News Digest
October 15, 2000
Restructuring
Plans. The Ohio PUC denied rehearing of its restructuring
order for FirstEnergy issued two months earlier, rejecting arguments
by all petitioners-utility, marketers, and consumer watchdog groups.
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Net
Metering. FirstEnergy had opposed requirements for net metering,
saying that billing credits for customers who self-generate would
allow them to bypass utility costs incurred to maintain wires capacity
and acquire ancillary services, but the PUC was unmoved, noting that
wires charges also include hidden subsidies because some wires capacity
functions essentially as a generation backup.
- Account Switching.
Consumer watchdog Citizens Power (CP) complained that FirstEnergy would
get credit against the state-mandated 20 percent switching target for
customer accounts switched to its own marketing affiliate, but the PUC
said that would not violate state law, and CP said it would appeal.
- Shopping Credits.
Enron, Exelon NewEnergy, and other retailers argued that the plan did
not spell out how long consumers could keep shopping credits designed
to encourage them to switch suppliers, but the PUC said the retailers
were to blame for any ambiguity since they had signed off on it: "It
is unusual for parties that have signed a stipulation to attack the
PUC's adoption of that settlement as an unreasonable act." Case No.
99-1212- EL-ETP, Sept. 13, 2000 (Ohio P.U.C.).
Electric Supply Choice. The Oregon PUC OK'd rules for
electric retail choice, set to begin for industrial and large nonresidential
customers on Oct. 1, 2001. The rules are broad, covering transition costs,
unbundling, billing and metering, supplier certification, and consumer rights.
The PUC postponed
action to set the value of generation resources, to inquire first if
it has authority to use an arbiter. It also postponed action on public
purpose programs, to allow its staff to study state law. AR 380,
Aug. 29, 2000 (Ore.P.U.C.).
Gas Price Fallout. Citing rising costs for natural
gas and transportation, Avista Corp. on Aug. 15 asked the Idaho PUC for
an overall natural gas rate increase of 29 percent, with residential customers
getting a 27.75 percent hike. Gas Pipeline Capacity. The New York PSC kept
in place last year's requirement that marketers serving natural gas customers
in the state must have firm primary pipeline capacity from November through
March to ensure gas delivery during the winter heating season, but it allowed
KeySpan to "test" the idea of giving marketers a lesser option of using
firm secondary capacity.
The PSC noted
that KeySpan's exception would involve only a small volume of capacity-
equivalent to about 1.7 percent of KeySpan's entire peak-day demand.
The PSC added that KeySpan would retain enough reserve capacity to meet
15 percent of marketer needs, allowing it to supply its own capacity
to "backstop" more than two-thirds of non-firm primary capacity used
by marketers. Case 97-G-1380, Aug. 28, 2000 (N.Y.P.S.C.).
Access to Books and Records. Citing "increasing difficulty"
in obtaining books and records from New York State Electric & Gas Corp.,
the New York PSC gave the utility just one day to respond to requests for
basic accounting and financial data, such as journal entries, and told NYSEG
to provide electronic access to data regarding the uniform system of accounts,
but on a read-only basis, to protect confidentiality.
The PSC noted
that other electric utilities provided such materials monthly-not quarterly,
as had NYSEG. Case 96-E-0891 et al., Aug. 25, 2000 (N.Y.P.S.C.).
Interruptible Gas Customers. To avoid a repeat of last
winter, when some interruptible gas customers were ill-prepared for service
cutoffs, the New York PSC told gas utilities to ensure that interruptible
gas customers will stockpile at a minimum a seven-to-10-day supply of alternate
fuel, through storage or otherwise, by Oct. 1.
Utilities must
conduct random on-site checks of customers taking interruptible service
and must charge a higher rate to customers who fail those spot checks.
"A repetition
of last winter's situation is unacceptable," said PSC chairman Maureen
O. Helmer. Case 00-G-0996, Aug. 24, 2000 (N.Y.P.S.C.).
CO2 Removal. Utah OK'd a $13.5 million (1.4
percent) increase in natural gas rates for Questar Gas (return on equity
set at 11 percent), and allowed the utility to recover two-thirds of costs
claimed for removing carbon dioxide from coal seam gas transported by its
affiliate, Questar Pipeline Co. Docket No. 99-057-20, Aug. 11, 2000 (Utah
P.S.C.).
