2017 AWT Fall Analyst

the Analyst The Voice of the Water Treatment Industry

Volume 24 Number 4

9707 Key West Avenue, Suite 100 • Rockville, MD 20850

Fall 2017

Failure Analysis and Investigation Methods for Boiler Tube Failures Corrosion Control for the Industrial Plant Steam– Condensate System

Volume 24 Number 4 Fall 2017

Phosphate Hideout: What Is It?

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Table of Contents 9707 Key West Avenue, Suite 100 • Rockville, MD 20850

the Analyst The Voice of the Water Treatment Industry

Volume 24 Number 4

Cover www.istockphoto.com

Fall 2017

Failure Analysis and Investigation Methods for Boiler Tube Failures Corrosion Control for the Industrial Plant Steam– Condensate System Volume 24 Number 4 Fall 2017

Fall 2017

Volume 24

Phosphate Hideout: What Is It?

Published by

Number 4

30 Failure Analysis and Investigation Methods for Boiler Tube Failures Mehrooz Zamanzadeh, Edward S. Larkin, George T. Bayer, William J. Linhart

Failure analysis methodology is applied to the principal mechanisms by which boiler tubes fail during service. Several important factors often associated with component failures are deficiency in design, fabrication, operating conditions, unsuitable materials selection, and expended useful life. These factors are of primary consideration. The failure analysis procedure, or methodology for evaluation, is provided in a step-by-step approach. This includes justification for conducting a failure analysis investigation; development of a logical plan for the investigation to follow; collection of background information; sample removal techniques; onsite inspection; laboratory testing and analysis; and the formulation of a final report based on relevant data, analysis, and recommendations. Among the case histories discussed are fatigue, erosion, short-term overheating, and hydrogen damage.

52 Corrosion Control for the Industrial Plant Steam–Condensate System Debbie Bloom, Nalco Champion, an Ecolab Company

Industrial plant steam and condensate systems vary widely in their design, sometimes with miles of pipe extending from process to process, carrying steam that drives rotating equipment, heats process streams, and at times enters into process reactions. Consequently, effective corrosion control in steam-condensate systems often requires a detailed understanding of the steam and condensate distribution network, the system metallurgy, the chemistry of the steam and its effect on the chemistry of the condensate, and any process restrictions on the treatment chemistry. This article will provide a basic understanding of the causes of condensate system corrosion, the effects of steam and condensate system design on corrosion potential, the chemistries employed to control corrosion, the limits and concerns associated with treatment options, and the recommended monitoring and control needed to ensure effective protection of important equipment throughout the plant.

64 Phosphate Hideout: What Is It?

4

Calendar of Events

6

President’s Message

8

Message From the President-Elect

10 Analyst Index 70 Association News 71 Membership Benefits 73 Industry Notes 76 Making a Splash 78 Certification Corner 80 CWT Spotlight 82 Ask the Experts

Heyl Brothers

A coordinated phosphate program is designed to provide good water chemistry and pH control to minimize corrosion. It is also designed to minimize phosphate hideout by staying below the solubility of sodium phosphate compounds. If there is a deposit of hideout or anything else, be it contamination, condenser leak, pretreatment failures, whatever, it is designed to be noncorrosive under the deposit. It is designed so that in case of deposits, the concentrating liquid under the deposit is not corrosive.

84 T.U.T.O.R. 89 Capital Eyes 91 Business Notes 94 Financial Matters 98 Advertising Index

3

the Analyst Volume 24 Number 4

9707 Key West Avenue, Suite 100 Rockville, MD 20850 (301) 740-1421 • (301) 990-9771 (fax) www.awt.org

2017 AWT Board of Directors President

Calendar of Events

Association Events 2018 Annual Convention and Exposition

Marc Vermeulen, CWT

Secretary

September 26–29, 2018 Omni Orlando Resort at ChampionsGate Orlando, Florida

Treasurer

2019 Annual Convention and Exposition

President-Elect

David Wagenfuhr, LEED OPM

Thomas Branvold, CWT Michael Bourgeois, CWT

September 11–14, 2019 Palm Springs Convention Center and Renaissance Hotel Palm Springs, California

Immediate Past President

Bruce T. Ketrick Jr., CWT

Directors

Matt Jensen, CWT Andy Kruck, CWT Bonnee Randall Andrew Weas, CWT

2020 Annual Convention and Exposition

Ex-Officio Supplier Representative

Kevin Cope

Past Presidents

Jack Altschuler John Baum, CWT R. Trace Blackmore, CWT, LEED AP D.C. “Chuck” Brandvold, CWT Brent W. Chettle, CWT Dennis Clayton Bernadette Combs, CWT, LEED AP Matt Copthorne, CWT James R. Datesh John E. Davies, CWT Jay Farmerie, CWT Gary Glenna Charles D. Hamrick Jr., CWT Joseph M. Hannigan Jr., CWT Mark R. Juhl

Brian Jutzi, CWT Bruce T. Ketrick Sr., CWT Ron Knestaut Robert D. Lee, CWT Mark T. Lewis, CWT Steven MacCarthy, CWT Anthony J. McNamara, CWT James Mulloy Alfred Nickels Scott W. Olson, CWT William E. Pearson II, CWT William C. Smith Casey Walton, B.Ch.E, CWT Larry A. Webb

Staff

Executive Director

Heidi J. Zimmerman, CAE

Deputy Executive Director

Sara L. Wood, MBA, CAE

Senior Member Services Manager

Angela Pike

Vice President, Meetings

Grace L. Jan, CMP, CAE

Meeting Planner

Morgan Prior

Meeting Planner

Kristen Jones, CMP

Exhibits and Sponsorship Manager

Barbara Bienkowski, CMP

Exhibits and Sponsorship Coordinator

Brandon Lawrence

Marketing Director

Julie Hill

Marketing Specialist

Jeyin Lee

Director of Editorial Services

Lynne Agoston

Accountant

Dawn Rosenfeld

the Analyst Staff Publisher

Heidi J. Zimmerman, CAE

Managing Editor

Lynne Agoston

Technical Editor

September 30–October 3, 2020 Louisville Convention Center and Omni Hotel Louisville, Kentucky

2021 Annual Convention and Exposition

September 22–25, 2021 Providence Convention Center and Omni Hotel Providence, Rhode Island

Also, please note that the following AWT committees meet on a monthly basis. All times shown are Eastern Time. To become active in one of these committees, please contact us at (301) 740-1421.

Second Tuesday of each month, 11:00 am – Legislative/Regulatory Committee Second Tuesday of each month, 2:30 pm – Convention Committee Second Wednesday of each month, 11:00 am – Business Resources Committee Second Friday of each month, 9:00 am – Pretreatment Subcommittee Second Friday of each month, 10:00 am – Special Projects Subcommittee Second Friday of each month, 11:00 am – Cooling Subcommittee Third Monday of each month, 9:00 am – Certification Committee Third Monday of each month, 3:30 pm – Young Professionals Task Force Third Monday of each month, 4:30 pm – Standards Task Force Third Tuesday of each month, 3:00 pm – Education Committee Third Friday of each month, 9:00 am – Boiler Subcommittee Third Friday of each month, 10:00 am – Technical Committee Quarterly (call for meeting dates), 11:00 am – Wastewater Subcommittee

Other Industry Events

ASHRAE, Winter Meeting, January 20–24, 2018, Chicago, Illinois ASHRAE, AHR Expo, January 22–24, 2018, Chicago, Ilinois BOMA, Winter Business Meeting, January 28–31, 2018, Washington, D.C. AWWA, AWWA-WEF Utility Management, February 20–23, 2018, San Antonio, Texas AWWA, Membrane Technology Conference, March 12–16, 2018, West Palm Beach, Florida ACS, Spring National Meeting & Expo, March 18–22, 2018, New Orleans, Louisianna ASHE, PDC Summit, March 25–28, 2018, Nashville, Tennessee AWWA, Sustainable Water Management Conference, March 25–28, 2018, Seattle, Washington WQA, Aquatech Meeting, March 26–29, 2018, Denver, Colorado

Bennett Boffardi, Ph.D., bennett.boffardi@gmail.com

Advertising Sales

Heather Prichard, advertising@awt.org

The Analyst is published quarterly as the official publication of the Association of Water Technologies. Copyright 2017 by the Association of Water Technologies. Materials may not be reproduced without written permission.

Contents of the articles are the sole opinions of the author and do not necessarily express the policies and opinions of the publisher, editor or AWT. Authors are responsible for ensuring that the articles are properly released for classification and proprietary information. All advertising will be subject to publisher’s approval, and advertisers will agree to indemnify and relieve publisher of loss or claims resulting from advertising contents. Editorial material in the Analyst may be reproduced in whole or part with prior written permission. Request permission by writing to: Editor, the Analyst, 9707 Key West Avenue, Suite 100, Rockville, MD 20850, USA. Annual subscription rate is $100 per year in the U.S. (4 issues). Please add $25 for Canada and Mexico.

International subscriptions are $200 in U.S. funds.

4

the Analyst Volume 24 Number 4

President’s Message

By Marc Vermeulen, M.Sc., CWT

Advocacy

It is exciting to start my presidential year coming off of the highly successful 2017 Annual Convention in Grand Rapids.

What a great meeting—with over 1,200 attendees!. During our time in Grand Rapids, we introduced the beta version of the STEM educational kit, honored leaders in our industry, met with suppliers and peers, sent 300 ducks down the river, and raised over $10,000 for Pure Water for the World. Thank you to all of you who participated and made it such a positive meeting.

If you have not already visited the AWT online advocacy center, I encourage you to do so. You can find it in the Members Only section of the website at https:// www.awt.org/members_only/legislative_and_regulatory_resources.cfm. The advocacy center identifies issues important to our community and provides information on how to interact with your local representatives and the media.

I am honored to serve as the 2018 AWT president.

With the adoption of the strategic plan, AWT has four outcomes we are focused on: technical resources, business resources, advocacy, and charity.

The next phase is the development of a career center for our profession, which will include resources not only for AWT members to go out into their own communities, but also resources for students, parents, and school counselors. Once completed, this section will be the go-to resource for anyone wanting to enter the profession or for anyone needing resources to recruit into the profession.

This new area will be available by March 2018.

Technical Resources

Charity

AWT currently has two teams of volunteers hard at work on the online new employee technical training.

One group is developing the content for the 14 modules, while the other group is gathering graphics, images, and videos. We’re very excited about this project, which should roll out in May 2018. The purpose of the training will be to quickly get a new service tech up to speed on our industry and their position. This will be a very valuable tool for our membership.

Coming off of the success of the 2017 Annual Convention, our Charity Task Force continues to work with Pure Water for the World on projects for 2018.

The task force is currently planning two trips for AWT members to go down to Haiti or Honduras. I had the privilege of visiting Port-au-Prince, Haiti, back in August.

It was a humbling trip that I encourage everyone to experience. We were able to apply the skills we use in our day-to-day work to improve the lives of others. It was incredibly rewarding.

Business Resources

As we look forward to 2018, I encourage you to get involved. AWT has a lot of projects in the works, and we are always looking for volunteers. And please don’t hesitate to reach out to provide feedback on AWT. I can be reached at president@awt.org.

As you may have heard, AWT is working with Dale Carnegie to provide live online sales and managerial training to members. You can sign up now for classes that begin in 2018. A sampling of the courses is listed below.

•

A Manager’s Guide to Sustainable Employee Engagement

•

Performance Reviews That Motivate

•

How to Cold Call and Build New Customers

•

Transforming Customer Complaints Into Opportunities

I hope you take advange of this great new resource.

6

the Analyst Volume 24 Number 4

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Message From the President-Elect

interest to the membership, submit an abstract to be part of the program. We’re also researching keynote speakers, and while we haven’t selected one yet, we are considering some great individuals to inspire and motivate you in your work.

Mark your calendars now for the 2018 Annual Convention in Orlando, Florida!

I just came back from our planning visit to the property and am excited about next September.

AWT will be taking over this hotel and will be the only group meeting at their property! This will allow for more networking opportunities, as there are lots of areas to sit down and have one-off meetings.

When we’re not in the exhibit hall or in education sessions, you’ll get to enjoy the fantastic property. The resort features a championship golf course, a spa, seven restaurants, and 15 acres of pools plus a lazy river. The resort offers secluded luxury, yet easy access to area attractions like Walt Disney World, Universal Studios, and SeaWorld. Complimentary scheduled shuttle transportation is provided to the Disney theme parks. This will be a great convention to bring the family along to visit the parks after the meeting.

We expect to have a sold-out exhibit hall in 2018. The exhibit hall is a great place to learn about the latest new technologies and to see what our suppliers have to offer.

I’m always impressed with the quality conversations I have with suppliers.

As we plan and prepare for Orlando, I welcome your input and feedback. I can be reached at dwagenfuhr@h2oeng. com. Thank you for the opportunity, and I look forward to serving you!

We’re currently accepting abstracts for the 2018 Annual Convention. If you have a presentation that would be of

By David Wagenfuhr, LEED AP O&M

8

the Analyst Volume 24 Number 4

2018 Technical Training (West)

2018 Technical Training (East)

February 28–March 4, 2018 Green Valley Ranch Resort Las Vegas, NV

March 21–25, 2018 Marriott Cleveland Cleveland, OH

Training Available Sales Training Polymeric-Membrane Separation Technologies RO/Ultrafiltration Training Fundamentals and Applications Training Water Treatment Training Certified Water Technologist (CWT) Exam

Sign up today at www.awt.org

AWT Analyst Index

By Issue

By Author

Name

Title

Year, Issue

Name

Title

Year, Issue

Gandhi, Ashish

Volatile Corrosion Inhibitors—Unique Water Treatment Applications

2000 Fall, p 9

Al-Zubi & Lampson

Cross-Linked Rotomoled Polyethylene Storage Tank Offers Superior Resistance to Rupture

2003 Winter, p 16

Cashion, Robert

Neutralization and Destabilization of Heavy Metals in the Metal finishing Industry

2000 Fall, p 16

Albao, Jed

Do “IT” Yourself—Wireless Internet Process Communication

2010 Spring, p 48 Supplement

McPherson, Lori

Automatic Temperature Compensation for Your Boiler Controller

2000 Fall, p 20

Amjad and Zuhl

Effects of Thermal Stress on SilicaSilicate Deposit Control Agent Performance—Part I

2011 Fall, p 10

Ulrich, Carl

Taking Advantage of Growth Opportunities for Independent Water Mgt Co in a Highly Cond Market

2000 Fall, p 25

Amjad and Zuhl

Effects of Thermal Stress on SilicaSilicate Deposit Control Agent Performance—Part II

2012 Winter, p 25

Keane, Tim

Chlorine Dioxide (Cl2)—Why All the Commotion?

2000 Spring, p 9

Amjad Z., et al.

Deposit Control Polymer Selection Criteria for High-Temperature Application—Part II Polymer Performance

2015 Fall, p 35

Nalepa, Chris J.

Oxidizing Biocides: Properties and Applications

2000 Spring, p 15

Amjad, et al.

Deposit Control Polymer Selection Criteria for High-Temperature Application—Part I

2015 Summer, p 40

Releny, Attila

Organic Film and General Organic Fouling Indicies

2000 Spring, p 33

Amjad, Z., Zuhl, R.

Water Treater Deposit Control Polymer Evaluation Criteria and Considerations

2013 Summer, p 29

Bush, Bruce D., et al.

Advances in The Inhibition of White Rust

2000 Summer, p 9

Amjad, Zahid

Factors to Consider When Selecting a Dispersant for Treating Industrial Water Systems

2001 Summer, p 9

O’Neal, Jeff

The Evolution of Chemical Metering Technology

2000 Summer, p 15

Amjad, Zahid

Controlling Metal Ion Fouling in Industrial Water Treatment Systems

2002 Winter, p 16

Boffardi, Bennett

Standards for Corrosion Rates

2000 Summer, p 57

Amjad, Zahid

Effect of Biocides on Deposit Control Polymer Performance

2003 Spring, p 9

Frayne, Colin

Early Boiler Water Treatments and the Use of Tannins In Modern Day Programs

2001 Fall, p 9

Amjad, Zahid

Factors Influencing the Precipitation of Calcium-Inhibitor Salts in Industrial Water Systems

2005 Winter, p 19

Kasinecz, Frank

Diethylhydroxylamine (DEHA), a Volatile Oxygen Scavenger for Boiler System Treatment

2001 Fall, p 17

Amjad, Zahid

The Use of Polymers to Improve Control of CaCO3 Scaling in High Stree Cooling Water Systems—Part II

2006 Spring, p 19

Juhl, Mark

The Solid Marketplace Trives in the New Millineum

2001 Fall, p 27

Amjad, Zahid

The Use of Polymers to Improve Control of CaCO3 Scaling in High Stress Cooling Water Systems—Part I

2006 Winter, p 9

Frayne, Colin

The Selection and Application of NonOxidizing Biocides for Cooling Water Systems

2001 Spring, p 16

Amjad, Zahid

The Impact of Thermal Stability on the Performance of Polymeric Dispersants for Boiler Water Systems

2007 Fall, p 20

Ganzer, George

Glutaraldehyde: A Versatile Microbiocide for Use in Water Treatment Applications

2001 Spring, p 23

Arduino, Jim

Wastewater Defoamers

2009 Fall, p 14

Freije, Mathew

New Standard Requires Legionella Management Plans for Hospitals

2001 Spring, p 33

Armitage & Nickrand

Statistical Process Control for WaterTreatment Systems

2003 Summer, p 18

Amjad, Zahid

Factors to Consider When Selecting a Dispersant for Treating Industrial Water Systems

2001 Summer, p 9

ASHRAE

ASHRAE GreenGuide

2008 Fall Green Supplement, p 15

Latzer, Kenn

The Importance of Side Stream Filtration in Water and Energy Conservation

2001 Summer, p 21

AWT

TUTOR: AWT BW Committee—Sodium Zeolite Water Softener Calculations

2010 Winter, p 56

Cavano, Lee

Understanding Proper Shipping Names

2001 Summer, p 29

AWT

Plant Operators’ References: Some Useful Tools

2011 Fall, p 8 Supplement

Rey, Susan P.

Carbon Steel Corrosion Control Ion the Past Twenty Years and in the Millineum

2001 Summer, p 35

AWT

What HR Needs to Know in 2016

2016 Spring, p 12 Business Supplement

Bassett, Al

How to Survey a Sodium Zeolite Water Softener

2001 Winter, p 9

AWT

Handing the Torch to the Next Generation

2016 Spring, p 41 Business Supplement

Cashion, Robert

How to Read MSDS Sheets

2001 Winter, p 29

AWT

Boiler Plant Flow Diagram

2016 Fall, p 20

Boffardi, Bennett

TUTOR: System Capacity of Water Volume

2001 Winter, p 52

AWT

Certification Corner

2016 Fall, p 31 Supplement

Peters, Charles

Internal Water Treatment for Industrial Boiler Systems

2001 Winter, p 17

AWT

AWT Boiler Water Pretreatment Matrix

2010 Winter, p 32

Cotton & Hollander

Boiler Systems: Design and Classification—Part 1

2002 Fall, p 9

AWT

Aluminum Corrrosion Coupon Discussion

2016 Summer, p 34

Zupanovich, John D

Oxidation and Degradation Products of Common Oxygen Scavengers

2002 Fall, p 17

AWT Boiler Committee

Boiler Efficiencies

2009 Fall, p 35

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AWT Analyst Index continued

By Issue

By Author

Name

Title

Year, Issue

Name

Title

Year, Issue

Silbert, Marvin D.

Flow-Accelerated Corrosion

2002 Fall, p 25

AWT BW Committee

Boiler Water Treatment Chemical Guidelines—Part I

2012 Fall, p 29

Dromgoole, J.C.

Laboratory Analysis and Interpretation— 2002 Fall, p 33 Water, Resin & Deposits

AWT BW Committee

Boiler Water Treatment Chemical Guidelines-—Part II

2013 Winter, p 10

Cavano, Robert R.

Phosphonates as Calcium Carbonate Control Agents

2002 Spring, p 9

AWT Green Task Force

Cooling Water Management

2010 Fall, p 12, Supplement

Johnson, Charles T.

The Control of pH and oxidation Reduction Potential (ORP) in Cooling Tower Applications

2002 Spring, p 25

AWT Pret Subcom

Dionizatin: Parts I & II

2014 Spring, p 10

McPherson, Lori

Understanding Oxidation Reduction Potential (ORP) Systems

2002 Spring, p 31

AWT Pretreetment

Pretreatment Water Analysis Tips & Recommendations

2012 Summer, p 10

Wiatr, Christopher L.

Detection and Eradication of a NonLegionella Pathogen in a Cooling Water System

2002 Spring, p 38

AWT Staff

Education & Certification Corner

2005 Fall, p 48

Ferguson, Robert J.

Computer Modeling of Water Chemistry

2002 Summer, p 9

AWT Staff

TUTOR: Clean Up That Cooling Tower

2005 Spring, p 43

Vanderpool, Dan

Hidden Assumptions in Saturation Calculations

2002 Summer, p 25

AWT Staff

Education & Certification Corner

2005 Spring, p 50

Freedman, Len

Computer Technology In Water Treatment: A Two-Edge Sword

2002 Summer, p 30

AWT Staff

Education & Certification Corner

2005 Summer, p 41

Baum, Matthew

Water Treatment in the Cyber World…

Are You Ready?

2002 Summer, p 39

AWT Staff

TUTOR: Cooling System Dynamics

2011 Summer, p 73

McDonald, James

Using Spreadsheets to Better Serve Your Customers

2002 Summer, p 61

AWT Tech Com

TUTOR: Boiler Pretreatment Matrix

2008 Fall, p 67

Lampson, Marshall

Polyethylene Chemical Storage Vessels

2002 Winter, p 9

AWT Tech Com

TUTOR: ATP Testing and Legionella

2004 Spring, p 52

Amjad, Zahid

Controlling Metal Ion Fouling in Industrial Water Treatment Systems

2002 Winter, p 16

AWT Tech Com

TUTOR: Does a Closed System Need Chemical Treatment?

2004 Summer, p 49

Youmans, R.O, et al.

Dimethylthiocarbamate and the Environmental Protection Agency

2002 Winter, p 33

Aydlett, Neil

Chemical Processing: Using Voice Over IP in Today’s Business World

2011 Fall, p 17 Supplement

Schmelter, Dean M.

Finally, A Safe Replacement for Dimethyldithiocarbamate

2002 Winter, p 38

Bain, Douglas, et al.

Laboratory and Field Development of a Novel Environmentally Acceptable Scale and Corrosion Inhibitor

2004 Spring, p 9

Erickson, Donovan

Evaluating Polymers and Phosphonates for Use as Inhibitors for Ca, PO4, & Fe in Steam Boilers—Part I

2003 Fall, p 11

Bardsley, Judy

Polymeric Scale Inhibitors for Reverse Osmosis Systems

2014 Winter, p 26

Dewitt-Dick, Dougles

Boiler Failure Mechanism

2003 Fall, p 17

Bassett, Al

How to Survey a Sodium Zeolite Water Softener

2001 Winter, p 9

Farmerie, James

Chemical Cleaning Assists Water Treatment Program Used for Industrial Utility Systems

2003 Fall, p 26

Baum, Matthew

Water Treatment in the Cyber World…

Are You Ready?

2002 Summer, p 39

Baum, Matthew

Water Treatment in the Cyber World…

Are You Ready? Part IV

2003 Fall, p 31

Baum, Matthew

Water Treatment in the Cyber World…

Are You Ready? Part IV

2003 Fall, p 31

McDonald, James

TUTOR: Condensate Problem Solving

2003 Fall, p 40

Baum, Matthew

Water Treatment in the Cyber World…

Are You Ready? Part III

2003 Summer, p 28

Marynchak, Terry

The 529 Plan—Finding Away to Fund a College Education

2003 Fall, p 48

Baum, Matthew

Water Treatment in the Cyber World…

Are You Ready? Part II

2003 Winter, p 28

Amjad, Zahid

Effect of Biocides on Deposit Control Polymer Performance

2003 Spring, p 9

Baum, Matthew

Water Treatment in the Cyber World…

Are You Ready? Part 5

2004 Winter, p 27

Cotton & Hollander

Boiler Systems: Chemical Treatment— Part 3

2003 Spring, p 26

Bearwood, Edward

Feedwater and Deaeration Within Industrial Steam-Generating Systems

2017 Fall,

Ganzer, George

Glutarahydle and DBNPA: An Effective Combination Treatment Program

2003 Spring, p 35

Berk, et al.

Occurrence of Infected Amoebae in Cooling Towers Compared with Natural Aquatic Environments

2007 Summer, p 10

Pescatore, Stephen

Which to Use: Ethyl Glycol or Propylene Glycol

2003 Summer, p 13

Bertasi and Cope

Oil Removal

2011 Summer, p 10

Armitage & Nickrand

Statistical Process Control for WaterTreatment Systems

2003 Summer, p 18

Bloch, Heinz

Avoiding Repeat Pump Failure

2014 Fall, p 20

Baum, Matthew

Water Treatment in the Cyber World…

Are You Ready? Part III

2003 Summer, p 28

Bloom, Debbie

Corrosion Control for the Industrial Plant Steam

2017 Fall, p 50

Marynchak, Terry

Alphabet Soup—Deciphering the Letters Behind the Financial Professional

2003 Summer, p 46

Boffardi & Hannigan

A Limited Evaluation of Pitting Corrosion of Cu Piping in a Hospital Domestic Hot Water System

2013 Fall, p 30 Supplement

McDonald, James

Using Reverse Osmosis for Boiler Pretreatment

2003 Summer, p 51

Boffardi et al.

Control of Lead Corrosion by Chemical Treatment

2016 Spring, p 44

Cotton & Hollander

Boiler Systems: Components—Part 2

2003 Winter, p 9

Boffardi, Bennett

Going Green: Green Chemistry

2008 Fall Green Supp., p 21

11

the Analyst Volume 24 Number 4

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AWT Analyst Index continued

By Issue

By Author

Name

Title

Year, Issue

Name

Title

Year, Issue

Al-Zubi & Lampson

Cross-Linked Rotomoled Polyethylene Storage Tank Offers Superior Resistance to Rupture

2003 Winter, p 16

Boffardi, Bennett

Standards for Corrosion Rates

2000 Summer, p 57

Paul, David H.

The Four Most Common Problems in Membrane Water Treatment Today

2003 Winter, p 21

Boffardi, Bennett

TUTOR: System Capacity of Water Volume

2001 Winter, p 52

Baum, Matthew

Water Treatment in the Cyber World…

Are You Ready? Part II

2003 Winter, p 28

Boffardi, Bennett

TUTOR: Why Does a Closed System Need a Filter?

2006 Summer, p 55

Jaffer, Arif

Chemical Cleaning of an Industrial Boiler—An Overview

2004 Fall, p 9

Boffardi, Bennett

TUTOR—Cooling Tower Operation During Winter Months

2007 Winter, p 52

Peters, John

Synthetic Antifoulants for the Water Treatment Industry—Part 2

2004 Fall, p 21

Boffardi, Bennett

Potable Water Chapter for the AWT Technical Reference and Training Manual

2007 Fall, p 47

Ning, Robert

Sustaining the Properties of Reverse Osmosis Plants

2004 Fall, p 29

Boffardi, Bennett

Mechanical Chillers

2008 Spring, p18

Marynchek, Terry

Everything You Ever Wanted to Know About Annuities…and More!

2004 Fall, p 59

Boffardi, Bennett

TUTOR: Calculating Chiller Efficiency

2008 Spring, p 59

Bain, Douglas, et al.

Laboratory and Field Development of a Novel Environmentally Acceptable Scale and Corrosion Inhibitor

2004 Spring, p 9

Boffardi, Bennett

TUTOR: Cathodic Protection

2009 Summer, p 66

Vanderpool, Dan

The pH Values for Cooling Water Systems

2004 Spring, p 21

Boffardi, Bennett

Corrosion and Fouling Monitoring of Water Systems

2010 Spring, p 8 Supplement

UY, Mario

Ozone in Cooling Water Treatment

2004 Spring, p 32

Boffardi, Bennett

Heat Exchangers

2015 Spring, p22

Marynchek, Terry

The IRA That No One Talks About—The Roth IRA

2004 Spring, p 42

Boffardi, Bennett

TUTOR: Consultants

2015 Spring, p 63

AWT Tech Com

TUTOR: ATP Testing and Legionella

2004 Spring, p 52

Boffardi, Bennett

TUTOR: Monitoring Condenstae Corrosion

Spring 2017, p 71

Ferguson, Robert

Water Treatment Rules of Thumb: Myths 2004 Summer, or Useful Tools? p 13

Bosscher, Jamie

TUTOR: Errors in ATP Testing and Reproducability

2006 Winter, p 35

Perry, Chuck

Metals Removal

2004 Summer, p 25

Bray, David

Three Meaningful Strategies for Managing Rapid Change

2017 Spring, p 27 Business Supplement

Peters, John

Synthetic Antifoulants for the Water Treatment Industry—Part 1

2004 Summer, p 37

Brooks, Alison W.

