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Here We Go Again: Potential Synergies of an Alstom (Power and Grid) Acquisition by General Electric:

As many long-term readers of Newton-Evans’ reports and articles knew from our assessment reported in 2009 there were then three major contenders for the $7 billion Transmission and Distribution business units of the old Areva T&D Corporation. These were the American firm General Electric, the French corporate combination of Alstom and Schneider Electric, and the Japanese company, Toshiba. In the end the French government simply divided Areva T&D in half, and placed the “T” business into Alstom and the “D” business into Schneider Electric.

This past week, there have been widely circulated rumors of another attempt by GE to acquire Alstom’s power business, principally Alstom Power (generation assets) and Alstom Grid, the HV component of the old Areva T&D business. The “D” business of Areva is now squarely in the capable Schneider Electric camp of medium voltage equipment offerings.

Newton-Evans Research believes there could be significant benefits to GE’s efforts targeting the global electric power industry if the company’s current purported acquisition attempts bear fruit. There are four key reasons for this view, in our opinion:

(1) As reported by others, GE will gain improved access to European and other world regions with long-established relationships nurtured under the French management and policies, which are likely to continue under GE ownership.

(2) GE Energy Management will again be able to lay claim to some real growth within 24 months. These increases will come from both inorganic growth (via this potential acquisition – itself worth about $4.5 Billion in current year sales of Alstom Grid products, systems and services) and organic growth (through increased interest and procurement of all GE Energy Management equipment, products and services). The four component businesses of GE Energy Management include: Digital Energy, Industrial Solutions, Power Conversion and Energy Consulting. These will each benefit significantly.

(3) GE will be able to fill several significant product/equipment gaps in its electric power transmission and distribution product line and related automation offerings. This will result in significant mid-term benefits to GE Digital Energy.

(4) Alstom’s power business includes assets for power generation such as turbines for coal, gas and nuclear power plants, and wind farms.  Alstom Grid  offers a world-class group of control systems for power transmission and distribution as well as many leading transmission-class equipment offerings. The company’s “e-terra” line of systems is the leading market shareholder among critical systems used in the global electric power industry.

A successful acquisition by General Electric would provide the firm with world-leading combined market shares in substation automation, protection and control and T&D control systems (energy management and SCADA). GE Energy Management would become a major player in several growing portions of the transmission equipment business, establishing a stronger foothold in the North American and international transmission market segments described below. Together these segments are worth $32-40 billion on a worldwide basis. Newton-Evans’ estimates that Alstom Grid earned about $3.5 billion to $4.1 billion in HV equipment sales in 2013.

FACTS and Reactive Power Compensation: ABB is probably the global leader in flexible AC transmission systems and the related reactive power compensation segment of high voltage equipment for transmission networks. Siemens Energy is a strong number two supplier with several others (notably Mitsubishi Electric Power Products, and American Superconductor) also active in North America, and around the world. Alstom Grid and GE are also participants that together could challenge the market leading positions of ABB and Siemens within three years of a merger of product lines.

HVDC Equipment: Siemens is the market leader in HVDC, with ABB a reasonably close second place share holder and MEPPI the likely third most important player. However, an integrated Alstom Grid-General Electric product grouping would enable the company to attain up to a quarter of the available market shares.

Gas Insulated Substations/Switchgear: The North American market for High Voltage GIS equipment is in excess of a quarter billion dollars. While Alstom Grid has only a small share (stronger in Canada than in the US), GE Energy could now present itself as a player in this growing market segment of high voltage switchgear. GE would also play a much more important role in international markets where – unlike in North America – GIS equipment is prevalent. Globally, GIS equipment is a 2-3 billion dollar annual market.

High Voltage Bushings: This relatively small (about $125-150M in annual worldwide sales) market is led by Siemens and ABB. However, the combined Alstom Grid and GE offerings could make GE into a formidable player in this segment.

High Voltage Capacitors: GE Energy is already the major participant in the North American market for HV capacitors, but globally, ABB is the leader. Alstom Grid, by virtue of its recent acquisition of the Finnish manufacturer, Nokian Capacitors, is also a very strong player in Northern Europe. Together, the product lines could pose a real threat to ABB dominance here (yet another billion dollar global product segment).

High Voltage Circuit Breakers: Alstom Grid is already a major player globally, and with GE’s “sales boots on the ground” could significantly increase its share in North America and abroad. ABB and Siemens are both very strong manufacturers in this large annual global market of better than $2 billion.

Disconnect Switches: High voltage disconnect switches are vital components of many transmission systems, and the global market runs to about $500 million annually. GE and Alstom Grid are among the six leading suppliers of disconnect switches in North America, but lag behind Hubbell, S&C and Southern States, some of which offer circuit switchers used for disconnect applications.

Instrument Transformers: The market for high voltage instrument transformers had been dominated by specialist “independent” manufacturers until recently. A recent buying spree had Siemens acquiring Trench Electric, Alstom Grid acquiring Ritz and ABB acquiring Kuhlman. Currently, the market for HV IT equipment is shared primarily by these three firms, with GE very active in the MV segment. Together, the combined HV/MV instrument transformer offerings of an integrated GE-Alstom Grid would change the shape of this market, which in North America alone hovers around $100 million, and close to one-half billion dollars worldwide.

