer ratings and imped-ances; and other relevant data. Using this informa-tion, the appropriate transfer switch and location can be selected.

Testing transfer switchesTo assign a WCR to a transfer switch, a short-circuit test is performed, which exposes the unit to its rated level of fault current. Then a dielectric voltage-withstand test is performed to check the unit still functions after the fault current has passed. UL1008: Standard for Safety: Transfer Switch Equipment (seventh edition, July 6, 2012, unless

1 The transfer switch must withstand a short circuit when the switch is closed.

2 The transfer switch must transfer and re-mained closed until the short circuit current is removed.

The short circuit test requirements are pre-sented in Section 9.13 of UL1008; the dielectric voltage-withstand test requirements are covered in Section 9.14.

Rating transfer switchesTransfer switch WCRs are typically listed in the

fuses.

generally popular on larger installations where a

-

breaker rating, it is advisable to select the breaker interrupt and I2t ratings to exceed the transfer switch withstand and I2t, especially with molded-case circuit breakers. As molded-case circuit breakers age, the trip characteristics may change, causing the tripping time to slow and exposing the ATS to energy above the WCR.

-

between the ATS and the test source. The fault current is applied for the time it takes the selected

Allen Frederick is a seniorstaff engineer with KohlerPower Systems, Americas.He has been with thecompany since 2008 andspecializes in switchgearproject management,electric utility distributionsystem engineering andplanning, and control systemengineering. Frederick has aBS in electrical engineeringfrom the University ofWisconsin, Platteville.

Steven Ennesser is anelectrical project engineerwith Kohler Power Systems,Americas. He has beenwith the company since2012 and specializes inautomatic transfer switches.Ennesser has a BS inelectrical engineering fromthe Milwaukee School ofEngineering.

Figure 2: An ATS con-nects critical loads withthe power source thatfeeds them, which is pri-marily the utility unless apower outage occurs, ortests are being con-ducted. Courtesy: KohlerPower Systems

N O V E M B E R 2 0 1 36

the fault current rating requirement and can clear

switch ratings decal. An ATS

with UL 1008) can withstand a fault of a given magnitude for 3 cycles (or 1.5 cycles for transfer switches with a rating smaller than 400 A with

that has an instantaneous trip function. Using the

where planning is generally not as detailed.For transfer switches rated above 400 A or for

those used on circuits with fault currents greater

current be applied for a minimum of 50 msec

to as an umbrella rating and gives the designer

ATS units using these ratings are generally over-protected and could be properly protected with a smaller WCR with one of the other methods. This is because they are protected by

currents for longer periods as they have a short-time—as opposed to instantaneous-trip—capabil-

amended the 1008 standard to account for short time ratings for transfer switches that are protected

fuses. Current-limiting fuses limit the current that passes through them during a fault and ensures the protection of downstream system components from catastrophic failure because they typically clear faults within a half cycle. Current-limiting fuses allow the ATS to be assigned a higher WCR

The bigger picture

into the overall electrical system. The power sys-

UL 1008-rated ATS units are tested on systems

current-limiting fuses deployed upstream. Current-

reduce the duration of a short-circuit current com-

the transfer switch must be understood so the cor-rect ATS can be selected to meet continuous and symmetrical current requirements.

-

-

attention to detail is crucial. While the transfer

overall system cannot be underestimated.

Figure 3: In this drawing,the ATS is shown in theemergency position and isconnected to the genset.During a specific breakertest, the ATS is transferredto the test power sourceinto fault current, which iscreated by connecting allthree phases of the load buswith a shorting bar. To passthe specific breaker test,the ATS must withstandfault current and return tofunctionality after the faultclears. Courtesy: KohlerPower Systems

Test power source

All phases ofload bus shorted

together

ATS h i

Specific breaker test

Most transfer switch manufacturers offer some combination of 3-cycle and short-time closing and withstand-rated switches.

Only Russelectric offers full lines of 3-cycle and 30-cycle rated UL tested, listed, and labeled ATSs and bypass/isolation switches.

Don’t settle for less than the best automatic transfer switches… Insist on Russelectric.

www.russelectric.com1-800-225-5250 An Employee-Owned CompanyAn Equal Opportunity Employer

Made in USA

The best line of automatic transfer switches provides a choice of 30-cycle or 3-cycle closing and withstand ratings


N O V E M B E R 2 0 1 38

To obtain an air emissions permit for facilities that have stationary diesel emergency standby generators, it is necessary to comply with U.S.

Environmental Protection Agency (EPA) and local regulatory requirements. Ensuring that the system design takes into account these regulatory require-

layout and cost.The EPA’s regulations are relatively complex and

overview of the EPA regulatory framework with a con-centration only on those requirements for stationary diesel emergency standby generators that are greater than 500 hp. This size range is commonly encoun-tered in larger data centers, hospitals, and municipal infrastructure. This article also focuses on new instal-lations only; it does not offer insight into the rules that

Targeted emissionsA diesel engine generates certain emissions that the EPA considers to be criteria pollutants. Criteria pollutants are deemed to be serious health risks and are measured by the EPA throughout the U.S. in geo-graphic entities called areas. The key criteria pollutants associated with diesel engines are: nitrogen dioxide (NO2), particulate matter (PM), and carbon monoxide (CO) (see Figure 1).

Explaining the regulatory environmentThe Clean Air Act forms the regulatory basis for all air compliance activity. It was originally established in the early 1970s. The most important recent major amend-ments to the Act occurred in 1990. These amend-ments recognized the need to consider the available technology as a component in determining achievable standards. The EPA terminology for this is maximum achievable control technology (MACT). Cost-effective technology advances in MACT have created the platform for the EPA to look at new emission require-ments for diesel engines.

As part of its risk assessment, the EPA allows emergency engines to meet somewhat lower standards than nonemergency units because of

“emergency” can be relatively complex. Clearly, a utility outage is an emergency condition. In general, a total of 100 hr/yr is allocated to emergency gen-erators for maintenance and testing. Of these 100 hr, the EPA currently allows up to 50 hr to be used for demand response programs in some jurisdic-tions. However, this aspect is currently under review and may be removed. There are no restrictions on the number of run hours for the engine when it is being used under emergency conditions.

EPA regulatory frameworkThe EPA regulatory framework has several compo-nents based on the details of implementation. These components include NAAQS; RICE NESHAP; NSPS; and Tiers 2, 3, and 4.

NAAQS: A NAAQS is based on limits that are designed to ensure healthy air quality for all citizens regardless of where in the U.S. they live. As part of

The modern lean-burn diesel engine has improved dramatically in recent years, but can still contribute

2,PM, and CO.

NO2 is one of the constituents of NOX, the formation of which is largely a function of combus-tion temperature. Typically, a higher combustion temperature results in a higher level of NOX formation. PM is also a function of combustion temperature.

By Bob Stelzer,Safety Power Inc.,Mississauga, Ontario

Engineers should

know the current

emission regulatory

requirements

to ensure their

designs comply.

Understanding emissionrequirements for standby gensets

Figure 1: The yellowhaze shown in this photois an indication of NOX

emissions. Courtesy:Safety Power Inc.

9N o v e m b e r 2 0 1 3 9

Typically, a higher combustion temperature results in less PM formation. As a result, undesirable NOX and PM formation act in opposing directions when engine designers are investigating combustion temperature. CO is often a reflection of incomplete oxidation of fuel in the combustion chamber. Most major diesel engine manufacturers have optimized their combustion processes to such an extent that often CO regulatory requirements are not an issue.

The required targets and the timetable for NAAQS implementation are always changing and apply to each of the criteria pollutants. The EPA goes through a public consultation process to establish the required NAAQS levels for each criteria pollutant. The U.S. is divided into a set of areas, and the EPA performs measurements of the criteria pollutants in each area. Areas that do not meet the NAAQS targets for criteria pollutants are deemed nonattainment areas. For each nonattainment area, the affected state is required to prepare a state implementation plan (SIP) to resolve the issue and achieve attainment.

When seeking an air permit for a new diesel emergency generator, if there is a NAAQS issue, it will most likely relate to NO2. In 2010, the EPA proposed limits based on an hourly worst-case scenario of 100 parts per billion. It is not uncommon, during certain times, for background concentrations in nonattain-ment areas to be high enough that very little NO2 needs to be added to make an installation exceed the limit. Prior to 2010, the NO2 limit was based on a yearly average.

