CRC Teams with TextPower to Offer Fast and Easy Power Outage Reporting via Text
Date: May 16, 2012
May 15, 2012 – SAN JUAN CAPISTRANO, California and Austin, Minn. –Cooperative Response Center, Inc. (CRC), a leading nationwide contact center and central station, has teamed up with TextPower, Inc., a text messaging (SMS) business solutions provider, to use TextPower’s SmartAlerts™ texting solution to enable customers of CRC’s utility company members a fast and easy way to report power outages via text messaging. CRC will use TextPower’s texting service to allow consumers to initiate a power ou
tage report and verify outage restoration back to consumers via text message.
"We are delighted to work with CRC to provide an innovative technology offering to their utility members that we believe is fast, effective, and practical particularly when the power goes out," said Mark Nielsen, TextPower's executive chairman."CRC's use of our text outage notification greatly enhances the personalization and immediacy of customer service its utility members can now provide. In a recent survey of utilities, the overwhelming top priority for texting was text notification of outages."
“Our partnership with TextPower is another example of CRC’s continual efforts to provide innovative, value-added services for our membership,” said Brad Fjelsta, CRC’s senior vice president of operations and project manager for the text messaging initiative. “TextPower’s technology helps us offer a relevant solution that meets the needs of today’s tech-savvy consumers, enabling them to report a power outage quickly and easily and verify the power is back on before line crews leave the area.”
For more information about CRC and its outage texting service, contact CRC at 507.437.2400 or info@crc.coop or TextPower at 818-222-8600 or sales@textpower.com.
About CRC
CRC is a nationwide, cooperatively owned and operated, 24/7 contact center and central station. Founded in 1992, CRC has steadily increased the size and scope of its operation with offices currently in Austin, Minn., Dunlap, Tenn., and Abilene, Texas. CRC serves over 280 members and associate members in 40 states, representing 4.3 million consumers. Visit CRC on the web at www.crc.coop.
About TextPower, Inc.
TextPower, Inc. provides alerts and authentication solutions to a variety of industries worldwide using text messaging (SMS). The company's software and text messaging services allow companies to use texting to enhance their revenues, decrease costs and improve customer service. TextPower's authentication product, TextKey™, replaces the token or security fob previously needed to verify the identity of online users for password-protected applications. TextPower’s mission-critical infrastructure employs geo-redundancy for the industry’s highest reliability, providing delivery to virtual every cell phone in the United States and connections to most recognized wireless operators around the world. Visit http://www.TextPower.com, email Info@TextPower.com or call 888.818.1808 for more information.
# # #
For more information contact:
Dan Chmielewski
Madison Alexander PR
714-832-8716
dchm@madisonalexanderpr.com
… more…Date: May 15, 2012
- New ‘Evercor®’ solution integrates LTE mobile data capabilities with professional mobile radio enabling real-time video, collaboration and data services that improve operations and safety
- Evercor will help network operators in public safety, transport and energy to save money by optimizing existing assets while providing an evolutionary path to LTE
- - -
TETRA World Congress (TWC), Dubai May 15, 2012 - Cassidian, an EADS company, and Alcatel-Lucent (Euronext Paris and
NYSE: ALU) are to enhance safety and operations for public safety agencies, energy and transport companies with the launch of a new solution called ‘Evercor®’. Based on 4G LTE technology, it enables the use of video, data and other media to improve the way the security professionals serve and protect their communities.
Evercor integrates Alcatel-Lucent’s 4G LTE mobile broadband with TETRA-based systems to form the first end-to-end integrated LTE 400 professional mobile radio (PMR) solution for the 380-470 MHz band – the frequency band currently used by public safety agencies and other essential services in many parts of the world. As a result it will support new broadband communications capabilities such as real-time video to complement existing radio systems. It also allows transport and energy companies using TETRA communications to benefit from mobile broadband applications.
Alcatel-Lucent and Cassidian are showing how Evercor enhances information-sharing between control centers and field operations at TETRA World Congress 2012 in Dubai. By delivering high-speed 4G LTE mobile broadband services such as enhanced location information and transmission of medical records to ‘smart’ emergency response vehicles, handheld tablet devices and control center systems, teams will be equipped with the vital information they need to rapidly prepare for and respond to any incident. This can improve safety and security for both the public and workers and allow teams to more quickly identify locations and respond to incidents.
