95TH GENERAL ASSEMBLY
State of Illinois
2007 and 2008
SB0582

 

Introduced 2/8/2007, by Sen. William R. Haine

 

SYNOPSIS AS INTRODUCED:
 
220 ILCS 5/16-125

    Amends the Public Utilities Act. Makes a technical change in a Section concerning reliability of transmission and distribution systems.


LRB095 10950 MJR 31248 b

 

 

A BILL FOR

 

SB0582 LRB095 10950 MJR 31248 b

1     AN ACT concerning regulation.
 
2     Be it enacted by the People of the State of Illinois,
3 represented in the General Assembly:
 
4     Section 5. The Public Utilities Act is amended by changing
5 Section 16-125 as follows:
 
6     (220 ILCS 5/16-125)
7     Sec. 16-125. Transmission and and distribution reliability
8 requirements.
9     (a) To assure the reliable delivery of electricity to all
10 customers in this State and the effective implementation of the
11 provisions of this Article, the Commission shall, within 180
12 days of the effective date of this Article, adopt rules and
13 regulations for assessing and assuring the reliability of the
14 transmission and distribution systems and facilities that are
15 under the Commission's jurisdiction.
16     (b) These rules and regulations shall require each electric
17 utility or alternative retail electric supplier owning,
18 controlling, or operating transmission and distribution
19 facilities and equipment subject to the Commission's
20 jurisdiction, referred to in this Section as "jurisdictional
21 entities", to adopt and implement procedures for restoring
22 transmission and distribution services to customers after
23 transmission or distribution outages on a nondiscriminatory

 

 

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1 basis without regard to whether a customer has chosen the
2 electric utility, an affiliate of the electric utility, or
3 another entity as its provider of electric power and energy.
4 These rules and regulations shall also, at a minimum,
5 specifically require each jurisdictional entity to submit
6 annually to the Commission.
7         (1) the number and duration of planned and unplanned
8     outages during the prior year and their impacts on
9     customers;
10         (2) outages that were controllable and outages that
11     were exacerbated in scope or duration by the condition of
12     facilities, equipment or premises or by the actions or
13     inactions of operating personnel or agents;
14         (3) customer service interruptions that were due
15     solely to the actions or inactions of an alternative retail
16     electric supplier or a public utility in supplying power or
17     energy;
18         (4) a detailed report of the age, current condition,
19     reliability and performance of the jurisdictional entity's
20     existing transmission and distribution facilities, which
21     shall include, without limitation, the following data:
22             (i) a summary of the jurisdictional entity's
23         outages and voltage variances reportable under the
24         Commission's rules;
25             (ii) the jurisdictional entity's expenditures for
26         transmission construction and maintenance, the ratio

 

 

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1         of those expenditures to the jurisdictional entity's
2         transmission investment, and the average remaining
3         depreciation lives of the entity's transmission
4         facilities, expressed as a percentage of total
5         depreciation lives;
6             (iii) the jurisdictional entity's expenditures for
7         distribution construction and maintenance, the ratio
8         of those expenditures to the jurisdictional entity's
9         distribution investment, and the average remaining
10         depreciation lives of the entity's distribution
11         facilities, expressed as a percentage of total
12         depreciation lives;
13             (iv) a customer satisfaction survey covering,
14         among other areas identified in Commission rules,
15         reliability, customer service, and understandability
16         of the jurisdictional entity's services and prices;
17         and
18             (v) the corresponding information, in the same
19         format, for the previous 3 years, if available;
20         (5) a plan for future investment and reliability
21     improvements for the jurisdictional entity's transmission
22     and distribution facilities that will ensure continued
23     reliable delivery of energy to customers and provide the
24     delivery reliability needed for fair and open competition;
25     and
26         (6) a report of the jurisdictional entity's

 

 

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1     implementation of its plan filed pursuant to subparagraph
2     (5) for the previous reporting period.
3     (c) The Commission rules shall set forth the criteria that
4 will be used to assess each jurisdictional entity's annual
5 report and evaluate its reliability performance. Such criteria
6 must take into account, at a minimum: the items required to be
7 reported in subsection (b); the relevant characteristics of the
8 area served; the age and condition of the system's equipment
9 and facilities; good engineering practices; the costs of
10 potential actions; and the benefits of avoiding the risks of
11 service disruption.
12     (d) At least every 3 years, beginning in the year the
13 Commission issues the rules required by subsection (a) or the
14 following year if the rules are issued after June 1, the
15 Commission shall assess the annual report of each
16 jurisdictional entity and evaluate its reliability
17 performance. The Commission's evaluation shall include
18 specific identification of, and recommendations concerning,
19 any potential reliability problems that it has identified as a
20 result of its evaluation.
21     (e) In the event that more than 30,000 customers of an
22 electric utility are subjected to a continuous power
23 interruption of 4 hours or more that results in the
24 transmission of power at less than 50% of the standard voltage,
25 or that results in the total loss of power transmission, the
26 utility shall be responsible for compensating customers