Emotion and the Art of Negotiation

2016 Spring, p 42 Business Supplement

AWT Tech Com

TUTOR: Does a Closed System Need Chemical Treatment?

2004 Summer, p 49

Brugman, Helmut

Corrosion and Microbiological Control in Firewater Sprinkler Systems

2006 Spring, p 9

Hennessy, Thomas

Theory of Water Clarification

2004 Winter, p 9

Burgess, John

Hiring for Success

2012 Spring, p 23 Business Supplement

Erickson, Donovan

Evaluating Polymers and Phosphonates for Use as Inhibitors For Ca, PO4, & Fe In Steam Boilers—Part II

2004 Winter, p 17

Bush, Bruce D., et al.

Advances in The Inhibition of White Rust

2000 Summer, p 9

Baum, Matthew

Water Treatment in the Cyber World…

Are You Ready? Part 5

2004 Winter, p 27

Cable, Daniel

Reinventing Employee Onboarding

2016 Spring, p 30 Business Supplement

Krenson, John

Drum Reuse—How I Turned a $25 Savings Into a $2,500 Fine

2004 Winter, p 30

Carpenter, Adam

Water and Hydraulic Fracturing

2014 Winter, p 12

MaBee, Paul

TUTOR: Galvanic Corrosion

2004 Winter, p 47

Cartwright, et al.

A New Technology for Softener Brine Recovery

2015 Summer, p 28

Wolfe, Thomas

Operation of Deaerators to Increase Boiler System Reliability

2005 Fall, p 9

Cartwright, P., et al.

Reverse Osmosis Membrane Processing: Application Insights

2015 Fall, p 41 Supplement

Farmerie, Jay

Developing a JCAHO Program and Action Manual for Legionellae

2005 Fall, p 19

Cartwright, Peter

Water Reuse with Membrane Technologies—An Update

2007 Fall, p 8

Levinger, Joe

Creating a Great Water Treatment Web Site

2005 Fall, p 27

Cartwright, Peter

Membrane Treatment Technology for Water Reuse

2011 Fall, p 27 Supplement

Nowosielski, Marek

On-Site Chlorine Dioxide: A Review of 2005 Fall, p 39 Uses, Safety and New Processes—Part I

Cartwright, Peter

Pretreatment Technologies for Reverse Osmosis and Nanofiltration

2012 Summer, p 22

AWT Staff

Education & Certification Corner

2005 Fall, p 48

Cashion, Robert

Neutralization and Destabilization of Heavy Metals in the Metal Finishing Industry

2000 Fall, p 16

Saita, Anne

Disaster Preparedness: Staying Up While Everything Else Is Down

2005 Fall, p 51

Cashion, Robert

How to Read MSDS Sheets

2001 Winter, p 29

Marynchak, Terry

It Is That Time Again—Filing Your Tax Return

2005 Fall, p 61

Cavano, Lee

Understanding Proper Shipping Names

2001 Summer, p 29

McIntyre, et al.

Metallurgical Examination of Cooling Water Equipment Failures

2005 Spring, p 9

Cavano, Lee A.,

Return Line Treatments Meeting Shipping and Storage Requirements

2012 Winter, p 33

Scott, P.J.B.

Expert Consensus on MIC - Prevention and Monitoring, Part 2

2005 Spring, p 27

Cavano, Robert

Phosphate Testing for Cooling Waters

2006 Summer, p 33

13

the Analyst Volume 24 Number 4

AWT Analyst Index continued

By Issue

By Author

Name

Title

Year, Issue

Name

Title

Year, Issue

Vogt, Peter

Tolyltriazole—Myth and Misconceptions

2005 Spring, p 35

Concentration and Feeding

2007 Winter, p 37

Cavano, Robert

AWT Staff

TUTOR: Clean Up That Cooling Tower

2005 Spring, p 43

Cavano, Robert

Cooling Water Treatments—Part I

2008 Winter, p 20

Marynchek, Terry

The World of REITs—Real Estate Investment Trust

2005 Spring, p 47

Cavano, Robert

Developing Cooling Water Treatments—Part II

2008 Spring, p 31

AWT Staff

Education & Certification Corner

2005 Spring, p 50

Cavano, Robert

Phosphonates as Calcium Carbonate Control Agents

2002 Spring, p 9

Scott, Mike

What’s in Your Tolbox? Test Methods for Industrial Water Analysis

2005 Summer, p 9

Cavano, Robert

Developing Cooling Water Treatments—Part III

2008 Summer, p 31

Garcia, Garret

Phosphonate Testing and Analysis

2005 Summer, p 19

Cavano, Robert

Developing Cooling Water Treatments—Part IV

2008 Fall, p 21

Vanderpool, Dan

Calculating Minimum Threshold Inhibitor Dosage

2005 Summer, p 25

Cavano, Robert

OPINION: Green Is With Us

2008 Fall Green Supp., p 38

AWT Staff

Education & Certification Corner

2005 Summer, p 41

Cavano, Robert

Millennium Plus Cooling Water Treatment: A First Decent Report and Urgent Summons

2010 Winter, p 20

Kelly, Doug

How to Learn Biofilm Information by Monitoring the Water

2005 Summer, p 41

Cavano, Robert

Wading Through The Swamp: Differing Choices of Cooling Water Scale Inhibitors—Part I

2011 Spring, p 10

Scott, P.J.B.

Expert Consensus on MIC— Prevention and Monitoring, Part 1

2005 Winter, p 9

Cavano, Robert

Wading Through The Swamp: Differing Choices of Cooling Water Scale Inhibitors—Part II

2011 Summer, p 18

Amjad, Zahid

Factors Influencing the Precipitation of Calcium-Inhibitor Salts in Industrial Water Systems

2005 Winter, p 19

CDC

Legionnaires’ Disease—Facts and Frequently Asked Questions

2013 Fall, p 8 Supplement

Oxford, Ann

An Overview of FIFRA: Regulating the Manufacturing, Sales, and Application of Biocides

2005 Winter, p 35

CDC

CDC Procedure for Cleaning Towers Infected with Legionella

2013 Fall, p 12 Supplement

Scott, James

TUTOR: Uncovering the Secret of Testing Low Hardness Water

2005 Winter, p 48

CDC

New Vital Signs Report: Legionnaires’ Disease on the Rise

2017 Fall, p 8 Supplement

Scholnick, Michael

Reducing Fuel Cost in a SteamGenerating System, a Review

2006 Fall, p 8

Chrisophersen, David

Reverse Osmosis for Boiler Water Makeup

2010 Spring, p 21 Supplement

Rey, Susan, et al.

Molybdate and Non-Molybdate Options for Closed Systems—Part II

2006 Fall, p 17

Christopherson, D

Flotation, Dissolved Air Flotation, Induced Air Flotation and Suspended Air Flotation

2009 Spring, p 34

Kiser, Phil

Monitoring Cooling Water For Potential Reuse—Part II

2006 Fall, p 39

Christopherson, D

Boiler Water Treatment Chemicals, Feed, and Control-Perhaps It Is More Complicated…

2013 Fall, p 10

Marynchak, Terry

Retiring Comfortably—Part II

2006 Fall, p 76

Christopherson, et al.

Copper Removal from Cooling Tower Blowdowns

2007 Winter, p 21

Brugman, Helmut

Corrosion and Microbiological Control in Firewater Sprinkler Systems

2006 Spring, p 9

Clark, Don

How Sensor and Gauge Accuracy Impact Chiller Efficiency

2008 Spring, p 8

Amjad, Zahid

The Use of Polymers to Improve Control of CaCO3 Scaling in High Stress Cooling Water Systems—Part II

2006 Spring, p 19

Cleveland & Walsh Water Treatment Contracts from a Risk Management Perspective

2016 Spring, p 37 Business Supplement

Nowosielski, Marek

On-Site Chlorine Dioxide: A Review of Uses, Safety and New Processes—Part III

2006 Spring, p 29

Cleveland, Donald

Why Do Water Treaters Need Insurance?

2015 Winter, p35

Scott, James

Controlling Your Cooling Tower

2006 Spring, p 36

Conner, Cheryl

Mentally Strong People: The 13 Things They Avoid

2017 Spring, p 16 Business Supplement

DeVaul, Randy

Workers’ Compensation Benefits: Improving Everyone’s Recovery

2006 Spring, p 61

Cook, Dan

How Green Is Your Cooling System

2008 Fall Green Supplement, p 29

Marynchak, Terry

Retiring Comfortably—Part I

2006 Spring, p 65

Corbin, Brian

Microbiological Control in Industrial Cooling Towers

2017 Winter, p 26

Elliott, Peter

Fight Formicary Corrosion

2006 Summer, p 9

Cotton & Hollander

Boiler Systems: Design and Classification—Part 1

2002 Fall, p 9

Kiser, Phil

Monitoring Cooling Water For Potential Reuse

2006 Summer, p 14

Cotton & Hollander

Boiler Systems: Chemical Treatment— Part 3

2003 Spring, p 26

Rey, Susan, et al.

Molybdate and Non-Molybdate Options for Closed Systems—Part I

2006 Summer, p 21

Cotton & Hollander

Boiler Systems: Components—Part 2

2003 Winter, p 9

Cavano, Robert

Phosphate Testing for Cooling Waters

2006 Summer, p 33

Coughlin, Michael

Sampling Strategies and Test Methods for Detection of Legionella in Potable Water Systems

2017 Fall, p 10 Supplement

Boffardi, Bennett

TUTOR: Why Does A Closed System Nees A Filter?

2006 Summer, p 55

Coutu, Diane

How Relience Works

2017 Spring, p 8 Business Supplement

Amjad, Zahid

The Use of Polymers to Improve Control of CaCO3 Scaling in High Stress Cooling Water Systems—Part II

2006 Winter, p 9

Daniels and Selby

Biofouling Control Options for Cooling Systems—Part I

2009 Spring, p 12

14

the Analyst Volume 24 Number 4

AWT Analyst Index continued

By Issue

By Author

Name

Title

Year, Issue

Name

Title

Year, Issue

Davenport, Ken

Effective Microbial Monitoring Systems

2006 Winter, p 15

Daniels and Selby

Biofouling Control Options for Cooling Systems—Part II

2009 Summer, p 22

Nowosielski, Marek

On-Site Chlorine Dioxide: A Review of Uses, Safety and New Processes—Part II

2006 Winter, p 19

Daniels, David

Using Guidelines to Develop Optimum Steam Chemistry Limits HRS

2016 Fall, p10

Bosscher, Jamie

TUTOR: Errors in ATP Testing and Reproducability

2006 Winter, p 35

Daniels, David G.

Taming Condenser Tube Leak: Common Condenser Tube Failure Mechanisms

2012 Fall, p 21

Cartwright, Peter

Water Reuse with Membrane Technologies—An Update

2007 Fall, p 8

Dargahi, M, et al.

Green Chemistry—Purfied Tannin Molecules for the Protection of Low CS Closed-Loop Systems

2015 Winter, p22

Amjad, Zahid

The Impact of Thermal Stability on the Performance of Polymeric Dispersants for Boiler Water Systems

2007 Fall, p 20

Davenport, Ken

Effective Microbial Monitoring Systems

2006 Winter, p 15

Nalepa, Christopher

Cooling Water Oxidizing Biocides: Properties and Applications—Part III

2007 Fall, p 28

Dawson, Erich

Developing Water Treatment Programs with Low Environmental Impact

2011 Summer, p 22 Supplement

Boffardi, Bennett

Potable Water Chapter for the AWT Technical Reference and Training Manual

2007 Fall, p 47

Dees & Paul

Cleaning Technique Maintaining Membrane Integrity

2014 Winter, p 22

McDonald, James

TUTOR: Boilers: Water Minimization

2007 Fall, p 69

Del Negro, A.

Peracetic Acid—A Green Cooling Water Biocide

2008 Fall Green Supplement, p 8

Lukanich, Jim

High pH Chlorination: Is Bromination an Advantage?

2007 Spring, p 8

DeVaul, Randy

Workers’ Compensation Benefits: Improving Everyone’s Recovery

2006 Spring, p 61

Vogt, Peter

Commerical Tolyltriazoles and Their Properties

2007 Spring, p 24

Dewitt-Dick, Dougles

Boiler Failure Mechanism

2003 Fall, p 17

Nalepa, Christopher

Cooling Water Oxidizing Biocides: Properties and Applications—Part I

2007 Spring, p 37

Dickinson & Wiatr

Manganese-Related Corrosion and Fouling in Water Systems

2013 Spring, p 20

UY, Mario

TUTOR: Cooling Tower Water Distribution Affects Mineral Deposits

2007 Spring, p 56

Dixit and Sharma

Biofouling and Associated Problems in Industrial Cooling Water Systems, A Case Study

2015 Summer, p 10

Berk, et al.

Occurrence of Infected Amoebae in Cooling Towers Compared with Natural Aquatic Environments

2007 Summer, p 10

Dow Chemical Co

Fundamentals of Ion Exchange

2016 Fall, p 18 Supplement

Nalepa, Christopher

Cooling Water Oxidizing Biocides: Properties and Applications—Part II

2007 Summer, p 22

Dow Chemical Co

Temperature of Dowex Ion Exchange Resins

2016 Fall, p 28 Supplement

Freedman, Len

The Rules of Good Process Monitoring

2007 Summer, p 32

Dromgoole, J.C.

Laboratory Analysis and Interpretation— 2002 Fall, p 33 Water, Resin & Deposits

McDonald, James

TUTOR: Cooling Towers: Water Minimization

2007 Summer, p 57

Drucker, Peter F.

Managing Oneself

2012 Spring, p 28 Business Supplement

Marynchak, Terry

Hidden Risks in Investment Strategies

2007 Summer, p 70

Dunler, Adam

Computerized Service Records

2015 Spring, p 29

Reggiani, Gary et al.

Trasar Technology—A Review and Comparison

2007 Winter, p 9

Elliott, Peter

Fight Formicary Corrosion

2006 Summer, p 9

Christopherson, et al.

Copper Removal from Cooling Tower Blowdowns

2007 Winter, p 21

Elliott, Peter

Corrosion in the Home

2013 Winter, p 39

Cavano, Robert

Concentration and Feeding

2007 Winter, p 37

Erickson, Donovan Evaluating Polymers and Phosphonates for Use as Inhibitors For Ca, PO4, & Fe In Steam Boilers—Part I

2003 Fall, p 11

Boffardi, Bennett

TUTOR: Cooling Tower Operation During Winter Months

2007 Winter, p 52

Erickson, Donovan Evaluating Polymers and Phosphonates for Use as Inhibitors for Ca, PO4, & Fe in Steam Boilers—Part II

2004 Winter, p 17

Del Negro, A.

Peracetic Acid—A Green Cooling Water Biocide

2008 Fall Green Supplement, p 8

Erickson, Donovan Don’t Let a Closed Loop Crash Your Treatment Program

2008 Summer, p 10

ASHRAE

ASHRAE GreenGuide

2008 Fall Green Supplement, p 15

Farmerie, James

Chemical Cleaning Assists Water Treatment Program Used for Industrial Utility Systems

2003 Fall, p 26

Keisler, T

Cooling Tower Water Management for USGBC LEED Green Building Certification

2008 Fall Green Supplement, p 19

Farmerie, Jay

Developing A JCAHO Program and Action Manual for Legionellae

2005 Fall, p 19

Boffardi, Ben

Going Green: Green Chemistry

2008 Fall Green Supplement, p 21

Farmerie, Jay

Selecting a Water Treatment Service Provider to Meet Green Technology Requirements

2008 Fall Green Supplement, p 33

Cook, Dan

How Green Is Your Cooling System

2008 Fall Green Supplement, p 29

Ferguson, Robert J.

Water Treatment Rules of Thumb: Myths 2004 Summer, or Useful Tools? p 13

Farmerie, Jay

Selecting a Water Treatment Service Provider to Meet Green Technology Requirements

2008 Fall Green Supplement, p 33

Ferguson, Robert J.

Anatomy of a Multifunctional Product

15

the Analyst Volume 24 Number 4

2008 Winter, p 10

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The IDEXX Privacy Policy is available at idexx.com.

AWT Analyst Index continued

By Issue

By Author

Name

Title

Year, Issue

Name

Title

Year, Issue

Cavano, Robert

OPINION: Green Is With Us

2008 Fall Green Supplement, p 38

Ferguson, Robert J.

pH Impact on Inhibitor Performance

2014 Summer, p 10

Ketrick, Bruce

Fuel Oil Additives and Applications— Part Il

2008 Fall, p 14

Ferguson, Robert J.

Computer Modeling of Water Chemistry

2002 Summer, p 9

Cavano, Robert

Developing Cooling Water Treatments—Part IV

2008 Fall, p 21

Ferguson, Robert J.

The Kinetics of Cooling Water Scale Formation and Control

2011 Summer, p 27

Hartford Steam Boiler

Boiler Tube Failure Handbook

2008 Fall, p 42

Fernandez-Araoz

21st Century Talent Spotting

2015 Spring, p 24 Business Supplement

AWT Tech Com

TUTOR: Boiler Pretreatment Matrix

2008 Fall, p 67

Frayne, Colin

Early Boiler Water Treatments and the Use of Tanins in Modern Day Programs

2001 Fall, p 9

Marynchak, Terry

Strategies for Investing in Uncertain Markets

2008 Fall, p 83

Frayne, Colin

The Selection and Application of NonOxidizing Biocides for Cooling Water Systems

2001 Spring, p 16

Clark, Don

How Sensor and Gauge Accuracy Impact Chiller Efficiency

2008 Spring, p 8

Frayne, Colin

Organic Water Treatment inhibitors: Myths, Disinformation & Next Generation—Part I

2009 Summer, p 31

Boffardi, Bennett

Mechanical Chillers

2008 Spring, p 18

Frayne, Colin

Organic Water Treatment inhibitors: Myths, Disinformation & Next Generation—Part II

2009 Fall, p 24

Cavano, Robert

Developing Cooling Water Treatments—Part II

2008 Spring, p 31

Frayne, Colin

The Economic and Environmental Case for Sustaining Water Management

2012 Summer, p 31

Boffardi, Bennett

TUTOR: Calculating Chiller Efficiency

2008 Spring, p 59

Frayne, Colin

A Brief Discussion on Boiler Water Treatment and the Practical Application of Phos, Chelants

2012 Fall, p 10

Erickson, Donovan

Don’t Let a Closed Loop Crash Your Treatment Program

2008 Summer, p 10

Frayne, Colin

Emerging Technologies and the Direction of the Water Treatment Industry: An Update

2013 Spring, p 8 Business Supplement

Ketrick, Bruce

Fuel Oil Additives and Applications— Part I

2008 Summer, p 22

Frayne, Colin

Effective Control of Waterside Corrosion and Heat Transfer Efficiency in Chemical Plant Cooling Systems

2015 Spring, p 10

Cavano, Robert

Developing Cooling Water Treatments—Part III

2008 Summer, p 31

Frayne, Colin

A Brief Discussion on BW Treatment: The Practical Application of Phosphates, Chelants, & Polymer

2015 Fall, p 10

Vlasblom, Jack

TUTOR: The Greening of Water Treatment and Development of Environmental Standards

2008 Summer, p 63

Frayne, Colin

The Future of Water and Treatment: Strategic Water Reuse Solutions and Energy Conservation

2016 Winter, p 10

Ferguson, Robert

Anatomy of a Multifunctional Product

2008 Winter, p 10

Freedman, Len

Computer Technology in Water Treatment: A Two Edge Sword

2002 Summer, p 30

Nalepa, Christopher

Cooling Water Oxidizing Biocides: Properties and Applications—Part IV

2008 Winter, p 18

Freedman, Len

The Rules of Good Process Monitoring

2007 Summer, p 32

Cavano, Robert

Cooling Water Treatments—Part I

2008 Winter, p 20

Freedman, Len

Basis of Statistical Process Control (SPC)

2014 Summer, p 18

McDonald, James

Boiler Inspections

2008 Winter, p 62

Freije, Mathew

New Standard Requires Legionella Management Plans for Hospitals

2001 Spring, p 33

Marynchak, Terry

It’s the Law: Changes to Pension and Tax Laws That Could Affect You

2008 Winter, p 68

Freije, Matthew

Interpreting Legionella Test Results: Case Studies Illustratig Key Criteria

2017 Fall, p 38 Supplement

Arduino, Jim

Wastewater Defoamers

2009 Fall, p 14

Friedman, Stewart

Work + Home + Community + Self

2015 Spring, p 39 Business Supplement

Frayne, Colin

Organic Water Treatment inhibitors: Myths, Disinformation & Next Generation—Part II

2009 Fall, p 24

Gandhi, Ashish

Volatile Corrosion Inhibitors—Unique Water Treatment Applications

2000 Fall, p 9

AWT Boiler Committee

Boiler Efficiencies

2009 Fall, p 35

Gannon et al.

Closed Water Systems: Relationship Between System and Microbial Growth—Part I

2013 Winter, p 21

McDonald, James

Technical Updates, Tips or Reviews— Deaeration

2009 Fall, p 66

Gannon et al.

Closed Water Systems: Relationship Between System and Microbial Growth—Part II

2013 Spring, p 12

Daniels and Selby

Biofouling Control Options for Cooling suystems—Part I

2009 Spring, p 12

Ganzer, George

Glutaraldehyde: A Versatile Microbiocide for Use in Water Treatment Applications

2001 Spring, p 23

Kouno, Kazuhito

Foulants and Cleaning Procedures for Composite Polyamide RO Membrane Elements—Part I

2009 Spring, p 24

Ganzer, George

Glutarahydle and DBNPA: An Effective Combination Treatment Program

2003 Spring, p 35

Christopherson, D

Flotation, Dissolved Air Flotation, Induced Air Flotation and Suspended Air Flotation

2009 Spring, p 34

Garcia, Garret

Phosphonate Testing and Analysis

2005 Summer, p 19

17

the Analyst Volume 24 Number 4

AWT Analyst Index continued

By Issue

By Author

Name

Title

Year, Issue

Name

Title

Year, Issue

Zupanovich, John

TUTOR: Dehalogenation of Industrial Water

2009 Spring, p 67

Glenhill, Robin

Which is the Best Choice for Your Installation—Diaphram Style or Peristaitic Style…

2014 Fall, p 34

Supplement 2009

Defining Green Chemicals

2009 Summer, p 9

Golden, Chris

Basic Calculations Necessary to Survive 2010 Spring, p 13 in the Field—Part I: Cooling Water

Supplement 2009

Sustainable Water Systems

2009 Summer, p 11

Golden, Chris

Basic Calculations Necessary to Survive 2010 Summer, in the Field—Part II: Pretreatment p 22

Simpson & Miller

Control of Biofilm with Chlorine Dioxide

2009 Summer, p 12

Golden, Chris

Basic Calculations Necessary to Survive 2010 Fall, p 22 in the Field—Part III: Boiler Water

Supplement 2009

Energy Star Heating and Cooling Upgrades and Survey

2009 Summer, p 15

Golden, Chris

AWT RO Workbook

2015 Fall, p 46 Supplement

Daniels and Selby

Biofouling Control Options for Cooling Systems—Part II

2009 Summer, p 22

Goleman & Boyatzis

Emotional Inteligence Has 12 Elements: Which Do You Need to Work On?

2017 Spring, p 24 Business Supplement

Supplement 2009

Energy Star Heating and Cooling Upgrades and Survey—Rightsizing System

2009 Summer, p 29

Goleman, Daniel

What Makes a Leader?

2013 Spring, p 31 Business Supplement

Frayne, Colin

Organic Water Treatment inhibitors: Myths, Disinformation & Next Generation—Part I

2009 Summer, p 31

Goulah, Christopher

Isolatiion of Legionella From Environmental Samples: CDC vs. ISO

2017 Fall, p 34 Supplement

Boffardi, Bennett

TUTOR: Cathodic Protection

2009 Summer, p 66

Greenlimb, et al.

Boiler and Condensate System Energy Calculation Workbook

2016 Fall, p22

Walter, R., Relenyi, A

Application of DBNPA and Glutaraldehyde as Biocides for Treatment and Control of Microbiological

2009 Winter p 37

Groysberg, Boris

Leadership Is a Conversation

2016 Spring, p 24 Business Supplement

Webb, D, et al.

A Multiyear Comparison Reiew of the Use of Cu-Ag Ionization and ClO2 to Contol Legionella

2009 Winter, p 12

Groysburg and Abramham

Manage Your Work, Manage Your Life

2014 Spring, p 8 Business Supplement

Kouno, Kazuhito

Foulants and Cleaning Procedures for Composite Polyamide RO Membrane Elements—Part I

2009 Winter, p 28

Hamill, Sean

Did Bias Skew the CDC’s Pittsburgh VA Legionnaires’ Report?

2017 Winter, p 50

McDonald, James

TUTOR: Condensate Values

2009 Winter, p 67

Hartford Steam Boiler

Boiler Tube Failure Handbook

2008 Fall, p 42

Kleve, Stephen

Boiler Inspection and Maintenance

2010 Fall, p 10

Hater, Wolfgang

Film-Forming Amines: An Innovative Technology for Boiler Water Treatment

2015 Fall, p 22

AWT Green Task Force

Cooling Water Management

2010 Fall, p 12, Supplement

Havashi, Aiden

Thriving in a Big Data World

2015 Spring, p 34 Business Supplement

Lewis, Mark T

Remote Visual Inspection

2010 Fall, p 16

Haynor, Kerry

Reactive Metals in Chemical Water Treatment

2010 Spring, p 65

Whitson, et al.

179D Tax Saving Article

2010 Fall, p 17, Supplement

Henke, Larry

Principles of Filtration: How Do Filters Filter Anyway?

2015 Summer, p 33

Golden, Chris

Basic Calculations Necessary to Survive 2010 Fall, p 22 in the Field—Part III: Boiler Water

Hennessy, Thomas

Theory of Water Clarification

2004 Winter, p 9

International SS Forum

Cooling With Heat: A Case Study About Solar Cooling

2010 Fall, p 23, Supplement

Herbst, Kent

DBNPA: Modeling Effective and Environmentally Acceptable Applications

2010 Spring, p 44 Supplement

Simpson, Greg

Treatment of Cooling Systems with ClO2

2010 Fall, p 8, Supplement

Heyl Brothers

Phophate Hideout, What Is It?

2017 Fall, p 64

Boffardi, Bennett

Corrosion and Fouling Monitoring of Water Systems

2010 Spring, p 8 Supplement

Highum, Michael

Understanding Risk & Insurance Maximizing Your Protection Appropriately in Today’s Business Environment

2012 Spring, p 16 Business Supplement

Golden, Chris

Basic Calculations Necessary to Survive 2010 Spring, p 13 in the Field—Part I: Cooling Water

Hockworth, Scott

The Improved Financial Health of Water Treatment Companies Since the Great Recession

2017 Summer, p 34

Chrisophersen, David

Reverse Osmosis for Boiler Water Makeup

2010 Spring, p 21 Supplement

Hopkins, et al

OSHA Hazard Communication Update

2013 Summer, p 35

Williams, Terry

The Mechanism of Action of Isothiazolone Biocides

2010 Spring, p 22

Hydrolic Institute

Pumps—Parts I-V

2014 Fall, p 8 Supplement

Sweeny, & Lammaring

Bardac LF 18—a Novel Cooling Water Algaecide

2010 Spring, p 34

Hyland, Bill

Odor Control in Collections

2013 Fall, p 29

O’Neal, Jeff

Online Monitoring of Biofilm in Cooling Tower Systems

2010 Spring, p 36 Supplement

Ibarra, Herinia

The Authenticity Paradox

2015 Spring, p17 Business Supplement

Herbst, Kent

DBNPA: Modeling Effective and Environmentally Acceptable Applications

2010 Spring, p 44 Supplement

International SS Forum

Cooling With Heat: A Case Study About Solar Cooling

2013 Summer, p 37

18

the Analyst Volume 24 Number 4

AWT Analyst Index continued

By Issue

By Author

Name

Title

Year, Issue

Name

Title

Year, Issue

Albao, Jed

Do “IT” Yourself—Wireless Internet Process Communication

2010 Spring, p 48 Supplement

Jaffer, Arif

Chemical Cleaning of an Industrial Boiler—An Overview

2004 Fall, p 9

Haynor, Kerry

Reactive Metals in Chemical Water Treatment

2010 Spring, p 65

Janikowski, Daniel

Condenser Tube Failure Mechanisms

2013 Summer, p 12

Sinha, Ashwini

Cleaning and Control of Fouling of High-Efficiency PVC Film Type CT Fills at Industrial Plants

2010 Summer, p 10

Johnson, Charles T.

The Control of pH and Oxidation Reduction Potential (ORP) in Cooling Tower Applications

2002 Spring, p 25

Golden, Chris

Basic Calculations Necessary to Survive 2010 Summer, in the Field—Part II: Pretreatment p 22

Johnson, Jeff

Chaising Methane

2014 Winter, p 18

Whalen, Razban, Roy

Water Treatment Battles with the Microbes—Knowing the Enemy

2010 Summer, p 33

Josowitz, et al.