Air Core Reactors: Another component of some transmission network architectures, Siemens-Trench and Alstom Grid-Ritz are key players, with GE also strong and MEPPI further behind, but with a growing share. A number of smaller participants account for a rather large share of this $400 million global business.

Surge Arresters: Another sizable market in its own right (about $1 billion per year globally) high voltage surge arresters are manufactured by a number of US-based firms such as Hubbell, Thomas & Betts, and Cooper Power, each of which competes quite successfully against the likes of ABB, Siemens and GE.

Automation Systems: GE’s long-established XA/21 EMS platform and Alstom Grid’s highly rated E-Terra offerings are both held in high regard, although GE’s systems are mainly installed in the USA. Earlier (1990’s era) acquisition efforts have been fraught with initial business unit integration problems (to wit- ABB with its acquisition of the older Ferranti EMS business (Spider v. Ranger offerings) and Siemens-Control Data (Sinault-Spectrum v. Empros).

Protection and Control: Internationally, Alstom Grid (with part of the Stafford, UK-based relay business) holds an estimated 16% share of the global protective relay market, estimated by Newton-Evans to be about $2.2-$2.4 billion on an annual basis. GE Multilin, based in Toronto, is also a very strong market participant, especially in the Americas, and is the leader in industrial protection and control markets.

T&D Services: GE is a major participant in T&D equipment repair and services, especially with its transformer repair business, and Alstom Grid outside of North America earns about $550 million per year with its array of high voltage equipment services and automation systems maintenance agreements.

We will soon see learn whether and how the French government will allow Alstom to sell off all but its transportation business to a “foreign” company. GE will likely have to make significant concessions regarding job retention among the French workforce. This could have ripple effects on its global workforce.

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Electric Utility SCADA/DMS and OMS Convergence Trends

Here are some more excerpts from our latest study of the World Market Study of SCADA, Energy Management Systems, Distribution Management Systems and Outage Management Systems in Electric Utilities: 2013-2015. The information below was collected from 101 electric utilities in the U.S. and Canada between the 4th quarter of 2012 and 1st quarter 2013. The survey sample consisted of Investor Owned utilities (21%), Public Power (35%), Cooperatives (44%), and Canadian Utilities (13%).

Has your utility converged SCADA/DMS and OMS functions?
A total of 35% of utility respondents either had already converged SCADA/DMS and OMS or planned to do so by the end of 2015. Only 6% of Public Power utilities surveyed had already converged these functions, but another 21% had plans in place to do this by 2015.

Has your utility converged SCADA/DMS and OMS functions? (as of Jan. 2013)
SCADA-OMS_convergence

What functions have been converged/or plan to be converged?
Eighteen respondents said they had either converged SCADA and OMS, or planned to. Some mentioned that their SCADA reported all operations and statuses of monitored devices to their OMS, and some indicated that SCADA and OMS were less tightly integrated (for example, in some cases SCADA might only report switch/breaker status to OMS.) Here are a few of the more specific comments that were mentioned on the survey:

  • AMI system will provide customer meters out to the OMS system on a limited basis.
  • All distribution SCADA functions have been integrated with OMS/DMS through interface applications.
  • SCADA reports all operations/statuses of monitored devices to OMS
  • One way interface from SCADA to OMS (breaker & switch status)
  • Integrated platforms – smart meter “last gasp” info feeding GIS & SCADA systems which then feeds Outage Notification system
  • Topology (coloring feeder); Load Flow; Real Time Metering; Volt-VAR Control; Outage Report
  • SCADA/DMS. SCADA provides the load data to operate the DMS.
  • Multispeak connections between SCADA and OMS
  • Predicted and actual outages
  • Telvent’s ADMS product (OMS&DMS) to be installed on top of upgraded Telvent OASyS DNA SCADA system.
  • Estimated restoration times, extent of outage, number of customers

Does your utility currently have real-time linkages between SCADA and GIS or OMS?
Sixty percent of utilities surveyed did not have any real-time linkages in place as of January, 2013. About one-third had real-time linkages in place between SCADA and OMS, while just 15% had real-time linkages between SCADA and GIS.

Larger Investor Owned utilities were more likely to have real-time communications linkages in these situations. Just over half of Investor Owned utilities (52%) had real-time linkages between SCADA and OMS, and 24% had real-time linkages between SCADA and GIS. Fifty-four percent of large utilities (i.e. serving more than 1 million customers) had real-time linkages between SCADA and OMS.

Does your utility currently have real-time linkages between SCADA and GIS or OMS? (as of Jan. 2013)
real-time_linkage

More details about the topics covered in this and other studies are available on our reports page.

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Interest in Combining Control Systems on a Common Platform Among North American Electric Utilities

The following is excerpted from the Newton-Evans Research study, “World Market Study of SCADA, Energy Management Systems, Distribution Management Systems and Outage Management Systems in Electric Utilities: 2013-2015.” Read more about it on our reports page here.

