EIA-411 Coordinated Bulk Power Supply Program Report

Electric Power Surveys

Electricity 2008 EIA-411 10-02-20071

Electric Power Surveys

OMB: 1905-0129

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U.S. Department of Energy
Energy Information Administration
Form EIA-411 (2007)
PURPOSE

REQUIRED
RESPONDENTS

Form Approved
OMB No. 1905-0129
Approval Expires:

COORDINATED BULK POWER
SUPPLY PROGRAM REPORT

Form EIA-411 collects information about regional electricity supply and demand projections for a
five-year advance period and information on the transmission system and supporting facilities. The
data collected on this form appear in the Energy Information Administration (EIA) publication,
Electric Power Annual. They are also used by the U.S. Department of Energy to monitor the
current status and trends of the electric power industry and to evaluate the future of the industry.
The Form EIA-411 is a mandatory report to be completed by each of the Regional Councils of the
North American Electric Reliability Corporation (NERC). Each Regional Council compiles the
responses from data furnished by utilities and other members within their Council and provided to
NERC. NERC then compiles and coordinates these data and provides them to the Energy
Information Administration.

RESPONSE DUE
DATE

Annual data are due to the North American Electric Reliability Corporation by April 30 following the
end of the calendar year. After review, NERC should submit the completed Form EIA-411 to the
EIA by July 15 following the end of the calendar year.

METHODS OF
FILING RESPONSE

The North American Reliability Corporation (NERC) will oversee the methods of filing response of
the data by the Regional Councils. NERC then submits the compiled report to EIA.
Submit the data via a secure file transfer
[email protected] for instructions.

process.

Contact

John

Makens

Maps and power flow cases can be transmitted electronically using a secure file transfer process.
CD-ROM disks containing the data can also be mailed to EIA at the following address:
John Makens, Survey Manager
Energy Information Administration, Mail Stop EI-53
1000 Independence Avenue, S.W.
Washington, DC. 20585-0690
Please retain a completed copy of this form for your files.
CONTACTS

Data Questions: For questions about the data requested on Form EIA-411, contact the Survey
Manager:
John Makens
Telephone Number: (202) 586-4059
FAX Number: (202) 287-1934
E-mail: [email protected]

U.S. Department of Energy
Form Approved
COORDINATED BULK POWER
Energy Information Administration
OMB No. 1905-0129
SUPPLY PROGRAM REPORT
Form EIA-411 (2007)
Approval Expires:
For
the
purposes
of
this
form,
“actual-year
data”
should
be
submitted
based on the same principles
GENERAL
as
the
planning-based
projected
data.
In
order
to
avoid
having
the
actual-year data change to
INSTRUCTIONS
operating data that is not comparable to planning data, please use the following:
Do not include:
•

forced outages

• short-term transactions (purchases and sales)
Do include:
• Changes to capacity due to return-to-service or new-to-service delays
All numbers should be entered as MW in whole, positive values – no decimals or negatives. (All
subtractions will be shown on the respective line found in the form).
The term, peak and distributive generator, are defined as follows:
•
•
•
ITEM-BY-ITEM
INSTRUCTIONS

Summer Peak Hour Demand: The maximum load in megawatts during the period June
through September. The summer peak period begins on June 1 and extends through
September 30.
Winter Peak Hour Demand: The maximum load in megawatts during the period
December through February. The winter peak period begins on December 1 and extends
through the end-of-February.
Peak Hour Demand: The maximum load in megawatts during the specified reporting
period.
SCHEDULE 1. IDENTIFICATION