PerQuat Technology: Enhanced Bio & Biofilm Removal Agent for CW

2011 Spring, p 26

Preising, Kevin

Save $91,000 Annually in LP WT Chemical and Fuel Costs Using a Dealkalizer

2010 Winter, p 12

Juhl, Mark

The Solid Marketplace Trives in The New Millineum

2001 Fall, p 27

Cavano, Robert

Millennium Plus Cooling Water Treatment: A First Decent Report and Urgent Summons

2010 Winter, p 20

Kaffer, Nancy

Why Did’t Flint Treat Its Water? An Answer at Last

2016 Summe, p 47

AWT

AWT Boiler Water Pretreatment Matrix

2010 Winter, p 32

Kaplan & Kaiser

Developing Versatile Leadership

2015 Spring, p 6 Business Supplement

AWT

TUTOR: AWT BW Committee–Sodium Zeolite Water Softener Calculations

2010 Winter, p 56

Kasinecz, Frank

Diethylhydroxylamine (DEHA), A Volatile 2001 Fall, p 17 Oxygen Scavenger For Boiler System Treatment

Amjad and Zuhl

Effects of Thermal Stress on SilicaSilicate Deposit Control Agent Performance—Part I

2011 Fall, p 10

Kaufman, Ron

How to Change Company Culture With Rewards

2014 Spring, p 35 Business Supplement

Aydlett, Neil

Chemical Processing: Using Voice Over IP in Today’s Business World

2011 Fall, p 17 Supplement

Keane, Tim

Chlorine Dioxide (Cl2)—Why All the Commotion?

2000 Spring, p 9

Martyak, Nicholas

On the Basicity of Neutralizing Amines—Part I: Review of Amine Basicity

2011 Fall, p 21

Keisler, Timothy

Cooling Tower Water Management for USGBC LEED Green Building Certification

2008 Fall Green Supplement, p 19

Moir, Bill

Department of Energy Software Tools to Improve Steam Efficiency

2011 Fall, p 21 Supplement

Keister, et al.

Cooling Tower System Design and Operation

2016 Spring, p 26

Cartwright, Peter

Membrane Treatment Technology for Water Reuse

2011 Fall, p 27 Supplement

Keister, Timothy

Cooling Tower Sidestream Filtration: A Green, Proven Cost Reduction Technology

2012 Spring, p 37

Michaud, C.F.

Improving Softening Efficiency From the Bottom Up

2011 Fall, p 30

Kelly, Doug

How to Learn Biofilm Information by Monitoring the Water

2005 Summer, p 41

Monjoie, Michel

Cooling Tower Fill Technology for Fouling—Scale Resistance

2011 Fall, p 35 Supplement

Ketrick, Bruce

Fuel Oil Additives and Applications— Part I

2008 Summer, p 22

AWT

Plant Operators’ References: Some Useful Tools

2011 Fall, p 8 Supplement

Ketrick, Bruce

Fuel Oil Additives and Applications— Part Il

2008 Fall, p 14

Cavano, Robert

Wading Through the Swamp: Differing Choices of Cooling Water Scale Inhibitors—Part I

2011 Spring, p 10

Kiser, Phil

Monitoring Cooling Water for Potential Reuse

2006 Summer, p 14

Vondra, Kroeger

Patriot Renewable Fuels Implements: Zero Liquid Discharge (ZLD)

2011 Spring, p 20

Kiser, Phil

Monitoring Cooling Water For Potential Reuse—Part II

2006 Fall, p 39

Josowitz, et al.

PerQuat Technology: Enhanced Bio & Biofilm Removal Agent for CW

2011 Spring, p 26

Kleve, Stephen

Boiler Inspection and Maintenance

2010 Fall, p 10

Wilson, Alex

Chill Factor: Utilizing Ice-Based Thermal Energy Storage to Cool Building Makes

2011 Summer, p 8 Supplement

Kouno, Kazuhito

Foulants and Cleaning Procedures for Composite Polyamide RO Membrane Elements—Part I

2009 Winter, p 28

Bertasi and Cope

Oil Removal

2011 Summer, p 10

Kouno, Kazuhito

Foulants and Cleaning Procedures for Composite Polyamide RO Membrane Elements—Part II

2009 Spring, p 24

Wilson, Alex

Three R’s of Sustainable Water Cooled Systems Operation

2011 Summer, p 13 Supplement

Krenson, John

Drum Reuse—How I Turned a $25 Savings Into a $2,500 Fine

2004 Winter, p 30

Cavano, Robert

Wading Through the Swamp: Differing Choices of Cooling Water Scale Inhibitors—Part II

2011 Summer, p 18

Kucera, Jane

Reverse Osmosis Operations

2015 Fall, p 14 Supplement

Dawson, Erich

Developing Water Treatment Programs with Low Environmental Impact

2011 Summer, p 22 Supplement

LaBrosse & Ereckson

The Pursuit of a Green Carbon Steel Corrosion Inhibitor

2015 Fall, p 14 Supplement

Ferguson, Robert J.

The Kinetics of Cooling Water Scale Formation and Control

2011 Summer, p 27

LaBrosse & Erickson

Pilot Research to Determine Effictive Aluminum Corrosion Inhibition

2017 Summer, p 22

AWT Staff

TUTOR: Cooling System Dynamics

2011 Summer, p 73

LaBrosse, M., et al. Use of Pilot Testing in Selecting an Effective Reverse Osmosis Scale Inhibitor

2015 Fall, p 33 Supplement

Wirth, Matthew

It’s Tough Being a Resin Bead

2011 Winter, p 10

Lampson, Marshall Polyethylene Chemical Storage Vessels

2002 Winter, p 9

19

the Analyst Volume 24 Number 4

AWT Analyst Index continued

By Issue

By Author

Name

Title

Year, Issue

Name

Title

Year, Issue

Michaud, C.F.

“Zero-D”—A Method of Reducing Industrial Softener Discharge

2011 Winter, p 20

Lassing, Ryan

A Primer: Reverse Osmosis

2015 Fall, p 8 Supplement

Perry, Phillip M.

Selling to Uncle Sam

2011 Winter, p 28

Latzer, Kenn

The Importance of Side Stream Filtration in Water and Energy Conservation

2001 Summer, p 21

Puckorius, Paul

MIC and More Than MIC in CT Water Systems—Know What You Are Dealing With

2012 Fall, p 9 Technical Supplement

Levinger, Joe

Creating a Great Water Treatment Web Site

2005 Fall, p 27

Frayne, Colin

A Brief Discussion on Boiler Water Treatment and the Practical Application of Phos, Chelants

2012 Fall, p 10

Lewis, Mark T

Remote Visual Inspection

2010 Fall, p 16

LaBrosse & Ereckson

The Pursuit of a Green Carbon Steel Corrosion Inhibitor

2012 Fall, p 19 Technical Supplement

Lukanich, Jim

High pH Chlorination: Is Bromination an Advantage?

2007 Spring, p 8

Daniels, David G.

Taming Condenser Tube Leak: Common Condenser Tube Failure Mechanisms

2012 Fall, p 21

MaBee, Paul

TUTOR: Galvanic Corrosion

2004 Winter, p 47

AWT BW Committee

Boiler Water Treatment Chemical Guidelines—Part I

2012 Fall, p 29

Mahal, Gurdeep

Three Benefits of ISO 9001 Cetification for Small Businesses

2017 Spring, p 33 Business Supplement

McDonald, James

Saving Boiler Fuel

2012 Fall, p 68

Mankins & Steele

Turning Great Strategy Into Great Performances

2014 Spring, p 17 Business Supplement

McCoy and Pearson

ASHRAE Standard 188P: Prevention of Legionellosis Associated with Building Water Systems

2012 Spring, p 10

Martyak, Nicholas

On the Basicity of Neutralizing Amines—Part I: Review of Amine Basicity

2011 Fall, p 21

Highum, Michael

Understanding Risk & Insurance Maximizing Your Protection Appropriately in Today’s Business Environment

2012 Spring, p 16 Business Supplement

Martyak, Nicholas

On the Basicity of Neutralizing Amines—Part II: Electron Donating and Withdrawing Factors

2012 Winter, p 10

Burgess, John

Hiring for Success

2012 Spring, p 23 Business Supplement

Martyak, Nickolas

On the Hydration of Amines and Basicity

2013 Fall, p 23

Pitochelli, A. R.

Odor Reduction by Chemical Oxidation

2012 Spring, p 25

Marynchak, Terry

The 529 Plan—Finding A Way to Fund a 2003 Fall, p 48 College Education

Drucker, Peter F.

Managing Oneself

2012 Spring, p 28 Business Supplement

Marynchak, Terry

Alphabet Soup—Deciphering the Letters Behind the Financial Professional

2003 Summer, p 46

Keister, Timothy

Cooling Tower Sidestream Filtration: A Green, Proven Cost Reduction Technology

2012 Spring, p 37

Marynchak, Terry

It Is That Time Again—Filing Your Tax Return

2005 Fall, p 61

Standish, Michael

Understanding Options to Overcome Harvest Pressures for AWT Businesses

2012 Spring, p 8 Business Supplement

Marynchak, Terry

Retiring Comfortably—Part I

2006 Spring, p 65

AWT Pretreetment Pretreatment Water Analysis Tips & Recommendations

2012 Summer, p 10

Marynchak, Terry

Retiring Comfortably—Part II

2006 Fall, p 76

Cartwright, Peter

Pretreatment Technologies for Reverse Osmosis and Nanofiltration

2012 Summer, p 22

Marynchak, Terry

Hidden Risks in Investment Strageties

2007 Summer, p 70

Frayne, Colin

The Economic and Environmental Case for Sustaining Water Management

2012 Summer, p 31

Marynchak, Terry

Strategies for Investing in Uncertain Markets

2008 Fall, p 83

McDonald, James

TUTOR: Using RO for Boiler Pretreatment

2012 Summer, p 64

Marynchek, Terry

Everything You Ever Wanted to Know About Annuities…and More!

2004 Fall, p 59

Martyak, Nicholas

On the Basicity of Neutralizing Amines—Part II: Electron Donating and Withdrawing Factors

2012 Winter, p 10

Marynchek, Terry

The IRA That No One Talks About-The Roth IRA

2004 Spring, p 42

Wirth Matthew

How Fast Can Ew Run? Ion Exchange Reaction Zones

2012 Winter, p 18

Marynchek, Terry

The World of REITs—Real Estate Investment Trust

2005 Spring, p 47

Amjad and Zuhl

Effects of Thermal Stress on SilicaSilicate Deposit Control Agent Performance—Part II

2012 Winter, p 25

McCoy & Leonidas Validation of Hazard Control in Building Water Systems

2013 Fall, p 15 Supplement

Cavano, Lee A.,

Return Line Treatments Meeting Shipping and Storage Requirements

2012 Winter, p 33

McCoy and Pearson

ASHRAE Standard 188P: Prevention of Legionellosis Assocoated with Building Water Systems

2012 Spring, p 10

CDC

Legionnaires’ Disease—Facts and Frequently Asked Questions

2013 Fall, p 8 Supplement

McDonald, James

Using Spreadsheets to Better Serve Your Customers

2002 Summer, p 61

Christopherson, D

Boiler Water Treatment Chemicals, Feed, and Control—Perhaps It Is More Complicated…

2013 Fall, p 10

McDonald, James

TUTOR: Condensate Problem Solving

2003 Fall, p 40

20

the Analyst Volume 24 Number 4

AWT Analyst Index continued

By Issue

By Author

Name

Title

Year, Issue

Name

Title

Year, Issue

CDC

CDC Procedure for Cleaning Towers Infected with Legionella

2013 Fall, p 12 Supplement

McDonald, James

Using Reverse Osmosis for Boiler Pretretment

2003 Summer, p 51

McCoy & Leonidas

Validation of Hazard Control in Building Water Systems

2013 Fall, p 15 Supplement

McDonald, James

TUTOR: Cooling Towers: Water Minimization

2007 Summer, p 57

Stout, Janet E.

Study Demonstrates New Monochloroamine System Effective in Controlling Legionella…

2013 Fall, p 22 Supplement

McDonald, James

TUTOR: Boilers: Water Minimization

2007 Fall, p 69

Martyak, Nickolas

On the Hydration of Amines and Basicity

2013 Fall, p 23

McDonald, James

Boiler Inspections

2008 Winter, p 62

Scott, James

Legionellosis Is Not the Killer It’s Thought to Be!

2013 Fall, p 24 Supplement

McDonald, James

TUTOR: Condensate Values

2009 Winter, p 67

Hyland, Bill

Odor Control in Collections

2013 Fall, p 29

McDonald, James

TUTOR: Deaeration

2009 Fall, p 66

Tracey et al.

Preventive Control of Legionella Through Real-Time Bioburden Testing

2013 Fall, p 30 Supplement

McDonald, James

TUTOR: Using RO for Boiler Pretreatment

2012 Summer, p 64

Boffardi & Hannigan

A Limited Evaluation of Pitting Corrosion of Cu Piping in a Hospital Domestic Hot Water System

2013 Fall, p 38 Supplement

McDonald, James

Saving Boiler Fuel

2012 Fall, p 68

Gannon et al.

Closed Water Systems: Relationship Between System and Microbial Growth—Part II

2013 Spring, p 12

McDonald, et al.

TUTOR: Reducing RO Membrane Fouling With Good CIP Procedures— Part I

2014 Winter, p 59

Williams & Miller

Change the Way You Persuade

2013 Spring, p 18 Business Supplement

McDowell, Bill

Peristaltic Pumps Wear Factors

2014 Fall, p 10

Dickinson & Wiatr,

Manganese-Related Corrosion and Fouling in Water Systems

2013 Spring, p 20

McInnis, C, et al.

Monitoring and Controlling Biofilm in Industrial and Commerical Cooling Water Systems

2014 Summer, p 25

Weiss, Scott

Generation Gap: How Technology Has Changed How We Talk About Work

2013 Spring, p 28 Business Supplement

McIntyre, et al.

Metallurgical Examination of Cooling Water Equipment Failures

2005 Spring, p 9

Goleman, Daniel

What Makes a Leader?

2013 Spring, p 31 Business Supplement

McPherson, Lori

Understanding Oxidation Reduction Potential (ORP) Systems

2002 Spring, p 31

Walter, R.

Testing Methods to Diagnose Micro-Bio Problems and Determine if Remedial Action Is Effective

2013 Spring, p 37

McPherson, Lori

Automatic Temperature Compensation for Your Boiler Controller

2000 Fall, p 20

Nalco

TUTOR: Cooling Tower Inspection

2013 Spring, p 65

McWhorter, Tom

Chlorine Dioxide for Control and Prevention of Biofilm and Legionella

2017 Fall, p 46 Supplement

Frayne, Colin

Emerging Technologies and the Direction of the Water Treatment Industry: An Update

2013 Spring, p 8 Business Supplement

Meitz, Amanda

What Is This Stuff?

Spring 2017, p 26

Janikowski, Daniel

Condenser Tube Failure Mechanisms

2013 Summer, p 12

Michaud, C.F.

“Zero-D”—A Method of Reducing Industrial Softener Discharge

2011 Winter, p 20

Poppe, Gregg

Maximizing the Life & Performance of RO Membranes in Industrial Water Purification Systems

2013 Summer, p 23

Michaud, C.F.

Improving Softening Efficiency From the Bottom Up

2011 Fall, p 30

Amjad, Z., Zuhl, R.

Water Treater Deposit Control Polymer Evaluation Criteria and Considerations

2013 Summer, p 29

Miskowski, Diane

NYS & NYC CT Regulations: Are They Enough to Prevent Cases of Legionnaires’ Disease

2017 Fall, p 28 Supplement

Hopkins, et al

OSHA Hazard Communication Update

2013 Summer, p 37

Moffet, Lora

What Should Be Part of Your Branding Repository?

2014 Spring, p 15 Business Supplement

AWT BW Committee

Boiler Water Treatment Chemical Guidelines—Part II

2013 Winter, p 10

Moir, Bill

Department of Energy Software Tools to Improve Steam Efficiency

2011 Fall, p 21 Supplement

Gannon, et al.

Closed Water Systems: Relationship Between System and Microbial Growth

2013 Winter, p 21

Monjoie, Michel

Cooling Tower Fill Technology For Fouling—Scale Resistance

2011 Fall, p 35 Supplement

Rekalake, Heather ORP vs. Free Chlorine: What ORP Is and When and How to Use It Instead of Free Chlorine

2013 Winter, p 31

Mukiibim Mo

Reverse Osmosis: Opportunities and Challengers

2015 Fall, p 26 Supplement

Elliott, Peter

Corrosion in the Home

2013 Winter, p 39

Nalco

TUTOR: Cooling Tower Inspection

2013 Spring, p 65

Whalen, Pat

TUTOR: 2nd Generation ATP Testing: Reliable On-the-Spot Microbiological Monitoring…

2013 Winter, p 62

Nalepa, Chris J.

Oxidizing Biocides: Properties and Applications

2000 Spring, p 15

Hydrolic Institute

Pumps—Parts I–V

2014 Fall, p 8 Supplement

Nalepa, Christopher

Cooling Water Oxidizing Biocides: Properties and Applications—Part I

2007 Spring, p 37

McDowell, Bill

Peristaltic Pumps Wear Factors

2014 Fall, p 10

Nalepa, Christopher

Cooling Water Oxidizing Biocides: Properties and Applications—Part II

2007 Summer, p 22

Bloch, Heinz

Avoiding Repeat Pump Failure

2014 Fall, p 20

Nalepa, Christopher

Cooling Water Oxidizing Biocides: Properties and Applications—Part III

2007 Fall, p 28

21

the Analyst Volume 24 Number 4

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9/11/17 4:05 PM

AWT Analyst Index continued

By Issue

By Author

Name

Title

Year, Issue

Name

Title

Year, Issue

Uribe, Carlos

Intelligent Metering Control Systems

2014 Fall, p 28

Nalepa, Christopher

Cooling Water Oxidizing Biocides: Properties and Applications—Part IV

2008 Winter, p 18

Glenhill, Robin

Which Is the Best Choice for Your Installation—Diaphram Style or Peristaitic Style…

2014 Fall, p 34

Ning, Robert

Sustaining the Properties of Reverse Osmosis Plants

2004 Fall, p 29

Pescatore, Stephen

TUTOR: Low Temperature Heat Transfer 2014 Fall, p 57 Fluids—Part II

Nogle, Christopher

Beyond Laboratory Research on White Rust and Passivation

2017 Summer, p 10

Groysburg and Abramham

Manage Your Work, Manage Your Life

2014 Spring, p 8 Business Supplement

Nowosielski, Marek

On-Site Chlorine Dioxide: A Review of 2005 Fall, p 39 Uses, Safety and New Processes—Part I

AWT Pretreatment Dionizatin: Parts I & II Subcommittee

2014 Spring, p 10

Nowosielski, Marek

On-Site Chlorine Dioxide: A Review of Uses, Safety and New Processes—Part III

2006 Spring, p 29

Moffet, Lora

What Should Be Part of Your Branding Repository?

2014 Spring, p 15 Business Supplement

Nowosielski, Marek

On-Site Chlorine Dioxide: A Review of Uses, Safety and New Processes—Part II

2006 Winter, p 19

Mankins & Steele

Turning Great Strategy Into Great Performances

2014 Spring, p 17 Business Supplement

O’Neal, Jeff

The Evolution of Chemical Metering Technology

2000 Summer, p 15

Rosenzweig, Phil

The Benefits—and Limits—of Decision Models

2014 Spring, p 29 Business Supplement

O’Neal, Jeff

Online Monitoring of Biofilm in Cooling Tower Systems

2010 Spring, p 36 Supplement

Wojtowicz, John

Calculation of Aqueous CaCO3 Scaling Potential Via a Modified Langelier Equation

2014 Spring, p 30

Oxford, Ann

An Overview of FIFRA: Regulating the Manufacturing, Sales, and Application of Biocides

2005 Winter, p 35

Kaufman, Ron

How to Change Company Culture With Rewards

2014 Spring, p 35 Business Supplement

Pascatore, Stephen

Low Temperature Heat Transfer Fluids Glycol Degradation

2015 Summer, p 49

Pescatore, Stephen

Glycol Tidbits—Degradation

2014 Spring, p 38

Paul, David

Five Tips for Effective Reverse Osmosis Chemical Cleaning

2015 Fall, p 48 Supplement

Ferguson, Robert

pH Impact on Inhibitor Performance

2014 Summer, p 10

Paul, David H.

The Four Most Common Problems in Membrane Water Treatment Today

2003 Winter, p 21

Freedman, Len

Basis of Statistical Process Control (SPC)

2014 Summer, p 18

Perry, Chuck

Metals Removal

2004 Summer, p 25

McInnis, C, et al.

Monitoring and Controling Biofilm in Industrial and Commerical Cooling Water Systems

2014 Summer, p 25

Perry, Phillip M.

Selling to Uncle Sam

2011 Winter, p28

Pescatore, Stephen

TUTOR: Low Temperature Heat Transfer 2014 Summer, Fluids—Part I p 57

Pescatore, Stephen

Which to Use: Ethyl Glycol or Propylene Glycol

2003 Summer, p 13

Carpenter, Adam

Water and Hydraulic Fracturing

2014 Winter, p 12

Pescatore, Stephen

Glycol Tidbits—Degradation

2014 Spring, p 38

Johnson, Jeff

Chasing Methane

2014 Winter, p 18

Pescatore, Stephen

TUTOR: Low Temperature Heat Transfer 2014 Summer, Fluids—Part I p 57

Dees & Paul

Cleaning Technique Maintaining Membrane Integrity

2014 Winter, p 22

Pescatore, Stephen

TUTOR: Low Temperature Heat Transfer 2014 Fall p 57 Fluids—Part II

Bardsley, Judy

Polymeric Scale Inhibitors for Reverse Osmosis Systems

2014 Winter, p 26

Pescatore, Stephen

Low-Temperature Heat Transfer Fluids

2015 Winter, p 29

McDonals et al

TUTOR: Reducing RO Membrane Fouling With Good CIP Procedures— Part I

2014 Winter, p 59

Pescatore, Stephen

Low-Temperature Heat Transfer Fluids

2015 Spring, p39

Frayne, Colin

A Brief Discussion on BW Treatment: The Practical Application of Phosphates, Chelants, & Polymer

2015 Fall, p 10

Pescatore, Stephen

Low-Temperature Heat Transfer Fluid

2015 Fall, p 41

Kucera, Jane

Reverse Osmosis Operations

2015 Fall, p 14 Supplement

Peters, Charles

Internal Water Treatment for Industrial Boiler Systems

2001 Winter, p 17

Hater, Wolfgang

Film-Forming Amines: An Innovative Technology for Boiler Water Treatment

2015 Fall, p 22

Peters, John

Synthetic Antifoulants for the Water Treatment Industry—Part 2

2004 Fall, p 21

Mukiibim, Mo

Reverse Osmosis: Opportunities and Challenges

2015 Fall, p 26 Supplement

Peters, John

Synthetic Antifoulants for the Water Treatment Industry—Part 1

2004 Summer, p 37

LaBrosse, M., et al.

Use of Pilot Testing in Selecting an Effective Reverse Osmosis Scale Inhibitor

2015 Fall, p 33 Supplement

Pitcher, John

How Heat Loads Affect Evaporative Cooling Tower Efficiency

2016 Winter, p 38

Amjad Z., et al

Deposit Control Polymer Selection Criteria for High-Temperature Application—Part II Polymer Performance

2015 Fall, p 35

Pitcher, John

Flow Optimization of Evaporative Cooling Towers—Part 2

2016 Spring, p 32

Pescatore, Stephen

Low-Temperature Heat Transfer Fluid

2015 Fall, p 41

Pitcher, John

How Air Flow Affects Evaporative Cooling tower Efficiency—Part 3

2016 Summer, p 26

23

the Analyst Volume 24 Number 4

AWT Analyst Index continued

By Issue

By Author

Name

Title

Year, Issue

Name

Title

Year, Issue

Cartwright, P., et al.

Reverse Osmosis Membrane Processing: Application Insights

2015 Fall, p 41 Supplement

Pitcher, Peter

Using the Affinity Laws to Calculate Evaporative CT Efficiency—Part 4

2016 Fall, p 30

Golden, Chris

AWT RO Workbook

2015 Fall, p 46 Supplement

Pitochelli, A. R.

Odor Reduction by Chemical Oxidation

2012 Spring, p 25

Paul, David

Five Tips for Effective Reverse Osmosis Chemical Cleaning

2015 Fall, p 48 Supplement

Poppe, Gregg

Maximizing the Life & Performance of RO Membranes In Industrial Water Purification Systems

2013 Summer, p 23

Lassing, Ryan

A Primer: Reverse Osmosis

2015 Fall, p 8 Supplement

Power Magazine

Ion Exchange

2016 Fall, p 8 Supplement

Havashi, Aiden

Thriving in a Big Data World

2015 Spring, p 34 Business Supplement

Preising, Kevin

Save $91,000 Annually in LP WT Chemical and Fuel Costs Using a Dealkalizer

2010 Winter, p 12

Friedman, Stewart

Work + Home + Community + Self

2015 Spring, p 39 Business Supplement

Puckorius, Paul

MIC and More Than MIC in CT Water Systems—Know What You Are Dealing With

2012 Fall, p 9 Technical Supplement

Kaplan & Kaiser

Developing Versatile Leadership

2015 Spring, p 6 Business Supplement

Rahimian-Pour, et al.

Legionella Outbreak Prevention for Cooling Towers

2016 Summer, p 38

Boffardi, Bennett

TUTOR: Consultants

2015 Spring, p 63

Rank, V., Wilson, P.

Is It Time to Ditch the Annual Employee Survey?

2017 Spring, p 20 Business Supplement

Frayne, Colin

Effective Control of Waterside Corrosion and Heat Transfer Efficiency in Chemical Plant Cooling Systems

2015 Spring, p 10

Reggiani, Gary, et al.

Trasar Technology—A Review and Comparison

2007 Winter, p 9

Ibarra, Herinia

The Authenticity Paradox

2015 Spring, p 17 Business Supplement

Reinmoeller, Patrick

How to Win a Price War

2016 Spring, p 8 Business Supplement

Boffardi, Bennett

Heat Exchangers

2015 Spring, p 22

Rekalake, Heather

ORP vs. Free Chlorine: What ORP Is and When and How to Use It Instead of Free Chlorine

2013 Winter, p 31

Dunler, Adam

Computerized Service Records

2015 Spring, p 29

Releny, Attila

Organic Film and General Organic Fouling Indicies

2000 Spring, p 33

Pescatore, Stephen

Low-Temperature Heat Transfer Fluids

2015 Spring, p 39

Rey, Susan P.

Carbon Steel Corrosion Control Ion the Past Twenty Years and in the Millineum

2001 Summer, p 35

Fernandez-Araoz

21st Century Talent Spotting

2015 Spring, p 24 Bus Supplement

Rey, Susan, et Al.

Molybdate and Non-Molybdate Options for Closed Systems—Part I

2006 Summer, p 21

Dixit and Sharma

Biofouling and Associated Problems in Industrial Cooling Water Systems, A Case Study

2015 Summer, p 10

Rey, Susan, et al.

Molybdate and Non-Molybdate Options for Closed Systems—Part II

2006 Fall, p 17

Cartwright, et al.

A New Technology for Softener Brine Recovery

2015 Summer, p 28

Rosenzweig, Phil

The Benefits—and Limits—of Decision Models

2014 Spring, p 29 Business Supplement

Henke, Larry

Principles of Filtration: How Do Filters Filter Anyway?

2015 Summer, p 33

Ross, Joe

Security Actions for the C Suite: Act Now to Avoid Trouble Later

2017 Spring, p 31 Business Supplement

Amjad, et al.

Deposit Control Polymer Selection Criteria for High-Temperature Application—Part I

2015 Summer, p 40

Saita, Anne

Disaster Preparedness: Staying Up While Everything Else Is Down

2005 Fall, p 51

Pascatore, Stephen

Low-Temperature Heat Transfer Fluids Glycol Degradation

2015 Summer, p 49

Schmelter, Dean M.

Finally, A Safe Replacement for Dimethyldithiocarbamate

2002 Winter, p 38

Scott, James

Waterborne Dangers: A Review of Data Available From CDC Resources 1971–2010

2015 Winter, p 10

Schmelter, et al.

Comparing Common Metal Precipitating Agents: A Close Look at DTC

2017 Winter, p 10

Dargahi, M, et al.

Green Chemistry—Purified Tannin Molecules for the Protection of Low CS Closed-Loop Systems

2015 Winter, p 22

Scholnick, Michael

Reducing Fuel Cost in a SteamGenerating System, a Review

2006 Fall, p 8

Pescatore, Stephen

Low-Temperature Heat Transfer Fluids

2015 Winter, p 29

Scott, James

TUTOR: Uncovering the Secret of Testing Low Hardness Water

2005 Winter, p 48

Cleveland, Donald Why Do Water Treaters Need Insurance?