Do you have any interest in combining EMS and DMS on a common platform?
In 2013, utility interest in combining these two systems was observed to be about the same as it was in 2010. A total of 26% of respondents had interest or had already combined their EMS and DMS systems. In 2010, 27% of utilities surveyed expressed an interest in doing this. Cooperatives showed less interest in combining, while Investor Owned utilities had more interest.


(Summary from the 2012 survey)

In the 2010 survey, there was some interest in combining EMS and DMS on a single platform; 27% of respondents answered “yes” they had an interest in combining the two. There was more interest among Canadian respondents (36%), IOUs and public power utilities (each at 32%), compared with only 13% of cooperatives (this sub-group of distribution cooperatives is less likely to use EMS technologies). Similarly, larger utilities were somewhat more interested in this combination of EMS and DMS than were smaller utilities.

Do you have any interest in combining DMS and OMS on a common platform?
Similar to what had been reported in the 2010 study, the 2013 study indicated that 41% of utilities either have interest in combining DMS and OMS (36%), or have already combined them (5%).

Do you have any interest in combining DMS and OMS on a common platform?
(Summary from the 2012 survey)

Overall, 40% of the 92 utilities responding to this part of question 3 expressed interest in a combined DMS/OMS platform. The highest level of interest was noted among Canadian respondents (64%); the lowest amount of interest was among U.S. cooperatives (17%). Fifty percent of utilities serving more than one million customers were interested in combining DMS and OMS capabilities on a single platform. Questions 3a and 3b are new questions added to the 2010 survey.

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U.S. Market for Feeder Protection Relays

According to GE Digital Energy, a feeder protection relay can provide primary circuit protection on distribution networks and backup/auxiliary protection for transformers, generators and motors. With a total estimated market of about $60 million in direct sales to the nation’s electric utilities, this total is expected to grow to $72 million by the end of 2014. Modern (digital/numeric) feeder relays are a key segment of the overall substation modernization and distribution automation equipment market. Feeder relays are just one of 84 types of electric T&D equipment and services discussed in the Newton-Evans report series, Overview of the U.S. Transmission and Distribution Equipment Market, which is presently being updated to reflect year-end 2013 U.S. market values and provide market forecasts and outlook through year-end 2016.  This summary of feeder relay activity is typical of the information contained in each of the 84 reports.  Market segment shares for suppliers are also provided in each report.  Here are a few of Newton-Evans’ observations on this important market segment taken from the 2011 market overview series as well as the Worldwide Study of the Protective Relay Marketplace In Electric Utilities: 2012-2014.

Average Unit Price Range:
Distribution feeder relays have been recently priced between $900 and $1,800 depending on whether or not other features like over-current protection are included.

Major Manufacturers:
ABB: REF615R Feeder Protection and Control, REF series
Basler: BE1-11f system
Beckwith: M7651
Cooper (now owned by Eaton): iDP210
Eaton: CH-Series, E-Series
GE: M Family, SR 3 350, F650
SEL: 751, 751a, 351S
ZIV: IRV, DRV
ERLPhase: F-Pro

Findings from the Worldwide Study of the Protective Relay Marketplace In Electric Utilities: 2012-2014 Volume 1 – North American Market:
The 2012 survey findings suggested a likely increase in purchase plans for transmission line relays and distribution feeder relays. In 2012, as in previous studies, distribution feeder relays made up the largest portion of planned relay purchases over the 2012-2014 time frame. A significant share of all utility relay purchases (units) planned for this period were distribution feeder relays.

The earlier 2009 study findings had indicated that distribution feeder relays were the “best-selling” and most widely used type of protective relay within the utility segment, even though redundancy in the distribution grid was not nearly as common as found in transmission applications. About 40% of the total number of units planned for purchase during the forecast period was to be distribution feeder relays.

Digital vs. Electromechanical
In 2012 the survey respondents indicated that 60% of distribution feeder relays in their installed base  were digital/microprocessor relays. This percentage continues to grow as more digital relays are added to the current system every year. The earlier 2009 study observed that 53% of the installed base was digital, with 97% of planned unit purchases likely to be digital as well.  As recently as 1999, the split was 50-50 (electro-mechanical versus digital/numeric).


To stay up to date on our progress with the Overview of the 2014-2016 U.S. Transmission and Distribution Equipment Market, sign up for our newsletter by emailing with the subject line “subscribe.” Visit our reports page for more information and to download a report brochure.

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U.S. Electric Transmission & Distribution Equipment Market Overview

In 2014 Newton-Evans plans to update its U.S. T&D Equipment Market Overview report series to reflect market observations from 2013 and estimates for 2014-2016. This series of 2-3 page “top line” summaries will present the 2013 market shares for major participants in dollars and % of U.S. total. Each report will also present U.S. market segmentation in $MUSD, and a forecast out to 2016. Vendor and IEEE equipment definitions are provided.

Make sure to email info@newton-evans.com and sign up for our newsletter and report availability notifications for this series.

