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Transmission Business
Evolution In a Period of Significant Resource Constraints
Patricia A. Park
UCONN MBA PROGRAM
April 24, 2008
2
The Cost of Reliability-August 10, 1996, Power Outages in the
Western State
The blackout in the western states on August 10, 1996, was a complex and dramatic
reminder of the importance our modern society places on reliable electricity service.
Ultimately, power was interrupted to approximately 7.5 million customers, for periods
ranging from a few minutes to about nine hours. Immediate costs to the region’s
economy were estimated at $2 billion. The August 10 outages were caused by multiple
transmission line failures over a period of several hours. A single transmission line failure is
a contingency that is routinely considered in reliability planning. However, the failure of
several lines, combined with the day’s pattern of operation, caused the system to become
unstable (which had not been anticipated by reliability planners), causing automatic controls
to open the California Oregon Intertie, a major link between the northern (Pacific Northwest)
and southern (California) portions of the western system. Opening the Intertie produced a
power surge from the Pacific Northwest through the eastern portion of the grid toward
Arizona and southern California, causing many lines to disconnect automatically and
eventually fracturing the western grid into four separate electrical “islands.” Within each
island, large blocks of customers lost power when their electricity demands suddenly
exceeded available local generation. The situation was worst in the southern island where
automatic controls disconnected over 90 generators to prevent them from being further
damaged. Some of the larger units were out of service for several days.Source: J. Hauer and J. Dagle, 1999. Review of Recent Reliability Issues and System Events. Report PNNL-1 3150.
3
Reliability Reality Check
Over the next five to ten years, electricity demand (25% +) will far outpace transmission capacity (increasing at a pace of only 4%). This short fall may lead to serious transmission congestion and reliability problems.
The benefits of increasing transmission capability to ensure reliability, even if this insurance is used only once to prevent a system-wide blackout, would be enormous and could far outweigh any potential gains from increased trade.
4
Today’s Discussion Topics
Transmission History
US Transmission System
NU Transmission System
Transmission Major Projects
Mitigating Risk of Resource Constraints
Labor Constraints – The Quanta Deal
Material Constraints & Contracting Strategies
Additional Information – Lead Times/Source of Supply
5
Transmission’s History
For nearly 100 years, US Power Industry was dominated by vertically integrated monopolies that generated, transmitted and distributed electric power in their own service territories
Initially, transmission was built by each utility for its own load purposes and to provide emergency support locally.
From the mid 1980s to 1994, approximately 23,000 miles of transmission capacity was added to the system.
From 1994 to 1998, total transmission capacity remained unchanged!
Factors contributing to construction lag included association with electric and magnetic fields (EMF), complexities of siting process, including required approvals from Federal, State, and local agencies.
During the 1990s, restructuring of the Power Business (under Order 888) began with generation, which was the easiest component to lend itself to free competition. Transmission and Distribution remained regulated.
6
Transmission’s History, Cont’d
During the 1970s, increased oil prices and higher inflation resulted in rising electricity production costs.
PURPA was drafted during this time to address the problem of America’s generation power plants operating at lower generation efficiencies.
PURPA created a special class of non-utility generators that constructed small power plants and co-generation facilities called Qualifying Facilities (QFs)
PURPA was not meant to start deregulation, but QFs began to flood the market.
Public Utilities Regulatory Policy Act of 1978 (PURPA)
7
Transmission’s History, Cont’d
EPAct of 1992 created a competitive wholesale market and the associated trading activities, ordering utilities to provide third-party access to their transmission systems.
During this time, utilities were still vertically integrated, owning generation.
EPAct enabled generation competitors (known as independent power producer or IPPs) to have transmission access.
Mid 1990s – IPPs began to search for new customers, as the regulator’s pricing policies required a lowering of prices paid by the utilities to the IPPs.
Access to transmission lines was critical for serving new customers who did not have their own lines.
This was a turning point in the history of transmission
Energy Policy Act of 1992 (EPAct)
8
Transmission’s History, Cont’d
1996 FERC Order 888 called for the “unbundling” of vertically integrated utilities into generation, transmission, and distribution activities Order 888 reflected FERCs commitment to provide free access to the
transmission grid Order 888 had mixed results:
The generation sector saw an increase in generation facilities and many utilities sold off their generation assets;
Transmission sector suffered the consequences, with increased load becoming too high for the transmission lines to handle.