Consumer Notifications. The Texas PUC proposed customer
protection rules that include a billing label ("Electricity Facts") that
the PUC likened to the "Nutrition Facts" label on food products, as well
as a "Do Not Call" list, allowing customers to decline calls from telemarketers.
The label would
include (1) cost of electricity, for 500, 1,000, and 1,500 kWh per month;
(2) time-differentiated, seasonal, or contract pricing information affecting
rates; (3) contract changes and early-termination penalties; (4) fuel
mix; and (5) percentages of air emission compounds created from electric
generation.
A hearing on
the rules was set for Oct. 16. Project 22255, Aug. 18, 2000 (Tex.P.U.C.).
Electric Retail Choice. West Virginia proposed rules
on (1) licensing of competitive electric service providers (ESPs); (2) codes
of conduct for transactions among utilities, affiliates, and ESPs; (3) consumer
protection; (4) a system benefits charge; and (5) rights for utility employees,
including creation of a labor-management council.
Hearings were
set for Oct. 26. A future rulemaking will address interconnection, distributed
generation, reliability, and net metering. General Order 255, Aug.
16, 2000 (W.Va.P.S.C.).
Offsystem Sales. Florida regulators replaced an older
program-that had encouraged the state's four largest investor-owned electric
utilities to sell power at wholesale offsystem-with a new plan for the utilities
to share profits of offsystem sales with ratepayers through a credit against
fuel costs. Ratepayers would get 100 percent of profits up to a certain
company-specific benchmark (set to reflect historic levels of short-term
offsystem sales), plus 80 percent of profits above the benchmark. Docket
No. 991779-EI, Aug. 15, 2000 (Fla.P.S.C.).
Electric Restructuring Plans. The Ohio PUC OK'd a restructuring
transition plan for Cincinnati Gas & Electric, setting a rate freeze, shopping
credits, and other incentives aimed at helping CG&E meet the requirement
imposed by state law for 20 percent of each customer class to switch to
a competitive energy supplier.
The residential
class sees a 5 percent cut in rates for generation service. Customers
who switch to an ESP keep their shopping credit through Dec. 31, 2005.
The switching fee is waived for first 20 percent of residential customers
that choose an ESP during a five-year "market development period" (MDP).
CG&E may terminate the MDP for any class, except residential, when 20
percent of class load switches to an ESP. When MDP ends for any class,
then rate freeze ends for nonswitching customers in that class, and
the freeze also ends on charges for wires ancillary services for switching
customers in the class. Case Nos. 99-1658-EL-ETP et al., Aug.31,
2000 (Ohio P.U.C.).
Electric Customer Enrollments. Massachusetts OK'd an
aggressive electric customer aggregation plan proposed by a group of municipalities
on Cape Cod and Martha's Vineyard that will allow the retailer, Select Energy,
to deviate from established customer enrollment protocols to ensure an adequate
customer base by requiring automatic initial enrollment of all new residents,
subject to opt-out rights after the fact. D.T.E.00-47, Aug. 10, 2000
(Mass.D.T.E.).
Automated Dispatch.
The North American Electric Reliability Council (NERC) asked the Federal
Energy Regulatory Commission for a 12-month extension of time to present
the design of its much-touted Market Redispatch Pilot Program, which the
FERC approved in principle in June. NERC said it would still file an interim
progress report on MRD by Dec. 1.
Also, NERC said it expected
on Oct. 17 to implement new definitions and other changes to its Transmission
Loading Relief (TLR) rules, also approved in principal by the FERC on
May 8.
NERC suggested the two moves
were connected.
"Key to both," said NERC, "is
the addition of a complex software change to allow for automated adjustment
and reallocation of transactions in the Interchange Distribution Calculator.
That change É [the automated MRD program] will make it possible to reduce
the three-hour scheduling limit for MRD transactions to 45 minutes." FERC
Docket Nos. ER00-2077-000, ER00-1666-000, filed Sept. 12, 2000.
Alliance RTO. The Alliance
group tendered its compliance filing to the Federal Energy Regulatory
Commission, with thousands of pages of testimony and analysis, answering
issues raised in prior FERC orders and announcing a proposed startup date
of Dec. 15, 2001.