Here is a complete list of reports that will be available for $150 each:

Continue reading U.S. Electric Transmission & Distribution Equipment Market Overview

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Smart Meter Deployments By Usage Segment

Even in mid-2013, American utilities continued to rely on more than 80+ million “dumb” electricity metering devices for data acquisition on electricity consumption. Most of the installed analog metering devices were manufactured in the United States. Smart metering technology is also largely developed and manufactured in the U.S.; at the very least, it is tested in the U.S., and its final assembly is completed here. There are several more suppliers of automated meters than there were of electromechanical meters. Here is Newton-Evans outlook for smart meter deployments in each of three key usage segments.

Smart Meter Deployments Timeline

Smart Meter deployments chart


For more information about U.S. electric utility equipment manufacturing capabilities see our recent report, “American Manufacturing and Systems Integration Capabilities for Power Grid Modernization” on our reports page.

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Encryption of Substation Communication Protocols On The Rise in North American Electric Utilities

The recent Newton-Evans survey of the Worldwide Market for Substation Automation and Integration programs in Electric Utilities: 2014-2016 reveals the increasing trend in North America of encrypting substation communication protocols. Here are a few facts about this topic:

1) Out of 59 North American electric utilities responding to the survey question, “What protocols do you use within the substation, between substations, and from the substation to the external host or network?” forty-five said they currently use DNP3 (serial) and 28 said they use DNP3 LAN (TCP or UDP) within the substation. For communication from substation to substation, 16 said they use SEL protocols and 21 said they use a version of DNP3. For communication from substations to the external host or network most respondents use a version of DNP3.

2) When asked the follow up question, “Are these protocols encrypted?” sixty-nine percent (41/59) said “No.” This seems like a lot, but the Newton-Evans survey has found that every few years more and more North American utilities are using encryption.

Are substation communication protocols encrypted?
SSA_enr_protocolsNA

3) Utilities were then asked, “If your protocols are encrypted, where do you employ encryption?” a) Inside the substation b) substation to substation c) substation to master (choose all that apply). Of the 15 North American utilities responding to this question, 14 indicated they encrypt protocols from substation to master, while only 3 use encryption within the substation and 2 from substation to substation.

Purchase the full report from our reports page for more detailed information on substation protocol use, encryption, and substation communications.

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Excerpts from Volume 2 of The World Market for Substation Automation and Integration Programs in Electric Utilities: 2014-2016

The Newton-Evans Research Company has released findings from the International volume (Volume 2) of its newly published four volume research series entitled: The World Market for Substation Automation and Integration Programs in Electric Utilities: 2014-2016. In addition to looking at plans for over 20 types of equipment commonly used in substation-wide automation and integration programs, this 200+page report includes a comprehensive look at the market trends for:

  • choice of communication protocols within and between substations, and from substation to control center
  • wireless devices inside the substation
  • number of Ethernet ports in a substation
  • number of simultaneous wireless connections allowed
  • protocol encryption and redundancy
  • communications architectures and links
  • Time Synchronization methods
  • protective relays
  • outsourcing of substation-related services

Key findings from 5 other recently Newton-Evans studies on substation-related topics accompanies the information gathered in late 2013 from thirty-two global electric power utilities that participated in the latest five-page survey.  A total of 96 unique utilities located in 57 countries around the world participated in one or more sections of the substation modernization study. On average, these international utility officials participated in two or three of the six topical surveys that form this report.

 

Some observations:
Potential obstacles to implementing substation automation and integration for both new and retrofit substations through year-end 2016
Similar to 2011, very few utilities ranked any of the listed “potential obstacles” as a 5. Of all the listed challenged, the two that least stand in the way are “Lack of appropriate communications technology inside the fence” and “Lack of appropriate communications technology substation to master.” Over 60% of respondents ranked these a 1 (“doesn’t stand in our way.”)

For new substations, “security concerns” was rated a 4 by 4 out of 31 respondents, as were “Not enough skilled internal staff” and “Substation equipment vendor community will not have required “open” products and equipment by year end 2016.”

Choice of protocol within the substation, between substations, and from the substation to the external host or network.
Within the substation, international utility respondents cited use of IEC 61850 as well as the variants for IEC 60870-5. Followed by Modbus (serial, LAN and Plus) versions. For the minority of utilities performing any peer-to-peer substations communications, IEC 60870-5 -101 and -104, led in mentions. These were closely followed by SEL mirrored bits, and by DNP 3, Growth in use of IEC 61850 for peer-to-peer communications is planned by this group. IEC 60870 variants were also the most widely used protocols for substation-to-control center communications internationally. Some DNP, common legacy protocols were also being used for substation-to-control center communications.

Additional information on the International substation market report, and the other three reports comprising the four volume study “Worldwide Market for Substation Automation and Integration Programs in Electric Utilities:2014-2016” is available from Newton-Evans Research Company, 10176 Baltimore National Pike, Suite 204, Ellicott City, Maryland 21042.
Phone 1-410-465-7316, write to info@newton-evans.com and see our reports page for more details.

An introductory price of only $1,495.00 for Volume Two is available to new subscribers until March 8, 2014.

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Excerpts from Volume 1 of The World Market for Substation Automation and Integration Programs in Electric Utilities: 2014-2016

The summaries in the Report Findings section of this report provide top-level views and synopsis of all 77 North American utility respondents combined. In the Data Tables section of the report, survey results are cross-tabulated by size and type of responding utility.