North American Electric Reliability Council (NERC) initiated transmission loading relief protocols to avoid damage to the system during peak usage.
FERC Order 888
9
US Transmission System
Comprised of more than 150,000 circuit miles of extra high voltage (EHV 230kV and above) lines.
While the transmission system experienced significant growth during the 60s and 70s, the past few decades experienced dramatic decline or slowing of growth because of regulatory uncertainties, siting restrictions, and delays.
The electric transmission system is comprised of tens of thousands of electrical and mechanical devices and components that are interconnected. These components include electric generators, transmission lines (cable) and protection components such as circuit breakers and relays.
10
The NU Transmission System
Upgrading NU’s Transmission System requires a significant increase in capital investment.
Major Projects: Bethel / Norwalk Line Middletown / Norwalk Line Glenbrook Cables Long Island Replacement Cable (LIRC) New England East West Solution (NEEWS)
11
Four Major Southwest Connecticut Transmission Projects – A $1.68 Billion Investment, About 2/3 Complete
Bethel-Norwalk 345-kV underground& overhead$350 Million
21 miles 345-kV (56% underground)
10 miles 115-kV (100% underground)
Completed October 2006 at a cost of $335 million Middletown-Norwalk 345-kV
underground & overhead$1,047 Million (NU share)Glenbrook Cables
115-kV underground$223 Million
9 miles 115-kV underground
Projected in-service date: December 2008
Under contract – construction under way, 69% complete at 1/04/08
Long Island Cable138-kV cross-sound$72 Million (NU share)
11 miles 138-kV submarine cable
Joint project with LIPA
Projected in-service date: mid-2008
63% complete at 1/04/08
69 miles 345-kV (35% underground)
57 miles 115-kV (1% underground)
Joint project with United Illuminating
Projected in-service date: Second-half 2009
62% complete at 1/04/08
COMPLETE
50% of CT Load
12
2008-2012 Transmission Capital Expenditures Increase By Over 20% From Previous Five-Year Program
$0
$100
$200
$300
$400
$500
$600
$700
$800
2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012
Major Southwest CT NEEWS Springfield 115-kV Cables Other
Historic Forecast
In M
illio
ns
Up To $3.0 Billion $1,816 Million
$560 million of major SWCT
projects in 2008-2012 forecast
period; $1.68 billion in total
NEEWS projects estimated at
$1 billion during the 2008-2012 forecast
period
$1.1 billion of additional
forecasted projects
Successful completion of
SWCT projects
NEEWS projects ramping up
Springfield 115-kV Cables projects
estimated at $350 million during the
2008-2012 forecast period
Springfield 115-kV Cables project
ramping up
13
Historical Transmission Capital Expenditures
$170
$257
$454
$740-750$758
$0
$100
$200
$300
$400
$500
$600
$700
$800
$900
2004 2005 2006 2007 2008
$ M
illio
ns
14
$592
$311
$155
$420$530
$108
$58
$55
$108
$72
$50
$137
$222
$135$104
$0
$100
$200
$300
$400
$500
$600
$700
$800
$900
2008 2009 2010 2011 2012
CL&P PSNH WMECO
Projected Transmission Capital Expenditures
$432
$663$706
$506
$740-$750
$ M
illio
ns
15
NEEWS Project Schedules - Forecast Project Total $1 Billion
NEEWS
Greater Springfield Reliability
(115-kV/345-kV)
Interstate Reliability (345-kV)
Central CT Reliability (345-kV)
ISO technical applications approval
Mid 2008 Mid 2008 Late 2008
State siting application filed
Mid 2008 Mid 2008 Late 2008
Procurement contracts 2009 – 2012 2009 – 2012 2010 - 2012
Siting completed Late 2009/Early 2010 Late 2009/Early 2010 2010
Construction targeted to start on staggered basis
2010 2010 2010/Early 2011
In-service Late 2012/2013 Late 2012/2013 2013
16
Other Forecasted Projects Total $1.1 Billion
$1.1 Billion
CL&P
115-kV Reliability Program 30.0
Fiber Optic Communications 20.0
310/368 Line Split 29.0
Eastern Connecticut Reliability 190.5
Barbour Hill Autotransformer 10.7
Aging Equipment & NERC Compliance Upgrades (24% in RSP) 91.4
Numerous Projects Addressing Maintenance, Reliability & Load Growth (55% in RSP) 202.9
Total CL&P Other Projects 574.5
$'s Millions WMECO
115-kV Reliability Program 15.0
Fiber Optic Communications 10.0
Ludlow Transformer Repl. 12.0
Berkshire 2nd Autotransformer 9.9
Aging Equipment & NERC Compliance Upgrades (100% in RSP) 64.5