Alliance proposes a single
access charge with license plate pricing for all transactions that deliver
power inside the RTO, plus a single region-wide "postage-stamp" rate for
all transactions that deliver power outside or through the RTO. Dr. David
Patton (Capital Economics) acknowledged that while the Alliance RTO would
be larger than any operating RTO in the nation, the presence of two RTOs
in the Midwest would "not inhibit" power markets there. FERC Docket
No. ER99-3144, filed Sept. 2000.
California Power Wars
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Rate Stabilization. Gov. Gray Davis on Sept. 6 signed Assembly
Bill 265, which stabilizes the commodity price of electricity year-round
at 6.5 cents per kilowatt-hour for residential and small commercial
customers of San Diego Gas & Electric Co., starting retroactively on
June 1, 2000, and extending to Dec. 31, 2003.
The California PUC implemented
the new law on the very next day. I. 00-08-002, Sept.
7, 2000 (Cal.P.U.C.).
FERC Investigation. With William Massey dissenting, the Federal
Energy Regulatory Commission opened hearings to consider the complaint
filed Aug. 2 by San Diego Gas & Electric Co. to review markets at the
California ISO and Power Exchange, but rejected SDG&E's request for
the FERC immediately to impose a cap of $250 per megawatt-hour on all
sellers in California. Massey would have granted relief.
The FERC also agreed
with various intervenors and stakeholders that any move to overhaul
the ISO's market structures or congestion-management procedures
was premature.
- Real-Time Pressures.
Yet the FERC did identify one problem area-the increasing reliance
on real-time markets at the ISO in place of longer-term markets
at the PX. "In some hours," said the FERC, "as much as 25 percent
of system needs were met in the ISO real-time market ... this
increasing level raises significant reliability and economic concerns.
... [T]he ISO must procure additional supplies out-of-market at
the last minute ... such spot-market purchases are not subject
to the ISO's buyer cap."
- Placing Blame.
The FERC noted a failure of risk management but declined to place
blame. On the one hand, as it observed, "SDG&E appears to be the
only major investor-owned utility in California that had not sought
state commission authority to hedge its price risks through forward
contracts designed to 'lock-in' a specific price." But the FERC
hedged its own comments: "It is unclear whether SDG&E's failure
to purchase hedging instruments for its retail operations is due
to state regulatory policies or its business decisions." Docket
No. EL00-95-000, 92 FERC ¶61,172, Aug. 23, 2000.
ISO Price Caps. The California Oversight Board asked the Federal
Energy Regulatory Commission to direct the California Independent System
Operator to maintain bid caps at no greater than $250 per megawatt-hour
for energy, $250 per megawatt-hour for ancillary services, and $100
for replacement reserves, until the FERC determines that markets are
workably competitive. FERC Docket No. EL00-104-000, filed Aug. 28,
2000. |
Liquidity in National Markets. Speaking on behalf of the American
Gas Association at the Sept. 19 conference held by the FERC to discuss liquidity
on U.S. natural gas markets, Leo Cody (manager of federal regulatory affairs
for Boston Gas) urged the FERC to change policy in two ways.
First, Cody asked the FERC
to repeal its "shipper must have title" policy, and instead allow local
distribution companies (LDCs) to control and use pipeline capacity for
the benefit of their customers and to better deal with state-imposed requirements
under retail unbundling programs.
Second, he urged the FERC to
require pipelines to further segment capacity and allow customers to buy
capacity from the wellhead to upstream hubs, separate and apart from capacity
from hubs to consuming areas.
"LDCs are not free riders,"
said Cody. "Unbundling reduces the amount of gas purchased by the LDC
for resale, and it becomes increasingly difficult to ensure that the necessary
volumes will be received at the required points.
"Repealing the title policy,"
he added, "would allow the LDC to use market area transportation to move
third-party gas from a citygate with an excess of supply to citygates
with a lack of supply." FERC Docket PL00-1-000, written comments filed
Sept. 8, 2000.
Reverse Flow Storage. Despite many objections from gas shippers,
markets, and winter-peaking local distribution companies (LDCs) in the Midwest,
plus the commission's own concerns over physical damage to aquifer fields that
require cycling of injections and withdrawals, the FERC authorized Natural Gas
Pipeline Co. of America (NGA) to boost the seasonal volume limit for its proposed
and discounted "firm reverse storage service"-a new idea designed to accommodate
the summer-peaking electric generation market by allowing gas shippers to withdraw
gas from storage from May 15 to Sept. 30, and then make up the difference by
injecting gas back into storage in the winter, the normal season for withdrawals.