1. Survey Contact: Verify contact name, title, telephone number, Fax number, and e-mail
address.
2. Supervisor of Contact Person for Survey: Verify the contact’s supervisor’s name, title,
telephone number, Fax number and e-mail address.
3. Report For: Verify the NERC council and reporting party.
If any of the above information is incorrect, revise the incorrect entry and provide the correct
information. Provide any missing information.
SCHEDULE 2. HISTORICAL AND PROJECTED PEAK DEMAND AND ENERGY
1. Enter annual and seasonal peak demands and net energy for load for designated years.
2. SCHEDULE 2 is to be reported in total by each Regional Council for all utilities, groups of
utilities, such as Council subregions, Independent System Operators, or Regional
Transmission Operators, within that Council. The reported capacity should comprise the sum
of all non-coincident peak loads for the various operating entities within a NERC Region during
the specified period. (Do not file coincident peak load.)
SCHEDULE 3. HISTORICAL AND PROJECTED DEMAND AND CAPACITY
1. SCHEDULE 3 is to be reported in total by each Regional Council for all utilities, groups of
utilities, such as Council subregions, Independent System Operators, or Regional
Transmission Operators, within that Council.
2. Enter demand and capacity for the summer (PART A) and winter (PART B) peak periods of
the designated years for the NERC region. Peak demands reported should agree with the
corresponding entries in SCHEDULE 2, Part B.
3. For hydroelectric capacity, explain in SCHEDULE 9, COMMENTS whether the projected years
data are for an adverse water year, an average water year, or other.
4. The information in SCHEDULE 3 is to be entered in megawatts (MW) for each peak period on
the same basis as reported in SCHEDULE 2, Part B.
5. For line 1, Internal Demand, the following instructions apply:
Internal Demand is the sum of the metered (net) outputs of all generators within the system
and the metered line flows into the system, less the metered line flows out of the system. The
2

U.S. Department of Energy
Form Approved
COORDINATED BULK POWER
Energy Information Administration
OMB No. 1905-0129
SUPPLY PROGRAM REPORT
Form EIA-411 (2007)
Approval Expires:
demands for station service or auxiliary needs (such as fan motors, pump motors, and other
equipment essential to the operation of the generating units) are not included. (Note: please
use integrated hourly demand values.)
Internal Demand includes adjustments for utility indirect demand-side management programs
such as conservation programs, improvements in efficiency of electric energy use, rate
incentives, and rebates. Internal Demand should not include Stand-by Demand (line 2) and
should not be reduced by Direct Control Load Management or Interruptible Demand, which are
reported on Lines 4 and 5, respectively.
6. For line 2, Standby Demand, enter the demand specified by contractual arrangement with a
customer to provide power and energy to that customer as a secondary source or backup for
an outage of the customer’s primary source. Standby Demand is intended to be used
infrequently by any one customer. If there are no arrangements for Standby Demand, report
“0” on line 2.
7. For line 3, Total Internal Demand, enter sum of lines 1 and 2. Data should be the same as
reported in SCHEDULE 2, Part B, Peak Hour Demand.
8. For line 4, Direct Control Load Management, enter the magnitude of customer demand that
can be interrupted at the time of the Regional Council seasonal peak by direct control of the
System Operator by interrupting power supply to individual appliances or equipment on
customer premises. This type of control usually reduces the demand of residential customers.
Direct Control Load Management as reported here does not include Interruptible Demand (line
5).
9. For line 5, Interruptible Demand, enter the magnitude of customer demand that, in
accordance with contractual arrangements, can be interrupted at the time of the Regional
Council’s seasonal peak by direct control of the System Operator or by action of the customer
at the direct request of the System Operator. In some instances, the demand reduction may
be effected by direct action of the System Operator (remote tripping) after notice to the
customer in accordance with contractual provisions. For example, demands that can be
interrupted to fulfill planning or operating reserve requirements normally should be reported as
Interruptible Demand. Interruptible Demand as reported here does not include Direct Control
Load Management (line 4).
10. For line 6, Net Internal Demand, enter line 3, less line 4, less line 5 (Internal Demand, less
Direct Control Load Management and Interruptible Demand).
11. For line 7, Total Internal Capacity, enter the internal capacity for the reporting area. (Defined
as seasonal rated capability at full load - where full availability of primary fuel, wind, and water
is assumed.) The reported value should include capacity of all generators physically located
and interconnected in the reporting area or planned to be physically located and
interconnected in the reporting area, including the full capacity of those generators wholly or
partially owned by (or with entitlement rights held by) entities outside of the reporting area.
The following conditions also apply:
• This number should NOT be reduced for the following conditions: transmission
constraints, inoperable capacity, wind capacity variations, hydro limitations, and other
fuel/energy source limitations (these conditions will be addressed in lines 8 and 10-13).
•

This number should NOT include “behind-the-meter” capacity if the load served by this
capacity is NOT included in the load forecast for the area.