2015 Winter, p 35

Scott, James

Controlling Your Cooling Tower

2006 Spring, p 36

Dow Chemical Co

Fundamentals of Ion Exchange

2016 Fall, p 18 Supplement

Scott, James

Legionellosis Is Not the Killer It’s Thought To Be!

2013 Fall, p 24 Supplement

Dow Chemical Co

Temperature of Dowex Ion Exchange Resins

2016 Fall, p 28 Supplement

Scott, James

Waterborne Dangers: A Review of Data Available From CDC Resources 1971–2010

2015 Winter, p10

AWT

Certification Corner

2016 Fall, p 31 Supplement

Scott, Mike

What’s in Your Tolbox? Test Methods for Industrial Water Analysis

2005 Summer, p 9

Power Magazine

Ion Exchange

2016 Fall, p 8 Supplement

Scott, P.J.B.

Expert Consensus on MIC— Prevention and Monitoring, Part 2

2005 Spring, p 27

24

the Analyst Volume 24 Number 4

AWT Analyst Index continued

By Issue

By Author

Name

Title

Year, Issue

Name

Title

Year, Issue

Daniels, David

Using Guidelines to Develop Optimum Steam Chemistry Limits HRS

2016 Fall, p 10

Expert Consensus on MIC— Prevention and Monitortng, Part 1

2005 Winter, p 9

Scott, P.J.B.

AWT

Boiler Plant Flow Diagram

2016 Fall, p 20

Silbert, Marvin D.

Flow-Accelerated Corrosion

2002 Fall, p 25

Greenlimb, et al.

Boiler and Condensate System Energy Calculation Workbook

2016 Fall, p 22

Simpson & Miller

Control of Biofilm with Chlorine Dioxide

2009 Summer, p 12

Pitcher, Peter

Using the Affinity Laws to Calculate Evaporative CT Efficiency—Part 4

2016 Fall, p30

Simpson, Greg

Treatment of Cooling Systems with ClO2

2010 Fall, p 8, Supplement

Wiatr, Chris

Bacterial Resistance to Antimicrobials in 2016 Spring, p 10 a Cooling Water System—Part 1

Sinha, Ashwini

Cleaning and Control of Fouling of High Efficiency PVC Film Type CT Fills at Industrial Plants

2010 Summer, p 10

AWT

What HR Needs to Know in 2016

2016 Spring, p 12 Business Supplement

Standish, Michael

Understanding Options to Overcome Harvest Pressures for AWT Businesses

2012 Spring, p 8 Business Supplement

Wojtowicz, John

Evaluation of Alternative to the Langelier Saturation Index

2016 Spring, p 18

Standish, Michael

Rules of Three: Simplifying the Selection of Polymers

Spring 2017, p 10

Groysberg, Boris

Leadership Is a Conversation

2016 Spring, p 24 Business Supplement

Stout, et al.

Advances in Legionella Testing: Methods and Interpretation

2017 Fall, p 20 Supplement

Keister, et al.

Cooling Tower System Design and Operation

2016 Spring, p 26

Stout, Janet E.

Sustainable and Safe: What’s in Your Reclaimed Water?

2017 Summer, p 30

Cable, Daniel

Reinventing Employee Onboarding

2016 Spring, p 30 Business Supplement

Stout, Janet E.

Study Demonstrates New Monochloroamine System Effective in Controlling Legionella…

2013 Fall, p 22 Supplement

Pitcher, John

Flow Optimization of Evaporative Cooling Towers—Part 2

2016 Spring, p 32

Supplement 2009

Defining Green Chemicals

2009 Summer, p 9

Torrice, Michael

How Lead Ended Up in Flint’s Water

2016 Spring, p 37

Supplement 2009

Sustainable Water Systems

2009 Summer, p 11

Cleveland & Walsh

Water Treatment Contracts from a Risk Management Perspective

2016 Spring, p 37 Business Supplement

Supplement 2009

Energy Star Heating and Cooling Upgrades and Survey

2009 Summer, p 15

AWT

Handing the Torch to the Next Generation

2016 Spring, p 41 Business Supplement

Supplement 2009

Energy Star Heating and Cooling Upgrades and Survey—Rightsizing System

2009 Summer, p 29

Brooks, Alison W.

Emotion and the Art of Negotiation

2016 Spring, p 42 Business Supplement

Sweeny, & Lammaring

Bardac LF 18—a Novel Cooling Water Algaecide

2010 Spring, p 34

Boffardi et al.

Control of Lead Corrosion by Chemical Treatment

2016 Spring, p 44

Torrice, Michael

How Lead Ended Up in Flint’s Water

2016 Spring, p 37

Reinmoeller, Patrick

How to Win a Price War

2016 Spring, p 8 Business Supplement

Tracey, et al.

Preventive Control of Legionella through Real-Time Bioburden Testing

2013 Fall, p 30 Supplement

Kaffer, Nancy

Why Didn’t Flint Treat Its Water? An Answer at Last

2016 Summer, p 47

Ulrich, Carl

Taking Advantage of Growth Opportunities for Independent Water Mgt Co in a Highly Cond Market

2000 Fall, p 25

Wiatr, Chris

Bacterial Resistance to Antimicrobials in 2016 Summer, p 12 a Cooling Water System—Part 2

Uribe, Carlos

Intelligent Metering Control Systems

2014 Fall, p 28

Pitcher, John

How Air Flow Affects Evaporative Cooling Tower Efficiency—Part 3

2016 Summer, p 26

UY, Mario

Ozone in Cooling Water Treatment

2004 Spring, p 32

AWT

Aluminum Corrrosion Coupon Discussion

2016 Summer, p 34

UY, Mario

TUTOR: Cooling Tower Water Distribution Affects Mineral Deposits

2007 Spring, p56

Rahimian-Pour, et al.

Legionella Outbreak Prevention for Cooling Towers

2016 Summer, p 38

Van Camp, James R.

Preserving Cooling Water

2016 Winter, p 25

Frayne, Colin

The Future of Water and Treatment: Strategic Water Reuse Solutions and Energy Conservation

2016 Winter, p 10

Vanderpool, Dan

Hidden Assumptions in Saturation Calculations

2002 Summer, p 25

Van Camp, James R.

Preserving Cooling Water

2016 Winter, p 25

Vanderpool, Dan

The pH Values for Cooling Water Systems

2004 Spring, p 21

Pitcher, John

How Heat Loads Affect Evaporative Cooling Tower Efficiency

2016 Winter, p 38

Vanderpool, Dan

Calculating Minimum Threshold Inhibitor Dosage

2005 Summer, p 25

Schmelter, et al

Comparing Common Metal Precipitating Agents: A Close Look at DTC

2017 Winter, p 10

Vlasblom, Jack

TUTOR: The Greening of Water Treatment and Development of Environmental Standards

2008 Summer, p 63

Corbin, Brian

Microbiological Control in Industrial Cooling Towers

2017 Winter, p 26

Vogt, Peter

Tolyltriazole—Myth and Misconceptions

2005 Spring, p 35

Williams, Terry

The Environmental Fate of NonOxidizing Biocides

2017 Winter, p 34

Vogt, Peter

Commerical Tolyltriazoles and Their Properties

2007 Spring, p 24

Hamill, Sean

Did Bias Skew the CDC’s Pittsburgh VA Legionnaires’ Report?

2017 Winter, p 50

Vondra, Kroeger

Patriot Renewable Fuels Implements: Zero Liquid Discharge (ZLD)

2011 Spring, p 20

25

the Analyst Volume 24 Number 4

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AWT Analyst Index continued

By Issue

By Author

Name

Title

Year, Issue

Name

Title

Year, Issue

Coutu, Diane

How Relience Works

Spring 2017, p 8 Business Supplement

Walter, R.

Testing Methods to Diagnose Micro-Bio Problems and Determine if Remedial Action is Effect

2013 Spring, p 37

Standish, Michael

Rules of Three: Simplifying the Selection of Polymers

Spring 2017, p 10

Walter, R., Relenyi, A

Application of DBNPA and Glutaraldehyde as Biocides for Treatment and Control of Microbiological

2009 Winter p 37

Conner, Cherly

Mentally Strong People: The 13 Things They Avoid

Spring 2017, p 16 Business Supplement

Webb, D, et al.

A Multiyear Comparison Review of the Use of Cu-Ag Ionization and ClO2 to Contol Legionella

2009 Winter, p 12

Rank, V., Wilson, P.

Is It Time to Ditch the Annual Employee Survey?

Spring 2017, p 20 Business Supplement

Weiss, Scott

Generation Gap: How Technology Has Changed How We Talk About Work

2013 Spring, p 28 Business Supplement

Goleman & Boyatzis

Emotional Inteligence Has 12 Elements: Which Do You Need to Work On?

Spring 2017, p 24 Business Supplement

Whalen, Pat

TUTOR: 2nd Generation ATP Testing: Reliable On-the-Spot Microbiological Monitoring…

2013 Winter, p 62

Meitz, Amanda

What Is This Stuff?

Spring 2017, p 26

Whalen, Pat Razban, Roy

Water Treatment Battles with the Microbes—Knowing the Enemy

2010 Summer, p 33

Bray, David

Three Meaningful Strategies for Mamaging Rapid Change

Spring 2017, p 27 Business Supplement

Whitson, et al.

179D Tax Saving Article

2010 Fall, p 17, Supplement

Ross, Joe

Security Actions for the C Suite: Act Now to Avoid Trouble Later

Spring 2017, p 31 Business Supplement

Wiatr, Chris

Bacterial Resistance to Antimicrobials in 2016 Spring, p 10 a Cooling Water System—Part 1

Mahal, Gurdeep

Three Benefits of ISO 9001 Cetification for Small Businesses

Spring 2017, p 33 Business Supplement

Wiatr, Chris

Bacterial Resistance to Antimicrobials in 2016 Summer, p 12 a Cooling Water System—Part 2

Wojtowicz, John

A simplified Langelier Saturation Index Equation

Spring 2017, p 46

Wiatr, Christopher L.

Detection and Eradication of a NonLegionella Pathogen in a Cooling Water System

2002 Spring, p 38

Boffardi, Bennett

TUTOR: Monitoring Condenstae Corrosion

Spring 2017, p 71

Williams & Miller

Change the Way You Persuade

2013 Spring, p 18 Business Supplement

Nogle, Christopher

Beyond Laboratory Research on White Rust and Passivation

Summer 2017, p 10

Williams, Terry

The Mechanism of Action of Isothiazolone Biocides

2010 Spring, p 22

LaBrosse & Erickson

Pilot Research to Determine Effictive Aluminum Corrosion Inhibition

Summer 2017, p 22

Williams, Terry

The Environmental Fate of NonOxidizing Biocides

2017 Winter, p 34

Stout, Janet

Sustainable and Safe: What’s in Your Reclaimed Water?

Summer 2017, p 30

Wilson, Alex

Chill Factor: Utilizing Ice-Based Thermal Energy Storage to Cool Building Makes

2011 Summer, p 8 Supplement

Hockworth, Scott

The Improved Financial Health of Water Treatment Companies Since the Greaat Recession

Summer 2017, p 34

Wilson, Alex

Three R’s of Sustainable Water-Cooled Systems Operation

2011 Summer, p 13 Supplement

Zamanzadeh, et al.

Failure Analysis and Investigation Methods for Boiler Tube Failures

Fall 2017, p 30

Wirth, Matthew

How Fast Can Ew Run? Ion Exchange Reaction Zones

2012 Winter, p 18

Bloom, Debbie

Corrosion Control for the Industrial Plant Steam

Fall 2017, p 50

Wirth, Matthew

It’s Tough Being a Resin Bead

2011 Winter, p 10

Heyl Brothers

Phophate Hideout, What Is It?

Fall 2017, p 64

Wojtowicz, John

Calculation of Aqueous CaCO3 Scaling Potential Via a Modified Langelier Equation

2014 Spring, p 30

Bearwood, Edward

Feedwater and Deaeration Within Industrial Steam-Generating Systems

Fall 2017, p 87

Wojtowicz, John

Evaluation of Alternative to the Langelier Saturation Index

2016 Spring, p 18

CDC

New Vital Signs Report: Legionnaires’ Disease on the Rise

Fall 2017, p 8 Supplement

Wojtowicz, John

A Simplified Langelier Saturation Index Equation

Spring 2017, p 46

Coughlin, Michael

Sampling Strategies and Test Methods for Detection of Legionella in Potable Water Systems

Fall 2017, p 10 Supplement

Wolfe, Thomas

Operation of Deaerators to Increase Boiler System Reliability

2005 Fall, p 9

Stout, et al.

Advances in Legionella Testing: Methods and Interpretation

Fall 2017, p 20 Supplement

Youmans, R.O., et al.

Dimethylthiocarbamate and the Environmental Protection Agency

2002 Winter, p 33

Miskowski, Diane

NYS & NYC CT Regulations: Are They Enough to Prevent Cases of Legionnaires’ Disease

Fall 2017, p 28 Supplement

Zamanzadeh, et al.

Failure Analysis and Investigation Methods for Boiler Tube Failures

2017 Fall, p 30

Goulah, Christopher

Isolatiion of Legionella From Environmental Samples: CDC vs. ISO

Fall 2017, p 34 Supplement

Zupanovich, John D

TUTOR: Dehalogenation of Industrial Water

2009 Spring, p 67

Freije, Matthew

Interpreting Legionella Test Results: Case Studies Illustrating Key Criteria

Fall 2017, p 38 Supplement

Zupanovich, John D

Oxidation and Degradation Products Of Common Oxygen Scavengers

2002 Fall, p 17

McWhorter, Tom

Chlorine Dioxide for Control and Prevention of Biofilm and Legionella

Fall 2017, p 46 Supplement

27

the Analyst Volume 24 Number 4

Thank You to Our 2016 Award Winners 2016 Supplier of the Year QualiChem, Inc.

2016 Ray Baum Memorial Water Technologist of the Year Jack Walker, CWT

Introducing Our 2017 Award Winners 2017 Supplier of the Year McGowan Insurance Group

2017 Ray Baum Memorial Water Technologist of the Year Robert J. Ferguson

Past Ray Baum Memorial Water Technologist of the Year Recipients

Past Supplier of the Year Recipients 2016 – QualiChem, Inc. 2015 – Scranton Associates, Inc. 2014 – Masters Company, Inc. 2013 – Taylor Technologies, Inc. 2012 – French Creek Software, Inc. 2011 – Lakewood Instruments LLC 2010 – Aqua Phoenix Scientific Inc. 2009 – AMSA, Inc. 2008 – Houghton Chemical Corporation 2007 – Water Color Management, Inc. 2006 – Advantage Controls, Inc. 2005 – ZIBEX, Inc

2016 – Jack Walker, CWT 2015 – James Scott, CWT 2014 – Allan R. Bassett, CWT 2013 – James McDonald, PE, CWT 2012 – Joseph M. Hannigan, CWT 2011 – Cindy Mitchell, CWT 2010 – Jack Soost, CWT 2009 – Jay Farmerie, CWT 2008 – Jim Lukanich, CWT 2007 – Richard L. Tassone 2006 – Bruce T. Ketrick Sr., CWT 2005 – William E. Pearson II, CWT 2004 – Colin Frayne, CWT 2003 – Richard T. Blake, CWT 2002 – Zahid Amjad, Ph.D. 2001 – Bennett Boffardi, Ph.D. 2000 – Arthur J. Freedman, Ph.D. 1999 – Janet E. Stout, Ph.D. 1998 – Brent W. Chettle, CWT 1997 – Jessie Jefferies 1996 – John J. Baum, CWT 1995 – E.J. Caruso 1994 – Dennis Clayton 1993 – Ronald Knestaut 1992 – Robert R. Cavano 1991 – D.C. “Chuck” Brandvold, CWT

29

the Analyst Volume 24 Number 4

Failure Analysis and Investigation Methods for Boiler Tube Failures

By Mehrooz Zamanzadeh, Edward S. Larkin, George T. Bayer, William J. Linhart

Failure Analysis and Investigation Methods for Boiler Tube Failures continued

Failure analysis methodology is applied to the principal mechanisms by which boiler tubes fail during service. Several important factors often associated with component failures are deficiency in design, fabrication, operating conditions, unsuitable materials selection, and expended useful life. These factors are of primary consideration. The failure analysis procedure, or methodology for evaluation, is provided in a step-by-step approach.

This includes justification for conducting a failure analysis investigation; development of a logical plan for the investigation to follow; collection of background information; sample removal techniques; onsite inspection; laboratory testing and analysis; and the formulation of a final report based on relevant data, analysis, and recommendations. Among the case histories discussed are fatigue, erosion, short-term overheating, and hydrogen damage.

Introduction

Failure analysis and the principal mechanisms by which boiler tubes fail in service will be examined in this introductory survey. As this is an introductory survey, the reader is referred to two excellent reference texts covering the field of boiler failures for more detailed information. These are the texts authored by French [1] and Port and Herro.[2] Deficiencies in design, fabrication, and operating conditions; unsuitable materials selection; and expended useful life are important factors to consider, not only for boiler tubes, but for operational components in general. Thus, the failure analyst must consider them of primary importance when a failure occurs in a boiler. If identified early, potential failures or accidents can often be prevented, and as a result, costly repair expenses, lost revenue, and legal expenses may be avoided.

To investigate a failure and analyze the conditions that promoted it, important information must be collected.

Background information on the make and model of the boiler and the tube, specifications, the service history, and physical evidence of the failed part are necessary to determine why, how, when, and where a failure may have occurred. If these answers are provided during the course of the investigation, future failures may be better understood or possibly prevented.

The conditions that promoted the failure are essential to identifying the underlying factors that may have initiated the failure. Other elements that may not be

readily acknowledged in failure analysis, yet are no less important, are common sense, a critical and unbiased mode of thinking, experience, knowledge, and experimental observation.

Provided in this survey is a step-by-step approach to failure analysis investigation. The accepted theories and mechanisms that cause boiler components to fail will be explored in this article.

Failure Analysis

A failure analysis investigation is much like the work of a detective. Clues or relevant facts pertaining to the investigation must be gathered, analyzed, explored, and studied to make a knowledgeable determination. As in the case of a good detective, firsthand field experience is of the utmost importance, yet academic studies are also essential.

A background and thorough understanding of materials used in construction, physical and mechanical properties of materials and their production, and fabrication and performance characteristics of the materials, as well as a working knowledge of machinery and structural design and the application and distribution of stresses resulting from service loads as they relate to the properties of materials, are vital to fully developing as a successful failure investigator.

In conjunction, a failure analyst must have a procedure, or more precisely, a method for evaluation when a failure occurs. If a product does not live up to its full life expectancy, there must be an evaluation procedure that will identify the loss. A method of evaluation that is logical and well planned will enable the analyst to determine the underlying contributing factors and provide valid information about the failure for future reference.

Failure Determination

Determining that a failure indeed occurred is the first step in the method for evaluation. In the case of a boiler tube, a failure has occurred if the tube develops a leak, breaks into two or more pieces, has physical signs of deterioration that will result in an unsafe environment, or is incapable of performing its intended function.

If the boiler tube breaks into two or more pieces, it is called a fracture failure. A fracture failure occurs 31

the Analyst Volume 24 Number 4

Failure Analysis and Investigation Methods for Boiler Tube Failures continued

by means of the formation and propagation of cracks resulting in the separation of two or more parts. Several factors that may produce this type of failure are mechanical stresses, environmental or chemical influences, or the effect of heat on the boiler tube. For a failure to be identified as a fracture failure, the item does not have to be completely broken. One small imperfection can jeopardize the entire system.

Once it has been determined that a failure has indeed occurred, the point of origin must be found, and a determination must be made as to whether the failure occurred as a result of design, method of manufacturing, service history and conditions, water chemistry excursions, or from a deficiency in the material. When the point of origin is located, the investigation may proceed to a study of how the failure occurred, possible causes or factors in the failure, and possible means of preventative measures.

Why a failure occurs is an important question in the method of evaluation. This question can be approached by breaking down the failure into “mode of failure” and “cause of failure.” Mode of failure is the process by which the failure occurred. Cause of failure is that which can be fixed or changed to prevent future failures. Each question provides important clues to the investigation, and although priorities may be quite different, each question must be addressed and resolved to determine why a failure may have occurred.

In a fracture failure, clues to the mode of failure can be revealed by fractography, while the cause of failure can be identified through the use of metallurgical and mechanical testing, and chemical and surface analysis data. Future failures may be prevented by fixing or modifying the cause of a failure. This can be demonstrated in the example of a brittle fracture being the mode of failure. The corresponding cause of the brittle fracture may be temperature, presence of micro-cracks, or state of stress in the metal.

In a failure analysis investigation, each question must be answered as completely as possible.

Determination of the mode of failure may be a relatively simple process for the failure analyst; however, identification of the exact cause of the failure is quite difficult, if not impossible, at times. The root cause of a failure in a complicated investigation may take months to 32

determine, while a simple investigation may take only an hour depending upon the degree of complexity and the confidence level of the analyst. The investigation must be finely tuned—not too narrow and not too broad.

The following survey will present a logical method for failure analysis investigation, which will be applied to the mechanisms by which boiler tubes fail in service.

Methodology

Justification for conducting an investigation is an important issue for a failure analyst. Usually, justification for conducting the failure analysis investigation of a boiler tube is given in the identification of operational and material corrective actions for improved safety and operating efficiency. It may also be conducted for litigation-related purposes in the event of suspected operational or material negligence.

If the investigation is fully justified, the method for evaluation proceeds with the second step in the process.

This step involves gathering relevant information and facts concerning the failure. The questions listed serve as a guide to follow during the investigation. When the information has been obtained, it must be carefully organized, labeled, and documented in a logical format for future reference.

The failure analyst should question why failure occurred, how to get the equipment back online as quickly as possible, how to prevent a recurrence, and if more information is needed, how the information can be readily obtained. Following these steps, a plan of attack can be formed. This is the single most important step in the method of evaluation. A logical plan for the investigation to follow must be developed and implemented. Each investigation will be different from the last, and many variables will make it necessary to make decisions based on the investigation at hand. If an analyst is hasty in his decisions and does not have a solid plan, the analysis could be a waste of time. By simply cutting or analyzing a sample carelessly, an analyst could destroy his only useful evidence.

Many possible tests and orders of application of tests for the identification of a failure mechanism are available. The selection made depends on the degree of precision required and the extensiveness of the range that has to be examined. the Analyst Volume 24 Number 4

Failure Analysis and Investigation Methods for Boiler Tube Failures continued

The stages of analysis performed when conducting a failure analysis investigation should begin with the collection of background data and sample removal. This step includes site inspection, information regarding the current history of the failure, all relevant recordkeeping, and statistics on past failures of the component.

Visual and Microscopic Examination

A preliminary visual examination of the failed part, as well as a nondestructive examination of the failure, with extensive photographic documentation, precedes any mechanical testing, including hardness and tensile testing or any metallurgical examination. The preliminary examination does not change or damage the failed part in any way.

At this point in the investigation, the specimens should be selected and identified for further laboratory testing and analysis. Management should be notified that any specimens taken from a failed component are often damaged and of little use after testing.

There is a wide variety of testing methods currently available for failure analysis. Sophisticated and highly calibrated laboratory equipment can detect the slightest imperfections on a specimen and accurately identify the inherent characteristics. The reference text of Brooks and Choudhury [3] provides extensive discussion of analytical techniques to the failure analysis of materials in general.

A macroscopic examination of the surface of the selected specimen begins this stage of analysis, followed by a microscopic examination. This includes fracture surfaces, secondary cracks, discoloration, abnormalities, origin of fracture, and direction of the crack growth. In addition, corrosion product thickness, dimensional analysis, and level of deposit accumulation (via deposit-weight-density, DWD measurements) can also be evaluated.

Upon completion of the macroscopic and microscopic examination, a metallurgical analysis including etched and unetched as well as transverse and longitudinal cross sections is conducted. This form of testing provides information on microstructural characteristics of the sample in failed and “good� areas, which allows for identification of the distinguishing characteristics.

33

Chemical Analysis Techniques

A chemical analysis of the metal and corrosion products utilizing X-ray fluorescence spectrometry (XRF), inductively coupled plasma spectroscopy (ICP), scanning electron microscopy (SEM) coupled with energy dispersive X-ray spectroscopy (EDS), X-ray diffraction (XRD), Fourier transform infrared spectroscopy (FTIR) for organic contamination studies, Auger electron spectroscopy (AES), and X-ray photoelectron spectroscopy (XPS) for surface characterization may follow the metallurgical analysis, depending on the investigation.

All of these techniques are covered in more detail in the reference text by Sibilia.[4] Information from these different types of analyses may provide clues as to the cause of failure.

XRF is a quantitative elemental analysis technique that uses X-rays to excite a sample. The excitation generates X-ray energies that identify the elemental composition of the sample. Using X-ray detection equipment to count the number of X-ray photons emitted by this technique, an XRF system is able of characterizing and quantifying the elemental composition of the sample.

ICP is an analytical technique used for the detection of dissolved metallic and nonmetallic elements in aqueous solution. The primary physical operating principle of ICP is to get elements to emit characteristic wavelength-specific light that can then be measured. It is an exceptionally useful analytical technique for the measurement of trace elements.

The SEM is a microscope that uses electrons rather than light to form an image. There are many advantages to using the SEM as an adjunct to the optical (light) microscope. The SEM has a large depth of field, which allows a large amount of the sample to be in focus at one time.

It also produces images of high resolution, which means that closely spaced features can be examined at a high magnification. Preparation of the samples is relatively easy since most SEMs only require the sample to be electrically conductive.

EDS systems are used in the characterization of materials through the use of ionizing radiation (electrons) to excite a sample. This excitation generates X-ray energies that identify the elemental composition of the sample.

Using X-ray detection equipment to count the number the Analyst Volume 24 Number 4

Failure Analysis and Investigation Methods for Boiler Tube Failures continued

of X-ray photons emitted by this technique, an energy dispersive x-ray spectrometry system is able to characterize and quantify in an approximate manner the elemental composition of the sample. Either used in conjunction with SEM imaging or on its own, the most common use for EDS in metallurgical analysis permits a general semi-quantitative determination of alloy, corrosion product, and contaminant chemistry.

met, then the intensity of the X-rays will be strong.

These conditions provide information concerning the spacing between planes of atoms in the crystal structure as well as a host of other details. XRD is used to identify unknown materials in terms of their crystalline structure, and to look for deviations from the perfect structure, which may indicate the presence of impurities and other fine-scale structural defects.

XRD is a powerful analytical technique relying on the constructive and destructive interference of X-rays diffracted from a sample that is illuminated by a filtered and focused beam of X-rays. If certain conditions are

FTIR records the interaction of infrared radiation (light) with experimental samples, measuring the frequencies at which the sample absorbs the radiation and the intensities of the absorptions. Determining these frequencies allows the sample’s chemical makeup to be identified, as chemical functional groups are known to absorb infrared radiation at specific frequencies.

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AES determines the elemental composition of conductive and semiconductive surfaces and can provide elemental depth profiles through sputtering. This information can then be utilized to solve problems associated with surface appearance, cleanliness, and bonding. Additionally, corrosion products may be identified. In principle, an electron beam bombarding a solid surface excites electrons from core electronic energy levels of atoms. The kinetic energy spectrum is used to identify the atom of origin and its concentration.

XPS provides similar analyses offered by AES and uses X-rays to excite core electrons, but it can be performed on a nonconducting surface, providing a definite advantage for organic materials and paints. XPS also may provide more detailed information on the binding state of an element, which provides the chemical bonds and the identity of compounds that EDS and AES cannot provide.

Fracture Mechanics

The analysis of fracture mechanics, including the measurement of fracture toughness and the evaluation of notch effects, provides information concerning

the Analyst Volume 24 Number 4 27.09.17 09:30

Failure Analysis and Investigation Methods for Boiler Tube Failures continued

the probability of a catastrophic failure under service conditions. Accelerated tests, as well as the recreation of the failure through simulated tests, confirm the proposed failure mechanism.

Analysis and Review of Evidence

Analysis of the evidence and a review of the existing data and documentation are the final stages of failure investigation. All information is gathered and analyzed to form a determination on the mode and probable cause of the failure. Identification of the mode and cause of failure provide the source for recommendations for corrective action. A final report including all relevant data, analyses, and recommendations is compiled and presented to the client. In litigation investigations, the client may not be interested in the recommendations section of the report.

Collection of Background Data

The failure analyst should determine when, where, and how the failure occurred. Interview all users and operators involved in the failure with point-related questions.

Examples of point-related questions include “how was the part treated after failure?”, “Was it protected?”, “How was the fracture handled?”, and “Did the failure involve overheating that could have altered the microstructure of the weld or of the base metal?”

Sample Removal

The decision to remove a sample specimen is an important part of the failure analysis investigation.

Samples selected should be characteristic of the material and contain a representation of the failure or corrosion attack. For comparative purposes, a sample should be taken from a sound and normal section. In conjunction, for a complete metallurgical examination of a failure, samples from the failure, adjacent to the failure, and away from the failure are necessary.

The sample must be removed without changing the surface conditions or characteristics of the sample nor inflicting physical damage of any kind. The sample is the basis on which the investigation and analysis rely, and extreme care must be taken with the sample so as to not destroy any of the sample’s properties.