By mid-2013, each state was to have submitted a SIP for its nonattainment areas with respect to NO2. When a major data center, hospital, or other installa-tion installs significant capacity of new diesel standby generators, the typical hourly worst-case scenario oc-curs during the full load test of the units. Modeling is done of the site, typically using the EPA’s atmospheric dispersion modeling (AERMOD) system. AERMOD is a mathematical simulation of how pollutants will dis-perse into the atmosphere. The modeling takes into account the topography of the site, its major emis-sions sources, prevailing wind conditions, and other factors that could lead to worst-case conditions.

RICE NESHAP and NSPS: The RICE NESHAP requirements from the EPA have received a lot of attention in the last few years, largely because of the impact these requirements have on existing nonemer-gency diesel and natural gas generators. These re-quirements have meant that many existing nonemer-gency diesel generators have had to add oxidation catalysts and other equipment to their engines.

A facility is deemed by the EPA to be an area source if it has the potential to emit less than 10 tons/yr of any single hazardous air pollutant or less than 25 tons/yr of any combination of hazardous air pollut-ants. A major source has emissions greater than the area source levels. Typically, major sources have more stringent requirements.

The EPA has classified more than 70 area source categories. Examples include stationary reciprocating internal combustion engines (RICE) and boilers. Each of these categories has special NESHAP require-ments and an associated timeline.

While NESHAP can impact new and existing RICE, NSPS applies to only new installations. As with RICE NESHAP, NSPS typically specifies performance standards that are defined within the EPA Tier levels discussed later in this article.

For the critical power engineer, RICE NESHAP and NSPS are typically not major issues for new emergency diesel gensets greater than 500 hp. Since 2008, all major manufacturers have produced engines that meet RICE NESHAP and NSPS requirements for new emergency diesel engines. To meet these requirements for a new diesel emergency engine, the engine must be certified to at least Tier 3; if it is greater than 752 hp, it must be certified to at least Tier 2. Most of the resulting obligations from RICE NESHAP apply to the facility operators, not the critical power engineer designing the facility.

Tiers 2, 3, and 4: There has been a lot of press coverage on Tier 4 and its subsets Tier 4i (interim) and Tier 4f (final). The Tier 4 standards have had a huge impact on engine manufacturers because significant emissions reductions have been required to meet these standards. It is not uncommon for a large T4 stationary engine to cost 40% more than a similar power Tier 2 or Tier 3 engine because of the exten-sive emissions aftertreatment equipment that may be required. In addition, large stationary T4 gensets often require significantly more space allocation than Tier 2 or Tier 3 units.

The concept of EPA Tiers started in the early 1990s. The current level for new stationary

Bob Stelzer is the chief technical officer for Safety Power Inc., Mississauga, Ontario He leads the engineering team that developed the company’s ecoCUBE family of products, which has been configured for more than 40 engine types from most of the world’s major engine manufacturers. He is a mechanical engineer with a master’s degree in engineering.

Figure 2: The SCR system shown in the photo combines silencing and other emissions functions in a single cube mounted on a standby diesel genset enclosure. Courtesy: Safety Power Inc.

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nonemergency diesel engines exceeding 560 hp is Tier 4i, and by January 2015, Tier 4f will be in place for large stationary gensets. Under Tier 4, a large engine is considered to be one that exceeds 752 hp, whereas under RICE NESHAP, it is 500 hp. In general, EPA T4 standards target on-highway, off-road mobile sources and stationary nonemergency engine-driven generators. EPA T4 is not required for emergency gensets, but some engine vendors are advocating use of T4 engines to ensure there are no operating re-strictions beyond the current 100 hr maintenance and testing limit currently in place. If a new engine is not T4, it must have a permanent label indicating that it is for emergency use only. It is important to note that, in

-

-

T4 emergency engine used in a data center must shut down if the urea is unavailable. This is not a desirable situation for an emergency generator running during a long utility outage.

Technology to dealwith air emissions from diesel enginesFor large stationary diesel engines up to and including Tier 3, engine manufacturers have adopted many innovative technologies that typically focus on in-cylinder optimizations. Looking beyond Tier 3, much of the focus has been on exhaust aftertreatment technologies. For diesel engines, the most common aftertreatment emission control technologies are:

K Oxidation catalyst to deal with CO and un-burned hydrocarbons

K -ments

K Selective catalytic reduction (SCR) to meet NOX

requirements.

All diesel engines will also require some level of -

tion for large critical power facilities in nonattainment areas is to use Tier 2 for engines exceeding 752 hp and Tier 3 for engines less than 752 hp in combina-tion with an SCR and silencing.

Oxidation catalysts and PM filtersFor diesel engines, oxidation catalysts are often

by applying the catalysts, which are usually platinum-

approach is to have separate oxidation catalysts up-

creates heat by oxidizing unburned hydrocarbons and shifts NO, creating a favorable environment for the

SCRSCR works by injecting a reductant, usually a 32.5% concentration of urea into the exhaust stream. The urea is converted into ammonia (NH3) in the hot exhaust stream. In the presence of a catalyst, the NH3 combines with the NOX in the exhaust to produce harmless water vapor and nitrogen. Many SCR systems can achieve NOX reductions of 95% or more. Some exhaust aftertreatment vendors offer multifunction systems that combine SCR, silencing,

impacting the size of the emissions unit and the sur-rounding piping should it be required for the air permit (see Figure 2).

Engineering challenges

compliance challenges because of the regulatory envi-ronment. These challenges are compounded if the

is done. A change in air shed location could lead to a -

lation. A change in emissions mitigation requirements

space required for various aftertreatment devices.Until recently, aftertreatment was done using

separate devices for each emissions function. The physical space required for the devices and the com-plex piping and expansion joints required between them makes this arrangement a large and overly complex system.

Some vendors now offer exhaust aftertreatment systems that combine all required functions in a single cube. These multifunction systems can contain any combination of SCR, silencing, oxidation catalyst, and

Final considerationsThe regulatory requirements for obtaining an air permit for large scale critical power facilities using station-ary diesel engines is continuing to become more complex. It is important for critical power engineers to understand the overall regulatory framework and build

requirements for an air permit can be met.

The criticalpower engineerfaces significantair compliancechallengesbecause ofthe regulatoryenvironment.

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When examining the key differences be-tween resistive and resistive/reactive load testing—and why the latter is necessary—

it is important to focus on addressing a facility’s emergency power generation system as a whole by testing the entire system to identify system-wide

weaknesses at the time of commissioning and at periodic test intervals to comply with regu-

latory agencies (see Figure 1).Reactive load testing is primar-

ily important at health care facilities, data centers, life safety, and mission critical applications where the need to demonstrate the capability to provide electrical power as intended is prescribed by regulatory standards and codes specified by the design-

ers. Examples of typical emergency power sources include gas- and diesel-

fueled reciprocating engine generators, liquid- and gas-fueled turbine generators,

rotary UPS, and battery UPS systems.

Understanding the standards for certificationWhile understanding the key benefits of reactive load testing is not necessarily a primary focus, it is important for consulting engineers and facility managers to understand the specific code require-ments for installation, performance, and testing of emergency power systems.

The National Fire Protection Association (NFPA) publishes and updates these standards on a regular basis with input provided by profes-sionals, engineers, and members of industries that provide related equipment and services. Applicable

NFPA resources include:J NFPA 101: Life Safety Code (2012)J NFPA 99: Health Care Facilities Code (2012)J NFPA 110: Standard for Emergency

and Standby Power Systems (2013)J NFPA 37: Standards for the Installation

and Use of Stationary Combustion Engines and Turbines (2010)

J NFPA 70: National Electrical Code (2011)J NFPA 70B: Recommended Practice for

Electrical Equipment Maintenance (2010)J Joint Commissions (formerly JCAHO).Specific regulations such as NFPA 101, Article

7.9.2.4 require that emergency generators be in-stalled, tested, and maintained in accordance with NFPA 110. Provisions dealing with maintenance and testing of emergency generators can be found in NFPA99, Article 4.4, which deals with issues such as:

J Test criteriaJ Test conditionsJ Test personnelJ Maintaining and testing circuitryJ Battery maintenance.Specifying engineers and facility managers

should have access to the latest versions of these NFPA standards. They are available online at www.nfpacatalog.org. Individual states and locali-ties also have standards, codes, and regulations pertaining to mission critical facilities.