•

The status of generators (either existing, under construction, or not under construction)
should be as of the assessment data reporting due date or a specific date no more
than 90 days prior to the assessment data reporting due date. Therefore a unit is
defined as existing (line 7a) if it is existing as of the data due date.
For the seasonal assessments, planned (under construction) units that are expected to
enter service prior to the beginning of the Reporting Period should be included in line
7c as planned (under construction) capacity. For example, for a unit expected to come
into service on July 1, the unit value should be zero MW for June and the full MW value
in line 7c planned (under construction) for July, August, and September.
For lines 7a and 7b, Uncommitted Resources, uncommitted resources are recorded if
one or more of the following conditions apply:

•

Have not been contracted nor have legal or regulatory obligation to deliver at time of
3

U.S. Department of Energy
Energy Information Administration
Form EIA-411 (2007)
peak
•

COORDINATED BULK POWER
SUPPLY PROGRAM REPORT

Form Approved
OMB No. 1905-0129
Approval Expires:

Do not have or do not plan to have firm transmission service reserved (or its
equivalent) or capacity injection rights to deliver the expected output to load within the
region

•

Have not had a transmission study conducted to determine the level of deliverability
For lines 7a2 and 7b, Energy Only Resources, generating resources that are
designated as energy-only resources or have elected to be classified as energy-only
resources may include generating capacity that can be delivered within the area but
may be recallable to another area.
12. For line 7a, Existing Capacity, included in this category are (1) all in service commercial
operating plants/generators within a defined regional boundary that are producing some
electrical output (real/reactive), (2) those that are available for service, but not normally used,
and (3) any out-of-service units that could not be used for the reporting year, but are expected
to be returned to service in the future. In addition, any generators that are scheduled to start
operation after modification or reactivation and those plants/generators that are operational
until their scheduled retirement or deactivation are also included. (Covers Form EIA-860
codes OP, SB, OS, FC, RP and RA.)
13. For line 7b, Less Retirements and Negative Rerating, a generator is included in this
category, for the appropriate seasonal periods and years, when a scheduled change from a
working operational status is known or identified in a projected effective date. This includes
generators scheduled or placed into a deactivated shutdown status or scheduled for
retirement. Those generators scheduled to start operations after modification or reactivation
with a negative rerating on capability will also be included for the appropriate seasonal periods
and years identified by the effective dates. (Covers Form EIA-860 codes RT, A, D, and M)
14. For line 8, Inoperable Capacity, this value should only include capacity that has been
mothballed or is otherwise expected to be unavailable, such as extended outages, during the
entire Reporting Period (as opposed to anticipated outages of shorter duration, which are
reported under Scheduled Maintenance in Line 11).
15. For line 9, Operable Total Internal Capacity, total Internal Capacity less Inoperable (line 8).
16. For line 10, Derates
For line 10a, Conditional Derates, enter the amount of conditional derates that decrease the
seasonal rated capacity. These include fuel unavailability, other fuel/energy source limitations,
and other non-machine-related conditions such as environmental or regulatory limitations.
For line 10b, Hydro Derates, enter the amount of hydro derates that decrease the seasonal
rated capacity.
For line 10c, Wind Capacity Variations, enter the amount of wind capacity variations that
decrease the seasonal rated capacity.
17. For line 11, Scheduled Maintenance, enter the amount of capacity expected to be out for
scheduled maintenance during the expected time of the peak during the Reporting Period.
Include only scheduled maintenance with a duration less than the entire Reporting Period (as
opposed to extended periods of inoperability which are reported as Inoperable Capacity in line
8). The following clarification also applies for this capacity reduction classification: The main
difference between inoperable capacity (line 8) and scheduled maintenance (line 11) is that
inoperable capacity cannot be brought back online or delayed at a given time period.
18. For line 12, Derated Operable Total Internal Capacity, line 9 less lines 10 through 11 (lines
10a, 10b, 10c, and 11).
19. For line 13, Energy Only Resources/ Uncommitted Capacity, includes generating capacity
resources that are built, planned, or in operation, but are not counted towards capacity margin
and reserve margin calculations. Capacity from individual units not counted towards capacity
margin and reserve margin calculations should be included unless its physical delivery
limitation was the result of a transmission study, in which case the amount of capacity from
such units(s) is not counted towards capacity margin and reserve margin calculations should
be included in line 15.
20. For line 14, Derated Operable Internal Capacity, line 12 less line 13. This value represents
the internal capacity (prior to transmission limitations) that a region considers towards the
4