The Newton-Evans 2014 sample for this study represents a total of at least 32,594,000 end-use customers, 2,019 transmission substations and 7,649 distribution substations in the United States and Canada. The sample distribution of North American utilities in this study is similar to previous year studies. About one-fifth of the responding utilities are U.S. Investor-owned, 36% are public power utilities, 32% are cooperatives and 12% of the respondents in the sample are Canadian provincials and municipals.


1. Please rank the significance from 1 to 5 for all of the following listed “potential obstacles” to implementing substation automation and integration for both new and retrofit substations through year-end 2016. Use: “1 = doesn’t stand in our way” to “5 = formidable obstacle.”
Just as in 2011, utilities seem to be least concerned with “lack of appropriate communications technology inside the fence.” For new substations, 69% of respondents said this “doesn’t stand in our way,” and for retrofitted substations, 48% said the same. “Lack of funding” for retrofitted substations seemed to be a potential obstacle, with 51% rating it a 3 or higher. This was also the chief obstacle in 2011, although “security concerns” was rated a 4 or higher by 33% of the same group. The current survey shows only 20%-24% of utilities in the sample rating “security concerns” a 4 or higher.

SSAvol1-non-obstacles

SSAvol1-obstacles

More information on how to order volume 1 or other volumes of this report series is available on our reports page.

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Newton-Evans Releases First Volume of 2014-2016 Substation Automation Series

The Newton-Evans Research Company has released findings from the North American volume (Volume 1) of its newly published four volume research series entitled: The World Market for Substation Automation and Integration Programs in Electric Utilities: 2014-2016. The new study compares the current round of research findings with several earlier substation modernization tracking studies conducted by the firm. More than 75 large and mid-size North American electric power utilities actively participated in this multi-part study. Investor-owned utilities, public power utilities, cooperatives and Canadian provincials and municipals took part in this complex study involved more than 400 survey data items.

Newton-Evans Research estimates the current mid-range of North American spending for substation automation and integration programs at $690 million, with an overall potential market size of nearly $10 billion. Global potential spending for substation modernization programs is estimated at about $38-$40 billion. This amount includes spending for a wide range of intelligent substation-resident equipment and devices and the manpower to undertake the systems integration efforts required.

Additional Observations:
1) The years 2008-2009 were slow growth years – while the 2010-2013 years provided moderate-to-good growth in most categories of intelligent electronic equipment sales related to the modern, increasingly digital, electric power substation. The pool of funding for substation automation projects increased during 2010-2013 thanks in part to the stimulus funds made available by the U.S. Department of Energy, with most of this amount now spent.

2) Newton-Evans further estimates that only about 12-15% of utility operated substations in North America have been fully automated and integrated by year end 2013. Most of these fully automated installations are in fact being reported as newly or recently constructed transmission voltage substations.

3) It is becoming more difficult to separate substation product classifications as equipment manufacturers tout their offerings as “multifunctional” and the product positioning of many intelligent electronic devices now cuts across multiple product classifications.

4) Most substation equipment manufacturers (mid size and smaller companies) and systems integrators surveyed in the second half of 2013 have indicated moderate-to-good growth market conditions within their addressable utility market segments, resulting in sales that are as much as 10-20% higher than 2010-2012 sales levels. The substation automation market outlook for 2014 is also for moderate to good year-on-year growth, continuing through 2016. Looking ahead to 2014-2016, substation retrofit programs are planned to be undertaken only for the most critical of distribution substations, while new electric power T&D substations will benefit from increased spending for integration and automation.

5) The outlook for increased reliance on commercial services providers working in substation modernization activities is strongly positive. Third party engineering and integration service firms have recently made significant strides in winning substation automation-related business, from planning to design to construction and equipment installation.

6) Utility manpower shortages and funding issues continue to negatively impact the ability of technology supplier companies to engage utilities for other than short-term automation requirements. In states and provinces wherein regulators have approved strong incentives for reliability improvements or for transmission line extensions, the spending outlook is robust.

7) North American utilities continue to strongly support DNP 3, and many have now implemented, or are migrating to, a LAN version of this protocol. This year’s study has found some increase in plans for use of at least some portions of 61850 within a few dozen of North America’s largest utilities. The use of encryption techniques for transmission of substation data is also growing.

8) In summary, retrofit substations will be upgraded as warranted during 2014-2016, based on regional load growth, load criticality to customers, and related distributed generation and renewables siting developments. New substations will increasingly be designed and constructed as integrated and automated remote assets for the utility. The current study finds the bulk of available substation automation budgets likely to be spent for new substations, primarily for transmission substations.

Additional topics being covered in the four volume series of substation automation studies include in-depth coverage of several communications topics, vendor security certification requirements, external systems linkages to the substation, preferred equipment suppliers, substation timing requirements, and an assessment of how North America’s electric power substations are positioned along a three-step path to complete automation.