Key reason for load testingTypically, gensets seldom run under full-load conditions after the manufacturer’s factory test-ing. Although they may be tested in compliance

Commissioning, testing gensets using resistive/reactive load banksConsulting engineers can help their clients by conveying to them the

importance of including reactive load bank testing during commissioning

and periodically during normal operations.

By HPS Loadbanks, San Diego

Figure 1: Reactive load test-ing should be performed on gensets at mission critical facilities to identify system-wide weaknesses during commissioning and at periodic test intervals. Courtesy: HPS Loadbanks

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13N o v e m b e r 2 0 1 3 1313N o v e m b e r 2 0 1 3 13

with the regulatory requirements that permit the use of actual loads, over time, this practice can lead to conditions that could affect performance and reliability. Modern diesel gensets designed to meet the stringent U.S. Environmental Protection Agency (EPA) Tier Level emission standards are designed to be operated at loads of more than 50% for optimum life and performance. In addition, the use of after-treatment particulate matter filters that depend on a certain exhaust temperature to facilitate regeneration can be compromised by low-load operation, and consequently can restrict exhaust gas flow due to buildup, causing higher than recommended exhaust back pressure, which can limit the performance of a reciprocating engine genset and/or increase the need for unscheduled maintenance.

When multiple units are installed, they are often run individually for periodic and annual test-ing using a test load much less than the manu-facturer’s recommended levels. The use of a large capacity resistive/reactive load bank can allow testing of multiple units simultaneously, thus re-ducing the time required to perform and document mandatory testing. Resistive/reactive load banks allow the paralleling controls to be exercised under realistic conditions.

Again, load bank testing is a critical compo-nent to meeting regulatory requirements. Today’s diesel gensets that use electronic engine and emission controls to meet current and future EPA emission requirements depend on the engines op-erating at the manufacturer’s recommended load levels and temperatures.

NFPA testing guidelines refer to minimum load levels of 30%, or as recommended by the manufacturer. Industry associations such as EGSA and the major engine-generator manufacturers recommend load testing at higher levels to ensure that the maximum benefits of load testing can be achieved.

As with regular maintenance, periodic testing is required by code in all health care applications to maintain compliance with the regulatory agency. It is common for health care facilities to perform regular genset testing during off-peak times when loads are at their lowest. While this practice pre-vents the possibility of serious interruptions to large and/or critical loads, it does not adequately test the genset under worst-case conditions.

The case for reactive load bank testingThe ability to simulate varying reactive loads, which

are more realistic, is the most essential benefit for a load bank that provides both kVA (resistive) and kVAR (reactive) loads. The critical differences between testing with a resistive-only load bank and a resistive/reactive load bank are compared in Table 1. A resistive-only load bank can provide adequate testing of the individual prime mover and load sharing (including load add/load shed) controls of a multiple unit facility. However, a reac-tive load bank allows testing of the alternator, load sharing, and transient responses because it can apply loads that approach those experienced dur-ing normal genset operation.

Genset engine governors respond to loads by reducing engine speed. Figure 2 compares the transient response for a large diesel standby genset when applying a block load using restive-only and resistive/reactive load banks. The result-ing initial synchronous voltage dip (Vdip1) using the 75% load at 0.80 power factor results in a voltage dip that is approximately 25% greater when com-pared to the equivalent resistive-only load applica-

TABLE 1: REsisTivE-onLy And REsisTivE/REAcTivE LoAd BAnk TEsTing compARison

Resistive load bank testingkW = kVA at unity power factor

Resistive/reactive load bank testingReactive power component

Characteristics Tests the prime mover (engine) at 100% load

Tests the alternator and voltage regula-tor at its fully rated (kVA/kVAR) capacity

Tests the fuel delivery system operation at maximum rating and fuel consumption

Simulates the actual load (kW, kVA, and kVAR) for which the systems are speci-fied and designed

Demonstrates the cooling system operation at the genset’s full operating capacity

Simulates transient loads to provide voltage and frequency response characteristics

Allows the exhaust and after-treatment system to reach normal operating temperatures

Simulates and verifies synchronizing, load sharing, and voltage regulation on multiple-unit paralleled systems under actual load conditions

Eliminates exhaust wet-stacking by burning off built-up carbon deposits from unburned fuel and oil, and reseats the rings when partial- or low-load conditions are encountered during periodic testing

Allows thermographic/infrared inspection of the electrical systems; identification of potential hot spots; and the condition of cables, terminations, and buss work

Evaporates moisture from the engine oil, which reduces wear-causing acid formation

Identifies deficiencies that can be corrected with proper maintenance and repair before failure, avoiding down-time and additional expenses

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N O V E M B E R 2 0 1 314

tions. The engine speed related voltage dip (Vdip2) is similar, in both cases, due to the manufacturer’s standard V/Hz-type voltage regulator.

During testing with a resistive-only load bank, a system that is sensitive to transient voltage dips would not necessarily provide an indication of a power supply or system condition that would lead to a potential problem during operation. Solid-state controls and power supplies are particularly sensi-tive to transients and can shut down unexpectedly

with a dedicated power source capable of riding through the voltage and frequency tran-

sients associated with block loading of the gensets.

When testing multiple unit generator systems, the ability to share reactive loads (kVAR) equally is critical to achieving the maximum-rated power

system output. When load sharing controls are not properly

current compensation, and measurement and control device polarities), resistive-only testing can fail to determine how the reactive load is ac-cepted by an individual generator. In addition, the paralleling switchgear and protective relays may perform adequately under resistive load applica-tions, but the reactive load bank testing will provide load acceptance and rejection that simulates real-world conditions more closely.

Choosing the right resistive/reactive load bankWhen selecting a resistive/reactive load bank it is important to consider key features including ease of operation, onboard diagnostics, metering, the ability for an operator to control multiple units from a single controller, and data download capabilities. Load banks offering automatic step loading and duration, and data collection and reporting capa-

records to demonstrate compliance with the facility and regulatory requirements.

Connecting load banks to a facility normally involves temporarily connecting the 3-phase power conductors to the load bus. Electrical testing and load bank rental companies can supply the necessary load banks, transformers, and cables to provide the correct service voltage for the equip-ment being tested.

The proof is in the testingSpecifying engineers can and should promote re-active load bank testing because it is the best way to test the entire system to identify system-wide weaknesses during commissioning and at periodic test intervals to be in compliance with the regula-tory agencies. Without proof of testing, the design remains hypothetical. Testing systems with the correct size and type of resistive/reactive load bank validates the power generation system design.

For existing installations, proper reactive load bank testing provides real-time data and factual evidence of reliability, functionality, and reduc-tion of capacity resulting from aged equipment. Additionally, reactive load bank testing provides a best-case simulated real-world condition where voltage-drop, thermal heating, harmonics, and ef-

a resistive load only.Full system integration testing of critical sys-

tems during commissioning establishes an accu-rate baseline for ongoing operational performance and is a valuable tool in providing a higher level of

Figure 2: This graph compares the transientresponse for a large diesel standby genset whenapplying a block load using restive-only andresistive/reactive load banks. Courtesy: HPSLoadbanks (Data source: Caterpillar EngineSizer program)

Without proof oftesting, the designremains hypothetical.

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N O V E M B E R 2 0 1 316

When Mark Twain said, “The trouble with the world is not that people know too little, but that they know so many things

the need for continuing education, but he might as well have been. Those who make their living providing engineering expertise to others have worked hard to ensure that they know the right answer, so they can provide the best possible guidance to their customers.

Good news, bad newsCustomer expectations can shift slightly and sometimes dramatically in response to new in-novations and changing market conditions. Not knowing the new rules can result in an engineer failing to maximize the value proposition with his or her customers. These realities are compounded by ever-changing codes, which always bring the real risk that an uninformed design choice will result in compliance issues with the authority having jurisdiction.

The good news is that whether an engineer is new to the power generator space and needs to quickly get up to speed, or a savvy veteran who just wants to make sure he or she is at the top of the game, there are continuing education classes

available to help provide the best answers to the tough questions. Knowledge truly is power when designing standby power solutions.