U.S. Department of Energy
Form Approved
COORDINATED BULK POWER
Energy Information Administration
OMB No. 1905-0129
SUPPLY PROGRAM REPORT
Form EIA-411 (2007)
Approval Expires:
calculation of capacity and reserve margins. Margin calculations also take into account
capacity that either enters or leaves the region via purchases, sales, ownership, or
entitlements.
21. For line 15, Adjustments for Studied Transmission Limitations, enter the amount of
transmission-constrained generation resources that have known physical deliverability
limitations to load within the region. The following conditions also apply: If capacity is limited
by both studied transmission limitations and generator derates (line 10), the generator derates
take precedence. For example, a 100 MW wind farm with a wind capacity variation reduction
of 50 MW and a transmission limitation of 60 MW would take the 50 MW wind variation
reduction first and list 10 MW in the transmission limitation.
22. For line 16, Deliverable Internal Capacity, line 14 less line 15. For purposes of this form, this
value represents capacity that is counted towards capacity margin and reserve margin
calculations. Margin calculations also take into account capacity that either enters or leaves
the region via purchases, sales, ownership, or entitlements.
23. For line 17, Purchases and Incoming Adjustments (Additions)
For line 17a, Purchases - Enter the amount of purchased capacity that will move from an
outside Region or subregion to the reporting Region or subregion. Transmission must be
available.
For line 17b, Owned Capacity/Entitlement Located Externally (see examples shown below
after Item 26 in the instructions) - Enter the amount of externally owned capacity or capacity
entitlements that will move from an outside Region or subregion to the reporting Region or
subregion.
26. For line 18, Sales and Outgoing Adjustments (Subtractions)
For line 18a, Sales, enter the amount of sold capacity that will move from the reporting Region
or subregion to an outside Region or subregion. Transmission must be available.
For line 18b, Capacity Owned by/Entitlement Held by External Entity, enter the amount of
externally owned capacity or capacity entitlements that will move from the reporting Region or
subregion to an outside Region or subregion.
The following examples are provided to show how transaction are handled between two
reporting areas for Purchases and Sales Incoming/Outgoing Adjustments:
1. Unit physically located in SERC that is fully owned by a FRCC company and not
connected to the SERC network but instead has a direct and adequate transmission
connection to FRCC.
Solution: Since the unit is electrically connected to only FRCC, account for the unit
completely in FRCC with no transfers.
2. Unit physically located in and electrically connected to SERC but is partially or fully
owned by an FRCC company.
Solution:
•
•
•
•
•
•

SERC lists entire capacity on line 7
SERC derates capacity on lines 10a – 10c (if applicable)
SERC shows outgoing ownership adjustment on line 18b
FRCC does not reflect this capacity in line 7
FRCC shows corresponding incoming ownership adjustment 17b
FRCC must be able to demonstrate adequate interregional transfer capability,
otherwise remaining capacity is accounted for in SERC
o FRCC must have or plan to have firm transmission service (or its
equivalent) across the interface, or
o FRCC must have conducted a transmission study to determine the level of
deliverability
27. For line 19, Net Capacity Resources, line 16 plus lines 17a through 17b less lines 18a
through 18b.
28. For line 20, Total Potential Resources, lines 19 plus lines 21 through 23.
29. For line 21, Distributed Generation less than 1 MW, show estimated value.
5