Numerous Projects Addressing Maintenance, Reliability & Load Growth (46% in RSP) 23.5
Total WMECO Other Projects 134.9
$'s Millions PSNH
115-kV Reliability Program 25.0
Fiber Optic Communications 15.0
Scobie 3rd Autotransformer 12.4
White Mountain Region Upgrades 14.9
Monadnock Region Upgrades 26.6
Nashua Area Solution 14.0
Deerfield & Gosling Autos 52.7
Aging Equipment & NERC Compliance Upgrades (64% in RSP) 163.8
Numerous Projects Addressing Maintenance, Reliability & Load Growth (42% in RSP) 76.9
Total PSNH Other Projects 401.3
$'s Millions
17
Mitigating Resource Constraints
Construction Expertise – experienced, proven firm, track record with NU Burns & McDonnell (Transmission, including MN, Glenbrook, NEEWS) Master Service Agreement Signed 8/2005, re-negotiated 2008 for another 5 years to
2013. Labor – partnered with the largest U.S. transmission constructor
Contract signed with Quanta for $750 million in transmission construction services Provides for 70% of labor over the next six years
Material – established worldwide network to procure key components Transformers, poles, underground cables and control systems
Cross-Functional Team Approach (Transmission Group, Purchasing, Legal)
18
The Quanta Contract
Terms 1/1/08 to 12/31/13 (six years) plus work awarded but not completed past
12/31/13 Commitments
Northeast Utilities Company (NUSCO) to award $ 750 million of work to any Quanta company (PAR, MJ Electric, Dashiell, etc) during contract term. Work awarded may be associated with any NUSCO Company or function (CL&P, WMECO, PSNH, Transmission, Distribution, etc.).
Quanta guarantees workforce to execute $ 750 million of work during contract term. All work offered by NU but refused by Quanta shall be treated as if it was work awarded.
Work can be awarded as T&M, fixed price (lump sum) or T&M with negotiated target.
Opt-out Clause If NUSCO fails to award $ 750 million of work during contract period (or elects
to cancel contract), there is a fee schedule that begins at $ 5 million and is reduced proportionate to work awarded and goes to zero when $ 500 million is awarded.
The opt-out clause is reciprocal for Quanta’s commitment.
Transmission Equipment
Procurement Strategy Team
Initiated: August 2007
Members: Purchasing, Transmission Group, Legal
20
Goals
Identify and prioritize equipment requiring procurement strategies
Identify tasks and sub-teams
Begin negotiations for new contracts, revisions to contracts and Master Services Agreements
24
Identify Equipment
Equipment Priority:
The following equipment priorities were established:
Equipment RFP Date Status
1. Transformers in process NU - final negotiations
2. Underground Cable in process NU – final negotiations
3. Poles/Towers 4/25/2008 B&M
4. Overhead Cable 7/2/2008 B&M
5. Hardware 10/2/2008 B&M
6. Fiber Optic Cable TBD B&M
7. GIS Equipment TBD NU
8. Breakers 6/22/2008 NU
9. CCVT’s TBD NU
10. Relays TBD NU
11. Control Cables TBD B&M
25
Status Update
Transformers Issued 3rd amendment for 3 single phase transformers for Ludlow S/S –
completed 2/26/08 Continue to gather information and negotiate with Areva to finalize amendment
for additional transformers for 2009 – 2013 Lessons Learned
Difficult to gather information regarding total transformer requirements and schedules Original contract for transformers not flexible to use as blanket order – in process of
modifying contract structure
Underground Cable Final negotiations in process with vendor Lessons Learned
Coordination of non-NEEWS requirements (e.g. UG requirements for Norwalk Harbor)
Poles Reviewing scope of work document and vendor list Burns & McDonnell is preparing to issue RFP by 4/25/08
Master Service Agreements Final negotiations completed with Siemens
26
Transformer Contracting Strategy
Purchasing/Transmission finalizing a 5-year agreement with Areva; Value per transformer is $2M
Working to obtain quantity data (# of transformers required) from Transmission Projects Group
Typical lead time for transformers is out 24 months. Deal to include 6 production slots yearly; guarantee by vendor to
produce within 18 months vs 24 months. Pricing Structure
Firm price for given period of time; Formula based pricing
Base firm with index floating for copper, core steel, oil (transformer), adjustments for currency.