Upon removal of the sample, the exact location on the piece of equipment from where it was taken must be 35

clearly identified. The piece of equipment from which the sample was taken should also be identified and illustrated on an overall map of the area, if possible.

To demonstrate the relationship of the sample and the piece of equipment, a photograph should be taken. If more than one sample is to be taken, proper designation of the sample and its location relative to the piece of equipment should be noted and photographed. The dimensions of the sample and part specification should be noted on the photograph as well as the date the failure occurred.

Any corrosion product found on the coating or the substrate should be examined. If there is a corrosion product on the piece of equipment, but not on the sample, a representative sample of the corrosion product should be collected with the removed sample. However, if at all possible, the corrosion product/deposit should be kept intact on the surface and not be separated from the sample. When the sample has been removed from the equipment, it should be carefully wrapped and packaged in a tight box, identified, and labeled.

There are many different ways that samples can be removed. Acetylene torch, air arc, saw, trepan, or drill can be used for the removal. All cuts made with an acetylene torch should be at least 6 inches from the area to be examined; cuts made by air arc should be at least 4 inches away.

If a cut were made closer to the area than stated, the heat generated could alter the microstructure, obscure the type of corrosive attack, or be cumulative to a failure, all of which would render the sample useless.

If the available distance for removal of the sample is less than 4 inches, the removal must be conducted with a saw or trepan. Drilling out the sample is also an option but may dislodge deposits and corrosion product layers that need to be studied intact.

Proper removal and documentation of the sample as well as information concerning the equipment, process, and service conditions are necessary. Important criteria that should be noted when a sample is removed are the date, equipment number, equipment process name, manufacturer, heat treatment received, material of construction, the Analyst Volume 24 Number 4

Failure Analysis and Investigation Methods for Boiler Tube Failures continued

environmental conditions (water treatment, temperature, pressure, and amount of time the equipment is used), and any abnormal service conditions existing at the time of the failure or prior to the failure. This background information will provide the basis for a sound failure investigation.

Figure 1: Photograph showing the as-received reheater tube assembly

Analysis of Industrial Failures

Four case histories concerning boiler tube failures will be the focus of the following section. The case histories discussed include fatigue, erosion, short-term overheating, and hydrogen damage. The approach adopted for each case history will provide the principal characteristics of the failure, main identifying features, basic problem-solving techniques, and applied aspects of the failures.

Industrial Case 1—Fatigue A failure analysis was conducted on one welded horizontal reheater lower bank tube assembly from a coalfired utility boiler identified as sample number 809. The sample was further identified as bundle number 188.

The failed tube was identified as tube number 2, and the adjacent tube was identified as tube number 1. The tubes were specified to be 2.25-inch (57.2 mm) outside diameter (OD); 0.188 (4.78 mm) minimum wall thickness (MWT); American Society of Mechanical Engineers (ASME) SA 213 Grade A-1 material (UNS K02707).

The tubes had been in service for only one year, with service conditions of 1010 Âş F (543Âş C) and 800 psi (5.52 MPa).

The as-received reheater tube assembly is shown in Figure 1. The two tubes were joined together by tie bars that were welded to the tubes. Tube number 2 possessed a single circumferential crack that had propagated past the end of the tie bar weld at the weld toe location, as shown in Figure 2. The end of the weld did not wrap around the end of the tie bar. The general arrangement of the welded assembly is shown in Figure 3. This cross section was cut approximately 1 inch behind the fracture surface. Failure of tube number 2 caused localized erosion of tube number 1.

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Figure 2: Photograph showing the circumferential crack in tube no. 2

Figure 3: Photograph showing the geometry of the welded assembly

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Failure Analysis and Investigation Methods for Boiler Tube Failures continued

The failed tube was cut so that the mating fracture surfaces could be examined. The fracture surface was relatively flat and smooth textured. A series of parallel, closely spaced crack arrest marks were observed at several locations, as shown in Figure 4. These features are characteristic of a fatigue mode of failure. The crack arrest marks were concentric about the fracture initiation location, which was found to be at the weld toe location at the end of the weld. The mating fracture surfaces at the fracture initiation location are shown in Figure 5.

The cluster of radially oriented ridges represents steps between separate, but closely spaced, fracture initiation sites.

Figure 4: Photograph showing parallel fatigue crack arrest marks on the fracture surface

One of the mating fracture surfaces was further examined at high magnifications using an SEM. Some of the concentric crack arrest marks are shown in Figure 6. The underlying microstructural features of the steel tube were observed on the fracture surface where the rougher textured areas are the carbon rich bainite or pearlite phase, and the darker, smooth-textured areas are the ferrite phase. Coarse crack arrest marks could be observed at some locations, as shown in Figure 7. The average spacing between these observed crack arrest marks was measured to be approximately 0.07 mm. No finer spaced fatigue striations could be observed between the coarser spaced crack arrest marks. Therefore, it was not possible to calculate the number of elapsed cycles since the fracture initiated.

Figure 6: Scanning electron micrograph at 14x showing fatigue crack arrest marks adjacent to the fracture initiation location

Figure 5: Photograph showing one of the mating fracture initiation sites

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Failure Analysis and Investigation Methods for Boiler Tube Failures continued

Figure 7: Scanning electron micrograph at 245x showing a series of fatigue crack arrest marks

Figure 8: Photograph at 8x showing the fracture initiation site at the weld toe location—2% nital

Figure 9: Photograph at 400x showing the microstructure of the heat affected zone (HAZ)—2% nital

A transverse cross section through the fracture initiation location, parallel to the length of the weld, was prepared for subsequent metallographic examination.

Etching with a 2% nital solution revealed the existing microstructures. The fracture initiation site at the weld toe location is shown in Figure 8. The microstructure of the heat affected zone (HAZ) is shown in Figure 9 and consisted of dark etching bainite plus white etching ferrite. The microstructure of the failed tube away from the weld is shown in Figure 10 and consisted of dark etching pearlite in a matrix of white etching ferrite. No microstructural evidence of overheating of the boiler tube steel was observed at locations away from the weld.

The microstructure of the weld metal deposit consisted of darker etching carbides in a white etching ferrite matrix.

The microstructure of the tie bar consisted of numerous small dark etching carbides in a white etching ferrite matrix.

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Figure 10: Photograph at 400x showing the base metal microstructure—2% nital

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Failure Analysis and Investigation Methods for Boiler Tube Failures continued

In the lightly etched condition, a Knoop microhardness inspection, using a 500 g load, was performed in the HAZ, weld metal, and the base metal of the failed tube. Knoop microhardness measurements ranged from 165–212 (80–92 HRB) in the HAZ, 224–255 (95 HRB–21 HRC) in the weld metal, and 159–168 (78–81 HRB) in the base metal.

A quantitative chemical analysis was performed on the failed tube, tie bar, and weld metal joining the tie bar to the failed tube. The failed tube conformed to the chemical requirements of ASME SA 213 Grade A-1 plain carbon steel (UNS K02707). The tie bar nearly conforms to the chemical requirements of ASME SA 213 Grade T22 ferritic alloy steel (UNS K21590), except that the measured phosphorus content is greater than the specified maximum value. The weld metal deposit could not be matched with any standard American Welding Society (AWS) electrode composition, most likely due to dilution with the base metal.

The failure of the reheater tube occurred as a result of high cycle fatigue, which initiated on the outside diameter surface of the tube, at the weld toe location, at the end of the weld joining the tie bar to the failed tube.

The weld did not wrap around the end of the tie bar, and so there was excessive stress concentrated at the weld toe location. The weld joint failure is a complex issue and is being further investigated. It is believed at this point that flow-induced vibrations may be causing the failure. The investigation is still underway, and it may take several more months to pin down the root cause and corrective actions.

weld. Along one of the 6.75-inch (171 mm) long edges of the window, the fracture surface was observed to be approximately 0.21 inch (5.3 mm) thick. Along the other 6.75-inch (171 mm) long edge of the window, the fracture surface was observed to be only approximately 0.03 inch (0.8 mm) thick. On the opposite side of the tube from the window failure, the tube wall thickness was measured to be approximately 0.22 inch (5.6 mm).

Outward plastic deformation of the fracture surfaces was observed along both long edges of the window fracture, as shown in Figure 11. Shallow corrosion pitting was observed on the inside diameter (ID) tube surfaces, as shown in Figure 12. Thick oxide scale deposits were observed on the outside diameter (OD) surface on the side of the tube where the failure had occurred.

Figure 11: Photograph at 1.4x showing the window failure in the waterwall tube

Figure 12: Photograph at 8x showing shallow corrosion pitting of the ID tube surface

Industrial Case 2—Erosion One rear waterwall tube from a coal-fired utility boiler that had failed in service was analyzed to determine the cause of failure. The tube was identified as sample number 782. The sample was further identified as: tube number 255, number 5 burner crotch tube at elevation 784. The tube was specified to be 1.75-inch (44.5 mm) OD, 0.200-inch (5.1 mm) MWT, ASME SA 210 material (UNS K02707).

The window failure in the waterwall tube is shown in Figure 11. The window was measured to be approximately 6.81 inches (173 mm) long. The failure occurred approximately 3.5 inches (89 mm) from a circumferential 39

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Failure Analysis and Investigation Methods for Boiler Tube Failures continued

A cross section through the fracture was made, and the wall thickness profiles for the tube at the fracture locations are shown in Figure 13. The rupture of the tube had produced an outward plastic deformation of the tube wall. A second cross section through the tube at a location away from the failure was also made. The tube wall thickness profile at this location is shown in Figure 14.

Approximately 30% loss of wall thickness was observed on the fireside surface in the tube, as shown in cross-sectional view in Figure 14, at the 2 o’clock position.

Figure 13: Photograph at 2x showing the tube wall thickness profile at the location of failure

Transverse cross sections were made through the fracture surfaces on both sides of the window failure, and also through non-failed areas of the tube for comparison purposes. In the as-polished condition, corrosion pitting was observed on the inside diameter surface of the tube around the entire circumference. The pitting appeared to be deepest on the failed side of the tube. The maximum pit depth at this plane of section was measured to be 0.38 mm. An example of a deep corrosion pit is shown in Figure 15. The thinner fracture surface is shown in Figure 16. All of the corrosion pit surfaces were observed to possess a thin layer of high temperature iron oxide, indicating that the corrosion pits were not likely to be active. The wall thickness at the fracture location was measured to be only 0.025 inch (0.62 mm).

Figure 15: Photograph at 100x showing corrosion pitting at the ID surface of the tube—as-polished

Figure 14: Photograph at 2x showing the tube wall thickness profile away from the location of failure Figure 16: Photograph at 50x showing the thinner fracture surface profile—as-polished

A quantitative chemical analysis of the failed tube material was performed. The failed tube did conform to the specified chemical requirements of ASME SA 210 Grades A-1 and C material (UNS K02707 and UNS K03501).

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Localized necking, or plastic deformation, was observed on the OD surface immediately adjacent to the fracture, as shown in Figure 16. In addition, many small black the Analyst Volume 24 Number 4

Failure Analysis and Investigation Methods for Boiler Tube Failures continued

voids were observed within the metal, across the entire tube wall thickness immediately adjacent to the fracture surface. These features are characteristic of a tensile overload mode of failure. A cross section through the tube away from the fracture, but in line with the area of reduced wall thickness, was also prepared for examination. The minimum wall thickness at this location was measured to be 0.108 inch (2.74 mm). The thicker fracture surface, on the other side of the window failure, is shown in Figure 17. This fracture surface exhibited a slanted profile characteristic of a ductile shear mode of failure. The wall thickness at this fracture location was measured to be 0.167 inch (4.24 mm). Secondary cracks were observed to have initiated on the ID surface close to the primary fracture location, as shown in Figure 18. The larger of the secondary cracks also exhibited a slanted profile. The thickness of the scale layer on the OD tube surface is shown in Figure 19. The maximum OD scale thickness was measured to be 0.081 inch (2.06 mm). Spherical particles of fly ash were observed in the outermost layers of the scale deposits. No evidence of internal sulfidation or oxidation was observed within the tube metal at the metal/scale interface.

Figure 18: Photograph at 100x showing secondary cracks initiating at the ID tube surface—as-polished

Figure 19: Photograph at 50x showing the scale deposits on the OD tube surface—as-polished

Figure 17: Photograph at 50x showing the thicker fracture surface profile at the ID surface—as-polished

Etching with a 2% nital solution revealed the existing microstructures. On the opposite side of the tube from the window failure the tube microstructure was found to consist of dark etching pearlite in a matrix of white etching ferrite, as shown in Figure 20. The pearlite usually occurred in bands. The microstructure of the tube at the thinner wall fracture location is shown in Figure 21. A slight elongation of the microstructure was observed immediately adjacent to the fracture surface.

The microstructure at this location consisted of dark etching pearlite in a matrix of white etching ferrite. No evidence of overheating was observed. The microstructure of the tube at the thicker wall fracture location is shown in Figure 22. The microstructure at this location consisted of dark etching pearlite in a matrix of white etching ferrite. Again, no evidence of overheating was 41

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Failure Analysis and Investigation Methods for Boiler Tube Failures continued

observed. The microstructure of the tube at the location of the secondary cracks is shown in Figure 23. Localized plastic deformation was observed in the vicinity of the secondary cracks. The outside diameter surface of the tube, in a region of reduced wall thickness, is shown in Figure 24. The OD tube surface exhibited a smooth profile and intersected the pearlite bands at an angle, as shown in the photographs. This is evidence of erosion of the OD surface of the tube.

Figure 22: Photograph at 100x showing the tube microstructure of the thicker fracture at the OD surface—2% nital

Figure 20: Photograph at 400x showing the microstructure of the tube away from the failure—2% natal

Figure 23: Photograph at 100x showing the tube microstructure at the location of the secondary cracks—2% nital

Figure 21: Photograph at 400x showing the tube microstructure at the thinner fracture surface—2% nital.

Figure 24: Photograph at 400x showing the smooth eroded OD surface profile of the tube—2% nital

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Failure Analysis and Investigation Methods for Boiler Tube Failures continued

The failure of the waterwall tube, sample number 782, produced a window-shaped opening in the tube.

Cross-sectional views and metallographic examination revealed a considerable reduction in tube wall thickness, especially on one side of the window-shaped opening.

Metallographic evidence indicated that the reduction in wall thickness of the tube occurred primarily as a result of localized erosion and oxidation of the OD tube surface. The erosive particles are believed to be fly ash, as much fly ash was observed within the OD scale deposits adjacent to the location of failure. The final failure then occurred as a result of a tensile overload. In this case, the fly ash problem is not a design or operational problem.

This was just routine fly ash erosion after many years in service.

Figure 25: Photograph showing the as-received horizontal reheater assembly front wall boiler tube

Figure 26: Photograph showing the as-received horizontal reheater assembly front wall boiler tube

Industrial Case 3—Short-Term Overheating One reheater tube sample was submitted for failure analysis from the horizontal reheater assembly front wall (row 94, tube 2) of a power station number 1 coal-fired boiler. The tube was further identified as sample number 816. The tube was specified to be 2.375-inch (60.33 mm) OD; 0.400-inch (10.16 mm) MWT; ASME SA 213 grade T2 material (UNS K11547). The tube had been in service for over 30 years, with service conditions of 1010 º F (543º C) and 800 psi (5.52 MPa).

The as-received horizontal reheater assembly front wall boiler tube is shown in Figures 25 and 26. The tube possessed one large window failure, as shown in Figure 25. The two longitudinal fracture surfaces did not mate together, indicating that a section of the failed tube is missing. One of the fracture surfaces exhibited localized tube wall thinning, while the second fracture retained its original tube wall thickness. Two longitudinal wear marks were observed on the OD surface adjacent to the thicker fracture surface. These marks suggest that the tube ruptured violently and struck an external object, causing a thicker, secondary fracture of the tube. The thinner fracture surface is shown in Figure 27. Slanted shear lips, characteristic of a tensile mode of failure, were observed. The thicker walled fracture surface is shown in Figure 28.

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Figure: 27 Photograph at 8x showing the thinner walled fracture surface

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Failure Analysis and Investigation Methods for Boiler Tube Failures continued

A transverse cross section through the thinner fracture surface was prepared for subsequent metallographic examination. The macroscopic appearance of the fracture is shown in Figure 30. In the as-polished condition, shallow corrosion pitting was observed along the outside diameter surface. Shallow secondary cracks were also observed, as shown in Figure 31. The fracture surface profile is shown again in Figure 32. Numerous elongated internal fissures were observed within the steel immediately adjacent to the fracture, as shown in Figure 32.

Many of these fissures were coincident with nonmetallic inclusions. The presence of internal fissures at nonmetallic inclusions is characteristic of a tensile overload mode of failure.

Figure 28: Photograph at 8x showing the thicker walled fracture surface

It was observed that the wall thickness of the failed tube was less on the side of the tube that was in line with the thin-walled fracture surface (see Figure 29). The outside diameter surface was observed to be relatively smooth in texture all around the tube circumference.

Oxidation of the outside diameter surface had occurred, but no erosion was found that would contribute to the decrease in observed wall thickness. The OD of the tube at the location shown in Figure 29 was measured to be between 2.500 and 2.702 inches (63.50 mm and 68.63 mm) versus a specified OD of 2.375 inches (60.33 mm). The increase in diameter indicates overheating and swelling of the tube. The minimum wall thickness shown in Figure 29 was measured to be 0.268 inch (6.81 mm) versus a minimum specified wall thickness of 0.400 inch (10.16 mm). The maximum wall thickness shown in Figure 29 was measured to be 0.412 inch (10.46 mm).

Figure 30: Photograph at 8x showing the thin-walled fracture surface profile—2% nital

Figure 31: Photograph at 400x showing secondary cracks near the fracture at the OD tube surface—aspolished

Figure 29: Photograph showing the non-uniform tube wall thickness

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Failure Analysis and Investigation Methods for Boiler Tube Failures continued

Figure 32: Photograph at 50x showing the thin wall fracture profile at the ID surface—as-polished

Figure 34: Photograph at 400x showing the tube microstructure adjacent to the thin wall fracture—2% nital

Etching with a 2% nital solution revealed the existing microstructure, which was found to consist of dark etching bainite and martensite plus white etching ferrite, as shown in Figures 33 and 34. The microstructure in the immediate vicinity of the fracture was found to be highly elongated due to the occurrence of localized plastic deformation. The microstructure of the tube away from the fracture surface is shown in Figure 35 and consisted of dark etching bainite in a matrix of white etching ferrite. The microstructure was not elongated at this location. The fracture surface profile, microstructure elongation, and presence of internal fissures at nonmetallic inclusions are characteristic of a tensile mode of failure.

Figure 35: Photograph at 1000x showing the tube microstructure away from the thin wall fracture—2% nital

Figure 33: Photograph at 50x showing the thin wall fracture profile at the ID surface—2% nital

A transverse cross section through the thicker fracture surface was also prepared for metallographic examination. The macroscopic appearance of the fracture profile is shown in Figure 36. The fracture at this location had initiated at the OD surface, as indicated by the presence of a slanted shear lip adjacent to the ID surface. No evidence of plastic deformation was observed at this location. The microstructure at this location consisted of dark etching islands of bainite and martensite in a white etching ferrite matrix, as shown in Figure 37.

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Failure Analysis and Investigation Methods for Boiler Tube Failures continued

Figure 36: Photograph at 8x showing the thick wall fracture surface profile—2% nital

Figure 38: Photograph at 200x showing the tube microstructure away from the fracture in the thinnest wall area—2% natal

Figure 37: Photograph at 200x showing the tube microstructure near the thick wall fracture—2% nital

A transverse cross section through the thinnest observed wall thickness away from the fracture, as shown in Figure 29, was also prepared for metallographic examination. The microstructure at this location consisted of dark etching islands of bainite and martensite in a matrix of white etching ferrite, as shown in Figure 38.

The microstructure at this location displayed a slight elongation. The microstructure of the tube at a location 180 º away, on the opposite, thickest walled area is shown in Figure 39 and consisted of dark etching bainite and martensite plus pearlite in a matrix of white etching ferrite

46

Figure 39: Photograph at 200x showing the tube microstructure away from the fracture in the thickest wall area—2% nital

The presence of martensite and bainite plus ferrite in the tube microstructures indicates overheating of the tube metal within the temperature range of 1320 º F (715º C) to 1650 º F (900 º C).

A quantitative chemical analysis was performed on the failed tube. The failed tube did conform to the chemical requirements of ASME SA 213 Grade T2 ferritic alloy steel (UNS K11547).

The horizontal reheater assembly front wall boiler tube failed as a result of a ductile stress overload failure caused by rapid short-term overheating. Rapid overheating in turn is caused by high tube metal temperatures and low the Analyst Volume 24 Number 4

Failure Analysis and Investigation Methods for Boiler Tube Failures continued

steam flow through the tube. In the present instance, the failure was promoted by the occurrence of a low tube wall thickness on the side of the tube that experienced failure (Figure 29). Creep expansion thinned the wall, and the creep rupture resulted in the failure by ductile stress overload at elevated temperatures.

Industrial Case 4—Hydrogen Damage One section of a boiler tube that had experienced corrosion of the inside diameter surface that led to perforation of the tube wall thickness was analyzed. The sample was identified as number 2 boiler; rear wall tube sample number 712. The rear wall tube was reportedly inclined and the corrosion occurred at the 12 o’clock position.

The tube material was specified to be 3.00 inch (76.2 mm) OD, 0.250 inch (6.35 mm) MWT, ASME SA 210 material (UNS K02707). The tube had reportedly been in service for approximately 260,000 hours, or over 29 years, with service conditions of 750 º F (400 º C) and 190 psi (13.10 MPa). The tubes were last chemically cleaned in 1995 using the chelant EDTA. We were requested to determine the mechanism of internal corrosion.

The outside diameter surface of the as received tube section is shown in Figures 40 and 41. All of the visible surfaces had been surface ground. The inside diameter surface of the as received tube section is shown in Figure 42. A large area of deep corrosion pitting accompanied by thick oxide scale layers at some locations was observed. Cracking was observed at the bottoms of the deepest corroded areas as shown in Figure 43. White colored deposits were observed around the periphery of and underneath the thicker black oxide scale layers.

Figure 41: Photograph showing the perforation in the tube wall thickness at the OD surface

Figure 42: Photograph showing the ID surface of the as-received tube section

Figure 43: Photograph showing the perforation in the tube wall thickness at the ID surface

Figure 40: Photograph showing the OD surface of the as-received tube section

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Failure Analysis and Investigation Methods for Boiler Tube Failures continued

The corrosion products within the corroded area of the inside diameter surface were further analyzed for their elemental compositions using a scanning electron microscope (SEM) equipped with an energy dispersive x-ray spectrometer (EDS). A spectrum of the brown deposit covering much of the inside diameter surface is shown in Figure 44. An EDS spectrum of the thick black scale was obtained and was confirmed to be iron oxide.

An EDS spectrum of the white colored deposit was obtained and was found to contain iron (Fe), phosphorus (P), oxygen (O), carbon (C), aluminum (Al), silicon (Si), copper (Cu), and zinc (Zn) plus lesser amounts of sulfur (S), calcium (Ca), and manganese (Mn).

Figure 44: EDS spectrum of the brown colored ID deposit

A transverse cross section through the secondary crack in the tube was prepared for subsequent metallographic examination. In the as-polished condition, the scale deposit on the inside diameter (ID) surface of the tube, in a non-corroded area is shown in Figure 45. The scale layer contained a considerable number of metallic copper particles. At locations where the tube wall thickness exhibited reduced values due to corrosion, cracking and void formation was observed adjacent to the ID surface that extended almost all of the way across the tube wall thickness. See Figure 46. Etching with a 2% nital solution revealed the existing microstructure which consisted of dark etching islands of pearlite in a matrix of white etching ferrite as shown in Figure 47. The microstructure within the damaged area is shown in Figure 48. The tube wall thickness at the secondary crack was measured

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to be 0.116 inch (2.95 mm). The tube wall thickness away from the corrosion pitted area was measured to be 0.214 inch (5.44 mm).

Figure 45: Photograph at 200x showing the ID oxide scale layer—as-polished

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Failure Analysis and Investigation Methods for Boiler Tube Failures continued

Figure 46: Photograph at 50x showing cracking and hydrogen damage void formation—as-polished

A quantitative chemical analysis of the tube material was performed. The tube did meet the specified chemical requirements of either Grade A-1 (UNS K02707) or Grade C (UNS K03501) of ASME SA 210.

The tube failed as a result of hydrogen damage that had initiated in a portion of the tube that had experienced a considerable decrease in wall thickness due to corrosion of the inside diameter surface. The corrosion, in turn, may have been caused by a localized acidic corrosion cell.

Conclusion

This article emphasized the basic problems and applied aspects of the corrosion and metallurgical failures of boiler tubes. Four separate types of failures were presented detailing the factors and mechanisms affecting the failures. Fatigue failures result in fracture initiation and propagation. Erosion failures lead to wall thinning and subsequent tensile overload. High tube metal temperatures lead to rapid short-term overheating, which in turn results in ductile stress overload. Hydrogen damage can be due to excessive tube metal temperatures or wall thinning from corrosion.

Figure 47: Photograph at 1000x showing the microstructure of the tube—2% natal

References

1. D.N. French, “Metallurgical Failures in Fossil Fired Boilers, Second Edition,” New York, NY: John Wiley & Sons, Inc., 1993.

2. R.D. Port and H.M. Herro, “The NALCO Guide to Boiler Failure Analysis,” New York, NY: McGraw-Hill, Inc., 1991.

3. C.R. Brooks and A. Choudhury, “Failure Analysis of Engineering Materials,” New York, NY: McGraw-Hill Companies, Inc., 2002.

4. J.P. Sibilia, “A Guide to Materials Characterization and Chemical Analysis, Second Edition,” New York, NY: Wiley-VCH, Inc., 1996.

Figure 48: Photograph at 1000x showing the microstructure of the tube in the hydrogen-damaged area—2% nital

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Reproduced with permission from NACE International, Houston, TX. All rights reserved. Zamanzadeh, Larkin and Linhart, 07/450 presented at CORROSION 2007. © NACE International.

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Corrosion Control for the Industrial Plant Steam–Condensate System

By Debbie Bloom, Nalco Champion, an Ecolab Company

Corrosion Control for the Industrial Plant Steam–Condensate System continued

Industrial plant steam and condensate systems vary widely in their design, sometimes with miles of pipe extending from process to process, carrying steam that drives rotating equipment, heats process streams, and at times enters into process reactions. Consequently, effective corrosion control in steam-condensate systems often requires a detailed understanding of the steam and condensate distribution network, the system metallurgy, the chemistry of the steam and its effect on the chemistry of the condensate, and any process restrictions on the treatment chemistry.

This article will provide a basic understanding of the causes of condensate system corrosion, the effects of steam and condensate system design on corrosion potential, the chemistries employed to control corrosion, the limits and concerns associated with treatment options, and the recommended monitoring and control needed to ensure effective protection of important equipment throughout the plant.

Introduction

A primary objective in the successful operation of any boiler system is to maximize its overall efficiency and reliability while minimizing the total cost of operation.

One of the greatest factors in achieving this objective is the amount and quality of condensate returned to the boiler as feedwater. Returned condensate, being condensed steam, is relatively free of impurities and has a fairly high heat content, making it ideal, both economically and technically, for boiler feedwater.

Economically, the more condensate returned, the less makeup water is required, which saves on both water and feedwater pretreatment costs. The high purity of condensate allows the boiler to operate at higher cycles of concentration while maintaining conductivity standards, thereby reducing costly water and energy losses to boiler blowdown. The higher heat content of condensate (158 Btu/lb at 190 °F [88 °C]) as compared to makeup water (28 Btu/lb at 60 °F [16 °C]) directly reduces the fuel requirements of the boiler to convert feedwater into steam. A 100,000 lb/hr [37,300 kg/hr] boiler system paying $3/MMBtu for natural gas could save roughly $17,500 a year in fuel just by increasing condensate return by 5 percent.

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Technically, the high purity of condensate frequently reduces the overall scale-forming tendency of boiler feedwater, especially in systems using softened or reverse osmosis pretreated makeup. This results in cleaner heat transfer surfaces and optimal heat transfer rates. Higher quality feedwater reduces the possibility of boiler tube failure due to excessive scaling. Additional savings will also be noted in reduced water treatment chemicals, water, and sewer costs.

To realize these benefits, however, a program of mechanical, chemical, and operational corrosion control must be implemented to manage the risks associated with condensate return. Left untreated or treated improperly, condensate is very corrosive to plant piping and equipment (commonly carbon steel or copper alloys). The resulting products of corrosion can enter the feedwater and form harmful, tenacious deposits on boiler heat transfer surfaces. Tube leaks at process exchangers can also allow process chemicals and raw or treated waters to contaminate the condensate and return to the boiler.

Thus, the consequence of condensate corrosion is often seen as boiler deposits, corrosion, or carryover, and results in the loss of boiler reliability. Effective chemical treatment, in conjunction with mechanical system improvements, condensate polishers, automatic dump systems, and proper testing and control, can ensure that condensate can be safely returned and valuable energy and water recovered.