U.S. Department of Energy
Form Approved
COORDINATED BULK POWER
Energy Information Administration
OMB No. 1905-0129
SUPPLY PROGRAM REPORT
Form EIA-411 (2007)
Approval Expires:
30. For line 22, Other Capacity less than 1 MW, show estimated value.
31. For line 23, Distributed Generator Capacity greater than or equal to 1 MW, show estimated
value of amount connected to a power grid.
32. For line 24, Capacity Total from EIA-860, final national and regional Net Summer and Winter
Capacity values are used.
33. For line 25, Existing Capacity Difference, line 24 minus Total Internal Capacity (Line 7).
Describes not counted 'behind-the-meter capacity' and unaccounted for capacity that could be
available for use or incorporated into the planning review.
SCHEDULE 4. HISTORICAL AND PROJECTED CAPACITY PURCHASES, SALES, AND
TRANSFERS
Enter all projected capacity purchases and sales (in megawatts) that involve entities outside of the
Council or Reporting Region. The totals should agree with the totals in SCHEDULE 3 Line 10,
Total Capacity Purchases and Line 11, Total Capacity Sales.
1. Some data may be non-coincident due to differences in the month of the seasonal peaks for
the purchaser and seller. An example would be a transfer that changes magnitude from July
to August. The transfer would be reported in July by the selling party whose peak occurs in
July and reported in August by the purchasing party whose peak occurs in August.
2. For column (a), Other Party, EIA Code, enter the five character numeric code for that party.
A list of the EIA company codes, by reporting party name, is available at the EIA website,
http://www.eia.doe.gov/cneaf/electricity/page/gen_companies/codesp1.html. If the name of
the reporting party is not on this list, please enter the name of the party on the form and a code
will be assigned by EIA.
3. For the Plant ID and Unit ID columns, enter the EIA code for those unit specific purchases,
sales, and transfers, if known.
SCHEDULE 5. BULK ELECTRIC TRANSMISSION SYSTEM MAPS
1. Each Council is to submit a map(s), in electronic format, showing the existing bulk electric
transmission system 230 kV and above, including ties to all other Councils, and the bulk
electric transmission system additions projected for a five-year period beginning with the year
following the reporting year.
2. Only major geographic features and State boundaries, bulk electric facilities, and the names of
major metropolitan areas need be shown. The map scale to be used is left to the discretion of
the Region or Reporting Party, but should be such as to allow convenient use of the map.
Show the voltage level of all bulk electric transmission lines. The year of installation of all
projected system additions may be shown at the option of the Council or Reporting Party.
3. The map requirement may be satisfied by either:
(a) A single map in electronic format showing the existing bulk electric transmission
system as of January 1 of the reporting year and system additions for a five-year
period beginning with the reporting year; or
(b) Separate maps for a set of subregions that comprise the whole region.
4. For Line 1, enter the number of maps provided.
5. For Line 2, enter the requested map information in columns (a) through (d).
SCHEDULE 6. PROJECTED TRANSMISSION LINE ADDITIONS
1. This SCHEDULE must be completed by each Regional Council for all transmission line
additions at 230 kV and above projected for the five-year period beginning with the year
following the reporting year.
2. For line 1, Terminal Location (From), enter the name of the beginning terminal point of the
line.
3. For line 2, Terminal Location (To), enter the name of the ending terminal point of the line.
4. For line 3, Company Name, enter the company name.