27
Underground Cable Strategy
Contracting strategy to select one player in the market place to provide 115kV and 345 kV cable.
Long term agreement ranging 3-5 years with preferred treatment for manufacturing slots
Price of cable would be fixed, with fluctuation allowances for metals and currency.
If a domestic supplier c/b identified, Currency issue disappears Transportation risk goes away
28
Master Services Agreements
Create a standard set of terms and conditions for equipment & services
Identify vendors to start immediate negotiations
Supplier Status Completion Date1. Siemens complete 3/31/20082. Areva start 4/15/2008 t/b/d3. ABB start 6/1/2008 t/b/d
30
Transmission Lead Time Report
Leadtime (weeks) AROEquipment Type Detail 2008 1Q 2007 2006 2005Breakers, 115kV 26 20 20 20Breakers, 345kV 32 28 28 28Breakers, 500kV 30 36 28 24Breakers, live tank 34 36 20 20Cable, control Conductor, 345 & 115-kV underground 40 18 20 20Conductor, 345 & 115-kV overhead 18 18 20 20Connectors, tubular bus 18 10Control Panels 22Hardware 18 10 10 10Insulators 18 14 14 14Pole, steel monopole 34 30 22 20Poles, laminated wood 10 10 10 10Reactors 110 100 58 46Reactors, air core 30 22RelaysStructures, lattice 24 20 20 20Switches, 115kV Disconnect 18 18 20 18Switches, 345kV disconnect 18 20 22 18Switchgear, gas insulated (GIS) 60 61 52 43Transformer, single phase auto 100 90 58 46Transformer, three phase auto 110 100 85 50Transformers, capacitor voltage 26 26Traps, wave 20 20Tuners, line 18 6Wire, overhead ground 14 16
31
Transmission Lead Time Report, Details
Manufacturer Equipment Type Detail Lead Time WeeksABB Breakers, 115kV 26
Breakers, 345kV 30Breakers, 500kV 30Breakers, live tank 28-30Switchgear, gas insulated (GIS) 56Transformer, single phase auto 90Transformer, three phase auto 90
AREVA Breakers, 115kV 14-16Breakers, 500kV 24-26Breakers, live tank 16-20Reactors *Shunt 76-80Reactors, air core 12-24Switches, 115kV Disconnect 14-16Switches, 345kV disconnect 16-18Switchgear, gas insulated (GIS) 54-56Switchgear, gas insulated (GIS) *230-kV GIS (115-kV/63-kV applications) 63-65Switchgear, gas insulated (GIS) *345-kV GIS 78-80Transformer, single phase auto 76-80Transformer, three phase auto 76-80Transformers, capacitor voltage 19-21Traps, wave 13-24Tuners, line 6-8
Brugg Wire, overhead ground 10-14Carter & Craw Control Panels 18-22
32
Transmission Lead Time Report, Details
Manufacturer Equipment Type Detail Lead Time WeeksDis-Tran Breakers, 115kV 24
Breakers, 345kV 30Breakers, 500kV 30Breakers, live tank 34Conductor, 345 & 115-kV underground 20Conductor, 345 & 115-kV overhead 18Connectors, tubular bus 18Hardware 18Insulators 18Pole, steel monopole 34Reactors 30Reactors, air core 30Structures, lattice 24Switches, 115kV Disconnect 18Switches, 345kV disconnect 18Transformers, capacitor voltage 26Traps, wave 20Tuners, line 24Wire, overhead ground 10
HD Supply Hardware 8-18Tuners, line 8-18
33
Transmission Lead Time Report, Details
Manufacturer Equipment Type Detail Lead Time WeeksHICO America Breakers, 115kV * 40 kA 16-18