Why Corrosion Occurs

Condensate corrosion is most commonly associated with carbon dioxide, although the presence of oxygen and ammonia may also be a problem. The major source of carbon dioxide (CO2) in steam is the breakdown of feedwater bicarbonate and carbonate alkalinity in the boiler. The liberated CO2 is carried with the steam into the condensate system. It is apparent that high alkalinity feedwater will produce very corrosive condensate.

Carbon dioxide is not harmful until it dissolves in condensate. As it dissolves, it forms carbonic acid (H 2CO3). Since condensate is extremely pure, even small quantities of carbonic acid can significantly lower condensate pH and increase its corrosivity. Figure 1 shows that as little as 1 mg/L of CO2 in the steam can depress condensate pH from 7.0 to 5.5 at typical condensate temperatures. the Analyst Volume 24 Number 4

Corrosion Control for the Industrial Plant Steam–Condensate System continued

Figure 1: pH Values of Carbon Dioxide in Pure Water

(Hamer, Jackson, and Thurston, 1961, p. 418)

on the temperature of the condensate and the location of ingress.

Oxygen can enter a condensate system through vented atmospheric receivers or heat exchanger leaks, or from air drawn in through small leaks when the system operates intermittently and pulls a vacuum as it cools (e.g., at threaded joints and faulty traps). An oversized mechanical condensate pump can empty a receiver so quickly that it pulls a vacuum, sucking air through acid in the receiver vent line. Air-powered pressure pumps that might be used in low-pressure portions of systems where condensate drainage is a problem will also increase condensate oxygen.

Severe pitting caused by oxygen attack can frequently be found at or just below the liquid surface in partially filled vessels and pipes and at points above the surface where condensate droplets are formed. Figure 3 shows the severe pitting typical of oxygen attack. These oxygen pits can rapidly corrode through metal surfaces, greatly reducing equipment life and contaminating feedwater with undesirable iron and copper corrosion products.

Corrosion rates also increase with increasing temperatures. Since condensate is hot, this causes it to be even more aggressive to metal surfaces.

Figure 3: Oxygen Pitting

Carbonic acid attack is characterized by a thinning or grooving of metal surfaces in contact with the corrosive condensate. In the absence of oxygen, carbonic acid generally creates a rather smooth surface where the iron has been dissolved away, as shown in Figure 2.

Figure 2: Carbonic Acid Corrosion

The combination of carbon dioxide and oxygen appears to accelerate corrosion rates by 10 to 40 percent of the sum of the corrosion rates occurring by either gas alone.

The overall corrosion can be very severe and appear as worming or surface roughness, as shown in Figure 4.

Oxygen present in most condensate systems is from air inleakage into the system itself. Oxygen concentrations greater than 100 Âľg/L are typical of systems with air inleakage. The final concentration is largely dependent 55

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Figure 4: Combined Carbonic Acid and Oxygen Attack

for modifications to be made as plant conditions change.

Chemical Treatment Strategies

Amine compounds are commonly used today to control condensate-system corrosion. These compounds generally fall into two different categories—neutralizing amines and filming technologies.

Condensate Best Practice Treatment Strategies

Application of a condensate treatment program usually consists of an original dosage estimate based on the amount of carbon dioxide potentially present in the boiler steam-condensate system, followed by pH determinations at the main condensate receiver. The measured pH may or may not be used to adjust treatment feedrate.

Some programs even go so far as to include corrosion coupons at a convenient location in the powerhouse to monitor corrosion rates. Rarely is this enough to ensure a successful treatment program, but it is a situation that is repeated frequently throughout industry.

A well-engineered condensate program will include chemical, mechanical, and operational components to minimize corrosion and optimize total cost of operation, as shown in Figure 5. Monitoring and control of the program is key.

Figure 5: The Components of Total Cost of Operation

To start with, we must first define the problems encountered in the current system so that the program can be designed to address each problem area. The design of the program must be simple to carry out but flexible enough 56

Neutralizing Amines: Neutralizing amines are volatile, alkaline compounds that are added to either the boiler feedwater or the steam supply system. They function by volatilizing into the steam and redissolving in the condensate with the CO2/carbonic acid. The amines chemically neutralize the carbonic acid present in the system. They raise pH to a level at which the condensate is not as aggressive toward the system metals. Examples of neutralizing amines used in condensate treatment include morpholine, cyclohexylamine (CHA), diethylaminoethanol (DEAE), ethanolamine (MEA), and methoxypropylamine (MOPA).

Most commercially available neutralizing amine condensate treatments are blends of various amines. The blends offer combinations of certain characteristics that are unique to each amine. The characteristics of greatest technical importance when selecting amines are specific volatility (V/L ratio), molecular weight, and basicity.

Compliance with government regulations, safety and handling characteristics, and threshold odor levels must also be considered in plants.

The measure of a neutralizing amine’s volatility, or its vapor-to-liquid distribution ratio (V/L), dictates when the amine will condense. All steam in a steam system does not condense at the same place or time. As the steam travels through the steam system, giving up energy in various processes, condensate forms and carbon dioxide dissolves into it. To neutralize carbonic acid, the amine must be present in the condensate as the carbon dioxide dissolves. The ratio is defined by equation 1 below:

The distribution ratio dictates how much of the amine will condense or remain in the vapor phase under existing conditions. Consider, for instance, a phase the Analyst Volume 24 Number 4

Corrosion Control for the Industrial Plant Steam–Condensate System continued

separation, when steam and condensate exist together in a 150-psig steam line. Suppose the steam has been treated with cyclohexylamine, an amine with a V/L ratio of 4/1 at that pressure. An analysis of the condensate would reveal that it contains 20 percent of the amine.

The remaining 80 percent would exist as a vapor in the steam. Under those same conditions, if the steam were to be treated with an amine with a relatively low V/L ratio, such as morpholine (V/L = 0.5/1 at 150-psig), 67 percent of the amine would be found in the condensate and 33 percent would be found in the steam.

Molecular weight and basicity determine an amine’s ability to neutralize carbonic acid dissolved in the condensate. The molecular weight of an amine determines how many molecules of the amine will be present in 1 lb. of chemical. On a pound-for-pound basis, lower molecular weight amines will neutralize more acid than higher molecular weight amines of equivalent strength.

The basicity of an amine indicates its ability to generate hydroxide ions. In the reaction with carbon dioxide, both the amine and carbon dioxide must first dissolve in water, as shown in equations 2 and 3. The OH- group generated by amine hydrolysis reacts with the H+ group from the acid to form water. A neutral amine salt (e.g., cyclohexylamine bicarbonate) is the end product of the reaction, equation 4.

Net reaction Amine basicity is also important after all the carbonic acid has been neutralized—resulting in a pH of 8.3— because it determines the ease with which the condensate pH can be further increased. These programs are most effective when fed to maintain a minimum pH of 8.5, ideally 9.0 to 9.3 for systems containing copper alloys and 9.2 to 9.6 for all ferrous systems, as shown in Figure 6.

Figure 6: Optimum pH control range for low pressure systems

Filming Technologies: Filming technologies are alternative condensate treatments available in both amine and non-amine forms. Unlike neutralizing amines, the amine-form filmers will neutralize very little carbon dioxide. Instead, they form a non-wettable film on all metal surfaces in contact with the condensate. This film acts as a barrier between the metal surface and the corrosive condensate. Thus, filming programs protect against both carbon dioxide and oxygen.

The non-amine filmers have seen recent popularity in the higher-pressure utility steam market, although their application in this industry is primarily as a feedwater and boiler treatment. They are typically proprietary chemistries that appear to significantly reduce metals transport, reportedly without adding much conductivity to the steam.

Non-amine filming technologies are also popular with industrial food and drug manufacturers. Since they are often non-volatile chemicals, they must be entrained in the steam to achieve distribution. When the product comes in contact with the metal, it forms a non-wettable barrier that isolates the metal from water and corrosive contaminants. Some show good persistence of the barrier and provide continued protection in systems that opperate intermittently or may be shut down overnight or on weekends. These products can be less toxic and odorless. They can also reduce the risk of handling and may be FDA approved.

Dosage of the filming technologies chemistries is dependent on the size of the condensate system being treated, not on the amount of dissolved gases present in the condensate. Some require a specific system pH

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Corrosion Control for the Industrial Plant Steam–Condensate System continued

to achieve desired results. At higher pH values, the film formed may be stripped off metal surfaces, causing deposits downstream. Acidic environments may inhibit film formation. Because of their low to no volatility, better performance is typically achieved when they are fed to the steam in industrial systems.

Concerns About Chemical Treatment

Industrial steam must be safe for use as needed. Treatment choice must comply with all appropriate government regulations and plant specifications. Steam requirements can limit, and in many instances, determine the potential options available for condensate treatment.

Food and Drug Administration (FDA): Food and drug processing falls under the jurisdiction of the FDA. Food preparation in which there is direct contact between the steam and the food is typically regulated by the Code of Federal Regulations (2016) 21 CFR 173.310 (Table 1) and 21 CFR 182-186 (Generally Recognized as Safe listing).

Table 1: From 21 CFR 173.310(d) — Boiler Water Additives for Steam-Condensate Treatment

Treatment

Cyclohexylamine

Morpholine

Maximum Level in Steam1,2

Not to exceed 10 mg/L in steam, and excluding use of such steam in contact with milk and milk products

Not to exceed 15 mg/L in steam, and excluding use of such steam in contact with milk and milk products

Diethylaminoethanol Not to exceed 10 mg/L in steam, and excluding use of such steam in contact with milk and milk products Octadecylamine

Sorbitol anhydride ester Ammonia

Not to exceed 3 mg/L in steam, and excluding use of such steam in contact with milk and milk products

Individual components of mixture not to exceed 15 mg/L in the steam See below3

(1) Amines cannot be used to treat steam that could contact milk or milk products (2) Total amine cannot exceed 25 mg/L (3) No more than required to produce intended technical effect 58

Only approved compounds that are applied in accordance with the regulation may be used in these applications. Additional regulations may apply or supersede 21 CFR 173.310, especially in the manufacture of drugs.

Steam is often used to humidify building air, especially during the winter. When steam is introduced into the air, any volatile compounds contained in the steam are also introduced into the air. The American Conference of Governmental Industrial Hygienists (ACGIH) and the Occupational Safety and Health Administration (OSHA) are the two regulating bodies for airborne substances in the United States.

ACGIH has adopted standard Threshold Limit Values– Time-Weighted Averages (TLV–TWA) for amines in air based on their irrigative properties. The TLV–TWA is the time-weighted average concentration to which nearly all workers may be exposed for eight hours per day, 40 hours per week, without adverse effect. OSHA has also established time-weighted average permissible exposure limits (PEL) for commonly used amines. These limits and odor thresholds are listed in Table 2. To date, no major agency or association has prohibited the use of steam treated with chemical additives for humidification, but questions and concerns about such use are common.

Odor threshold is also listed in Table 2.

Table 2: Amine PEL and Odor Threshold Summary

Amine

Morpholine

Diethylaminoethanol

Cycloheylamine

ACGIH TLV-TWA (8 hr) mg/m3

OSHA PEL/ TWA mg/m3

OSHA PEL/ TWA g/m3

0.7

41

0.04

71

41

71

41

0.14

0.90

It is not uncommon for people to complain of amine odors. The relationship between the OSHA PEL, the odor threshold for the amine, and the concentration of amine generally required for its intended use should be understood. Table 2 shows that the odor threshold for these amines is significantly lower than their OSHA PELs. Odor complaints can be triggered well before any regulatory limit has been reached. It is also important to note that the concentration of amines generally needed to provide condensate system protection is often an order of magnitude lower than the odor threshold for the the Analyst Volume 24 Number 4

Corrosion Control for the Industrial Plant Steam–Condensate System continued

amine. Generally, if an odor is detected, more amine is present than is required for its intended use.

Mechanical Treatment Strategies

Although chemical-based solutions to condensate corrosion are common, they should always be applied in conjunction with mechanical treatment strategies. These include: Good system design Proper maintenance Reduction of system carbon dioxide Polish or sewer condensate as needed System Design: Steam-condensate system design not only affects the delivery of quality steam but also the ability to remove condensate from the system. Poor drainage of condensate can result in corrosion, erosion, and water hammer, all of which will eventually result in leaks and failures and limit the amount of condensate returned for reuse as boiler feedwater. It is not within the scope of this article to thoroughly discuss all the design issues that might affect a plant’s ability to return condensate. However, common good engineering practices are listed (Spirax Sarco, 2000).

Supply dry, high-quality steam. Steam quality must generally match system requirements and be of sufficient quality (dryness) to not erode components.

In those instances when high-moisture steam is used, a steam separator should be considered. Supply lines should also be insulated and trapped to prevent accumulation of condensate.

Isolate steam from unused lines with properly located isolation valves. Any dead leg open to steam should be trapped to prevent condensate accumulation.

Make sure lines and traps are properly sized. This minimizes pressure loss, erosion, heat loss, and blowthrough steam. Horizontal lines should be sloped at 1 inch per 10 feet in the direction of flow and should be properly supported to prevent sagging and condensate accumulation.

Install sufficient traps on steam mains to remove condensate as quickly as possible. At a minimum, traps should be located on all vertical risers upstream of control valves and at 100 to 300 foot intervals along horizontal runs of pipe.

Use the correct trap for the application. Never group trap, as it invariably leads to backup of condensate in the system.

Ensure that piping allows the condensate to be removed effectively. Coils should be fitted with a

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Corrosion Control for the Industrial Plant Steam–Condensate System continued

vacuum breaker to allow condensate to drain freely.

Waterlogged equipment not only fails to operate as expected but also is prone to corrosion and water hammer.

When possible, avoid any increase in elevation on return condensate lines. Condensate that is evacuated to a higher elevation doesn’t flow by gravity. It requires a pressure slightly greater than the head pressure resulting from the elevation rise. When elevation of condensate after a trap is necessary, a pumping trap may be necessary to ensure good drainage.

Install receiver vents of the proper size. Receiver vent lines that are too small restrict the loss of flash steam. This in turn results in hotter condensate return temperatures and potential problems with cavitation of electric condensate return pumps. Alternatively, use air-powered pressure pumps.

Make sure condensate return lines are sized to move the flash and blow-through steam present after a trap as well as the condensate. Steam (vapor) is more voluminous than condensate (liquid). Condensate piping that is sized for liquid only is grossly undersized.

Choose materials of construction that will minimize corrosion.

Maintenance: Good maintenance is critical, especially for steam traps and steam or condensate leaks. Both result in wasted energy and directly affect Total Cost of Operation. A survey published by the U.S. Department of Energy in 2002 but still relevant today, estimated that: Typical fuel savings of 3 to 7 percent could result from an effective steam trap management program.

Typical fuel savings of 1.4 percent could result from repairing steam leaks.

Steam traps are automatic mechanisms that remove condensate from the steam system. They may be located on the steam distribution line (very little condensate) or following some sort of heat exchange equipment (mostly condensate). Like other mechanical equipment, they have a finite life expectancy that depends in part on the severity of operating conditions to which they are exposed. A certain percentage of the trap population will fail every year — typically between 10 and 15 percent (US DOE, 2002). The lack of steam traps or the use of failed traps leads to a gradual decline in heat-transfer efficiency, waterlogged heat exchangers, and water hammer.

• Traps that “fail open” may allow considerable volumes of steam to blow-through, resulting in a reduction in the overall boiler system efficiency.

• Traps that “fail shut” lead to waterlogged lines and water hammer.

• Traps that are corroded lead to steam and waste heat energy.

When adequate maintenance of traps is neglected, the boiler load must increase to supply the required plant steam in addition to the extra steam lost from the system.

In every case, the trap will not begin to lose steam until the leakage area exceeds that needed to discharge the condensate load. The cost of the failure then begins to climb and reaches a maximum when the trap has failed completely open. The object of a trap survey is to prevent the failure from reaching that stage.

The amount of the steam lost through a failed open trap blowing to atmosphere is shown in Table 3.

Table 3: Leaking Steam Trap Discharge Rate*

*Data based on a variant amount of the Napier formula (Spirax Sarco, 2000, p. 57)

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Corrosion Control for the Industrial Plant Steam–Condensate System continued

A single trap leaking at only 10 lbs/hr (4.5 kg/hr) will cost roughly $50 over the course of two months at today’s energy prices. This doesn’t sound like much, but when multiplied by the total number of failed traps in your plant and the total time they are left in disrepair, the number can grow substantially. The steam system always functions best when traps are selected that are best for the application and checked on a regular basis to control losses.

Carbon Dioxide Reduction: Carbon dioxide in the steam can be reduced by removing bicarbonate and carbonate alkalinity in the makeup water. This can be accomplished by a number of well-run pretreatment systems:

condensate. The type of polishing equipment selected depends on the contaminant and quantity to be removed, and also on the water chemistry requirements of the boiler system. Most polishers rely on some sort of ion-exchange technology, which replaces the contaminant with a less-objectionable species. Ion-exchange units can also serve as filters of suspended particulates, typically metal oxides, if operated at a flow rate sufficient to compact the bed. As mentioned previously, no process is 100 percent efficient; so even with a condensate polisher in line, some amount of contaminant will likely make it through the polisher to the feedwater.

Another means of minimizing the effect of contaminated condensate is to sewer it before it returns or reaches the polishers. Depending on the degree of contamination, this is often a prudent action. Badly contaminated condensate may quickly exhaust or foul polishers, allowing the full amount of contamination to return to the feedwater system.

• Dealkalization • Demineralization • Reverse osmosis • Gas transfer membranes In can also be accomplished by increasing the amount of condensate return, and a small amount may be lost by deaeration, depending on makeup water pH. These processes are never 100 percent complete, so some bicarbonate/carbonate will always be present in the boiler feedwater, with the actual amount depending on the pretreatment process and the operational conditions. As a result, some carbon dioxide will always be present in the steam.

Originally presented at the International Water Conference: November 6–10, 2016. Please visit www.eswp.com/water for more information about the conference or how to purchase the paper or proceedings.

Polish or Sewer Condensate as Needed: Because condensate is a valuable product and its reuse is considered essential to minimizing the Total Cost of Operation, condensate is usually recycled. Although impurities in condensates are usually quite low, in some instances they must be removed before the condensate is reused, or else the condensate will have to be sewered.

These impurities originate from dissolved solids introduced through condenser and heat exchanger leaks, dissolved solids carried over with the steam from the boiler water, and soluble and insoluble metallic species originating from condensate system corrosion.

Polishing units can be used to minimize the effect of contaminated condensate so that it can be reused as boiler feedwater. A variety of polishing equipment is available for the removal of contaminants from 62

the Analyst Volume 24 Number 4

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Phosphate Hideout: What Is It?

By Heyl Brothers

64

the Analyst Volume 24 Number 4

Phosphate Hideout: What Is It? continued

That’s what I asked myself on more than one occasion.

The first time was at a meeting with a plant chemist at a utility. My first thought was “you’re asking me? You’re the plant chemist.” I guess plant chemists don’t know everything after all. An important lesson. Even utility plant chemists look to our industry for answers.

At this point, all I knew was phosphate hideout has to do with precipitation of phosphate in the boiler. The next time I thought about this issue of phosphate hideout was in the 90s, when the power industry was experiencing a lot of high-pressure boiler tube failures. All of these plants were on coordinated phosphate, and many had excellent control. Our industry—the water treatment chemical companies—did not have answers. There were so many questions that EPRI was called upon to investigate.

Apparently, I wasn’t the only one that did not understand phosphate hideout. Even more fundamental to the issue was a thorough understanding of coordinated phosphate program itself. The investigation proceeded with failure analyses, deposit analyses, and every kind of inspection and analysis you can imagine. One of the key findings in the failure analyses was that there were two things in common. All of these failures were related to deposits of phosphate—what I call phosphate hideout. The second thing in common was corrosion. All of the failures were caused by the underdeposit corrosion that a well-controlled coordinated phosphate program is supposed to stop, or at least minimize.

A coordinated phosphate program is designed to provide good water chemistry and pH control to minimize corrosion. It is also designed to minimize phosphate hideout by staying below the solubility of sodium phosphate compounds. If there is a deposit of hideout or anything else, be it contamination, condenser leak, pretreatment failures, whatever, it is designed to be noncorrosive under the deposit. It is designed so that in case of deposits, the concentrating liquid under the deposit is not corrosive.

These failure analyses indicated that this was not the case. They were corrosion failures. The corrosion was related to deposits. So now everyone was in a dilemma.

What happened? What’s wrong with our coordinated phosphate programs?

65

The search for answers started with a lot of boiler water microanalyses. We were doing ppb level total analyses of our boiler water to make sure our Na to PO4 molar ratio was correct. We were correcting for contaminants. All anionic contaminants have to be associated with a cation.

If there is not a cation associated with all of the anions, then sodium must be added as the associated cation to neutralize the anions. Otherwise, it is an acid in the water and will be acidic under a deposit. This sodium then has to be subtracted from the total sodium. This is because this sodium is not available to associate with the phosphate and be counted in the Na/PO4 ratio. The analyses were revealing. Sometimes we were in ratio and sometimes out. Contamination could be very significant. Even when control was within the proper range in pH/PO4 control box. This created more questions.

How do you (or I) control a program with contaminants? Polishing condensate can be one way. Addressing condenser leaks aggressively may be another depending on the case.

The one comment that was often heard was “if you have a clean boiler, it’s not an issue.” This is a true statement. Maybe it was not paid enough attention. But it didn’t really answer the question of what is causing the problem. Yes, these failures were associated with deposits. But why? And why are there deposits if control is good?

The next time I asked the question about hideout, I had an opportunity to treat a 1,400 psi boiler with “issues.”

The issues were not totally clear. I suspected phosphate hideout. But reading about it and treating it are two entirely different propositions. That’s when I really started to read the literature and talk to the experts and consultants; I read the EPRI papers. I learned a lot quickly. In the meantime, almost immediately after I undertook the treatment of the high-pressure boiler, the plant dropped the load, reducing boiler operating pressure (and temperatures), and the phosphate took off through the roof. Simultaneously, the pH dropped down to the 5s. Oh yes, phosphate hideout. The phosphate re-dissolves off the former hot spots as the temperature cools and the phosphate solubility increases. What to do?

The phrase “clean boiler” comes to mind. From that day, the phosphate feed was discontinued. The first step if you have hideout is to get rid of the phosphate on the tubes.

We formulated a dispersant blend with no phosphate to the Analyst Volume 24 Number 4

Phosphate Hideout: What Is It? continued

feed during the cleanup. The cleanup continued for 14 months. During this period, the initial boiler inspection showed phosphate caked in hotter areas. It was clearly precipitating at the hot spots.

To find the answers to these questions, the research went backwards. Back to the original Dr. Hall’s work that developed the coordinated program.

The original coordinated phosphate program was designed in the lab. The control box was built on lab data of distilled water, sodium, and phosphate. The sodium-to-phosphate ratio was the critical parameter. Samples were made down in the correct sodium-to-phosphate ratio in various concentrations and tested to determine the pH at the various concentrations.

Once you understand this, it becomes obvious where to look for the problems.

How many boiler systems on conditioned phosphate programs do not use an oxygen scavenger, dispersant, or neutralizing amine? Not very many. None that I know of in fact. And do any of these affect the pH of the program? Of course they do. And when you control your pH in the box, does this change your sodium-to-phosphate ratio. Yes. And this was the problem. The entire premise of a coordinated phosphate program is the sodium-to-phosphate ratio. Changing that ratio makes the program no longer neutral. It is now either acidic or caustic.

Examples: Let’s say you are feeding an amine. I think this is the simplest and easiest to follow scenario. You feed an amine to raise the pH of the condensate in most cases. Does this change the boiler pH? It seems to in the boilers I treat. Not all of the amine is volatile and goes with the steam. Some stays in the boiler. This varies depending on the amine in use and its distribution ratio.

You adjust your sodium and phosphate feeds to maintain control in the box. What has happened to the Na/PO4 ratio? It has dropped. You are now in an acidic treatment.

Under a porous deposit, the amines boil out. The solids (sodium and phosphate) do not.

Oxygen scavengers are also volatile. Some are acidic and some are alkaline. These work in the same manner as the amines to throw off your sodium-to-phosphate ratio.

66

Dispersants are slightly different. Most dispersants I am familiar with are acidic. They are often neutralized to a neutral or alkaline pH. The critical thing with dispersants is to know exactly how much sodium is required to reach the equivalency point. The sodium associated with the dispersant equivalency point cannot be used for the sodium to phosphate ratio. Under a deposit, the sodium associated with the dispersant is not available to associate with the phosphate.

The sodium in the program has to be adjusted for. If you have contamination of any kind, the sodium associated with any anions has to be subtracted from the total sodium before the sodium-to-phosphate ratio is determined. The net sodium after subtraction is what is used for the ratio calculation.

Other factors are condensate polishers. These can be regenerated with either sodium brine or amine. Which one is better for a good coordinated phosphate program?

All of these examples are to show how easy it was to stay in the control box and yet change the sodium-to-phosphate ratio to the point you are out of the proper ratio of Na to PO4.

What Is Phosphate Hideout?

If these programs are designed to be soluble at the various pressures, why are they not? Have things changed since the original program was designed?

Metallurgy? Heat rates? Heat flux on the hottest tubes in the firebox? Boiler designs including all of the above?

Certainly all of the above. Thinner tubes mean better efficiency. Thinner tubes also mean higher heat flux across the tubes, meaning hotter temperatures on the water side metal skin. This reduces solubility of the sodium phosphate. Certainly one of EPRI’s findings and recommendations was that you may have to reduce the phosphate control range for a particular boiler. You may even have to determine the phosphate solubility for your particular boiler. Could this be the phosphate hideout root cause? In my opinion, it certainly is one of the root causes if not the primary. Phosphate hideout is the precipitation of sodium phosphates in boilers.

The phosphate scale precipitates on the hot spots and low-flow areas as any scale does. It could be so hot that it is boiling dry, or there could be another cause. But the old saturation curves that tell us that as temperature the Analyst Volume 24 Number 4

Phosphate Hideout: What Is It? continued

increases, so does the sodium phosphate solubility are wrong. In high-pressure boilers, the sodium phosphate solubility can be less than the coordinated phosphate/pH curve would indicate. The sodium phosphate becomes inversely soluble with temperature similar to the divalent cations.

What else affects solubility besides temperature?

Certainly chemistry can be an issue. But control was good in many cases.

When we look at how these additives can change our water chemistry, it is understandable how it also can change the solubility of phosphate and create hideout where our pH control says it should not. If we are using something acidic and we adjust with more alkaline chemistry, we tend to raise our sodium-to-phosphate ratio. This tends to reduce the solubility of the phosphate, thus allowing phosphate precipitation.

A poor understanding throughout our industry (myself included) is one of the reasons this has been allowed to happen. Many of our clients depend on us to prevent this kind of thing.

Recognizing Phosphate Hideout

Phosphate hideout indictors are not always easy to spot.

In severe cases, it is easier. Significant load changes are usually the best indicator. In my case, with the 1400 psi boiler, a significant drop in load led to a large increase in the phosphate reading and a drop in the pH. Conversely, as load increases, the phosphate level drops significantly.

This makes it pretty easy. Other indicators are the boiler itself. When open for inspection, I could see phosphate caked into the tube ends and crevices where the flow rate dropped and the hotter tube ends acted like radiator fins and were hotter than the surrounding water and drum walls. In this case, we were fortunate. This was a peaking plant and had significant load changes that radically changed the solubility of the phosphates. Base loaded plants and industrial plants with minimal load swings make it much more difficult to diagnose. This is one of the reasons there were so many failures due to hideout.

The hideout was not found until there were tube failures.

Suspicion: How Do I Know?

Determining whether or not a hideout condition exists can be a difficult and expensive proposition if the case 67

is not obvious like mine was. Good, thorough boiler inspections are a must. Good deposit analyses are also required. Testing phosphate level prior to and after a load change is another good indicator. Any increase at all is a pretty sure indicator.

The next step if you are not sure is probably tube X-rays or nondestructive testing of tubes for scale. This can be time consuming and expensive. This sometimes does not provide all of the information required. Knowing you have a scale does not tell you what it is. Tube sampling and following up with deposit weight densities are an industry standard for boilers at risk. The biggest issue in this case is where to sample. The hot spots are the places to sample, but these can vary depending on the boiler, fuel, and other factors. There are a lot of resources to look for with regard to your particular case. Industry groups are very good. In the electric industry, we have the Electric Power Research Institute (EPRI). In the paper industry, we have the Technical Association of the Pulp and Paper Industry (TAPPI) and the Black Liquor Recovery Boiler Action Committee (BLRBAC).

BLRBAC is one of the foremost authorities on boiler tube sampling. It can provide diagrams of boiler furnaces and the recommended annual sample points. B & W boiler manufacturer has published papers on allowable deposit weight densities for varying boiler pressures.

Reading the literature on case histories and the EPRI papers on the topics can provide additional guidance. In fact, they provide a guide as to how to determine the solubility of the phosphate in a particular boiler system.