U.S. Department of Energy
Form Approved
COORDINATED BULK POWER
Energy Information Administration
OMB No. 1905-0129
SUPPLY PROGRAM REPORT
Form EIA-411 (2007)
Approval Expires:
5. For line 4, EIA Company Code, identify each organization by the six-character code assigned
by EIA.
6. For line 5, Type of Organization, identify the type of organization that best represents the line
owner including the following types of utilities – Investor-owned (I), Municipality (M),
Cooperative (C), State-owned (S), Federally-owned (F), or other (O).
7. For line 6, Percent Ownership, if the transmission line will be jointly-owned, enter the
percentages owned by each individual respondent.
8. For line 7, Line Length, enter the number of miles between the beginning and ending terminal
points of the line, regardless of the number of conductors or circuits carried.
9. For line 8, Line Type, select physical location of the line conductor – overhead (OH),
underground (UG), or submarine (SM).
10. For line 9, Voltage Type, select voltage as alternating current (AC) or direct current (DC).
11. For line 10, Voltage Operating, enter the voltage at which the line is normally operated in
kilovolts (kV).
12. For line 11, Voltage Design, enter the voltage at which the line was designed to operate in
kilovolts (kV).
13. For line 12, Conductor Size, enter the size of the line conductor in thousands of circular mils
(MCM).
14. For line 13, Conductor Material Type, enter the line conductor material type – aluminum,
ACCR, ACSR, copper, or other.
15. For line 14, Bundling Arrangement, enter the bundling arrangement/configuration of the line
conductors – single, double, triple, quadruple, or other.
16. For line 15, Circuits per Structure Present, enter the current number of three-phase circuits
on the structures of the line.
17. For line 16, Circuits per Structure Ultimate, enter the ultimate number of three-phase circuits
that the structures of the line are designed to accommodate.
18. For line 17, Pole/Tower Type, identify the predominant pole/tower material for the line – wood,
concrete, steel, combination, composite material, or other. Also include the type of structure –
single pole, H-frame structure, tower, underground, or other.
19. For line 18, Capacity Rating, enter the normal load-carrying capacity of the line in millions of
volt-amperes (MVA).
20. For line 19, Projected In-Service Date, enter the projected date the line will be energized
under the control of the system operator. Please provide a month and year (e.g., 12-2004).
SCHEDULE 7. ANNUAL DATA ON TRANSMISSION LINE
OUTAGES FOR EHV LINES, GENERAL INSTRUCTIONS FOR PART A AND PART B
In general terms, an Outage is defined as the removal from service availability of a generation unit,
transmission line, or other facility for either scheduled (planned) or unscheduled (unplanned)
reasons. For this reporting purpose, individual outage duration should be reported following similar
company standards and/or regional reliability guidelines. The outage durations reported on the
Form EIA-411 represent the annual summation (in hours) of all these events for the reporting
NERC region.
The duration of an outage is the amount of time that the transmission line was completely deenergized. For preferred reporting practices, do not start recording duration until the line is
completely de-energized and stop recording duration when the entire line is reenergized. If
practices differ, please SCHEDULE 9, COMMENTS.
Outages that occur on intertie lines between regions are to be reported only once by one or the
other of the reporting regions.
Scheduled Outages
Information collected on scheduled outages is for the events where the duration was 1 hour or
more in length. This includes line upgrades and the normal maintenance that is usually performed
during non-peak load periods. Each time a line is removed from service, this is recorded as one
scheduled outage (this includes accounting for periods where lines are returned to service on a
7

U.S. Department of Energy
Form Approved
COORDINATED BULK POWER
Energy Information Administration
OMB No. 1905-0129
SUPPLY PROGRAM REPORT
Form EIA-411 (2007)
Approval Expires:
periodic basis during a previously scheduled work period).
Unscheduled Outages
The information requested on unscheduled outages covers all events in which a line is
automatically removed from service by system protection or must be removed from service due to
unforeseen circumstances. The unscheduled outage of any circuit continues until that circuit is
restored to service. If company practices are different from this, please note in SCHEDULE 9
COMMENTS.
•

For any set of outages that have more than one cause, please report the initial cause (i.e.,
the cause that occurred first).

•

For an outage of a circuit to be considered, the line(s) must be deenergized. If the line
recloses and trips again within a minute of the initial outage, it is only considered one
outage. The line would need to remain in service for longer than one minute between the
breaker operations to be considered as two outages.

•

‘Failed tests’ are not considered additional outages. If the operator or dispatcher tries to
energize a circuit that has a fault on it, and it immediately re-opens, this is considered a
‘failed test’ and is not an additional outage. However, if the test ‘passed’ and the line
remained in service for longer than one minute, any additional outages will be recorded as
a new outage.

•

Removal of any transmission line (including radials) from service is considered as an
outage. However, transmission lines that are removed for system stability (such as ‘voltage
control’) should not be reported as an outage. These may be reported separately as a
footnote.

•

When a tap off a transmission line is removed from service (scheduled or unscheduled
outage) and the transmission line itself remains energized only the tap is considered out-ofservice.
SCHEDULE 7. PART A. ANNUAL DATA ON TRANSMISSION LINE
OUTAGES FOR EHV LINES, A.C. LINES, SPECIFIC INSTRUCTIONS