The use of real-time video and data services will improve operations for those working in the transport and energy industries. Early warnings of outages and incidents will in turn result in faster response and reduced maintenance time and costs. For all companies using TETRA communications, the solution will enable cost-efficiencies, allowing them to re-use their existing sites and equipment.
Jean Marc Nasr, Head of Secure Communication Solutions at Cassidian said: “The launch of this innovative solution comes only a year since we announced the joint work program between Alcatel-Lucent and Cassidian and shows the real progress we’ve made to enhance operations for companies using the 400 MHz band. We are able to integrate these services within the Cassidian command-and-control collaborative suite of applications for our Public Safety and Defence users.”
Philippe Keryer, President of Alcatel-Lucent’s Networks Group said: “Alcatel-Lucent’s 4G LTE architecture is being embraced by the public safety sector. Evercor delivers the highest speeds and greatest capacity for mobile broadband communications networks today and supports essential operations in the most cost-effective manner. Alcatel-Lucent has deep-rooted expertise in providing groundbreaking mobile broadband communications solutions to enhance operations and safety across many industries and we are pleased to work with Cassidian to achieve this.”
The Evercor solution uses Alcatel-Lucent’s eNodeB base stations, wireless packet core and backhaul solutions, and Cassidian LTE 400 Remote Radio Head, terminals and applications. The LTE 400 eNodeB can be fitted into Cassidian’s new TB3S TETRA Base station. Working in the 400 MHz bands delivers advantages over communications in a higher frequency band. Fewer base stations are required to provide coverage to a comparable geographic area and communication is made more reliable inside buildings and within built up urban areas.
Watch a video with Jean-Marc Nasr and Philippe Keryer: http://www.youtube.com/watch?v=yVh8-YG-F2g
… more…Date: April 02, 2012
Gig Harbor, Washington – SmartGridCIS, an emerging leader in the field of AMI enabled prepay and time-of-use billing and CIS solutions for utility companies, announced today that Peninsula Light Company (PenLight) has chosen SmartGridCIS to support its residential prepay business.
PenLight wanted a flexible technology solution that could meet their unique requirements for an Advance Pay, or Prepay electricity offering that will ultimately serve as a platform for a broader energy efficien
cy initiative in the future. They plan to market this to residential customers interested in an alternative to traditional post-pay billing, and see SmartGridCIS as a solution partner that will enable this success. “We selected SmartGridCIS as much for their willingness to meet our unique requirements, as for their robust feature set,” said Jonathan White, Manager of Member Services for PenLight. “We can already tell they are team players.”
SmartGridCIS offers a low risk, low cost opportunity to implement a prepay energy program. In addition to multiple deployment options, from stand-alone to a fully integrated solution that exchanges data with legacy billing/CIS systems, they provide a technology platform that easily integrates with other energy solutions. “We know that cooperatives are trying to offer creative energy programs to their members, but concerned with passing through costs,” states John Bastian, President for SmartGridCIS. “So our intent is to enable maximum flexibility, a rapidly deployable platform, and a very attractive price point.”
About SmartGridCIS
SmartGridCIS (www.SmartGridCIS.com) is a leading provider of prepaid utility billing and CIS solutions designed specifically for regulated utilities, cooperatives, municipalities and deregulated retail energy companies utilizing smart metering infrastructure. SmartGridCIS provides their clients with a powerful, integrated enterprise platform that includes innovative secure web-based software, providing true integration to the smart grid via leading MDM and AMI platforms. SmartGridCIS is privately owned and headquartered in Atlanta, Georgia. For more information, call 1-866-678-1110.
About Peninsula Light Company
Peninsula Light Company is a member owned cooperative located in Gig Harbor, WA and is a
full requirement utility of the Bonneville Power Administration. The utility began in 1925. Since then, the cooperative has grown to be the second largest cooperative in the Northwest, with 26,000 members and serving over 31,000 meters on the Gig Harbor and Key Peninsulas. The utility provides electric power and water services.
… more…SAIC Awarded Contract To Design Academic Building For The Department Of Defense
Date: March 28, 2012
(McLean, Va.) April 11, 2012 – Science Applications International Corporation (SAIC) [NYSE: SAI] announced today that its wholly-owned subsidiary, SAIC Energy, Environment & Infrastructure, LLC, was awarded a prime contract by the U.S. Army Corps of Engineers (USACE) – Mobile District to provide architectural and engineering services for the design of the Joint Special Operations University (JSOU) at MacDill Air Force Base (AFB). The single award firm fixed price contract has a two year period o
f performance. The design work will be performed primarily by SAIC’s Oklahoma City, Okla. office.