More choices = better choicesIncorporating the unique requirements of a standby generation solution into various types of applica-tions can be challenging. Matching customer expectations for performance, reliability, growth, and sustainable environmental responsibility can create multiple competing design requirements. This is where having options becomes essential to success. Only when an engineer has a complete understanding of the breadth of available technolo-gies and best application practices can he or she achieve optimal solutions.

New technologies = new possibilitiesToday, the standby generator industry is innovat-ing to achieve new possibilities for customers. The major manufacturers have reconsidered how they provide simple, high value, and redundant standby power solutions. These solutions have created a new set of customer expectations for reliability and scalability. Natural gas exploration technology has fundamentally changed the supply and pricing of this fuel, triggering a corresponding

By Michael Kirchner,Generac Power Systems,

Waukesha, Wis.

In addition to hosting an annualpower generation conference,Generac offers courses withCEU/PDH credits and the back-ing of the Milwaukee School ofEngineering. Courtesy: GeneracPower Systems

Knowledge is power

when designing

standby power

systems.

Continuing standbypower education

17N O V E M B E R 2 0 1 3 17

rise in customer expectations on how best to use low-cost, clean-burning natural gas generators. In response, manufacturers have innovated new solutions, such as bifuel, that combine natural gas into traditional diesel engines, as well as new approaches to maximize the power density and lower the cost of natural gas gensets.

Now more than everWhile standby generators are not automatically part of every project, they are inarguably becom-ing more important due to the ever-increasing demands placed on our antiquated power grid. Americans are using 400% more electricity now than they were in 1990, and each home uses seven times more power than the average home in 1950. What once was a practical option for some has rapidly become an absolute neces-sity for many. These realities are causing standby power to expand into new market segments at an increasing rate.

What I learned in school todayA recent poll of attendees of Generac’s Engineering Power Symposium this year asked the engineers to share the most important thing they learned there. Their answers are provided in the following paragraphs and may help you create a road-map for ongoing continuing education relative to standby power generation.

Generator sizing: Proper sizing of generators was one of the biggest concerns. Today’s market constantly uses more power electronic devices that make sizing generators more challenging. Predict-ing the impact of VFDs, soft starters, UPSs, and other harmonically challenging devices on standby generators is an exercise in harmonic analysis with which most general consulting engineers are not familiar. When these challenges are combined with the transient effects of across-the-line motor start-ing, it’s no surprise that many system designers are looking for more sizing information and best in-class analytical tools. These concerns should be addressed by obtaining detailed training on these vital issues and comprehensive transient and harmonic analysis tools. If, through continuing education, a misapplication can be avoided, the education was well worth the time invested.

Code requirements: Code requirements were, unsurprisingly, also a topic of high interest.

The National Electrical Code was never written with on-site power generation as a particular focus, which can lead to confusion. NEC issues prompted several engag-ing discussions on requirements for disconnects on incoming generator feeders, separation of circuits, reliability of fuel, equip-ment installation locations, and

Code compliance can be an exercise in detailed investigation while trying to avoid the land-mines of interpretation and local norms. Having a deeper under-standing of how the code works as a whole to address the correct implementation of on-site power is key. It is also essential to understand what causes confusion in the code, resulting in different interpretations and local market norms.

Paralleled power generation: Paralleled

scalability that it offers is another area of keen interest. Changes in technology continue to bring integrated paralleling solutions into all applica-tions. Most engineers don’t have much experience with the basic concepts of synchronization, real and reactive power balancing, and how these are achieved within traditional and integrated solutions. Only through a thorough understanding of the concepts and various implementation technologies can an engineer achieve an optimized solution to meet the unique requirements of each application.

Never stop learningThere is a balance between occupying your professional comfort level and keeping your skills fresh by stretching out and continuing your education. Luckily, there are a number of avenues available to pursue that education, many of them at a low cost or even free.

Because this article started with a quote from Mark Twain, it is only appropriate that he should have the last word: “Anyone who stops learning is old, whether 20 or 80. Anyone who keeps learning stays young. The greatest thing you can do is keep your mind young.”

Who are we to argue with Mark Twain?

Michael Kirchner is technicalsupport manager for GeneracPower Systems, Waukesha,Wis., where he supportsand trains on all industrialproducts. He has a BSEE andan MBA from the Universityof Wisconsin. He has beenwith Generac Power Systemssince 1999.

Not knowing the newrules can result inan engineer failing tomaximize the valueproposition with hisor her customers.

N o v e m b e r 2 0 1 318

A funny thing happened on the way to the forum for better power reliability: monitoring and controlling that power started taking

center stage.Reliability-based design, reliability-centered

maintenance, and failure prevention depend on gathering, analyzing, and acting on data from criti-cal power generation and distribution components and systems. Everyone involved in designing, constructing, commissioning, and maintaining a building—consulting engineers, contractors, and building owners/managers—has a stake in opti-mizing power system monitoring and control. They all win when it works; they all lose when it doesn’t.

Data center and health care facility executives, especially, crave more power control informa-tion. One reason is that power systems are more complex and sophisticated than ever, and could

mean the difference between life and death to an organization’s operations. For example, data cen-ter downtime costs business more than $5,000/min, according to a 2011 Ponemon Institute study of U.S.-based data centers. With an average reported incident length of 90 min, that’s nearly $500,000 on the line—or off the bottom line.

Complex power systems are vulnerable to problems that can undermine the very power reli-ability they’re designed to provide. Sophisticated power monitoring and control technologies help ferret out potential problems and provide a raft of benefits that can extend throughout an organiza-tion (see Figure 1). The starting point for evaluat-ing and selecting power monitoring and control technologies is for the facility executive to pinpoint information needs and thoroughly understand the business’s operational processes.

The monitoring and control technologies that are usually considered are legacy supervisory control and data acquisition (SCADA) systems and building management systems (BMS). The two new technologies are data center infrastructure management (DCIM) systems and critical power management systems (CPMS). The first three are overarching technologies. They aim to monitor and control an entire facility or campus, including criti-cal power. The fourth dedicates itself to controlling only critical power generation and distribution systems.

These four technologies have similarities and differences that are important to consulting engineers, contractors, building owners, and facil-ity executives (see Table 1). This article describes each technology, highlights its capabilities and limitations, and suggests which system may be best suited for a given application.

Selecting a critical power monitoring and control technology Choosing a monitoring and control technology should be based

on the power reliability requirements for the application.

By Bhavesh S. Patel, ASCO Power Technologies,

Florham Park, N.J.

Figure 1: Sophisticated power monitoring and control technologies help reveal potential problems and provide a plethora of benefits that can extend throughout an orga-nization. All graphics courtesy: ASCO Power Technologies

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19N o v e m b e r 2 0 1 3 19

SCADATechnically, all systems designed to monitor and control business operations and processes are SCADA systems. This article addresses legacy SCADA systems meant for a variety of industrial, commercial, and institutional applications. Tele-communications, power utilities, water and waste control, energy, oil and gas refining, and transpor-tation have historically applied SCADA.

SCADA systems help improve efficiency and operational reliability, and lower costs, thus increasing profitability of operations and pro-cesses and enhancing worker safety. Best-in-class SCADA provides alarm handling, trending, diagnostics, maintenance scheduling, logistics, and other benefits. For alarm handling, though, a cascade of quick alarm events could mask the underlying causes of trouble.

Third-generation SCADA systems include a computer and open, or off-the-shelf, system architecture that acquires data from and sends commands to monitored equipment, a human-machine interface (usually a computer monitor screen), a networked communication infrastruc-ture, sensors and control relays, remote terminals units (RTUs), and programmable logic controllers (PLCs). Note that the range of available RTUs and PLCs require careful consideration to ensure the classes of equipment selected will provide needed scalability, optimize functionality, and prove most cost effective for a given SCADA application.

Standard protocols and Internet accessibility of networked SCADA systems make the systems susceptible to remote attack. In April 2008, the Commission to Assess the Threat to the United States from Electromagnetic Pulse (EMP) At-tack issued a Critical Infrastructures Report that concluded: “SCADA systems are vulnerable to EMP insult. The large numbers and widespread reliance on such systems by all of the Nation’s critical infrastructures represent a systemic threat to their continued operation following an EMP event. Additionally, the necessity to reboot, repair, or replace large numbers of geographically widely dispersed systems will considerably impede the Nation’s recovery from such an assault.”