1. All transmission line outages involving Extra High Voltage (EHV) A.C. lines of 230 kV and
above are to be aggregated by each Regional Council and reported on this schedule.
2. For line 1, if you are reporting an outage(s) of a voltage class that is not listed, identify the
voltage class in column e.
3. For line 2, Number of Scheduled Outages, report the total number of scheduled outages that
occurred in the reporting period for each voltage class.
4. For line 3, Number of Circuits Involved, report the total number of “circuit outages”, that
occurred during the reporting period, for all scheduled outages. For example, if there was one
outage and five circuits are involved, the respondent should report five circuit outages.
Alternatively, if there was one outage with two circuits involved and subsequently there is
another outage with four circuits involved, the respondent should report six circuit outages, for
each voltage class.
5. For line 4, Scheduled Circuit-Hours Out of Service, report the total scheduled circuit-hours
out of service for all of the scheduled outages for each voltage class during the year. This is
the sum across all circuits of the number of hours each circuit was out of service for scheduled
reasons during the reporting period.
6. For line 5, Number of Non-Momentary Unscheduled Outages, report the number of nonmomentary (lasting 60 seconds or longer) unscheduled outages that occurred during the
reporting period for each voltage class.
7. For line 6, Number of Circuits Involved, report the total number of “circuit outages”, that
occurred during the reporting period, for all unscheduled outages, both momentary and nonmomentary. For example, if there is one outage and five circuits are involved, the respondent
should report five circuit outages. Alternatively, if there was one outage with two circuits
involved and subsequently there was another outage with four circuits involved, the
respondent should report six circuit outages, for each voltage class.
8. For line 7, Unscheduled Circuit-Hours Out of Service, report the unscheduled circuit-hours
out of service for all of the unscheduled outages for each voltage class during the year. This is
8

U.S. Department of Energy
Form Approved
COORDINATED BULK POWER
Energy Information Administration
OMB No. 1905-0129
SUPPLY PROGRAM REPORT
Form EIA-411 (2007)
Approval Expires:
the sum across all circuits of the number of hours each circuit was out of service for
unscheduled reasons during the reporting period.
9. For line 8, Weather, includes all unscheduled outages caused by severe weather conditions
(tornado, hurricane, lightning strikes, ice, high winds, etc.) that are the primary cause of the
outage.
10. For line 9, Animals, Fire and Smoke, Human Accidents, includes the events caused by
actions where animal movement or nesting impacts electrical operations of equipment or
facilities. Actions by humans (accidents or intention) that not employed or under contract by
the utility in the responsible area that impact operations will be reported. Fire and conditions
linked to this from whatever event that started the fire/smoke conditions need to be accounted
for in this category.
11. For line 10, Vegetation, includes outages initiated by vegetation in the proximity of
transmission facilities. Reporting definition will be consistent with the NERC template and
vegetation management criteria.
12. For line 11, Operator Action, includes any action traceable to employees and/or contactors
for companies operating, maintaining, and/or providing assistance for actions that impacted
any part of the operations of the Nation’s power grids will be identified and reported in this
category. Also, any failure or interpretation of standard industry practices and guidelines that
cause an outage event will be reported in this category.
13. For line 12, Equipment Failure, includes failure of any line or terminal equipment.
14. Line 13, Unknown, any unknown sources should be reported in this category.
15. Line 14, Other, includes all other causes (computed automatically to be the difference
between 100 percent and the sum of lines 8 through 13).
SCHEDULE 7. PART B. ANNUAL DATA ON TRANSMISSION LINE
OUTAGES FOR EHV LINES, D.C. LINES, SPECIFIC INSTRUCTIONS
1. All transmission line outages involving Extra High Voltage (EHV) D.C. lines of ±100 kV and
above are to be aggregated by each Regional Council and reported on this schedule.
2. For line 2, Number of Scheduled Outages, report the total number of scheduled outages that
occurred in the year for each voltage class.
3. For line 3, Number of Circuits Involved, report the total number of “circuit outages”, that
occurred during the year, for all scheduled outages. For example, if there is one outage and
five circuits are involved, the respondent should report five circuit outages. Alternatively, if
there was one outage with two circuits involved and subsequently there was another outage
with four circuits involved, the respondent should report six circuit outages, for each voltage
class.
4. For line 4, Scheduled Circuit-Hours Out of Service, report the total scheduled circuit-hours
out of service for all of the scheduled outages for each voltage class during the year. This is
the sum across all circuits of the number of hours each circuit was out of service for scheduled
reasons during the year.
5. For line 5, Number of Non-Momentary Unscheduled Outages, report the number of nonmomentary (lasting 60 seconds or longer) unscheduled outages that occurred during the year
for each voltage class.
6. For line 6, Number of Circuits Involved, report the total number of “circuit outages”, that
occurred during the year, for all unscheduled outages, both momentary and non-momentary.
For example, if there is one outage and five circuits are involved, the respondent should report
five circuit outages. Alternatively, if there was one outage with two circuits involved and
subsequently there was another outage with four circuits involved, the respondent should
report six circuit outages, for each voltage class.
7. For line 7, Unscheduled Circuit-Hours Out of Service, report the unscheduled circuit-hours
out of service for all of the unscheduled outages for each voltage class during the year. This is
the sum across all circuits of the number of hours each circuit was out of service for
unscheduled reasons during the year.
8. For Line 8, Weather, includes all unscheduled outages caused by severe weather conditions
(tornado, hurricane, lightning strikes, ice, high winds, etc.) that are the primary cause of the
outage.
9. For Line 9, Animals, Fire and Smoke, Human Accidents, includes the events caused by
actions where animal movement or nesting impacts electrical operations of equipment or
9