The USACE provides vital public engineering services in peace and war to strengthen the nation’s security, energize the economy, and reduce risks from disasters. Co-located with the U.S. Special Operations Command at MacDill AFB, JSOU is the designated agency within the U.S. Special Operations Command to conduct joint education. They are tasked with providing relevant, realistic, leading-edge education opportunities to military and civilian special operations forces personnel around the world.
Under the contract, SAIC will provide architectural and engineering design services for the state-of-the-art 90,000 square foot JSOU facility that employs advanced classroom technology systems. The building will feature one auditorium, two lecture halls, a library, classrooms and seminar rooms, faculty and staff offices spaces, media development areas, conference rooms, and student break/holding areas.
“SAIC specializes in designing technology-rich buildings that accommodate blended teaching approaches, including video-conferences, smart boards, tele-presence, and other innovative learning management systems,” said Ron Reid, SAIC design project manager.
“We look forward to providing the USACE-Mobile District with architectural and engineering design services for the construction of the Joint Special Operations University at MacDill Air Force Base,” said JT Grumski, SAIC senior vice president and business unit general manager.
About SAIC
SAIC is a FORTUNE 500® scientific, engineering, and technology applications company that uses its deep domain knowledge to solve problems of vital importance to the nation and the world, in national security, energy and the environment, critical infrastructure, and health. The Company’s approximately 41,000 employees serve customers in the U.S. Department of Defense, the intelligence community, the U.S. Department of Homeland Security, other U.S. Government civil agencies and selected commercial markets. Headquartered in McLean, Va., SAIC had annual revenues of approximately $10.6 billion for its fiscal year ended January 31, 2012. For more information, visit SAIC: From Science to Solutions®… more…Date: March 06, 2012
Seattle – March 6, 2012. The AreaMax, Evluma's premier LED luminaire for security and area lighting, will debut at TechAdvantage 2012. Affordable and easy to install, the low profile 40W AreaMax features ConnectLED Bluetooth Low Energy (BLE) remote capabilities. Remotely enable or disable power to the luminaire from up to 150' away with a hand held device, such as an iPhone, or Evluma's custom designed key fob controller. The AreaMax debuts at TechAdvantage, San Diego, CA March 6-9, 2012 in Se
rvice Concepts Booth # 1331.
The AreaMax is designed for new installations, or where retrofitting existing 100W-175W HID fixtures may not be the preferred option. “We've received a great deal of feedback over the years as to what our utility and co-op customers are looking for in a new luminaire. An affordable, easy to install fixture, with comparable lumen output was at the top of the list,” said David Tanonis, VP of Sales and Marketing at Evluma. The AreaMax slides onto the existing pole arm typically used by NEMA Type V dusk-till-dawn fixtures and is compatible with NEMA standard twist-lock photocells and the new wireless photocells recently released onto the market. The AreaMax also features a replaceable high capability surge protection module for 20kV/10kA. An expected output of 3000 lumens will be confirmed once final certification testing is completed next month, says the company.
“As we test the new AreaMax and the new ConnectLED remote interface, we expect to fine tune features according to customer preference,” said Keith Miller, President and CEO of Evluma. Prototypes are currently being tested with three different illumination patterns including a full cut off version. A 100W version of the AreaMax is being considered. The ConnectLED iPhone app that mirrors the functionally of the Bluetooth key fob can be expanded to provide additional data to the lineman. Stop by the Service Concepts booth for a complete demonstration.
“The years of value engineering that we've put into our Clearlight line, plus a recent drop in LED prices helped us to create a robust, utility-compatible design that can be priced affordably,” says Mr. Miller. Pilot tests will be underway during Q2 with an anticipated formal release for the AreaMax sometime this summer, says the company.
About Evluma
Evluma is a division of Express Imaging Systems, LLC a small business with over 150 years of combined experience developing lighting applications for photographic equipment and the photofinishing industry. Formed in 2008, Evluma is committed to developing environmentally low impact SSL lighting solutions that are affordable and long lasting.
… more…E Source White Paper: The What, Why, and How of Customer Experience Management
Date: May 15, 2012
The concept of customer experience management (CEM) is simple, but understanding, measuring, and enhancing CEM can be difficult. Utilities across North America are challenged with finding ways to make their customers’ experience a positive one—from redesigning the customer bill to increasing first contact resolution and adopting consistent self-service methods across all contact channels. We examine what CEM is, why it’s important for utilities, and how you can start implementing it within your
organization. To download the white paper, go to www.esource.com/Customer_Experience_Management_Excerpt.