This newest edition of this flagship Newton-Evans study features excerpts from other recent substation research programs, including precision timing requirements; CAPEX/OPEX outlook; dynamic line rating systems and synchrophasor-related monitoring systems; the expanding role of relay-centric devices and imbedded sensors; and user-reported vendor preferences for 21 specific substation-resident equipment categories.

Additional information on the North American substation market report, and the other three reports comprising the four volume study “Worldwide Market for Substation Automation and Integration Programs in Electric Utilities:2014-2016” is available from Newton-Evans Research Company, 10176 Baltimore National Pike, Suite 204, Ellicott City, Maryland 21042.
Phone 1-410-465-7316, write to info@newton-evans.com and see our reports page for more details.

An introductory price of only $1,495.00 for Volume One is available to new subscribers.

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Market Trends Digest

A special December 2013 edition of the Newton-Evans Research Company’s Market Trends Digest is now available on our website. This edition looks at some of the studies Newton-Evans has put together in 2013. Also, see some preliminary results from our study of the World Market for Substation Automation & Integration 2014-2016, and read two articles by our CEO Chuck Newton:

1. ASAT and Alstom Grid: One Year Post-Merger
2. Cyber-security: Still Time to Heed the Warning Signals

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Newton-Evans Study Shows Cumulative Shipments Of HV/MV Instrument Transformers During 2013-2016 Will Approach $1.5 Billion

According to a recent study published by Newton-Evans Research, the “Mid-2013 Assessment and Outlook for the North American Market for HV and MV Instrument Transformers,” the manufacturing of HV IT equipment has a high “concentration ratio” of suppliers. MV IT equipment manufacturing is less concentrated, and the market is supplied by several participants.

Of the key North American IT equipment manufacturers, only ABB participates to a significant extent in both the HV and MV segments. ABB is the clear market segment leader in MV IT shipment values, and is growing to become a significant player in the HV IT segment in North America. One competitor did state that in their opinion, most of ABB’s HV IT shipments to U.S. and Canadian customers are still in sub-transmission and lower HV ranges. ITEC believes its own business will grow nicely with planned new HV offerings in the 230kV range.

Overall, the IT sub-industry group of firms is positive regarding the outlook for IT equipment sales as the deployment of substation automation devices, including more relays and additional substation meters, continues to increase. Utility personnel and T&D engineering consultants we talked with also believe that the IT market is growing nicely, thanks to increases in transmission expenditures and the expansion of renewable energy facilities.

The full 14 page report is available for $575 on our reports page (scroll down to “Mid-2013 Assessment and Outlook for the North American Market for HV and MV Instrument Transformers”)

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Substation Automation, A Look Back: External Assistance Required by Utilities for Substation Automation-related Activities

One subject Newton-Evans tries to measure in many surveys is the need for third party services among electric utilities that – for many possible reasons – might find themselves understaffed or lacking the specific technical expertise for a new type of equipment.

When we asked the question in 2010 to electric utility substation planners and engineers, “Will any external assistance be needed for substation automation and integration-related activities?” here is how our sample responded:

North America:
The Newton-Evans 2010 North American sample included 58 utilities in the U.S. and Canada representing a total of 27,459,646 end-use customers, 1,633 transmission substations and 5,448 distribution substations.

Engineering drawing support was indicated as a near-term requirement by 38% of the respondents. Training services followed with about one third citing a need for educational support.

Growth areas for services were expected for security-related services (vulnerability assessments, remediation services), training services and installation support.

External Assistance Needed For Substation Automation And Integration-Related Activities: North America
SSA_assistance2010NA

International:
The Newton-Evans 2010 International sample included 43 utilities in 32 countries.

Personnel training was the substation-related activity that most required outsourcing to a third party. Sixty-two percent of international respondents required assistance with training in 2010, and 29% were estimated to require it by 2013.

Commissioning and testing, Installation, and security also currently require third party assistance by more than 40% of respondents, similar to the 2005 survey results.

External Assistance Needed For Substation Automation And Integration-Related Activities: International
SSA_assistance2010INT

In the 2005 study, training was the most important “external” service required by the world’s utilities for substation automation activities, mentioned by 54% of the respondents. This was followed by installation services and commissioning and testing services (both at 42%).

For more information about the world market for Substation Automation and Integration activity, write to us at info@newton-evans.com or give us a call: 1 410 465 7316. Also see our sample material and brochures for the upcoming 2014-2016 substation automation world market study on our Reports page.

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Newton-Evans Fourth Quarter 2013 Research Efforts and Topics

In-house Studies
Substation Automation & Integration: 2014-2016
This survey-based report series is currently in the planning stages. Newton-Evans is currently requesting suggested topics for inclusion in the survey questionnaire from early subscribers to this series.

RESEARCH IS CURRENTLY PLANNED TO BEGIN SHORTLY. THIS IS THE FINAL OPPORTUNITY FOR SUBMITTING CLIENT INPUT TO THE SURVEY BEFORE IT GOES OUT. VISIT OUR REPORTS PAGE NOW AND ORDER WITH A CREDIT CARD TO SAVE $1,500 OFF THIS 4-VOLUME REPORT SERIES DUE OUT IN JANUARY 2014!