- Seasonal Flexibility.
Many shippers complained unsuccessfully that if the FERC should allow
the unconventional reverse service, then it should at least reconsider
terms and rates for conventional storage, including restrictions that
limit flexibility for timing of conventional injections and withdrawals,
but the FERC refused to entertain changes in terms and conditions of
collateral tariffs.
- Subsidies. The FERC
also denied arguments that shippers taking conventional storage would
subsidize the reverse flow service, since the tariff proposed to recover
only 80 percent of costs.
- Free Riders. The
FERC also denied Dynegy's counterintuitive argument that if the FERC
did restructure conventional storage to make it more flexible, then
LDCs serving electric generators located off of NGA's system would get
a free ride, as they could then use the more flexible services to supply
their gen plant customers, while shippers serving gen plants on the
NGA system would be forced to subscribe to the reverse-flow storage
tariff, and would pay higher net charges. Docket No. RP00-169-000,
92 FERC ¶61,221, Sept. 15, 2000.
Market Power.
The FERC authorized Petal Gas Storage LLC to construct and operate certain
storage facilities near Hattiesburg, Miss., finding no untoward market
concentration and no reason to withdraw authority for market-based pricing
despite the firm's acquisition by El Paso Energy. Docket Nos. CP00-59-000
et al., 92 FERC ¶61,220, Sept. 15, 2000.
Electric Reliability
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PBR Plans. Massachusetts proposed service quality standards
for performance-based rate (PBR) plans for the state's electric distribution
utilities, with separate company-specific benchmarks, based on 10-year
average SAIDI (System Average Interruption Duration Index) data for
each company.
Regulators said performance
varied too much among utilities to warrant use of nationally recognized
standards for SAIDI or SAIFI (System Average Interruption Frequency
Index).
It decided not to assess
penalties for power quality performance (short-term or momentary
outages and voltage surges), citing a lack of reliable data, but
did tell utilities to collect data to measure MAIDI (Momentary Average
Interruption Frequency Index). D.T.E. 99-84, Aug. 17, 2000 (Mass.D.T.E.).
System Improvement Strategies. Wisconsin Energy Corp. has announced
a decade-long, $6 billion plan to construct new power plants, refurbish
or retire older plants, improve reliability by upgrading its distribution
system, and reduce common stock dividends to fund growth. WEC estimates
that by 2010, power demand in the state will outstrip capacity by approximately
4,000 megawatts.
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Sierra + Portland.
The Oregon PUC staff, Sierra Pacific Resources, and industrial customers
and consumer advocate groups reached a settlement paving the way for Sierra
Pacific to acquire Portland General Electric-a takeover already OK'd by
the U.S. Dept. of Justice, Federal Trade Commission, and Securities and
Exchange Commission. The deal calls for a six-year freeze on certain electricity
prices and a $95 million price credit for PGE customers over seven years.
UM 967, filed Sept. 8, 2000 (Ore.P.U.C.).
Citizens<–> Kauai.
The Hawaii PUC blocked efforts by Citizens Communications Co. (formerly
Citizens Utilities Co.) to exit the electric industry and focus solely
on its telecommunications business. It denied approval to Citizens to
sell its Kauai Electric Division (KED) to Kauai Island Utility Co-op,
as it ruled that the co-op would barely meet coverage standards for debt
service and "is not financially fit to own and operate KED." Docket
No. 00-0108, Decision & Order No. 17970, Aug. 14, 2000 (Haw.P.U.C.).
CP&L + Fla. Progress.
North Carolina OK'd the merger of CP&L Energy Inc. and Florida Progress
Corp., on condition that if a regional transmission organization (RTO)
is not formed in time to accommodate RTO filing deadlines at the FERC,
so that CP&L opts to join a different RTO other than one "with a southeastern
focus," then state regulators may require CP&L to withdraw and join a
southeastern RTO, once such a group is formed. Docket No. E-2, Sub
760, Aug. 22, 2000 (N.C.U.C.).
Out-of-State Exports.
Dismissing concerns that new merchant power plants might export power
out of state, a New York siting board denied rehearing on its prior order
that had authorized the construction and operation by Athens Generating
Co. L.P. (AGC) of a 1,080-MW power plant.