Public Relations Contacts
Wendy Bloechle, Vice President of Marketing, E Source
wendy_bloechle@esource.com
303-345-9158… more…LEARN WHAT’S AHEAD FOR DEMAND SIDE MANAGEMENT –– READ LANDIS+GYR'S WHITE PAPER
Date: March 30, 2012
In the past, utility demand side management (DSM) programs relied on incentive options, mechanical switching or one-way load control transmitters — with unverifiable results. In order to meet today’s load reduction needs, utilities now need to leverage next generation tools, like:
• Dynamic voltage management
• Direct load control programs that utilize advanced metering and monitoring
• Two-way technologies that provide for flexible and adjustable scheduling
Landis+Gyr’s whit
e paper "Demand Side Management: Why Utility-Directed Load Management Programs Make More Sense Than Ever Before" provides a practical look at what strategies you can use to shed load now.
Read the white paper. http://gurl.im/c9c62RC
… more…Date: February 03, 2012
Regulatory accounting and GASB 62 applications
(with specific example for contributions in aid of construction)
Russell Hissom, CPA, Partner
January 2012
With the issuance of Government Accounting Standards Board (GASB) Statement 62, utilities required to follow governmental accounting standards will no longer be allowed to follow any Financial Accounting Standards Board (FASB) guidance, including that for regulatory accounting (FAS 71/ASC 980). GASB 62 Codification of Accounting
and Financial Reporting Guidance Contained in Pre-November 30, 1989 FASB and AICPA Pronouncements is effective for financial statements for periods beginning after December 15, 2011.
This article explores the answers to some of the allowable uses of regulatory accounting under GASB 62.
FAS 71/ASC 980 lives on in GASB 62
FAS 71/ASC 980—Accounting for the Effects of Certain Types of Regulation
ASC 980 is the accounting tool used by public utilities where strictly following GASB does not necessarily meet their business model and the intent of certain accounting transactions that will benefit future periods or be charged against future periods. This is also the manner in which public utilities recover their costs through rates charged to their ratepayers, make their operating benchmarks comparable to their investor-owned peer utilities, and also match their accounting to utility industry standards.
GASB 62 has codified ASC 980 in a form that will allow public utilities a seamless transition without change to their current application of regulatory accounting under ASC 980. GASB 62 discusses using these regulated accounting rules in paragraphs 476–500 of the standard.
Regulated accounting under GASB 62
GASB 62 uses the term “Regulated Operations,” and discusses regulated accounting rules under paragraphs 476–500 of the standard.
Regulated accounting defined
The standard states that regulated accounting rules … “may be applied to business type activities that have regulated operations that meet all of the following criteria:
1. The regulated business-type activity’s rates for regulated services provided to its customers are established by, or are subject to approval by, an independent, third-party regulator or by its own governing board empowered by statute or contract to establish rates that bind customers;
2. The regulated rates are designed to recover the specific regulated business-type activity’s costs of providing the regulated services, and;
3. In view of the demand for the regulated services or products and the level of competition, direct and indirect, it is reasonable to assume that rates set at levels that will recover the regulated business-type activity’s costs can be charged to and collected from customers. This criterion requires consideration of anticipated changes in levels of demand or competition during the recovery period for any capitalized costs.”
These are substantially the current rules followed under ASC 980.
Application of ASC 980 rules under GASB 62
GASB 62 goes on to discuss how regulators may adjust rates for cost or revenue deferrals and the related accounting considerations that will be in play, depending on those regulator actions. Remember, for most public utilities the regulator is the city council or utility governing board.
The standard states that, “Rate actions of a regulator can provide a business-type activity with reasonable assurance of the existence of an asset. A regulated business-type activity should capitalize all or part of an incurred cost (that otherwise would be charged to expense) if both of the following criteria are met:
a. It is probable that future revenue in an amount at least equal to the capitalized cost will result from inclusion of that cost in allowable costs for rate-making purposes, and;
b. Based on available evidence, the future revenue will be provided to permit recovery of the previously incurred cost rather than to provide for expected levels of similar future costs. If the revenue will be provided through an automatic rate-adjustment clause, this criterion requires that the regulator’s intent clearly be to permit recovery of the previously incurred cost.”