Breakers, 115kV *50/63 kA 20-24Breakers, 345kV 32Breakers, 345kV*362-kV Breakers 20-26Reactors 52-60Switchgear, gas insulated (GIS) 60Transformer, single phase auto *Core Design 52-60Transformer, single phase auto *Shell Design 58-60Transformer, three phase auto *Core Design 52-60Transformer, three phase auto *Shell Design 58-60
Intral Wire, overhead ground 4-6Laminated Wood SystemsPoles, laminated wood 8-10LS Cable Conductor, 345 & 115-kV underground 24MEEPI Breakers, 115kV 52
Breakers, 345kV 52Breakers, 500kV 52Reactors 110Switchgear, gas insulated (GIS) 60Transformer, single phase auto 100Transformer, three phase auto 110
Phoenix Wire (HICO)Conductor, 345 & 115-kV underground 14-16Conductor, 345 & 115-kV overhead 14-16Wire, overhead ground *(OPGW) 12-14
34
Transmission Lead Time Report, Details
Manufacturer Equipment Type Detail Lead Time WeeksPrysmian Conductor, 345 & 115-kV underground 40Service Wire (HICO) Wire, overhead ground *(Copper GW) Stock-14Siemens Reactors 156Siemens -US Breakers, 115kV 16-18
Breakers, 345kV *(live tank) 32Breakers, 500kV *(dead tank) 24
Silec Conductor, 345 & 115-kV underground 72South. States Breakers, 115kV *(Circuit Switchers) 12-14
Breakers, live tank *(Circuit Switchers) 12-14Switches, 115kV Disconnect 12-14Switches, 345kV disconnect 14-16
Southwire Conductor, 345 & 115-kV underground 18Conductor, 345 & 115-kV overhead 12
T&B Pole, steel monopole 17-20Structures, lattice 12-24
Trench Reactors, air core 18Transformers, capacitor voltage 14-16Traps, wave 18Tuners, line 6
? Cable, control Relays
35
Established Worldwide Access to Key Suppliers
GC Cable from Prysmian in Finland
GC DFR from Qualitrol in Ireland
GC Breakers & Switches from ABB Power in U.S.
GC Scada Cabinet from GE Harris in Canada
M-N Steel Poles from Thomas & Betts in U.S.
M-N Overhead Ground Wire from Intral in Canada
M-N 345-kV Breakers from HICO in South Korea
M-N Autotransformers & Transformers from Areva in Brazil
M-N Shunt Reactors from Siemens in Germany
M-N GIS from Mitsubishi in Japan
M-N 115-kV Cable from Prysmian in Italy
M-N 345-kV Cable from Silec in France
B-N Underground Cables from VISCAS in Japan
36
Numerous Firms Support NU Transmission’s Capital Program
Poles $75M PennSummitt Tubular LLC Sabre Tubular Structures TransAmerican Power Products Thomas & Betts Valmont
Substations $300M ABB Areva BTW Crompton Greaves / Pauwels Group General Electric HICO Mitsubishi Siemens
Cables & Wire $375M ABB Alcan LS Cable Nehring Nexans Okonite Pirelli/Prysmian Silec/General Cable/Sagem Southwire Sural USA Viscas/Fujikura
Engineering Firms $90M American Electrical Test Black & Veatch Corporation Burns & McDonnell Engineering Commonwealth Associates, Inc. Engineering & Environmental
Consulting, LLC L. E. Myers Co. (an MYR Group
company) Power Engineers, Inc. Sargent & Lundy, LLC TRC Companies, Inc.
Construction $1.3B Bond Brothers E. S. Boulos (an NU company) Hawkeye Henkels & McCoy KemsCo Equipment Co. Mass. Electric Construction Co. (A
Kiewit company) McPhee MJ Electric (Quanta) New River Electrical Corp. PAR Electrical Contractors, Inc.
(Quanta) S. M. Electric Co. Thiro USA W. A. Chester