The board, rejecting intervenor
arguments that the facility will not be required to serve the state only,
reiterated its position from its original order approving the plant (Case
No. 97-F-1563, June 15, 2000) that "regionalization of the power market
benefits all states" and that even out-of-state sales would enhance in-state
reliability, given that plant owners must comply with ISO rules for dispatch
and security.
The board said that because
grid capacity to New England was limited, the new plant might find it
more profitable to sell in New York during constraints. It rejected intervenor
claims that the plant owners might act "irrationally" and sell at a loss
in New England. "It is not reasonable to conclude that the applicant will
act in a manner diametrically opposed to its financial interests." Case
97-F-1563, Aug. 10, 2000 (N.Y.Bd. on Elec.Gen. Siting).
Out-of-State Imports.
North Carolina regulators allowed Carolina Power & Light Co. to relocate
two combustion turbine generators already approved for installation, noting
that relocation would enhance reliability by making CP&L less dependent
on other utility transmission systems for importing power to meet load.
Company witness Verne Ingersoll had testified that growing offsystem power
imports were pushing the limits of transmission capacity. Docket No.
E-2, Sub 763, Aug. 17, 2000 (N.C.P.U.C.).
Courts
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Utility Marketing
Affiliates. A group of four investor-owned electric utilities
failed to get an Illinois court to strike down the state's 1997
electric customer choice law as unconstitutional or to overturn
rules adopted under the act that imposed restrictions on utilities
in their dealings with marketing affiliates.
- The court said that
a ban against joint advertising and marketing efforts by utilities
and affiliates did not violate corporate rights to commercial
free speech.
- It held that the
state commission did not violate the 1997 law when it barred electric
utilities from offering to their affiliates different terms and
conditions on regulated services than those offered to unaffiliated
alternative retail energy service (ARES) companies. Nor did it
err when it barred utilities from requiring customers to buy energy
from a utility affiliate to qualify for special billing offers
from the utility, or when it required utilities to compile and
post information on the Internet regarding availability of competitive
ARES firms.
- Third, the court
upheld commission rules forcing utilities to offer the same rebates,
discounts, or fee waivers to ARES customers that they offer to
the customers of their own marketing affiliates, regardless of
whether the service is regulated or competitive. It said the legislation
was unclear on the distinction between "essential" and "nonessential"
services. Illinois Pwr. Co. v. Illinois Commerce Comm'n, No.
5-98-0808, Sept. 6, 2000 (Ill.App., 5th Dist.).
Road Construction.
In a case of first impression, a New York court ruled that electric
utilities must pay their own costs when public road construction
projects interfere with utility facilities located within the right-of-way
under a private easement granted by a private landowner before the
road was constructed. It upheld a statute that overturned the common
law rule that the city pays costs. City of New York v. Consol'd.
Ed. Co., No. 1615, Sept. 14, 2000 (N.Y.App.Div.).
Hinshaw Gas Pipelines.
A federal appeals court struck down an order by the Federal Energy
Regulatory Commission, explaining that the FERC could not expand
its limited authority over intrastate "Hinshaw" pipelines for forcing
them to file periodic cost reports under Section 4 of the Natural
Gas Act to justify rates for incidental interstate services.
The court conceded that
the FERC could require cost reports under NGA Section 5, but suggested
the FERC was trying to "slide through" Section 4 to expand its jurisdiction.
It added, "[T]his is one of those peculiar cases in which it is
not easy to understand what the litigants are disputing." Consumers
Energy Co. v. FERC, No. 99-4097, Sept. 12, 2000 (6th Cir.).
Hydropower Entitlements.
A federal appeals court reversed a 1999 decision by the U.S.
Court of Federal claims that struck down the method adopted by the
federally owned Western Area Power Authority to refund excess revenues
collected for sales of power from Hoover Dam after unexpected high
rainfall increased runoff and plant output in the mid-1980s. So.
Calif. Ed. Co. v. U.S., Nos. 99-5074 et al., Sept. 11, 2000 (Fed.Cir.).
Purchased Power Costs.
In reversing a trial court, and thus affirming a state PUC order
that disallowed recovery of purchased power costs incurred by TXU
Electric following an accident at a power plant, a Texas appeals
court said it was bound to defer to the PUC, since the agency ruling
was a matter of policy and administrative discretion, not a matter
of tort law or determining the proximate cause of the accident.