Additionally, in June 2010, an antivirus security company reported the first detection of the Stuxnet malware, which attacks SCADA systems run-ning on Windows operating systems. SCADA and control product vendors have developed special-ized industrial firewalls and virtual private network products for TCP/IP-based SCADA networks.

BMSA BMS controls, monitors, optimizes, and reports on mechanical and electrical equipment such as air handling and cooling, lighting, power, fire, and security systems. BMS comprises software and hardware similar to that of SCADA. Software can be either proprietary, using protocols such as C-bus or Profibus, or open architecture that inte-grates Internet protocols and open standards such as XML, BACnet, LonWorks, and Modbus. Basic controls include manual switching, time clocks, or temperature switches that provide the on and off signals for enabling pumps, fans, or valves.

Unlike other monitoring and controls systems, BMS enables two-way communication between building and property managers and their employ-ees, tenants, or residents. This two-way commu-nication feature is a valued capability for hospitals and office buildings because both types of facilities must maintain a comfortable environment, and in the process, save energy. Systems linked to a BMS typically represent 70% of a building’s energy usage, including lighting. The BMS also track and schedule building maintenance. For example, the Bryan Medical Center East Campus in Lincoln, Neb., uses a BMS to maintain temperature and other environmental conditions for patients, visi-tors, and staff.

A BMS can also play a role in protecting the critical power system. Geisinger Medical Center in Danville, Pa., monitors crucial power generators through both its BMS and its security system. “We are monitoring emergency power at both loca-tions 24 hr daily,” said Al Neuner, Geisinger’s vice

Bhavesh S. Patel is director of marketing and customer support at ASCO Power Technologies, a business unit of Emerson Network Power. He is an accomplished public speaker with expertise in power system markets and has delivered presentations at NFMT, PowerGen, and ASHE. He has written many articles about power reliability and quality, and has hosted roundtable discussions of industry stakeholders to continue surfacing issues that help to improve power reliability.

TABle 1: Power SySTeM MAnAgeMenT MoniToring AnD ConTrol TeChnology CoMPAriSon

SCADA BMS DCIM CPMS

Feature

Facility-wide Critical-power specific Data center centric Open architecture Proprietary / semi-proprietary architecture Cross-compatibility Extremely fast data capture Highly secure Sophisticated power analytics / diagnostics Power compliance reporting

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N o v e m b e r 2 0 1 320

president of facilities operations. “So, if one misses the alarm, the other location will catch it before we experience power problems.”

However, some say the functionality offered by a legacy BMS does not include the software tools needed to manage mission critical operations and processes. More than basic alarm and control no-tification are required. In addition, a BMS may not distinguish between critical and noncritical monitor-ing. The same technology manages temperatures of offices as well as data center hot aisles.

Also, data transfer between critical power equipment occurs at speeds and bandwidths that could incapacitate most BMSs. Power quality data, such as waveform capture and transient harmonic displays, are cases in point.

A BMS needs to be sophisticated enough to import crucial operational data from power controls. “The building automation system should allow a one-line diagram of the emergency backup power system,” said Robert McCarthy, senior as-sociate with Environmental Systems Design.

DCiMTechnology research firm Gartner defines data center infrastructure management (DCIM) as “tools that monitor, measure, manage, and/or control data center use and energy consumption of all IT-related equipment (such as servers, storage, and network switches), and facilities infrastructure components (such as power distribution units and computer room air conditioners).” Said another way, it manages energy, assets, availability, risk, services, the supply chain, and IT automation by

acquiring data using simple network management pro-tocol, BACnet, or Modbus.

As the relatively new monitoring and control technology continues evolv-ing, it seems the larger the data center, the greater the need for DCIM. Well-known Internet service provid-ers, search engine entities, and upcoming enterprise computing centers have particular need for the specialized capabilities of DCIMs. As a system, DCIM can encompass specialized 3-D visualization software,

hardware, and sensors to monitor and control all IT and facility infrastructure equipment in real time. It automates three primary functions: data collection, infrastructure modeling, and analytical reporting.

The primary DCIM drivers are:K Greater power and heat densitiesK Growing virtualization and cloud computingK Increasing dependence on critical IT systemsK Increasing demand for energy efficiencyK Pursuit of green IT initiatives.

At its best, DCIM produces improved uptime, efficient capacity planning and management, valu-able business analytics, and deeper process and change management. However, the relationship between IT and facility infrastructure management, and the equipment they manage, must continue evolving to realize its promise.

As with BMS, DCIM systems need to be sophisticated enough to import crucial operational data from power controls to effectively monitor and control critical power systems.

According to 451 Research, “DCIM systems today mostly look at the present status of the data center for the purpose of improving operational efficiency and availability. But data center manag-ers must also look forward—some of their biggest challenges are in avoiding huge cost overruns by over-provisioning and avoiding becoming con-strained operationally by a shortage of power, cooling, or space.”

CPMSCompared to legacy SCADA and BMS, and emerging DCIM, monitoring and control capabili-

Figure 2: Sophisticated high-speed power controls can provide a significant amount of electrical system data and share them with other devices without disrupting other facility functions.

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Other opportunities to connectWhile our print magazines remain the touchpoint for more than 200,000 qualifi ed subscribers each month, we also recognize that there are so many other opportunities each day to reach busy end users. That’s why we’ve developed a wide range of ways to connect with our audience:

• Webcasts

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• An expanding global video library

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Our goal?To give you the knowledge you need, when you need it, in the format you want it, delivered to the device you’re using, with the ability to utilize that knowledge to do your job better.

CFE Media1111 W. 22nd StreetOak Brook, IL 60523630-571-4070

www.cfemedia.com





You take pride in your profession — one of acquiring and applying design and build structures, machines, devices, systems, materials and processes that safely realize a solution to the needs of society.

And, to do your job better each day, you need a trusted source of information: CFE Media – Content For Engineers.

CFE Media strives to...• Inspire engineers to interact, respond to peers, and contribute to content that will assist other engineers with similar challenges.

• Develop an infrastructure that aligns, organizes and maps content to audiences specialized needs and business opportunities.

• Fully understand our audience and its changing needs for targeted information and delivery channels through the use of industry experts and leaders.

CFE Media is home to three of the most trusted names in the business: Consulting-Specifying Engineer — provides the latest knowledge on commercial and institutional facility construction and management. Visit www.csemag.com

Control Engineering — delivers a wide array of strategies and solutions to help control system designers create a more effi cient process. Visit www.controleng.com

Plant Engineering — delivers plant-fl oor knowledge and expertise to help manufacturers operate smarter, safer and more effi ciently. Visit www.plantengineering.com

N o v e m b e r 2 0 1 322

ties of CPMSs are apples to their oranges. Rather than being all things to all infrastructure systems, CPMS monitoring and controls are dedicated to managing critical power generation and distribu-tion. These high-end power controls are proprie-tary or semiproprietary solutions, running on either a shared or a dedicated backbone.

They typically work in tandem with a SCADA, BMS, or DCIM, providing the needed sophisti-cation, speed, and analytics specific to power generation and distribution. Bryan Medical Center depends on the seamless exchange of information between its CPMS and BMS.

CPMSs typically oversee gensets, circuit breakers, transfer switches, bus bar, paralleling control switchgear, UPSs, and other critical power distribution equipment. They watch normal and emergency voltages and frequency, and indicate transfer switch position, source availability, normal and emergency voltage and frequency, current, power, and power factor. They also display trans-fer switch event logs, time-delay settings, rating, and identification. They facilitate critical power system load management, bus bar optimization, testing, maintenance, reporting, trending, and analytics. They ensure power reliability during surges, sags, and outages.

CPMS reporting capabilities help health care facilities comply with NFPA 70, NFPA 99, and NFPA 110 requirements for hospitals, as well as joint commission reporting requirements for maintaining accreditation. A dedicated and fully integrated power monitoring system helps data

centers and telecommunica-tions sites satisfy National Electrical Code requirements and EN50160 Power Quality Compliance.

Sophisticated power controls operate at extremely high speed (in milliseconds) and cache or share volumi-nous data from one device to the next without disrupting other building functions (see Figure 2).