Our Reports

For examples of previous Substation Automation studies, see our reports page or go to the following URL for samples from the past study:
www.newton-evans.com/SSA2011_Samples.zip

Recent Reports
American Manufacturing and Systems Integration Capabilities for Power Grid Modernization – Important Resource for staff and management at manufacturing companies and systems integration firms. Multiple facets of “smart grid” are discussed, including substation modernization.

Assessment and Overview of the World Market for Time Synchronization in Electric Power Substations: A Utility and Industry Survey-Based Report on Precision Timing Requirements – “Must Have” Information on Timing Requirements for Substation Modernization Programs involving utility clients at the substation level.

Global CAPEX and O&M Expenditure Outlook for Electric Power T&D Investments: 2013-2014, Funding Outlook for Smart Grid Development Based on Summer 2013 Survey Results – Great resource for global and regional outlook on grid modernization- focused on control systems, substation modernization and other key components of “smart grid” interest to the supply and demand side of electric power delivery industry.

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Overview of the U.S. Market for Fuses and Fusing Products Among Mid-sized Electric Utilities

This past summer Newton-Evans Research conducted a market survey of mid-sized electric utilities in the U.S. on the topic of fuses and fusing products. A total of 38 replies were received from utility operations officials. This respondent group included: 4 Investor Owned utilities, 21 Public Power utilities, and 13 Cooperatives. These 38 utilities serve a combined total of 8.2 million end user customers, or about 6% of the 144.5 million U.S. electricity end users.

Among several of the survey questions, utility engineers were asked to select the five voltage, current and speed power fuse combinations that were most used. Thirty-two respondents answered this question. Some respondents selected less than five combinations, and some selected more than five combinations. Twenty-seven respondents use 100 amp power fuses at either 7.2kV, 14.4kV, 25kV or 34.5kV. The table below provides a complete count of each combination selected on the survey.

Voltage, current and speed power fuse combinations used most: number of mentions
VCSusedMost
*Note: respondents were allowed to pick multiple options.

Utility officials were also asked about their typical annual budgets for fusing products, as well as which manufacturers are used as a percent of their overall fuse purchases.

This new 37 page market report is based on a survey of mid-size utilities regarding usage levels and brand preferences for fuse links, power fuses, and current limiting fuses. The report looks at the most common amp ratings, key manufacturers, budgets and annual usage levels of fuse links, power fuses and current limiting fuses among the sample, and offers projections to the entire U.S. market. The power fuse section also looks at indoor versus outdoor applications and refillable versus one time use units. Voltage and current combinations are charted by usage levels for current limiting fuses. The fuse products report is priced at $675.00.

See our reports page to place an order.

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Upcoming World Market Study of Substation Automation

Newton-Evans Research Company is currently in the survey design phase as we update our biennial world market study of substation automation and modernization. As usual, the results of this survey will be published in a 4-volume report series titled, “The Worldwide Market for Substation Automation and Integration Programs in Electric Utilities: 2014-2016” which will be available near January 15 of next year.

The report series will forecast spending on many aspects of substation automation and construction, and it will also track technology trends in substation communications, security, computing platforms, protocols, router requirements, and other topics. The report will also discuss challenges utilities face with regard to updating and modernizing substations, their approaches to equipment purchasing and installation, need/lack of need for third party services, and more.

With a typical world market potential in the tens of billions of dollars, substation automation is a key piece of the Smart Grid modernization picture. Insights from this study will help both utilities and electric power equipment manufacturers alike plan for the future.

See our brochure for a complete list of topics that have been covered in previous studies of the Substation Automation market.

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New Report from Newton-Evans Emphasizes U.S. Know-How and Capacity to Forge a Modern Electric Power Grid

Study entitled “American Manufacturing and Systems Integration Capabilities for Power Grid Modernization” Provides Specific Guidance from Manufacturers and Systems Integration Firms concerning Readiness to Serve

September 25, 2013. Ellicott City, Maryland. Newton-Evans Research believes that American manufacturers can accommodate more rapid growth in U.S. grid modernization efforts than currently exists. Based on repeated surveys of several of the key manufacturing companies active in grid modernization product development and firms involved with grid management and control systems integration activities, there is sufficient manufacturing and integration capacity to meet expected demand levels for almost all core components of the smart grid investment grant program identified by the U.S. Department of Energy as well as additional grid modernization components studied by Newton-Evans Research Company. The latter group includes the intelligent electronic devices required for various automation projects from transmission and distribution level applications down to smart infrastructure equipment.

Regarding the nation’s ability to increase systems integration workloads and capabilities, there is sufficient integration expertise available to expand usage levels of the following: (1) dynamic transmission line rating systems; (2) synchrophasor-related monitoring systems used in the nation’s high-voltage transmission networks; (3) operational control systems deployed for power generation management, transmission and distribution network operations and outage management; (4) information technology with which to intelligently manage deployments of grid modernization components, including telecommunications and analytical tools.

Newton-Evans’ ongoing discussions and formal studies with suppliers, appropriate consultants and utilities have enabled the research firm to develop an independent update and prepare a fresh outlook for each of the DOE-identified smart grid components and a number of additional grid modernization components studied on a repetitive basis by Newton-Evans. Nationwide grid modernization efforts could be largely completed by 2040, including widespread deployment of a variety of scalable energy storage devices sited along the electric power delivery network and at customer premises, according to these observations and insights.