This boil down to discontinue feeding phosphate and see how long it takes to drop down to zero phosphate. This should not take too long depending on boiler volume and blowdown rate. The blowdown rate on a higher pressure boiler is usually around 1 %, so a few days may be required. The biggest issue with the process is owner resistance. Most owners do not want to shut off the phosphate feed. This will require a lot of confidence in their water treatment chemistry provider. The EPRI papers on the topic may be a good tool in this case. This method is probably the best and ultimate test to determine if phosphate hideout is an issue. If the loads vary in the system, a low load is usually a requirement. If deterioration of the phosphate level takes longer than can be explained by blowdown, hideout is occurring.

the Analyst Volume 24 Number 4

Phosphate Hideout: What Is It? continued

What to Do?

The phosphate hideout issue is all about water chemistry creating a scale and thus damaging the boiler. In high-pressure boilers, the water quality is typically extremely good. Usually, the water is mixed bed quality.

The boiler is getting this very good water. We want to make sure we are not killing the patient. The most important water-side condition of a high-pressure boiler is cleanliness. Scale of any kind is a bad thing. Scale can be an insulator and create overheat damage to tube metal. In addition, in the case of porous deposits like phosphate, it allows underdeposit concentration of boiler water that can lead to corrosion. Therefore, when phosphate hideout is found, cleaning it up is the number one priority. Shutting off the phosphate is the first step. An interim water chemistry program without phosphate is the next step.

The design of an interim program is critical. We know we have a porous scale that will allow salt concentration underneath it. We need to keep the water salts sodium neutral. We would like to feed a dispersant to help with the cleanup process. This also needs to be sodium neutral. We need to also keep the overall water chemistry at a non-aggressive pH for the clean boiler metal.

The formulation may vary depending on a particular case. We did not have a lot of detailed chemistry of the prior products fed, or overfed in my particular case. We made an assumption that the sodium-to-phosphate ratios in the chemicals fed during the overfeed, which created the hideout, were correct. Therefore, we did not add additional sodium to the cleanup treatment for the phosphate in the water that was coming off the tubes.

We maintained the pH control with amine chemistry.

We continued this program until the phosphate was zero.

This took 14 months. This allowed a lot of time to determine a proper coordinated phosphate program for this system. Each system needs to be looked at independently.

The New Coordinated Phosphate pH Program

There are several factors in designing a coordinated phosphate pH program. The single most important may be knowing how much sodium is entering the system.

We know what we are feeding in our treatment. The other possible areas could be a condensate polisher and the pretreatment mixed bed or demineralizer. Most polishers are sodium cycle and will contribute sodium. If 68

nothing else, it will exchange the amines. Mixed beds are notorious for issues. Mixed beds are complex units with very sensitive flowrates and temperature controls.

Sodium leakage can occur here, and these should be evaluated. In our case, we had no condensate polisher and an extremely good mixed bed operation. The chemical feed system is the next consideration. If sodium is stable, you can feed a pre-blended product. This is the best possible scenario. Operator blending, weighing out mono, di, and tri sodium phosphates, dispersants, etc. can be an accident waiting to happen. The importance of feeding a proper sodium-to-phosphate mix and sodium-neutralized dispersant cannot be overstated.

Controlling the Program to Prevent Future Hideout and Stay in Coordination

The first step in setting control parameters is to determine the phosphate solubility in the boiler. The solubility changes with load and thus temperature.

Therefore, this determination should be made at maximum load. EPRI has a procedure for this. In our case, we decided we did not want to go through this process. We decided on a relatively low and safe phosphate target. One of the drawbacks of the solubility determination process is that you oversaturate the boiler with phosphate to see how much stays in the water. This is the solubility point. You put phosphate back on the tubes because you overfeed to make sure you get to saturation. Then you have to clean up again.

This is a hard sell to most plant operations managers.

In our case, we chose an undersaturated point for our phosphate target. The drawback is some loss of protection of the phosphate buffer. Phosphate is a buffer for contamination as well as normal chemistry issues of control, feeding, make down, etc. The more phosphate in the water, the more protection from these upsets, swings, contaminants, etc. So, there is a tradeoff of sorts if you do not go through the EPRI procedure.

Once the control limits are chosen, control capabilities need to be reviewed. Can you stay within the control parameters? A poorly controlled program is what I call an “uncoordinated phosphate program.� In some cases, this may not be the best choice of programs. You would need to look at the alternatives and make a decision. The alternatives will depend on pressure and system capabilities. the Analyst Volume 24 Number 4

Phosphate Hideout: What Is It? continued

Verifying

The final step in correcting a hideout issue or operating any coordinated phosphate program is to verify. The sodium-to-phosphate ratio needs to be verified. A good program should be able to calculate the expected sodium from dispersant, chemical additions, and all other cations and anions, and calculate how much is available for coordination with the phosphate. This should be done periodically to verify coordination. Microanalysis of all ions is required for this methodology.

Summary

Simply put, phosphate hideout is the reversible precipitation of phosphate in a high-pressure boiler. The mechanism of the precipitation may not be totally defined. But the rules of influence of pH, alkalinity, concentration, and temperature apply. High-pressure boilers can have hot spots and limit the solubility of phosphate below the concentration shown on the charts (PO4 /pH). These hot

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spots can and will vary with load. Thus, solubility of PO4 will vary with load. Therefore, operating ranges need to be designed for max load.

Phosphate hideout can be determined and cleaned up online.

Bibliography 1. Hollander, O., “Control of Sodium to Phosphate Ratio in Real Time in a Boiler in the Presence of Additives and Impurities”, Paper 99236, presented at The National Association of Corrosion Engineers Conference, CORROSION 99, SYMPOSIUM: 99-T-3U 2. Dooley, B, and Peterson, S. “Phosphate Treatment: Boiler Tube Failures Lead to Optimum Treatment,” Proceedings of the 55th International Water Conference, Pittsburgh, PA, October, 1994 3. Buecker, B., “Utility Water Chemistry Update,” POWER Engineering, July 2001

4. Setaro, D., “High Pressure Boiler Water Treatment,” Paper presented at American Institute of Chemical Engineers, San Francisco, CA, November 28, 1979 5. Gibson, G., “The Basics of Phosphate-pH Boiler Water Treatment,” Power Engineering, February 1978

6. Stodola, J., Silbert, M., “Enhanced Phosphate Treatment for Drum-Recirculating Boilers,” InterCorr/96

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Association News

Greenbuild Exhibit

AWT recently exhibited at the USGBC Greenbuild show in Boston. The goal is for USGBC to continue to look to AWT as experts in industrial water treatment and seek our counsel as they revise LEED standards.

AWT currently has a member on the USGBC Water Efficiency Technical Advisory Group (WETAG).

Membership Dues

Be on the lookout for your 2018 membership dues invoice. Membership dues for 2018 remain the same as last year. Payments received after December 31, 2017, are subject to a late fee of $50, so get your dues payment in early! This is also a great time to make any updates or additions to your company contact information. Watch your mailbox!

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AWT Presents 2017 Award Winners

AWT awarded the Ray Baum Memorial Water Technologist of the Year and the Supplier of the Year Awards at the 2017 Annual Convention and Exposition in Grand Rapids, Michigan.

Robert Ferguson, French Creek Software, Inc., received the prestigious Ray Baum Memorial Water Technologist of the Year Award. The award recognizes entrepreneurial spirit and outstanding contributions to the field of water treatment and service to AWT and its members. “Rob has been a very active member in AWT and his contributions have helped this organization, and our industry, grow and prosper,” said Bruce T. Ketrick Jr., CWT, AWT’s immediate past president.

Michael Highum, on behalf of McGowan Insurance Group, received the Supplier of the Year Award.

McGowan received this award because of its outstanding customer service, quality products, and contributions to the industry.

the Analyst Volume 24 Number 4

Membership Benefits

Are you taking advantage of all the discounts available to you through your AWT membership? Your membership can pay for itself if you sign up for any of these programs.

TSYS Merchant Services Discount Program

With more than 30 years of industry experience, TSYS Merchant Solutions offers AWT members a full portfolio of payment-acceptance solutions that include credit, debit, prepaid, mobile, chip, digital wallet, and B2B.

Legionella and Water Management Plan (WMP) Training

AWT members who are not HC Info water management plan (WMP) partners can now get 25% off HC Info e-Learning courses—the same discount given to the partners.

David H. Paul, Inc. Training

AWT members can save 15% on all DHP seminars and certifications that provide water treatment professionals with an independent and objective verification of their knowledge and proficiency, contributing to job security and personal advancement for the employee and an effectively trained workforce for the employer.

OfficeMax Partner Advantage Program

Members of AWT will enjoy substantial savings of 31% to 88% off the manufacturer’s list price on frequently purchased items and get reduced pricing on more than 12,000 in-stock products and 3,700 environmentally preferable products and services.

audio conferencing. Members also have access to web conferencing and Microsoft® Office 365.

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As AWT’s preferred transportation provider, members benefit from GTS’s group buying power of over 2,000 strategic partnerships and expertise in contract management and negotiation. GTS delivers big savings to AWT members of up to 35% off freight shipping.

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Plus, savings begin at 70% on UPS Freight® shipments over 150 lbs.

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the Analyst Volume 24 Number 4

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Industry Notes

H2O APTech Group Appoints Creative and Marketing Director

APTech Group, an innovative global manufacturer of blended solid-concentrate water additive products that provide a safer and cleaner alternative in treating cooling towers, boilers, and closed-loop systems, recently appointed Kathleen Collier to creative and marketing director. In this new role, Kathleen will interact closely with partners to develop and drive momentum associated with APTech’s solid-concentrated water treatment product offerings and develop APTech’s “story” with a creative and innovative approach. With eight years of experience at APTech Group, her background is well suited to coordinate and lead the creative and marketing activities for the company.

Matt Horine, APTech’s managing director, stated, “Kathleen is very creative and will be able to take all that she has absorbed during her eight years working for APTech Group and have a very deep impact on us and the market. I am very excited to see the direction Kathleen takes with our story and how it’s told.”

APTech Group is a global manufacturer of blended solid concentrate water treatment products, with headquarters and a blending facility located in Blue Ash, Ohio. Blended solid concentrate products provide a clean, green, and safe alternative to treat water in cooling towers, boilers, and closed-loop systems. APTech Group offers a complete line of proven water treatment products designed to manage most types of raw water components, such as hardness, pH, and alkalinity.

Today, APTech Group’s blended solid concentrate products are supplied and serviced by over 200 water 73

treatment partners in the United States. Additionally, its products are exported throughout Canada, Mexico, Central America, South America, the United Kingdom, Europe, Australia, New Zealand, Korea, Malaysia, and Thailand. An estimated 10,000+ installations of APTech 2 4 Group’s blended solid concentrate water treatment products are worldwide.

H SO

APTech Group has been nominated for the EPA’s 2007 and the 2010 Presidential Green Chemistry Award.

It has also been a finalist in the Cincinnati Business Courier Green Awards and several local chamber of commerce business award competitions, and has been ranked in the Inc. 5000 list of the fastest growing privately held companies.

For more information visit www.aptechgroup.com.

LANXESS Doubles Membrane Production Capacity

Specialty chemicals company LANXESS—as announced previously in mid-2017—has doubled its membrane capacities. “We have expanded the capacity of our plant in Bitterfeld so that we can continue meeting the rising demand for reverse osmosis membrane elements. This step makes us even more attractive as a supplier to major customers,” says Jean-Marc Vesselle, head of the Liquid Purification Technologies business unit at LANXESS.

The market for reverse osmosis membrane elements is currently projected to continue growing at an above-average annual rate of 10 percent (CAGR 2015-2020) in the years ahead. Because the plant was already operating almost at the limit of its capacity, LANXESS decided to double it.

Production of membrane elements for the Lewabrane line is a multistage process. It begins with the fabrication of a thin-film composite membrane comprising several the Analyst Volume 24 Number 4

Industry Notes continued

individual layers. A polysulfone base layer and an active filter layer are applied on a nonwoven base substrate.

The filter layer is made of polyamide and applied in a complex coating process. Produced as flat components, the reverse osmosis membranes are then wound by fully automated autowinders into spiral-shaped elements. This design helps to conduct untreated water towards the membrane surface and to collect the permeate (filtrate).

In addition to the membrane elements plant, LANXESS also operates the world’s largest plant for monodisperse ion exchange resins in Bitterfeld. LANXESS has been continuously expanding its line of membrane elements since production began in September 2011 and the products were introduced to the market in early 2012. Today, numerous types of Lewabrane elements are available in different sizes, which can be optimized for high fouling resistance, high energy efficiency, or high performance.

The new Lewabrane RO ULP line is the latest addition. These “Ultra Low Pressure” elements display higher water permeability than the standard elements while offering the same high level of rejection of critical substances. The operating pressure required in the pressure vessel is 40 percent lower, which reduces operating costs. Furthermore, the new membranes are a good option for removing micropollutants from wastewater and drinking water.

the future will hold for this leader in the water-testing industry.

Stephen Heard will be purchasing Taylor Technologies.

He comes to Taylor after 27+ years with Lonza Group LTD (most recently serving as global business unit head).

There, he led the pro channel teams on a global basis for recreational water.

Stephen has worked in nearly every business discipline, including sales, sales management, manufacturing, supply chain, business management, mergers and acquisitions, and strategy. Stephen’s strengths, passion, and successes all center around people. He has a zeal for building winning teams, cultivating differentiating strategies, and developing enduring relationships. Those relationships, including international connectivity and industry know-how, will accompany him to his new post at Taylor Technologies, and he’s sure to hit the ground running.

A father of four, Stephen and his wife, Karen, look forward to their new residence in Maryland, which will include two horses for their two girls.

Detailed information is available online at http://lpt. lanxess.de/. The LewaPlus design software can also be downloaded from this website free of charge.

Taylor Technologies, the most trusted name in water testing, offers nearly 600 different wet and dry test kit configurations and tests strips as well as micro-processor-based instruments and water-testing software.

Wherever water quality is monitored, Taylor makes it fast, simple, and reliable. For more information, please visit www.taylortechnologies.com/.

Taylor Technologies Announces New CEO

Walchem Announces New W900 Series Controller

A new CEO is about to take the helm at Taylor Technologies, and he brings with him a global network of suppliers, customers, and innovators in the fields of science, technology, and product development and distribution.

The water-testing industry has been holding its breath with collective grief since February, which saw the untimely passing of Taylor Technologies’ CEO, Alex Wooden. His father, Paul Wooden, had a difficult decision to make, and we now have news about what 74

Walchem is pleased to announce the new Walchem W900 Series Controller. Powerful programming gives you complete control of chemical metering pumps and valves in a broad range of water treatment applications.

With easy, icon-based programming on the large touchscreen display, the W900 can be configured to control multiple outputs using one of many pre-engineered algorithms. Four I/O slots permit exceptional flexibility to utilize almost any type of sensor, including pH/ORP, conductivity, disinfection, fluorescence, temperature, and level and flow, to name a few. Internet connectivity lets you maintain control via remote access. For more information, please visit our website at www.walchem.com. the Analyst Volume 24 Number 4

Industry Notes continued

Markhoff to Lead SUEZ Water Technologies & Solutions

Together with Caisse de dépôt et placement du Québec, SUEZ has completed the acquisition of former GE Water & Process Technologies (GE Water) for €3.2 billion enterprise value in an all‐cash transaction, effective as of September 30, 2017.

In connection with the completion, SUEZ has set up a business unit, Water Technologies & Solutions, under the leadership of Heiner Markhoff, former president and CEO of GE Water.

This new business unit combines both the acquired business and SUEZ’s own industrial service activities.

SUEZ Water Technologies & Solutions will operate with over 10,000 employees and address the needs of over 50,000 customers worldwide. Additionally, the business will include 650 R&D and expert staff as well as 17 Research & Excellence Centers of SUEZ. SUEZ said the integration will build on its international footprint, especially in the United States. The company plans to present its strategy for the industrial water markets in mid-December.

U.S. Water CEO. “We are very excited to welcome Tonka Water. Their experienced and customer-focused employees will be a great addition to our team.”

Located in Plymouth, Minnesota, and serving customers throughout the United States, Tonka Water is recognized as a best in class water treatment company that is dedicated to partnering with its customers to provide innovative, cost-effective water treatment solutions.

“I am confident that joining U.S. Water will strengthen our position in industrial water treatment and the municipal market, further solidifying our customized and innovative solutions,” said Tom Davis, Tonka Water President. “Together, with our shared vision, values and commitment to service, we will bring superior value to our customers and employees for years to come.”

Headquartered in St. Michael, Minnesota, U.S. Water’s national footprint serves a growing and diverse mix of over 4,800 industrial customers, including a significant number of Fortune 500 companies. U.S. Water provides integrated water solutions for industry by combining chemical, equipment, engineering, and service to optimize system performance, reduce water and energy usage, and improve efficiency.

Jean-Louis Chaussade, CEO of SUEZ, said, “This is an exciting moment for SUEZ, as our group now has an ever-stronger knowledge and skillset to bring innovation and enhanced value to industrial and municipal customers around the world.”

U.S. Water Acquires Tonka Water

Tonka Water, a major supplier of municipal and industrial water treatment systems, has joined the U.S. Water family. The acquisition of Tonka Water will allow U.S. Water to expand its integrated water treatment equipment offerings and applications. Tonka Water’s engineers customize water treatment solutions for a variety of applications, including surface water, groundwater, water reuse, industrial process water, remediation, and advanced wastewater treatment.

“The addition of Tonka Water to the U.S. Water family strengthens our engineering and equipment capabilities and the integrated solutions we can offer our customers throughout the market,” said LaMarr Barnes, 75

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Making a Splash

Mark R. Juhl

Tell us about a current project you or your committee is working on?

Jaytech, Inc., Scottsdale, AZ

What prompted you to start volunteering with AWT?

I’ve always looked to volunteer within an organization because it centers me and challenges me to improve myself.

For AWT, it was easy. I have a love for our industry and was honored that I was asked to be a part of the association.

What has been the most rewarding thing about volunteering?

Being a volunteer has many rewards. Foremost, I treasure the friendships I have made through service on committees, the board, and task forces, and at meetings and events. Secondly, volunteering often puts me out of my comfort zone. It is so easy for me to just sit back and let life happen, but I really only feel professional growth when I am challenged on a regular basis. AWT volunteering challenges me.

How has volunteering improved your professional career?

The contact with peers has kept me sane. There is great value in being able to pick up the phone and have industry influencers as your friends. They answer your calls!

Why would you encourage others to become a volunteer?

During the most recent convention in Grand Rapids, Michigan, I felt the most rewarded to date as the vision of the Business Resource Committee (which I have the honor of chairing) was, in my mind, finally realized. The Business Resource Committee sponsored its first Business Owner’s Meeting on Saturday. It took six years to bring together over 30 companies in one room representing over $200 million in gross annual sales and 30,000 customers.

Things just keep getting better. This year, we are implementing the Dale Carnegie sales and management training and will have a candid webinar, an Analyst article, and a presentation at convention from a lawyer that represents affected persons.

What is a past project that your committee produced that you feel has had the greatest impact on AWT and why?

Over the past six years, the committee has really gained momentum. We have developed numerous business webinars, added a business track to the convention programming, begun a business roundtable meeting during convention, established commercial corners at convention, and now held an amazing program specifically about business for owners.

How have you been able to utilize the expanded business connections you’ve made while volunteering?

I always encourage people to volunteer within some organization at any given time. Even though we all have seasons in our lives, I would argue that you need to be constantly reminded that there are causes bigger than yourself. Volunteering maintains a humility and connectedness with the world, whether it is through faith-based, civic, or professional organizations.

I have been able to not only casually contact the AWT member business owners across the country for assistance, but also contact many of the speakers who specialize in areas within and outside our industry. Being a part of the Business Resource Committee is special because I frequently interact with people that directly affect my business.

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Certification Corner The Certified Water Technologist (CWT) exam is the only legally defensible exam that represents the highest professional credential in the industrial and commercial water treatment field. Designed and tested by AWT, it provides professional recognition for individuals involved in water treatment and technology to indicate to the general public, co-workers, employers, and others that an individual has achieved a certain level of experience, knowledge, and education in the water treatment industry. The CWT designation ensures that the water treatment professional possesses a core body of knowledge and has extensive professional experience in all aspects of water treatment.

Preparation materials, such as the types of questions to be asked on the exam, can be obtained from this column and from selected text and manuals. The following reference materials are available for purchase through the AWT bookstore at www.awt.org: AWT Technical Reference and Training Manual AWT Raw Materials Specifications Manual Water Treatment: Industrial, Commercial and Municipal (Textbook) Boiler Water Treatment: Principles and Practice, Volumes I and II (Textbook) Cooling Water Treatment (Textbook)

1. If feedwater calcium increases from 1 ppm to 3 ppm in a boiler carrying phosphate at 30 ppm, and the feedwater is cycled 8 times, what kind of increase in phosphate treatment will be needed to maintain the residual?

A. 30 % D. triple B. 60 % E. No increase will be seen C. double 2. If feedwater hardness increases from 1 ppm to 3 ppm in a system using a chelant treatment and the feedwater is cycled 8 times, about what kind of increase in chelant treatment will be experienced?

A. 30 % D. triple B. 60 % E. No increase will be seen C. double 3. Several metals in soluble form in boiler feedwater can contribute to chelant demand. Which of the following creates the largest demand for EDTA? A. hardness D. aluminum B. Iron E. They all have equal demand C. copper

4. Caustic embrittlement is a form of boiler corrosion.

Three conditions are required. These include: 1) water with embrittling characteristics, 2) the presence of sodium hydroxide, and 3) __________.

A. a concentration mechanism B. low phosphate levels C. lack of coordinated phosphate and pH D. improper boiler water pH level E. a lack of proper alkalinity control 5. A boiler system operating at 100 HP for 24 hours per day and returning 20% condensate would require about how many gallons of makeup water per day? Feedwater cycles of concentration is 8.

A. 813 gallons D. 11,500 gallons B. 1,920 gallons E. Not enough information given C. 9,072 gallons 6. A standard “recipe” for boilout compound includes disodium phosphate, caustic soda, and sodium nitrate.

What is the sodium nitrate for?

A. Improves removal of mill scale B. Prevents caustic embrittlement C. Prevents foaming D. Protects boiler guage glasses E. Sodium nitrate is not used in this manner 7. Which of the following does not belong to the group?

A. octadecylamine D. cyclohexylamine B. morpholine E. aminomethylenepropanol C. diethylaminoethanol 8. Neutralizing amines are used to elevate condensate pH. What is the ideal range for minimum corrosion?

A. 4 to 6 D. 6.5 to 7.5 B. 10 to 12 E. 8.2 to 9.0 C. above 7.0 9. Will filming amines control oxygen corrosion in condensate systems?

A. Yes B. No 10. The use of filming amines is acceptable at what pH in the condensate?

A. 6.5 D. 8.2 B. 7.0 E. All of the above C. 8.0 11. Neutralizing amines recycle in condensate. Which of the following will suffer the greatest loss in a deaerator?

A. morpholine D. AMP B. DEAE E. None will be lost in a deaerator C. cyclohexylamine

Answers: 1 A, 2 D,3 D, 4 A, 5 C, 6 B ,7 A, 8 E, 9 A, 10 E, 11 E 78

the Analyst Volume 24 Number 4

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CWT Spotlight

What was the most difficult aspect of the exam?

Daniel Merritt, CWT CH2O, Incorporated Olympia, Washington

What prompted you to obtain your CWT, and when did you begin the process by taking the test?

I began my career in water treatment in 2002 with Industrial Water Engineering (IWE) in Albuquerque, New Mexico. IWE highly valued the training and resources offered by AWT, and I was encouraged to take part in the Technical Training seminar in my first year.

The training was a big eye opener to the world of water treatment, and it was a challenge to absorb all the information provided. Being a former high school science and math teacher, I used the next two years to learn as much as I could and study the AWT Technical Reference and Training Manual. In March 2004, I took the CWT test for the first time and passed, gaining my CWT in 2005.

What advice would you give those preparing to take the exam?

If I were to pick one source, I believe the AWT Technical Reference and Training Manual is the single best printed resource to study. I also found that taking the three-day Technical Training seminars prior to the test was the best way to immerse myself in the information and bring it up to the surface. I would also encourage people to practice the math calculations sections of the Manual and Training sessions. Find out what printed material will be offered (for the last test I took, we had a booklet with some basic equations, equivalents, etc.). Find another person or group that will also be taking the exam and set up times to study—you’ll find that people will remember different things about the sessions or information in the manual. You should also know that it’s a long test—it took me about 4 hours to complete.

Get a good night’s sleep beforehand!

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For me personally, it was the regulatory section. That was information that, at the time, I was not necessarily using on a daily, consistent basis. And now with GHS and new labeling and SDS formats, it’s even more important to understand that information! The three-day Technical Training seminars covering regulatory issues were critical for me to get a better handle on what I needed to know.

What is an interesting fact about your CWT exam experience?

I have taken and passed the CWT exam three times. The first time was in 2004, to initially gain my CWT. The second time was in 2010 to re-certify. The last time was in 2016. Why a third time? Due to some clerical errors (and ultimately my neglect), I had failed to provide AWT with the paperwork necessary to recertify my CWT back in 2010—so I had lost my certification without even knowing it! After many email exchanges with Angela Pike, the AWT certification manager, I realized I had to repeat the entire process from scratch—starting with retaking the CWT exam. So, my cautionary tale is summed up in Angela’s words to me as I turned in my exam on the third time: “Right, now DON’T FORGET YOUR PAPERWORK!” (said in my best Scottish accent)

Why do you feel this credential is important to have? What are the advantages of holding a CWT?

The CWT shows your customers, your peers, and the water treatment industry that you have worked hard to gain one of the most meaningful certifications directly related to your business. It sets you apart from those who make a living in water treatment and those who are industry leaders and ongoing professional resources for their customers.

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CWT Spotlight continued

How has your CWT improved your professional career?

Besides the increased professional knowledge I have gained to solve problems and design systems, it connects me with some of the best minds in the water treatment industry. Professionals with decades of experience and technical knowledge are usually only a phone call or an email away. The level of comradery, respect, and willingness to help others that I have found within the AWT is a breath of fresh air!

What has been your greatest professional accomplishment?

In 2016, after 14 years in the industry, I was promoted to the Western Washington regional manager for CH2O Inc. I now have the privilege to train and oversee other professionals in our industry. Also in 2016, I was invited to teach one of the AWT Fundamentals and Applications sessions for the San Diego AWT Training Seminar.

What do you think are the most prominent issues facing the water industry today?

I’ve seen a big push for greener, more environmentally friendly solutions for the water treatment needs of customers. This, combined with tighter regulatory factors, will drive the industry to further develop systems that will conserve water and energy and reduce chemical residual in wastewater. I see more focus on the advantages of pretreatment equipment to maximize the usefulness of water, and in some cases, eliminate the need for certain chemistries. This emphasizes the need for more trained, flexible, and knowledgeable professionals in the industry who have a broad spectrum of expertise to establish credibility and develop real valueadded solutions to our future problems.

Congratulations to Our Newest CWTs

Please join us in congratulating the latest individuals to become CWTs (April 10, 2017-October 20, 2017) Greg Bacon, CWT, AFCO Shawn Dittrich, CWT, Fremont Industries. LLC Bruce Graveley, CWT, Aries Chemical, Inc. Paul Hamner, CWT, Southern Air, Inc. Jessica Egan, CWT, Magnus Chemicals Ltd. Chuck Ehst, CWT, Syntec Corporation Scott Gardiner, CWT, Keytech Water Management Kelsey Hale, CWT, ProAsys Susan Hayes, CWT, International Chemstar Inc. Eric Lewin, CWT, Industrial Water Engineering

Jonathan Miller, CWT, Bond Water Technologies, Inc. Scott Nunley, CWT, International Chemstar Inc. Ron Phares, CWT, Fremont Industries LLC Dan Pruitt, CWT, International Chemstar Inc. Justin Ranger, CWT, CH2O, Incorporated Eric Russo, CWT, DuBois Chemicals Inc. Benjamin Shriner, CWT, Tasco Water Works, Inc. Kyle Wohlgemut, CWT, U.S. Water Services, Inc. Eric Woodring, CWT, ProAsys

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Ask the Experts

The discussion below occurred on AWT’s listserv and/ or LinkedIn page. Be sure to join to be part of the conversation!

Cleaver Brooks Clear Fire Vertical Oxygen Pitting Issues Question: I am hoping to get some input based on your experience treating the Cleaver Brooks CFV-060 steam boiler. We have been treating this new boiler for about 6 months and received a call today of the boiler being down due to oxygen pitting. We were asked to utilize the competitor’s product that was left on site to use it up and we were having difficulties maintaining the sulfite residual we wanted of > 50 ppm. But we were still maintaining some sulfite about 10-12 ppm of product being introduced into the feedwater tank. Once we switched to our product we were getting levels around 20 ppm for the past 2 months of the 6 months of operation. The feedwater temperature is 80 ºF. There was about 1” of sludge in the bottom of the boiler. Cleaver Brooks rep simply said it was an oxygen pitting issue which we agree with but we feel that the cause would be due to low feed water temps and sludge built up around the tubesheet and tubes. All of the corrosion and pitting is on the bottom 12” of the tubes and everything above that is clean and looks great. Please let me know your thoughts or experiences in treating these types of boilers.