“When you are doing forensics, you need fast and accurate time marks to track down where things went wrong,” said Morris Toporek, senior vice president for Envi-

ronmental Systems Design.Northwestern Memorial Hospital’s Prentice

Women’s Hospital in Chicago accomplishes data transfer with a self-sustaining, isolated network that includes a self-healing Ethernet dual fiber optic ring. “Self-healing means that communication hap-pens both ways on both rings,” said Junnaid Malik, electrical engineer with Cosentini Associates mis-sion critical group. “One ring could be physically cut and the system could still communicate.”

Power quality analysis is the leading edge of power control technology (see Figure 3). It is very different from traditional monitoring. Analytics look at power harmonics and high-speed transients, and can be used for trending and predicting growth.

In terms of security, some CPMSs are pro-tected with the same 128-bit encryption technol-ogy used by NASA.

Deciding which of these monitoring and control technologies is optimal depends on the application for which it is intended. The decision should be based on the importance of power reliability for a given set of operations or pro-cesses. If reliable power isn’t absolutely critical, a SCADA system or BMS might be appropriate. If a holistic view of a data center’s IT and facility infrastructure is a high priority, DCIM might be the logical choice. However, when the stakes are high for maintaining critical power, consider the special-ized capabilities of CPMS monitoring and control that can also work alongside the other monitoring and control technologies.

Figure 3: In addition to active power, voltage, and current, analytics can monitor power har-monics and high-speed transients, and can be used for power system trending and predicting growth.

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23N o v e m b e r 2 0 1 3 23

Combined heat and power (CHP) involves the production of heat and electric power from a single energy source, usually natural gas,

but other forms of methane-based fuel are also used. The business can be divided into four market clusters, each of which has unique features: natural gas CHP, biogas, landfill and wastewater treat-ment, and natural gas non-CHP. While certain nu-ances are associated with each of these clusters, a common analysis exists for all CHP market clusters (see “CHP market clusters”).

Generally, the best applications are those that use electricity and heat simultaneously, operate for more than 4,000 hr/yr, and have a suitable gaseous fuel supply (see Figure 1). However, some applications that need only electricity, such as landfills and wastewater treatment facilities, are also well suited for the technology because the fuel source is virtually free. Electricity rates between $0.07/kWh and $0.10/kWh provide for a positive influence on most projects depending on the price

of gas. However, each project must be evaluated and validated (see “Project evaluation, validation”).

The final decision of whether an applica-tion is good almost always starts with a financial analysis. The analysis consists of two parts: procurement, installation, and construction costs; and operating and maintenance costs. The first part—procurement, installation, and construction costs—consists of an analysis of capital expen-ditures, depreciation, and taxes. The second part—operating and maintenance costs—consists of fuel consumption, and preventive, scheduled, and corrective maintenance compared to the cur-rent (or projected) cost of electricity and heat. The analysis results in a return on investment, which provides the net cash flow to the initial investment over a number of years. This analysis ultimately helps determine the financial viability of the project. Of course, influences other than financial, such as environmental impact, may factor into determining the viability of a project.

By Christian Mueller and George Polson, MTU Onsite Energy

Figure 1: Modern CHP modules can provide economic benefits and long-term return on investment, and reduce environmental impact. Courtesy: MTU Onsite Energy

Modern CHP modules can increase a facility’s energy efficiency, reduce

environmental impact, and contribute to corporate sustainability.

Analyzing CHP installation validity

creo

Calculating payback

CHP unit of 358 kW (electrical) and 1.771 kBtu/hr (thermal) will meet the requirements of a facility.

The facility currently has a boiler that -

cy of 80%. Electricity costs $0.10/kWh and natural gas

costs $6.00/MMBtu. The unit is expected to oper-ate 8,000 hr/yr.

Armed with usage and cost information, facility

owners can take advantage of computerized payback calculators

typically offered by CHP module manufacturers.

module recommendations to calculate the time pe-riod required for the facility to earn back its system investment in operating cost savings.

The cost of the CHP module and average an-nual operating cost calculations should include fuel and maintenance costs. Annual savings in gas and electricity by avoiding purchasing electricity from the utility and burning gas in a boiler should also be included. Based on the aforementioned criteria, the example facility could achieve annual net savings of more than $180,000 by using a CHP system.

could be expected and indicates a break-even

CHP market clusters

The following paragraphs explain each cluster.

Natural gas CHP:This business cluster represents applications such as commer-cial buildings, industrial facilities, healthcare facilities, district heating, prisons, hotels, con-dominiums, apartments, and universities. The cluster also includes commercial complexes such as athletic clubs, shopping malls, and greenhouses. These

round demand for cooling/heat-ing and electricity. Sizing of the installation is critical to allow for

analysis is needed, the unique requirements of this cluster include:

K Electrical and thermal loads of the facility—ide-ally by the hour based on historical data

K Type of thermal load such as hot water, steam, or

pressure, and tempera-tures

K The piping and instru-mentation diagram of the facility’s existing thermal distribution system.

Biogas:This business cluster represents applications that use anaerobic digesters to produce biogas from dairy, livestock, and food waste. The focus is to provide energy from waste products. The emphasis is to reduce the amount of methane that escapes to the atmosphere because methane is a far worse greenhouse gas than CO2.Electricity is the main energy produced in this application—either for self-consumption or to feed to the grid. Biogas quality is critical to long unit life as sulfur (H2S) content in the fuel must be minimized. Unique requirements of this cluster include:

K Consistency of waste stream and therefore consistency of gas quality

K Thermal demand for heat-ing of digester and facility

K Gas analysis show-ing methane and H2Scontent.

wastewater treatment:This business cluster repre-sents a specialty segment that focuses on converting waste to energy to produce electricity for self-consumption or to feed to the grid. Gas quality is critical because the content of the raw material used to produce the gas may change continually. Gas composition must be moni-tored continuously for methane and siloxane content to provide quality gas for the module. Spe-

include:KKK

K Gas analysis showing methane and siloxane content.

Natural gas non-CHP:This business cluster focuses on electrical production only. Typical applications include peaking plants, independent power producers, industrial facilities, and any other require-ment for electric power genera-tion. These applications provide independence from the grid.

lifecycle cost are critical. The mode of operation can be either grid parallel and/or island. For island operation, the character-istics of the connected electrical loads must be analyzed. These characteristics include:

K Description of connected loads in island operation

K Connected load starting sequence.

N O V E M B E R 2 0 1 324

For island operation,the characteristics of theconnected electrical loadsmust be analyzed.

point after 2.5 yr. Thereafter, savings continue to accumulate. After 10 yr, cumulative positive cash

Final analysisCurrent reciprocating engine CHP modules have made it possible for many facilities to reap the en-

-

system.

Christian Mueller is a sales engineer at TognumAmerica Inc./MTU Onsite Energy. He began hiscareer with the company in Australia in 2007and later moved to the company headquarters inAugsburg, Germany. Mueller provides engineeringsupport to the sales organization for customer-specific CHP installations. Since 2012, he hassupported the MTU Onsite Energy CHP productportfolio in North America as a sales engineer basedin Houston. Mueller has a diploma in industrialengineering with an emphasis in energy systems.

George Polson is a consultant for Tognum AmericaInc./MTU Onsite Energy where he co-leads theteam to release continuous gas CHP products intoNorth America. He retired from MTU Detroit Dieselas director of Sales Integration in 2009 after 40years of service with the company. Polson beganhis career at Detroit Diesel conducting emissioncertification testing in the early days of the U.S.Environmental Protection Agency program. Hewas also involved in product development, facilityplanning, application engineering, and programmanagement. He spent more than 15 yearssupporting the off-highway business involved inengineering, customer support, and sales. Polson isa graduate mechanical engineer.

25N O V E M B E R 2 0 1 3 25

Project evaluation, validation

of the opportunity. An early, yet thorough, understanding will pay dividends as the

1 What is the type of installation: power generation, CHP, or tri-generation?2 What is the local cost of gas and electricity?3 What voltage is required?4

5 Do heat and electrical demand curves exist?6

7

8 What are the room dimensions?9 Will the installation be exposed to weather elements?J What are the sound/noise requirements?K

L What are the local exhaust/emission requirements/restrictions?M What are the site conditions?N What ancillary equipment will be required?O What is an estimate of the balance of plant?P

Q

R

S Has a consulting engineer and/or contractor been chosen?