The core technologies identified as smart grid investment grant (SGIG) program components by DOE and discussed anew in this report are as follows: Energy storage, dynamic line rating (DLR), operational control and monitoring systems including SCADA and energy management, distribution management system, Advanced Distribution Automation (ADA) and outage management systems, synchrophasors, advanced metering infrastructure, smart meters, home-area networks and smart electricity loads

In addition, Newton-Evans has included observations from its own related studies of other essential components of grid modernization. These additional grid modernization components include substation modernization programs, protection and control activities, cyber security developments, time synchronization and a variety of grid infrastructure equipment.

Newton-Evans also conducted its fifth tracking study of capital investment in grid modernization during the summer of 2013. This new report includes key excerpts from findings reported in the company’s report Global CAPEX and O&M Expenditure Outlook for Electric Power T&D Investments: 2013-2014.

The 41 page report is priced at $975.00 and is available on our reports page.

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Power Fuse Applications in the U.S. Electric Utility Industry

Earlier this year, Newton-Evans received 38 responses to a four page survey on the topic of power fuses, current limiting fuses and fuse links. Topics on the survey included number of power fuses, current limiting fuses and fuse links purchase annually; what brands are used; which current levels, voltage levels and speed ratings (K, E and DR) are used the most; what % of fuses are re-fillable vs. one-time use; and what % are used for indoor vs. outdoor applications.

What percent of power fuses being purchased are re-fillable power fuses (i.e. SM4, SM5) versus one time use (replaceable) power fuses (i.e. SMD20/SMU20, SMD40/SMU40)?

Newton-Evans Research found that most utilities either buy nearly all re-fillable power fuses or nearly all one time use power fuses. Among the sample, an average of 40% of power fuses are re-fillable, and an average of 60% are for one-time use. A frequency distribution of individual responses shows that the 2 largest portions are either 0% or 90-100% for either type.

What % of Power Fuses Are Refillable Vs. One-time Use?
powerFuses_refillV1time_tblchrt

What percent of power fuses are used for indoor applications (i.e. SM4Z, SM20) versus outdoor applications (i.e. SMD20, SMD40)

Overall findings from the surveyed utilities indicated that about 86% of power fuses are purchased for outdoor applications, and the remaining 14% for indoor applications. However, note that five survey respondents indicated that 70% or more of their power fuses were in fact for indoor applications.

What % of Power Fuses Are For Indoor Use Vs. Outdoor Use?
powerFuses_indoorVoutdoor_tblchrt

To download a sample .pdf of this report or to order online, see our reports page.

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Use and Plans for Vendor Security Certification Programs: 2011-2013

The final question in the 2011 survey requested information on vendor security certification requirements that utilities may have adopted since the previous study in 2008. In North America, only 11% of utilities in the sample had implemented such a program, but another 19% planned to require vendor security certification by year end 2013. Two thirds of the utilities have no plans for such vendor security certification.

North America Sample, 2011:
vendorsecurityprog

North America Sample, 2011:
VSPinvolves

Of the International utilities that answered this question in 2011, three out of twenty-one (14%) had implemented such a program, while another 33% plan to require vendor security certification by year end 2013. Almost half had no plans for such vendor security certification. Of the three out of twenty-one utilities with such a plan, all of them said it involved commissioning and maintenance processes; two said it involved product and service design, development and testing, and one indicated that their plan also involved organizational processes and disciplines.

International Sample, 2011:
vendorsecurityprogINT

To get more excerpts from our research studies, and to receive news and updates about our upcoming research projects like World Market for Substation Automation and Integration Programs in Electric Utilities: 2014-2017, write to info@newton-evans.com with a subject line, “Sign me up!”

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Substation Automation Spending: Recap

Here are some of the key findings from the last survey of the World Market for Substation Automation and Integration Programs in Electric Utilities which was conducted in 2011. This study will be updated when research begins in 4th quarter of 2013. The 2011 study sampled roughly 20% of electric utilities worldwide by number of end use customers.

How much is your utility likely to spend on new and retrofit substation automation and integration programs between 2011 and 2013?

NA_SSAspending2011
A frequency distribution shows that most of the respondents in the sample did not have funds budgeted for one or more years in both categories (retrofit and new). About twenty utilities were spending less than $100,000 in one or more years, and eleven utilities planned to spend over $1 million. A handful of respondents planned to spend between $500,000 and $600,000.

INT_SSAspending2011
The international sample of utilities outside the U.S. and Canada had a larger proportion of respondents spending over $1 million, however, the international utilities in the sample tend to individually represent much larger, less deregulated infrastructures than U.S. utilities. The sample of international utilities spent an average of $6.5 million per year on new substations with a median of $1.4 million.

To get more excerpts from our research studies, and to receive news and updates about our upcoming research projects like World Market for Substation Automation and Integration Programs in Electric Utilities: 2014-2017, write to info@newton-evans.com with a subject line, “Sign me up!”