 

 

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1 affected by that interruption for 4 hours or more for all
2 actual damages, which shall not include consequential damages,
3 suffered as a result of the power interruption. The utility
4 shall also reimburse the affected municipality, county, or
5 other unit of local government in which the power interruption
6 has taken place for all emergency and contingency expenses
7 incurred by the unit of local government as a result of the
8 interruption. A waiver of the requirements of this subsection
9 may be granted by the Commission in instances in which the
10 utility can show that the power interruption was a result of
11 any one or more of the following causes:
12         (1) Unpreventable damage due to weather events or
13     conditions.
14         (2) Customer tampering.
15         (3) Unpreventable damage due to civil or international
16     unrest or animals.
17         (4) Damage to utility equipment or other actions by a
18     party other than the utility, its employees, agents, or
19     contractors.
20 Loss of revenue and expenses incurred in complying with this
21 subsection may not be recovered from ratepayers.
22     (f) In the event of a power surge or other fluctuation that
23 causes damage and affects more than 30,000 customers, the
24 electric utility shall pay to affected customers the
25 replacement value of all goods damaged as a result of the power
26 surge or other fluctuation unless the utility can show that the

 

 

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1 power surge or other fluctuation was due to one or more of the
2 following causes:
3         (1) Unpreventable damage due to weather events or
4     conditions.
5         (2) Customer tampering.
6         (3) Unpreventable damage due to civil or international
7     unrest or animals.
8         (4) Damage to utility equipment or other actions by a
9     party other than the utility, its employees, agents, or
10     contractors.
11 Loss of revenue and expenses incurred in complying with this
12 subsection may not be recovered from ratepayers. Customers with
13 respect to whom a waiver has been granted by the Commission
14 pursuant to subparagraphs (1)-(4) of subsections (e) and (f)
15 shall not count toward the 30,000 customers required therein.
16     (g) Whenever an electric utility must perform planned or
17 routine maintenance or repairs on its equipment that will
18 result in transmission of power at less than 50% of the
19 standard voltage, loss of power, or power fluctuation (as
20 defined in subsection (f)), the utility shall make reasonable
21 efforts to notify potentially affected customers no less than
22 24 hours in advance of performance of the repairs or
23 maintenance.
24     (h) Remedies provided for under this Section may be sought
25 exclusively through the Illinois Commerce Commission as
26 provided under Section 10-109 of this Act. Damages awarded

 

 

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1 under this Section for a power interruption shall be limited to
2 actual damages, which shall not include consequential damages,
3 and litigation costs. Damage awards may not be paid out of
4 utility rate funds.
5     (i) The provisions of this Section shall not in any way
6 diminish or replace other civil or administrative remedies
7 available to a customer or a class of customers.
8     (j) The Commission shall by rule require an electric
9 utility to maintain service records detailing information on
10 each instance of transmission of power at less than 50% of the
11 standard voltage, loss of power, or power fluctuation (as
12 defined in subsection (f)), that affects 10 or more customers.
13 Occurrences that are momentary shall not be required to be
14 recorded or reported. The service record shall include, for
15 each occurrence, the following information:
16         (1) The date.
17         (2) The time of occurrence.
18         (3) The duration of the incident.
19         (4) The number of customers affected.
20         (5) A description of the cause.
21         (6) The geographic area affected.
22         (7) The specific equipment involved in the fluctuation
23     or interruption.
24         (8) A description of measures taken to restore service.
25         (9) A description of measures taken to remedy the cause
26     of the power interruption or fluctuation.

 

 

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1         (10) A description of measures taken to prevent future
2     occurrence.
3         (11) The amount of remuneration, if any, paid to
4     affected customers.
5         (12) A statement of whether the fixed charge was waived
6     for affected customers.
7     Copies of the records containing this information shall be
8 available for public inspection at the utility's offices, and
9 copies thereof may be obtained upon payment of a fee not
10 exceeding the reasonable cost of reproduction. A copy of each
11 record shall be filed with the Commission and shall be
12 available for public inspection. Copies of the records may be
13 obtained upon payment of a fee not exceeding the reasonable
14 cost of reproduction.
15     (k) The requirements of subsections (e) through (j) of this
16 Section shall apply only to an electric public utility having
17 1,000,000 or more customers.
18 (Source: P.A. 90-561, eff. 12-16-97.)