Appropriate answers to these questions and an analysis of the heat and electri-

Figure 2: This graph indicates expected cumulative cash flow as well as a2.5-yr break-even point, after which savings continue to accumulate.Courtesy: MTU Onsite Energy

-$1 million

-$500,000

$0

$500,000

$1 million

$1.5 million

0 1 2 3 4 5 6 7 8 9 10

Project financial overview

Dolla

rs

Years of operationNo. of years in operation Net annual cash flow Cumulative cash flow

N O V E M B E R 2 0 1 326

Diesel generators are used for on-site power generation and mission critical operations. They are also used for standby power in

hospitals, airports, public safety complexes, and even nuclear power plants. In these locations, failure is not an option. However, many generator own-ers neglect a core component of genset reliability: maintenance.

Consulting engineers can do their clients a great service by encouraging them to incorporate formal, computer-aided generator maintenance programs into their projects at the outset and underscoring the importance of following them to the letter. Because

generators to maintain such programs in house, discussing generator maintenance services can

-

specialize in this important process.

Why maintenance is a problemWith generator maintenance, the old adage, “If it

generators in particular are such workhorses that it is easy for companies to let maintenance schedules slip or be reprioritized out of existence, especially in

levels. Generator operators with only one gen-erator—or even a few—don’t have the personnel to assign a generator maintenance manager to oversee maintenance efforts, so the task is added to someone else’s already long list of duties, with inattention being a predictable result.

Furthermore, companies with few generators may lack the technical skill to perform all mainte-nance routines correctly. For standby generators,

facility’s property, it’s often a simple case of out of sight, out of mind. Maintenance engineers have the best of intentions to get someone to crank the generator, perform fuel checks, and schedule necessary, periodic maintenance, but typically, it just doesn’t happen.

First step: automationAlthough no one has come up with a way to automate generator maintenance itself, consulting engineers can recommend that their clients do the next best thing: automate the management pro-cess. Most companies have or are planning to use some type of enterprise asset management (EAM) software/system to keep tabs on their equipment. Generators are, after all, an asset that needs to be managed, and many times they can be incorpo-rated into these systems. However, the EAM must support scheduling of events, and the company (or you, as their consultant) must establish a mainte-nance interval timeline with details on what opera-tions should be performed during each event.

The platform should also be able to generate advance alerts and work orders, as well as remind-ers that preferably cannot be overridden without management approval and will continue until the op-

the system can send alerts and reminders directly to the phones and PCs of those responsible for doing the work.

In this photo, main-tenance techniciansare performing atest on a generator.Courtesy: WorldwidePower ProductsConsulting engineers

are in an excellent

position to

recommend

structured

maintenance

programs to their

clients.

Structuredmaintenance

ensures gensetreliability

By Scott Spidle,Worldwide Power Products,

Houston

27N O V E M B E R 2 0 1 3 27

The platform should also support an interface

-form should be able to store historic data and then

-tions and out-of-range conditions that might point to

Depending on the client and chosen plat-form, these features may require custom coding

-

-

Reporting and auditing

-

-

accept all the data input by technicians during maintenance, but it should also be able generate

-

Using third-party maintenance

outsource at least their annual maintenance rou--

is mission critical often outsource all their generator

-mendations for parts that are nearing the end of

If your clients appear totally befuddled at the thought of implementing a technological solution to

-

Conclusion-

responsible for thousands, if not tens of thousands, of dollars in unnecessary repairs and part replace-

Scott Spidle is vice presidentof Rental and Service atWorldwide Power Productsin Houston, where heoversees the company’srental fleet and serviceteam. He has more than18 years of experience inoperations and management,specializing in developingand implementing operatingprocedures.

N o v e m b e r 2 0 1 328

The recently upgraded power system at Rex Hospital in Raleigh, N.C., which came online in spring of 2013, was designed to ensure

seamless delivery of normal and emergency power to the 660-bed facility. The hospital’s design team, led by Mike Raynor, director of facility and construc-tion services, envisioned a fail-safe emergency power system that would serve the facility’s electri-cal power needs for the next 30 years.

Raynor and his team designed the modernized system to provide the hospital with an emergency power system with more capacity, reliability, redun-dancy, and flexibility than the system it replaced, which was installed in the mid-1980s. The design team chose Russelectric Inc., Hingham, Mass., to supply power control switchgear, transfer switches, the SCADA system, design assistance, and imple-mentation support.

Upgrade detailsRex Hospital’s emergency power system upgrade included replacing three 1.25 MW generators with two new 4,160-V, 1,800 rpm, 3.0 MW units (0.8 power factor). An existing 2.25 MW generator that matches the operating voltage of the new units was retained. The generators are capable of paralleling with each other as well as with the utility source.

The hospital’s previous backup power system was the closed-transition type. The upgraded system retained that configuration because no one wanted a service interruption when the feed switches from utility power to generator power (when both sources are available). The existing utility substation at the hospital was replaced, and new switches and switchgear were relocated from cramped quarters in the main hospital building to a newly constructed central energy plant. Another automatic transfer switch was added to protect the hospital’s data center. When the generators are up to speed, an outdoor switchgear arrangement fed by the utility’s outdoor transformers allows the hos-

pital to disconnect from the utility either manually or automatically.

Whereas the previous system’s fuel capacity was 60,000 gal, the new system has two 40,000-gal underground fuel tanks. Also, the system main-tains fuel in each generator’s emergency 150-gal day tank at all times. With all tanks full, the hospital could meet its peak demand of about 5,200 kW for almost six days. However, because that peak is reached only for short periods on warm summer days, and peak demand during winter doesn’t ex-ceed 4,500 kW, the hospital could probably oper-ate under its own power for more than nine days.

The hospital’s emergency power system em-ploys a both-sides-hot strategy, which feeds utility power to both sides (normal and emergency) of every automatic transfer switch. If any downstream feed is lost, a breaker trips, immediately transferring power to the other side of the switch with minimal interruption and without starting the generators. This strategy also allows the power plant staff to test transfer switches with no interruption and with-out starting the generators.

Upgrade resultsPresently, the hospital’s peak-demand load is about 5,200 kW. However, taking its anticipated growth into account, its power system now has enough emergency capacity (8.25 MW) for a seven-story heart center currently on the drawing board as well as a future cancer center addition. With this N+1 strategy, the facility could lose—or take out of ser-vice—any single generator and still have adequate capacity.

Regular equipment testing occurs with no inter-ruptions or inconveniences. All tests run so far indi-cate that the power system is functioning perfectly. For example, the base load test connects 30% of the generation capacity to hospital load for 45 min biweekly (as required by and reported to authorities) without interrupting any hospital services or loads.

Rex Hospital gets a power system upgrade By Edmund Malley,

Russelectric, Hingham, Mass.

Edmund Malley is vice president of engineering and field service for Russelectric.

The upgrade increased the system’s emergency power generating capacity

and boosted its fuel storage capacity.

CASE STUDY

creo

About the ElectricalGenerating SystemsAssociationFor almost 50 years, the Electrical Generating Systems Association (EGSA) has been on the cutting edge of generated power solutions.

Providing codes and standards updates, emerging technologies, education, best practices,

enrichment, we are the leading authority in the on-site power industry.

EGSA represents more than 950 members worldwide. This number includes 750 member companies and 200 student members. We manufacture, distribute, market, sell, install, maintain, and service on-site power equipment. Our trade association is poised to help people and organizations like yours meet ever-increasing business demands for emergency power solutions, while balancing those demands with cost, safety, security, and technology.

the industry benchmark that provides organizations like yours with an objective way to gauge if someone

hope you remember this when it comes time to install, maintain, and service your clients’ systems

Technician.EGSA also offers a rigorous, two-tiered

educational program with schools throughout the U.S. that outline the technical aspects of power

School curriculums, taught by leading industry

to keep your skills sharp and to stay abreast of the technologies that support the power generation industry.

Finally, we also give back to the industry with EGSA’s David I. Coren Scholarship Program. Since the program’s launch in 2002, EGSA has granted a total of 106 scholarships to students pursuing

program are immeasurable, not only increasing students’ personal knowledge and earning power, but also increasing their value to employers within our own industry.

We actively encourage and promote the

www.egsa.org for details of our programs and initiatives, or contact our staff at 561-750-5575.