Finally, the standard provides for return of revenues to customers, stating that, “A regulator can require that a gain or other reduction of net allowable costs be given to customers over future periods. That would be accomplished, for rate-making purposes, by amortizing the gain or other reduction of net allowable costs over those future periods and reducing rates to reduce revenues in approximately the amount of the amortization. If a gain or other reduction of net allowable costs is to be amortized over future periods for rate-making purposes, the regulated business-type activity should not recognize that gain or other reduction of net allowable costs in the current period. Instead, it should be deferred for future reductions of charges to customers that are expected to result.”
Standard uses of regulatory accounting
Again, “intent” is the key element in the use of regulatory deferrals (i.e., how will we recover these costs from our ratepayers or defer revenue recognition to future periods to mitigate rate impacts). Typical uses of regulatory assets and liabilities include:
Regulatory assets
Extraordinary maintenance costs such as planned unit outages, weather damage, or other unforeseen events
Premature losses on asset retirements
Decommissioning of generating units
Future recoverable costs (i.e., the difference between depreciation and debt service on bond financed plant) used to smooth the earnings impact
Long-term deferred receivables
Deferred power costs to be recovered in the future
Mark-to-market derivative and investment losses
Advanced debt refunding losses
Regulatory liabilities
Rate stabilization (funded or unfunded)—the difference of earnings over bond coverage to be used in future periods to offset anticipated increases in power costs and other expenses
Deferred costs collected in rates now that will be expended in future periods—such as those for future maintenance projects or decommissioning expenses
Contributions in aid of construction
Use of regulatory accounting and contributions in aid of construction
The use of regulatory accounting is well suited for deferring recognition of contributions in aid of construction for utility plant additions.
Under GASB 33—Accounting and Reporting for Non-Exchange Transactions, utility plant received from customers or developers is required to be recognized as revenue in the period of the transaction. Under the utility business model this does not necessarily make sense, as the utility will record depreciation on these contributed assets in future periods, while recognizing the full revenue of the contribution in a single period.
The application of regulatory accounting in this instance allows the income impact of the transaction to be matched over the depreciable life of the contributed assets, resulting in an income impact of zero.
For example, let’s assume these events:
1. A subdivision developer constructs $1 million of utility infrastructure (services, mains, etc.) and turns this infrastructure over to the utility per the utility’s service territory rules. This infrastructure will be maintained and eventually replaced by the utility.
2.The useful life of this infrastructure is thirty years
The entries under two scenarios to record these events are as follows:
GASB 33 required method
1.Receipt of utility infrastructure—
Debit Utility Plant in Service $1,000,000
Credit Revenues $1,000,000
2. Record annual depreciation expense over thirty years
Debit Depreciation Expense $33,333
Credit Accumulated Depreciation $33,333
Using this method results in revenue recognition of $1 million in the year of the transaction, but recognition of the related expense over thirty years—violating the common accounting principle of matching.
Using regulatory accounting to reflect the impact of the transaction on utility income and rates
The impact above can be mitigated through the use of regulatory accounting, as follows:
1. Receipt of utility infrastructure—
Debit Utility Plant in Service $1,000,000
Credit Deferred Regulatory Liability $1,000,000
The regulatory liability is a balance sheet account
2. Record annual depreciation expense over thirty years
Debit Depreciation Expense $33,333
Credit Accumulated Depreciation $33,333
3. Record recognition of deferred revenue over thirty years
Debit Deferred Regulatory Liability $33,333
Credit Depreciation Expense $33,333
Using this method makes the annual impact to utility income zero—reflecting that the utility must recognize depreciation expense for a utility plant that it did not finance and which is offset by the contribution for
that infrastructure.
Replacement financing of that plant after thirty years when it is fully depreciated is a separate question from this accounting approach.
Other thoughts
As with ASC 980, Baker Tilly recommends that utilities document their cost or revenues for deferral and seek governing board approval for such items either through a blanket resolution for routine items, or through board action, passing resolutions for specific material items. Documentation should reflect the cost or revenues to be deferred, pertinent details of the transaction, and the intended rate recovery or revenue return period. Changes in any circumstances should be reflected in future accounting from the point of the change in circumstances.
Summary
GASB 62 Codification of Accounting and Financial Reporting Guidance Contained in Pre-November 30, 1989 FASB and AICPA Pronouncements appears to have addressed any concerns public utilities may have about their use of FASB pronouncements, especially ASC 980 for regulated accounting. While there will be a note needed in your utility’s financial statements about implementing GASB 62 (effective for periods beginning after December 15, 2011), there should be no change in your financial statements if you’re currently using ASC 980.