Answer 1

What pressure is the boiler operating at? I think it is a low-pressure steam boiler and if so, he have had no luck trying to treat these systems using a traditional sulfite/phosphate program, because an adequate sulfite can never be maintained. This is due to the continuous heating and cooling of the boiler.

Response 1

I forgot to mention this boiler operates at 125 psi. They operate 12 hour shifts (8a-8p). The boiler goes on low fire at 25 psi during downtime every day.

Answer 2

This sounds like a great application for sulfite and DEHA. I run this in similar applications with great success for boiler treatment and condensate treatment in applications where the boiler is run on a daily shift.

Answer 3

You say the feed water temperature is around 80 ºF. What is the temperature of the condensate tank should be at least above 165 degrees up to 180 degrees.

Anything lower you most likely are sending oxygen into your boiler. 10 to 20 ppm of sulfite in boiler is not enough. You try and maintain 30-60 ppm of SO3 at the levels you are caring. You don’t have enough of a buffer in the case of an excess of O2 entering the boiler.

A rule of thumb by J. N. Tanis is that it takes approximately 8 ppm of sulfite to consume 1 ppm of O2, so you can see that just maintain a low level of SO3 could be problematic.

Answer 4

My view is that the low feedwater temperature is a huge problem. Even if the sulfite is catalyzed, it will react very slowly at 80 ºF.

I once treated a fire-tube boiler where, because the boiler was steaming at near 100%, and the main condensate return pump went out, the customer put a city water garden hose in the top of a heated feed tank. We pitted several tubes in less than one week!

Even though you have some residual sulfite in the boiler, oxygen is still likely getting in and attacking the lower tubes, probably near the feedwater inlet.

Heating the feedwater is a must.

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Ask the Experts continued

Answer 5

Until you get the feedwater temperature adjusted, the potential for oxygen pitting will always be a problem not to mention thermal shock when 80 ºF water mixes with 353 degree (125 psig) boiler water.

Answer 6

I agree it is the temperature. Also, many times if you think you have 10 to 12 ppm of sulfite, but cannot get it up higher, it is not really 10 to 12 ppm but rather a false test and you have 0 ppm of sulfite. If you had a true sulfite residual it would come up quickly when you add more product.

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1/23/17 2:57 PM

T.U.T.O.R.

Technical Updates, Tips, or Reviews

Feedwater and Deaeration within Industrial Steam Generating Systems Edward S. Beardwood, Wilmington, DE

The following tables are from the article “Feedwater and Deaeration within Industrial Steam Generating Systems,” by Edward S. Beardwood of Solenis LLC, presented at the International Water Conference, 2016, paper IWC 16-54 Deareator Hook-Ups Schematic

A: Main Water Inlet – All returns 16.6 º C (30 ºF) and less than steam temperature, all makeup B: Hot Water Returns – All returns within 30 ºF of steam temperature with maximum of 10% of total unit capacity C: Hot Water Returns – All returns within 30 ºF of the steam temperature in excess of 10% total unit capacity D: Trap Returns – All returns above steam temperature

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T.U.T.O.R continued

Table 1: Typical Design Velocities in Water Treatment Service Application

Velocity; ft/sec

Service Water Piping

4–10

Pump Suction

4

Avoid Sedimentation

>3 Min

Water Mains

2–5

Boiler Feedwater Piping

6–13

Pump Discharge

4–8

Stainless Steel

>5Min

Prevent Impingement

Fresh Water; non-resistant metals

≤ 6 MAX

Sea Water; non-resistant metals

≤ 3 MAX

Sea Water; resistant metals

≤ 12 MAX

Note: To avoid cavitation/collapse, determine NPSH by measuring the height of the liquid above the pump impeller center line, convert to feet, and divide by 2.31 feet per pound. Locate the pressure on steam tables and read the associated saturation temperature. If this temperature is lower than the fluid operating temperature, lower the operating temperature or increase the feet of head present or increase the operating pressure of the vessel.

Table 2: Typical Fresh Water Velocities for Various Metallurgies Most Favorable Velocity ft/sec

Metallurgy

General Range ft/sec

Carbon Steel

4.0

2.5–6

Admiralty Brass

3.0

2.5–5

Red Brass

2.5

Aluminum Brass

2.5–4

5.0

90/10 Copper Nickel

70/30 Copper Nickel

4–8

7.0 – 8.0

1–12

8.0

6–12

7.5

Monel

Type 316 Stainless Steel

5–10

10.0

Copper

8–15

4.0

Velocity (V) can be calculated as follows:

3–5

V = [F x C]/D2 ; where F= Flow; USgpm or m3/hr, and D= Diameter; inches or centimeters, and C= Constant; 0.408 for US or 0.085 for metric units.

Table 3: Feedwater Heater Materials of Construction Susceptibility Corrosion Mechanism and Alloy Susceptibility

Admiralty Brass 90-10 Cu-Ni

80-20 Cu-Ni

70-30 Cu-Ni

Carbon Steel

SCC S I

Erosion Corrosion

Crevice Corrosion

Pitting

I

I

I

I

I

M

S

I

I

M

Austenitic Stainless Steel

S

Monel 400

M

Ferritic SS 439

Exfoliation

S

S I I

I

I

I

I I

I

I

S

I

I

S

I

I

I

I

I

Condensate Corrosion

General Corrosion

Snake Skin

I

S

I

S

I

S

I

I

I S I

I

I

I I

I

S

S

I

I

S

S

I

I

S

I

I

S

I

S

S = Susceptible, I = Immune, M = Marginally Susceptibility; in the annealed state and susceptible in the drawn stress relieved state. AISI Type 439 stainless steel has greater immunity than AISI Type 304; AISI Type 446 is virtually immune.

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T.U.T.O.R continued

Table 4: Known Stress-Corrosion Cracking Agents in Feedwater System Alloy

Metal Corrodant

Austenitic Stainless Steel

Chlorides/Halides, Hydrogen Sulfide

Hot Concentrated Caustic

Carbon Steel

Concentrated Caustic and Nitrates

Concentrated Carbonates and Bicarbonates

Copper-Based Alloys

Ammonia (Vapors and Solutions)

Titanium

Ethanol, Methanol, Sea Water/Brine

Amines, Sulfur Dioxide Nitrates, Nitrites

Hydrochloric Acid (10%) and Organic Acids

Cracking Defined: Fretting (Tube to Tube Sheet or Stay): Cracking from high frequency low amplitude vibrations or thermal expansions contractions at a fixed/stressed location.

Stress Corrosion Cracking (SCC): Occurs due to high residual stress or residual stress with an anion corrodant present. Cracks are fine, tight, thick walled, typically intergranular with branched chains and a branched tip (can be transgranular).

Corrosion Fatigue from thermal or bending modes: May have a corrodant present that interferes with protective oxide regrowth after fracture.

Transgranular, oxide filled, and blunt tipped.

Table 6: Typical Efficiency of Deaerator Equipment Pressure PSIG

Temperature °F

Vacuum (Cold Process)

11 to 24 inHg

Open Heaters

Atmospheric

6 to 11 inHg

185

Deaerating Heaters

Gas Transfer Membranesª

Vacuum (Hot Process)

Deaerators

Oxygen

Carbon Dioxide

< 180

0.4 to 1.4

150 to 210

1.0 to 5.0

0.4 (0.015)

N/A

2 to 15

216 to 250

< 0.05

0

28 inHg Vacuum

44 to 75

98 to 99% Removed

35% Removed

4 to 11 inHg

Hotwell or Condenser (with Sparging)

Effluent Concentration mg/L

180 to 200

2 to 15

5 to 10

0.3 to 0.5

216 to 250

5 to 10 N/A

< 0.01

0

a) See reference (R.M. Mode, W.E. Haas, 2005). Installed after strong acid cation ion exchange in two-bed demineralization setup within series three pass membrane setup.

Table 10: Application Data of the Various Oxygen Scavengers

Scavenger

Sulfite

Cat Sulfite Cat HZ

HQ

CHZ

EA

DEHA

MEKO

Morpholine

DEAE CHA

Dosage ppm/ppm O2 7.9

7.9

1.0

Direct Metal Passivation No

No

RT–540

0

0

Scavenger Rate Constant K2, (M-1 Min-1 ) Efficacy2 1 X 104 1 X105

200–400

0.023

Yes

9.5–12

200–400

0.023

3 X 102

RT–422

1.26

2 X 102

5.5

Yes

2.78

8.5–10

RT–540

Volatility1 D.R.

9.5–12

Yes

5.44

8.5–10

Desired Temp ºF Range

Yes

3.43

1.43

Desired pH Range

Yes

Yes

Yes

7.5–11

N/A

8.0–11

8.5–12

6.0–10

185–622

RT–5724

No

0

0

9.8

0.47

4.28

No

Note: 1. Distribution Ratio (i.e., Steam phase/Water phase; DR) are at atmospheric pressure and 212 ºF. 2. Efficacy given in per mole per minute at pH 7.7 and 230 ºF. 3. There are catalysts available for all scavengers.

4. Has 1000 ºF superheat survivability.

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3 X 10

3 X 103

2 X 102 5 X 103

T.U.T.O.R continued

Table 11: Oxygen Reduction by Scavengers Scavenger pH

Percentage Reduction in 10 minutes

8.5

IPHA (Catalyzed)

9.5

20.0%

Hydroquinone (Uncatalyzed)

16.6%

DEHA (Catalyzed)

10.0%

Hydrazine (Uncatalyzed)

100.0%

29.0%

90.0%

8.3%

16.6%

-

11.0%

MEKO (Uncatalyzed)

-

16.6%

6.6%

10.5

50.0%

25.0%

The passivation potential of hydrazine and its substitutes (E.S. Beardwood, 2015) are provided in Table 12. It can be seen that the degree of decreasing passivation capability is as follows: EA > MEKO > HQ > HZ/CHZ Table 12: Passivation Potential of Hydrazine and Hydrazine Substitutes Chemical Compound

Blank

Passivation Potentials RP (Ω)

Temperature Dependency

Passivation

4.0 x 103

Yes

None

5.4 x 103

Yes

Yes

4.7 x 103

Sulfite

DEHA

No

4.7 x 103

Hydroquinone Hydrazine

Yes

5.0 x 103

MEKO

Erythorbate

Yes

Yes

5.6 x 103

Yes

Yes

1.25 x 104

None

Yes

Yes

Yes

Conditions: Deaerated (<2 µg/L O2), 257 ºF, pH 9.0 - Stoichiometric for Oxygen plus 100 µg/L theoretical excess as N2H4 - LPR (polarization resistance) with 0.1M sodium perchlorate Table 13: Specifications for Various Treatment Regimes for Units with High Purity Feedwater

Treatment Regime

Oxygenated Treatment1 - Once Through - Drum Boiler

All Volatile Treatment1 • Oxygenated • Reducing

pH2

Cation Conductivity μS/cm < 0.15 < 0.15

8–8.5 9–9.6

Dissolved Oxygen μg/L

Feed Water ORP mV

+100 - +150 +100

30–150 30–50

9.2–9.6 9.2–9.6

<0.2 <0.2

<0.2

<5 (2)

-300 to -350

Equilibrium Phosphate

9.2–9.6

<0.2

<5 (2)

-300 to -350

Phosphate Treatment Congruent Phosphate

9.2–9.6

<0.3

< 5 (2)

-300 to -350

Caustic Treatment

9.2–9.6

<10 <5(2)

0 to +50 -300 to -350

Comments

Boiler Water pH will be about 9.0

Boiler Water pH level will be about 9.0

Limited to 16.5 MPa (2400 psia) or less. 0.4 to 2.4 mg/L NaOH Typically, 1 to 1.5 mg/L NaOH minimum NaOH = 2.5 x Cl mg/L Na:PO4 = 3:1 to 3:1 + 1 mg/L NaOH (3.44:1), 0.2 to 2.4 mg/L PO4, pH 9.3 to 9.7 in the boiler water.

Na:PO4 = 2.8to3:1to3:1+1mg/L NaOH. 3 to 10 mg/L PO4, pH 9.2 to 10 in the Boiler Water. Na:PO4 = 2.6 – 2.8 (2.22.8):1, 3-15 mg/L PO4, pH 9.2 - 9.7 in the boiler water. Limited to 12.4 MPa (1800 psia).

1. Must have full flow condensate polishing 2. Values are for all ferrous metallurgy. For mixed Fe-Cu metallurgy the pH range is 8.8–9.3 (9.0–9.3) under reducing conditions; -300 to -350 mV ORP, dissolved oxygen < 5 μg/L 3. Ammonia will be present if used or organic amines, hydrazine substitutes in use. It may vary from 0.1, 0.2, 0.3, 0.4, 0.5, 1.0, 2.0, 3.0 mg/L depending on CO2 presence or degree of thermal degradation 4. All treatment regimes for drum boilers are designed to provide at boiler water pH of 9–10 @25 º C 87

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T.U.T.O.R continued

Table 14: Troubleshooting Observation

Investigate

Deaeration dome temperature less than 1 to 2 ºF (0.55 to 1.1 º C) of saturation.

- control of steam supply - adequate steam supply

Deaeration section less storage section temperatures; 2 to 4 ºF (1.1 to 2.2 º C) negative value (scrubber in storage section)

- condensing due to poor steam control or inadequate steam supply - oversized pressure reducing valve hunting

Vent plume inconsistent

- pressure reducing valve hunting due to oversize - pressure reducing valve control sensor either improperly installed or faulty leading large lag response times - cold water makeup addition control too broad

Deaeration section less storage section temperatures; 2 to 4 ºF (1.1 to 2.2 º C) positive value

Fluctuating operating pressures

Vent plume contains entrained water Storage section loop seal blow-off; overflow

- atomization is poor, check sprays and trays - check internal baffling - upstream air or non-condensables inleakage, increase venting rate to displace

- inadequate supply of steam - exceeding design throughput capacity - exceeding design approach temperatures - exceeding design makeup quantities and / or lower temperatures than design - poor control of steam supply, lag response too great, control sensor not located at the first point of condensation - batching of condensate and / or makeup supply - improve the storage level maintenance to a narrower band - pressure reducing station hunting due to oversize - improperly sized down comers and equalizers tubes from deaerator to storage section

- external vent condenser leakage or cracked internal vent condenser and or shroud - water piston from operating pressure drop or loss - blown spray nozzle or spray distribution system - oversized pressure reducing valve hunting, internal condensation and development of shrink/swells, water piston - poor set up of makeup and condensate pump overs

Pressure relief valve blowing

- overpressure due to excessive exhaust or flash steam

Flashing causing storage water level bouncing and hammer

- loss of steam supply with or without poorly controlled and sized supplemental steam pressure reducing valve - poor control of both steam and cold water additions to deaerator. PRV sizing and hook-ups as well as poor set up of makeup and condensate pump overs are suspect

Vibration

Hammer/vibration from cavitation of feedwater pumps

Hammer/vibration from water/condensate hook-up lines

Observation

High oxygen content in the effluent High oxygen scavenger consumption

- inadequate supply pressure to spray nozzles for the preload and vessel operating pressure present - high pressure drops across makeup and condensate control valves as well as hunting of said valves

- same as preceding group - broken deaerator storage section outfall vortex breaker - over pressurization of deaerator for the operational design

- improperly routed lines for the operating and discharge pressures, (see figure above); condensate return lines undersized for the carrying capacity of both condensate and flash steam, resize the line - mixing of condensate and makeup waters too close to the deaerator inlet. Minimum of 15 pipe diameters upstream from the inlet, consider stainless steel pipe run from mix point forward - insufficient back pressure, too much flash, reroute, (see figure above).

- failed check valve at the point of discharge/delivery to vessel. Use spring preloaded check valves Investigate

- all of the above - exceeding design throughput - exceeding design throughput capacity exceeding design approach temperatures - exceeding design makeup quantities and / or lower temperatures than design -inadequate venting -approach temperature less than 20 ºF, either re-route hook-ups, (see figure above), cool the water with a heat exchanger or raise the operating pressure of the deaerator with increased venting -inadequate supply pressure for the distribution and atomization of incoming waters -pump seal failures

Note: Flash steam can be from a flash tank supply or that produced by high-pressure condensate returns discharged directly to the deaerator.

Originally presented at the International Water Conference: November 6–10, 2016. Please visit www.eswp.com/water for more information about the conference or how to purchase the paper or proceedings.

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the Analyst Volume 24 Number 4

Capital Eyes

A Slow December in D.C.—Not! Every year, we think the holiday season in D.C. and on Capitol Hill will be peaceful and slow, but this is rarely the case.

Congress punted on several items at the end of September that will absolutely have to be dealt with before the end of 2017.

Funding the Government

To avoid a government shutdown at the end of September, Congress passed a temporary $1.2 trillion spending bill that funds the government until December 8, 2017. That means the threat of another shutdown exists if Congress does not pass, and the president does not sign, another spending bill to fund the government through the end of the fiscal year— September 30, 2018. It is likely that Congress will opt to enact an all-encompassing spending package known as an “omnibus” that funds all agencies in one lump sum. This package will have to include a change to the current budgetary caps or else across-the-board cuts (known as sequestration) will kick in.

The threats of blocking this bill and thus forcing a shutdown are flying from both parties, however. Democrats are warning that they will block any funding bill from passage if the Administration and/or Congress does not somehow reinstate the subsidies provided to health insurance companies to help offset the cost of covering low-income subscribers to Obamacare health plans.

The president announced that he will no longer make the payment to these companies.

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Democrats are also threatening to hold up the funding bill if the DREAM Act is not passed—a measure that would allow children of illegal immigrants born in the United States a path to citizenship. The White House had announced the end of the Deferred Action for Childhood Arrivals (or DACA) program, with a six-month delay to give lawmakers time to find a legislative solution.

Meanwhile Trump has threatened not to sign a funding bill if it does not include money for building his border wall. While he did back off this threat in September, it remains to be seen whether he will make this demand again.

Debt Ceiling

Treasury Secretary Steven Mnuchin had been warning that the U.S. could run out of money to pay its bills as soon as the first week of September, especially with a Hurricane Harvey recovery fund in the works. Trump struck a deal with congressional Democrats to raise the debt ceiling for just three months, and then push to get rid of it entirely, overriding Republicans’ plan to raise the debt ceiling through November 2018.

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Capital Eyes continued

When Congress revisits the debt ceiling in December, Republicans may need Democrats’ help again, since fiscally conservative Republicans are hesitant to approve something that could force the U.S. further into debt without cutting spending elsewhere.

National Flood Insurance Program

Included in the same bill that temporarily funded the federal government until December 8 was a provision that would reauthorize the National Flood Insurance Program until that date—a program that has received much attention this year due to the multiple hurricanes that hit the United States causing widespread flooding.

Payouts under the program can go as high as $350,000.

The program needed to be reauthorized, as it had hit its $30 billion borrowing limit.

All but a tiny portion of U.S. flood policies are underwritten by this program, which was established in 1968 after private insurers left the flood insurance market because of large and unpredictable losses.

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Etcetera

Also distracting Congress and the White House are a host of other issues that just seem to continue to percolate, including the investigation into Russia’s involvement with the presidential election, the trial of New Jersey senator Robert Menendez (which could result in his resignation), the senatorial election in Alabama to replace Attorney General Jeff Sessions, the approval of thousands of presidential nominations of appointees to serve in senior Administration and agency positions, the North Korean threat, the confusion in the Affordable Care Act marketplaces, and the ever-continuing tweets coming out of the White House.

The days of peaceful and calm Decembers in D.C. are gone. Now it is “govern by chaos and lastminute deals.”

Janet Kopenhaver is president of Eye on Washington and serves as the AWT Washington representative. She can be reached at (703) 528-7822 or janetk@eyeonwashington.com.

the Analyst Volume 24 Number 4

Business Notes

The Importance of Online Marketing and Why You Need an Updated Brand Image Why both are critical for all water treatment companies and vendors Think about your buying habits. When buying a product or service, don’t you always visit the company’s website before making your decision to buy? Don’t you immediately form an opinion about that company based on the online look and feel? If the company website and online presence are dated, you will leave the site with a negative impression of the company. Things have changed dramatically over recent years, and that’s how people make buying decisions today.

So, why would the water treatment business be any different? When companies choose a water treatment vendor, it’s typically a long-term relationship, and it’s a very important decision because their work can have a big impact on asset protection and even on the health of the people in your facility. Choosing the right water treatment partner is critical, and your potential customers are going to look for you online and form an opinion about you and your company. What impression are you making?

Whether you’re a small, medium or large company, you must be properly represented online with a professional mobile-friendly website and a clean, professional brand image. If not, you are losing business and you will continue to fall further behind your competition.

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Consider the statistics below.

The new Environmental Safety Technologies website showcases the services it offers. It’s mobile friendly and features an updated logo and brand position, and we use it as a communication tool for clients and prospects.

What Research and Statistics Tell Us

Today, everyone researches online before buying a product or service, especially in the Business 2 Business space. Most of the time, the first place people go is your website. Recently DiscoverOrg completed a research study that shows websites are an extremely influential part of the buying process.

Consider this: only 2 percent of buyers said that a company’s website doesn’t influence their vendor evaluation. 61% of the people surveyed said that the website definitely influenced their buying decision, 37% said the site somewhat influenced the decision, and 2% said it did not matter. If it wasn’t obvious before, companies must make their websites a priority by doing things like refreshing copy and updating the design to be engaging and mobile friendly, and you must start using your site as an online marketing and communication tool.

the Analyst Volume 24 Number 4

Business Notes continued

Remember what we said before about first impressions being critical? All it takes is 2.5 seconds for your visitors to form an opinion of your company. In fact, Entrepreneur says that more than half of your visitors will spend fewer than 15 seconds on your website.

Failure to follow best practices (frequent, updated rich content, compelling visuals, etc.) leads to a loss of traffic and conversion. A stale, unappealing, difficult-to-navigate website will turn off visitors and encourage them to go elsewhere.

According to a recent IBM Digital Experience Survey, online content produces brand recall, which increases engagement. The survey shows that content helps consumers remember a brand, it also encourages them to engage more personally with the company.

Brand image indeed makes an impression. Just as your business cards and the way your employees dress all make a positive impression on your customers, your website is often the first point of contact consumers have with your company and should represent a clean, professional brand image, points out Forbes.

Here Is Why You Need an Online Marketing Strategy

Your customers expect you to have an online presence.

Your competitors are doing it. If they aren’t, you need to get there first!

You need a consistent and professional brand position that works together for everything you do, including print, trade shows, email campaigns, social media, your website, and promotional materials.

It helps with hiring younger online-savvy people.

If you have any interest in selling or merging with another company, your website and online marketing will showcase your company as an innovative, smart investment.

Business development has changed. People are communicating online, and you need to start using your website, social media and email marketing to promote your products and services.

what you do depends on the size of your company, staff, and budget. At a minimum, you need a mobile-friendly website.

Check out these online and general marketing tactics: A website that is mobile friendly Logo and online brand redesign Consistent branding for all online marketing, as well as print ads, trade shows, and promotional materials Email marketing Social media plan, including using LinkedIn to communicate with potential new hires, clients, and prospects Search Engine Optimization Pay Per Click Paid LinkedIn and other social media marketing Automated marketing Remarketing Analytics for tracking website, email, and social media visitors.

Connecting Your Offline Branding With Your Online Branding The key to an effective marketing plan is consistency across all marketing platforms. That includes your website, social media channels, email marketing, print ads, promotional materials and even your trade show booth.

See below for how Bond Water Technologies uses its trade show booth to complement its other marketing efforts.

Elements of an Online Marketing Program

It’s not just about your website, but it does start there.

Below is a list of online marketing tactics that water treatment companies and vendors might use. Usually, 92

the Analyst Volume 24 Number 4

Business Notes continued

Does Your Logo Portray a Modern Updated Brand?

The Solution

Below is a look at the dramatic impact an updated logo design can have on a company brand. This is the new logo design we recently completed for Arthur Freedman Associates. The new logo is the foundation for a brand transformation strategy that includes a new mobilefriendly website, an email marketing program, content marketing strategy, and a social media marketing plan.

You don’t have to break the bank to have a professional online presence. There are affordable turn-key ways to get started that won’t require a huge capital investment or take up too much of your time. Start small and build as you go. If you haven’t started to build your online presence, you need to start now with an affordable website and go from there. If you have already started with your website, make sure it is up to date and mobile friendly. Then you can begin to add email marketing, social media, video, analytics, marketing automation, and other elements to your marketing efforts.

Want to Learn More?

This summer, Bridge the Gap Media produced a webinar for all AWT members. The webinar is titled “Content Marketing and How to Effectively Use Online Marketing to Grow Your Business.” You can download the presentation and watch the webinar at Bridge the Gap Media’s AWT Webinar. Online Marketing and Branding.

What Holds Companies Like Yours Back From Effectively Using Online Marketing?

Water treatment companies and other businesses tell us these are the main reasons they don’t have a solid online marketing plan. Is this you?

You are too busy with other responsibilities. You won’t do it unless you have someone inside that CAN do it, or you need to hire someone from outside to help design and manage your plan.

Water treatment companies and most industries don’t understand online.

There is a lack of technical expertise.

You lack the money to execute an effective program.

Your staff does not have the time or experience to build and execute the program.

You don’t know where to start or what to do.

You think you will do it on your own, but that does not happen.

You are trying to do it on your own, but it doesn’t look professional, and it’s hurting your brand.

Good content is hard to create.

You started and stopped.

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About Jim Weiskopf and Bridge the Gap Media: Since 2010, Jim Weiskopf of Bridge the Gap Media has worked with AWT water treatment companies and vendors. His company helps small business owners compete in today’s competitive business environment and online world. We offer free consultations and affordable services in website development, email marketing, social media, content marketing, marketing automation, and brand development for companies of all sizes Contact Jim at (301) 641-1444 or Jim@BtgMedia.com.

the Analyst Volume 24 Number 4

Financial Matters

When an Inheritance Is Too Good to Be True How income in respect of a decedent works

Most people are genuinely appreciative of inheritances, and who wouldn’t enjoy some unexpected money? But in some cases, it may be too good to be true. While most inherited property is tax-free to the recipient, this isn’t always the case with property that’s considered income in respect of a decedent (IRD). If you have large balances in an IRA or other retirement account—or inherit such assets—IRD can be a significant estate planning issue.

IRD explained

IRD is income that the deceased was entitled to, but hadn’t yet received, at the time of his or her death. It’s included in the deceased’s estate for estate tax purposes, but not reported on his or her final income tax return, which includes only income received before death.

To ensure that this income doesn’t escape taxation, the tax code provides for it to be taxed when it’s distributed to the deceased’s beneficiaries. Also, IRD retains the character it would have had in the deceased’s hands.

For example, if the income would have been longterm capital gain to the deceased, such as uncollected payments on an installment note, it’s taxed as such to the beneficiary.

IRD can come from various sources, including unpaid salary, fees, commissions or bonuses, and distributions from traditional IRAs and employer-provided retirement 94

plans. In addition, IRD results from deferred compensation benefits and accrued but unpaid interest, dividends, and rent.

The lethal combination of estate and income taxes (and, in some cases, generation-skipping transfer tax) can quickly shrink an inheritance down to a fraction of its original value.

What recipients can do

If you inherit IRD property, you may be able to minimize the tax impact by taking advantage of the IRD income tax deduction. This frequently overlooked write-off allows you to offset a portion of your IRD with any estate taxes paid by the deceased’s estate and attributable to IRD assets. You can deduct this amount on Schedule A of your federal income tax return as a miscellaneous itemized deduction. But unlike other deductions in that category, the IRD deduction isn’t subject to the 2%-of-adjusted-gross-income floor.

Keep in mind that the IRD deduction reduces, but doesn’t eliminate, IRD. And if the value of the deceased’s estate isn’t subject to estate tax—because it falls within the estate tax exemption amount ($5.45 million for 2016), for example—there’s no deduction at all.

Calculating the deduction can be complex, especially when there are multiple IRD assets and beneficiaries. the Analyst Volume 24 Number 4

Financial Matters continued

Basically, the estate tax attributable to a particular asset is determined by calculating the difference between the tax actually paid by the deceased’s estate and the tax it would have paid had that asset’s net value been excluded.

If you receive IRD over a period of years—IRA distributions, for example—the deduction must be spread over the same period. Also, the amount includible in your income is net IRD, which means you should subtract any deductions in respect of a decedent (DRD). DRD includes IRD-related expenses you incur—such as interest, investment advisory fees or broker commissions—that the deceased could have deducted had he or she paid them. Thus, to minimize IRD, it’s important to keep thorough records of any related expenses.

Be prepared

As you can see, IRD assets can result in an unpleasant tax surprise. Because these assets are treated differently from other assets for estate planning purposes, contact your estate planning advisor. Together you can identify IRD assets and determine their tax implications. © 2016 Thomson Reuters

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