EGSA announces 2014 boardelection resultsThe Electrical Generating Systems Association has announced the election of

The 2014 EGSA Executive Board members are:President: Vaughn Beasley, Ring Power Corp., St. Augustine, Fla.President-elect: Ed Murphy, Power Search Inc., Hampstead, N.H.

Emergency Systems Service Co., Quakertown, Pa.Secretary-treasurer: Charlie Habic, Gillette Generators, Elkhart, Ind.Immediate past president: Debra Laurents, Cummins Power Generation,

Also elected to the Board of Directors for the 2014 to 2016 term are:Bill Kaewert, Stored Energy Systems LLC (SENS), Longmont, Colo.Dennis Pearson, Woodward, Fort Collins, Colo.

The following members will remain on the Board of Directorsthrough the coming year:

Katie Evans,Steve Evans, DEIF Inc, Fort Collins, Colo.Todd Lathrop,Rick Morrison,Walter Petty, Atlantic Power Solutions, Siler City, N.C.Lanny Slater, GFS Corp., Weston, Fla.Kyle Tingle

29N O V E M B E R 2 0 1 3 29

Important on-site power industry eventsEGSA Power Source PavilionNational Facilities Management & Technology ConferenceBaltimore, Md., March 4-6, 2014Join EGSA members as they exhibit together in the country’s No. 1 conference and exposition for nonresidential building owners, facility managers, maintenance engineers, directors of sustainability, planning, operations, and management. EGSA is partnering with NFMT for the third year in a row to bring end users the Power Source Pavilion. The Power Source Pavilion and educational sessions will provide facility professionals and consulting/specifying engineers with exclusive access to on-site power solutions. For more information, contact EGSA at 561-750-5575, ext. 203, or e-mail Kim Giles at [email protected].

EGSA 2014 Spring ConventionSavannah, Ga., March 23-25, 2014The Annual Spring Convention features educational sessions on issues that impact today’s on-site power industry. If you are an engineer or facility manager in the Savannah area and are interested in joining us for breakfast during our convention, we would love to host you. For more information, visit www.egsa.org/spring (after Jan. 1, 2014) or call 561-750-5575.

EGSA 2014 Fall Technical & Marketing ConferenceMission Bay (San Diego), Sept. 14-16, 2014The Fall Technical and Marketing Conference is designed to focus on technical and marketing issues. EGSA invites speak-

-ment agencies, and others to give presentations. If you are an engineer or facility manager in the San Diego area and are interested in joining us for breakfast during our conference, we

to be the ideal place for networking within the on-site power community. Registration information will be available in July 2014 at www.egsa.org/fall or by calling 561-750-5575.

EGSA’s On-Site Power PavilionPOWER-GEN International 2014Orlando, Fla., Nov. 12-14, 2014EGSA’s On-Site Power Pavilion—a “show within a show”—

products, and services, raises awareness of on-site power’s place within the larger context of the overall electrical power generation industry. For exhibit information, contact EGSA at 561-750-5575, ext. 205, or e-mail Jalane Kellough at [email protected].

Advertiser IndexCOMPANY PAGE RS. PHONE WEBSITE

NO. NO. NO.

Baldor Electric Company 32 505 479-646-4711 www.baldor.com

Basler Electric Co 11 502 618-654-2341 www.basler.com/11CSE2020

CFE Media,Engineering Is Personal 21 630-571-4070 www.csemag.com

EGSA 31 504 561-750-5575 www.egsa.org

Generac Industrial Power 2 500 800-436-3722 www.generac.com/industrial

MTU Onsite Energy 15 503 507-625-7973 www.mtu-online.com

Russelectric Inc. 7 501 800-225-5250 www.russelectric.com

EGSA education andtraining opportunities

Informally known as the Rowley School, EGSA’s Electrical Generating Systems School was renamed the EGSA George Rowley School of On-Site Power Generation in 2013. The school continues to offer a rigorous two-tiered program for professionals who need to understand the basics of power generation.

EGSA’s on-site power generation schools provide the most comprehensive on-site power generation system overview. The schools now offer Continuing Education Units. For information, visit www.egsa.org or call 561-750-5575.

Basic School: The Basic School is a general, but techni-

for those who are working in nontechnical positions such as sales, marketing, administrative, or company management positions, and for those who have worked in the industry less than three years. The

when available.Advanced Schools: Advanced Schools

offer more highly technical and in-depth cover-

Advanced School is designed for those who have attended the EGSA Basic On-Site Power Gen-eration School; those employed in engineering, project management, or service positions; and for those who have worked in the industry more than three years. The 2014 Advanced School

when available.

N O V E M B E R 2 0 1 330

What Does this StatueHave in Common with

Your Back-Up Power System?(Maybe More Than You Think?)

Our Members manufacture, distribute, market and sell; and they also install, maintain and service on-site power equipment. From codes and standards, emerging technologies, best practices, educa-tion, technician certification and industry enrichment, EGSA truly is the leading authority in On-Site Power!

1650 S. Dixie Hwy, Suite 400, Boca Raton, FL 33432 (561) 750-5575 www.egsa.org

Consulting & Specifying Engineers invest hundreds of hours into carefully crafting, devel-oping and installing On-Site Power Generation systems. The work is intricate and painstak-

ing — all to produce a unique system that precisely fits a client’s back-up power demands.

In the end, the Consulting Engineer specifies an On-Site PowerGeneration system that not only meets the client’s power needs,

increases efficiency and reduces emissions, but also complies with all the necessary codes and standards to withstand a catastrophic event.

Protect Your Masterpiece & Your Client’s Investment!Ensure your client’s system is operating at its peak performance,

specify that only EGSA Certified Generator Techniciansmaintain and repair it. EGSA’s Certification Program uses

rigorous testing to identify generator technicians whohave attained sufficient levels of skill, knowledge and

expertise to demonstrate proficiency in various aspects of generator set and On-Site Power Generation

systems maintenance and repair.

Only technicians who pass the test canuse the title “EGSA Certified Electrical

Generator Systems Technician.”

That System is Your Masterpiece…Your Opus…

“Magnum Opus”noun: \ ‘mag-n m- ‘o-p s\ a great work; especially: the greatest achievement of an

artist or writer.

e e_


UL Verified Components

Tested as a Complete System

Not every UL 2200 genset on the market

is fully tested as a complete system. Many

are open units that are upgraded with

third party components and shipped to

customers without a complete system test

to verify performance and reliability.

Every Baldor UL 2200 genset is a complete

system designed, manufactured AND

tested at our plant. We use only UL verified

components and every genset is tested

as a complete system before it leaves our

factory. Once each genset passes rainwater

ingress tests, hipot alternator tests, air

blockage and flammability tests, proper

safety shutdown checks and verification

that component temperatures are below

combustion levels, then and only then will

we apply the UL label and the Baldor name.

baldor.com 479-646-4711

©2012 Baldor Electric Company

Baldor UL 2200 Gensets


YA S K AWA A M E R I C A , I N C .D R I V E S & M O T I O N D I V I S I O N 1 - 8 0 0 -YA S K AWA | YA S K AWA . C O M

For more info:http://Ez.com/yai554

Get personal with Yaskawa.Call our Building Automation team today. 1-847-887-7146

©2013 Yaskawa America Inc.

DRIVEN.TOP-TO-BOTTOM.

Yaskawa drives offer the quality performance you need for your assets from the air handlers and cooling towers on the roof to the secondary chilled water pumps in the basement. More importantly, our engineers and world-class distributor network provide outstanding support to give you easy programming, simple installation, thorough training and a worry-free product experience.

Our Z1000, for example, is a variable speed drive that is designed for building automation applications such as fans, pumps, and cooling towers through 500HP. The Z1000 features an easy-to-read LCD keypad that provides a Hand-Off-Auto interface and a real time clock. These features make the Z1000 perfect for many building automation applications that require reliable motor control.

We’ve got your HVAC drives needs covered – top to bottom. Give us a call today.


HIGH LEVEL INNOVATIONAT FLOOR LEVEL.

Evolution™ Series. Imagine having enough capacity to house power, communications and A/V services together. Imagine keeping you and your technology safer with recessed devices and a cover that always lies fl at. All with decreased installation time and a two-hour fi re rating. Imagine all this and more right at your fi ngertips. Go to legrand.us/epd2 to discover it all.

WIREMOLD® POKE-THRU DEVICES


consulting specifying engineer 11 2013

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