Nucor Steel v. Tex. PUC, No. 03-99-00698-CV, Aug. 31, 2000 (Tex.App.,
Austin).
Merger Savings.
Reversing a trial court order, the Louisiana Supreme Court ruled
that Entergy could not take expenses disallowed by state regulators
in a current rate case and then treat them as ratepayer "savings"
under a savings tracking ratemaking clause approved years earlier
that allowed utility shareholders to keep 60 percent of savings
generated by Entergy's takeover of Gulf States Utilities.
The court also agreed
with regulators that weather data gathered statewide was too unreliable
to justify a weather normalization clause to adjust test-year revenues
for Entergy's specific service territory. But it said regulators
erred by adopting a range of authorized returns on common equity
(between 10.31 and 11.34 percent) without specifying a single approved
point within the range. Entergy Gulf States Inc. v. La. PSC,
No. 00-CA-0336, Aug. 31, 2000 (La.).
Nuclear Waste Claims.
In two companion cases, a federal appeals court ruled that electric
utilities may proceed in a damage suit based on breach of contract
to recover costs incurred to dispose of nuclear waste temporarily
at power plant sites because of the delays by the federal government
in arranging for permanent disposal. Maine Yankee Atomic Pwr.
Co. v. U.S., Nos. 99-5138 et al., Northern Sts. Pwr. Co. v. U.S.,
No. 99-5096, Aug. 31, 2000 (Fed.Cir.).
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GE Global eXchange Services's
application integration product, GE InterLinx, now supports the latest
industry standards for RosettaNet and the Gas Industry Standards
Board, allowing companies in the high-tech, gas, and utility industries
to extend their e-commerce reach by using XML (eXtensible markup language)
and the Internet to align business processes among their supply chain
partners. "Integration solutions based on key industry standards are crucial
if buyers and sellers expect to draw upon both internal and external information
resources for maximum benefit," said Steve Scala, GXS's vice president
of integration solutions.
Enron North America
and Swiss Re New Markets have applied risk capital management techniques
to arrange a $102 million oil and gas production loan on behalf of a client
in the exploration and production sector. Developed jointly with Enron's
Global Risk Markets group, the financing employed a combination
of derivatives, insurance, and bank credit to finance future production
of 160 billion cubic feet over a five-year period from a portfolio of
working interests in fields located primarily in Texas, Louisiana, and
New Mexico.
Reliant Energy has formed
Reliant Energy Renewables Inc., an unregulated affiliate of Reliant
Energy Wholesale Group, and started two major Texas renewable energy
projects that will produce electricity for the state's consumers using
wind power and methane gas extracted from landfills. The wind power project
is the largest single installation of its kind in the world, and the methane
gas-to-electricity generation project will involve 12 existing landfill
sites in Texas. Plans call for Reliant Energy to begin purchasing electricity
from both projects by fourth-quarter 2001.
Convergent Group Corp.
has completed a Digital Utility road map and signed a new contract with
Boston-based NSTAR that forms the foundation for Convergent to
integrate energy delivery and business operations across the four utilities
that make up the NSTAR enterprise. NSTAR is the parent company of Boston
Edison, Commonwealth Gas, Commonwealth Electric, and
Cambridge Electric, with a combined customer base of 1.3 million
people.
The Geothermal Heat Pump
Consortium has been selected by the Canadian government to help increase
the market in Canada for geoexchange (also called geothermal heating and
cooling) technology. The consortium will work with Natural Resources
of Canada, a Canadian government department that specializes in the
areas of energy, minerals and metals, forest, and earth sciences.
DTE Energy Technologies,
an unregulated subsidiary of DTE Energy Co., has signed agreements
with Pratt & Whitney Canada Corp. and Turbo Genset Co. Ltd.,
of the United Kingdom, for the development of a 400-kW turbine generator.
The new high-efficiency product, the "energy/now turbine-generator," model
ENT 4000, is targeted for distributed generation applications for small-
to medium-sized commercial customers and micro-grids serving both residential
and commercial development projects.
News Digest was compiled
by Carl J. Levesque, associate editor, Lori Burkhart and Phillip Cross,
contributing legal editors, and Bruce W. Radford, editor-in-chief. For
more frequent updates, see www.pur.com.
Articles found on this page are available to Internet subscribers only. For more information about obtaining a username and password, please call our Customer Service Department at 1-800-368-5001.
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