As always, we seek your input into practical application of the new statement. If you have comments or ideas, please respond to russ.hissom@bakertilly.com, or post your comments to our Utility Accounting Issues Forum on LinkedIn. For a link to the page, visit www. bakertilly.com/powerup.… more…A Rapid Response to the NERC Facilty Rating Methodology Alert
Date: December 28, 2010
Burns & McDonnell has written a new whitepaper entitled A Rapid Response to the NERC Facility Rating Methodology Alert. This paper will help you learn more about required responses to NERC in the coming months as part of your overall compliance plan.
Click here to read more:
http://www.burnsmcd.com/tdThe Challenges Faced When Converting Solid Heavy Fuel Oil Fired Boilers To Bioma
Date: November 05, 2010
By: Thomas Stringfellow
Senior Consulting Engineer at Halcrow, Inc.
Introduction
In today’s world, biomass has become the golden word for Utilities, Municipalities and other industries that are examining ways to become carbon neutral or meeting Renewable Portfolio Standards (RPS) mandated by their State. However, converting existing boilers to biomass is not as simple as switching the fuel being burned in the boiler. There are impacts that need to be considered and addr
essed during the decision making process. These impacts will determine whether or not a boiler owner can convert their boiler to biomass and the following discussion provides some guidance in the decision making process.
Impacts
Firing biomass in boilers that were originally designed for coal and heavy fuel oil will have challenges for the boiler owner. First biomass usually contains higher moisture content than the other two fuels, second the ash chemistry of biomass is vastly different than the chemistry of coal and heavy oil ash. These differences alone will impact the boiler’s performance and overall operation of the boiler, if modifications are not performed.
Although the boiler is the main focus of this discussion, there will be other impacts to consider. These impacts will be on the fuel and ash handling systems, which may or may not require modification or replacement.
Halcrow analyzed the firing of biomass in the same size boilers designed to fire a sub-bituminous, a bituminous and a lignite coal. This analysis was also performed on a heavy oil or No. 6 oil fired boiler. In order to keep an apples to apples comparison all boiler conditions (steaming rate, steam temperature and pressure) were identical for each case.
Analytical Results
The results from the analyses show that firing biomass in an existing coal or heavy oil fired boiler will cause the boiler owner to make modifications to their boilers, or de-rate the boiler to lower steaming rates and or/conditions. The other option would be to dry the biomass to a 10% or less level. The table below shows the numeric results of our analyses.
Fuel Sub-Bituminous Bituminous Lignite Heavy Oil Biomass
MMBtu Output 500 500 500 500 500
MMBtu Input 588.5 565.3 601.7 572.2 623.9
Air Flow lb/hr 530,150 509,010 539,930 494,150 540,010
Flue Gas Flow lb/hr 596,140 549,610 617,950 525,700 630,480
Ash Flow lb/hr 3,140 4,560 8,000 300 8,060
Boiler Efficiency % 85.07 88.51 83.12 87.43 80.20
As expected, biomass and lignite performance are similar, yet the fouling and slagging indices for the biomass is higher than the lignite due to the amount of sodium and potassium in the biomass ash. In all cases, with the increased flue gas weight, the velocity will be higher in the convection pass if these boilers were converted to 100% biomass, without modifications.
So does this mean that boiler owners should not convert their boilers to burn biomass? Halcrow believes that the answer to that question is NO! Even though converting to biomass brings challenges and changes to the boiler, there are economic and environmental reasons and incentives to proceed with the fuel switching conversion.
The next questions are what do we do and how do we do it? The answer to these two questions and the possible solutions are discussed below.
First, if full load steaming conditions are not required the only change may be changing to a burner designed for biomass, adding strategically placed ash removal equipment (soot blowers) and operate the boiler with lower steaming conditions (de-rate). Second, if full load steaming conditions are required it may be necessary to add larger air and flue gas equipment (fans), opening the convection pass clear side tube spacing, replacing the burners and adding strategically placed ash removal equipment. Third, change the way the boiler is operated by installing overfire air and monitor the combustion process to mitigate the fouling and slagging conditions.
Conclusion
Every boiler is different and its design may hold potential for conversion. Boiler owners should employ qualified people to investigate converting to biomass and to provide them with an analysis that one, they can understand, two that they can use to make the optimum decision and finally put into their future planning for conversion. We believe this type of analysis is critical in the initial planning stages of any process of converting existing boilers to biomass.
… more…