U.S. Department of Energy
Form Approved
COORDINATED BULK POWER
Energy Information Administration
OMB No. 1905-0129
SUPPLY PROGRAM REPORT
Form EIA-411 (2007)
Approval Expires:
facilities. Actions by humans (accidents or intention) that not employed or under contract by
the utility in the responsible area that impact operations will be reported. Fire and conditions
linked to this from whatever event that started the fire/smoke conditions need to be accounted
for in this category.
10. For Line 10, Vegetation, includes outages initiated by vegetation in the proximity of
transmission facilities. Reporting definition will be consistent with the NERC template and
vegetation management criteria.
11. For Line 11, Operator Action, includes any action traceable to employees and/or contactors
for companies operating, maintaining, and/or providing assistance for actions that impacted
any part of the operations of the Nation’s power grids will be identified and reported in this
category. Also, any failure or interpretation of standard industry practices and guidelines that
cause an outage event will be reported in this category.
12. For line 12, Equipment Failure, includes failure of any line or terminal equipment.
13. For line 13, Unknown, any unknown sources should be reported in this category.
14. For line 14, Other, includes all other causes (computed automatically to be the difference
between 100 percent and the sum of lines 8 through 13).
SCHEDULE 8. BULK TRANSMISSION FACILITY POWER FLOW CASES
1. Each Regional Council is to coordinate the collection of data on basic electrical data and
power flow information on prospective new bulk transmission facilities of 230 kV and above
(including lines, transformers, HVDC terminal facilities, phase shifters, and static VAR
compensators) that have been approved for construction and are scheduled to be energized
over the next two years.
2. If the prospective bulk transmission facilities are represented in the respondent’s current FERC
Form 715 submission, please provide a copy of an annual peak load power flow case
submitted which represents a period of at least two years into the future and complete (see
Instructions 6 through 13).
3. If the facilities are not represented in the respondent’s current FERC Form 715 submission,
please submit a power flow case(s) representing the prospective facilities. The respondent
may submit a single annual peak load power flow case that includes all prospective facilities to
be energized in the next two years. Alternatively, the respondent may provide a copy of any
annual peak load power flow case that includes the new facility for the year it is to be
energized. If more than one facility is to be energized in a given year, it is acceptable to
provide a single annual peak load power flow case that includes all the new facilities added in
that year. The power flow shall be in the same format as used for the respondent’s FERC
Form 715 filing.
4. For each power flow case that is provided in response to Items 2 and 3 above, please identify
on SCHEDULE 8 all prospective facilities that are not currently in service and the projected inservice date of those facilities. Complete one page for each new power flow case. In each
case, identify only the new facility by type and list bus numbers and names that the new facility
is connected with electrically.
5. The EIA expects that in nearly all cases the power flow format will be one of the following:
•

The Raw Data File format of the PTI (Power Technologies, Inc.) PSS/E power flow
program;
• The Card Deck Image format of the Philadelphia Electric power flow program;
• The Card Deck format of the WSCC power flow program;
• The Raw Data File format of the General Electric (formerly Electric Power Consultant,
Inc. or EPC), or the PSLF power flow program; or
• The IEEE Common Format for Exchange of Solved Power Flows.
Respondents submitting their own cases must supply the input data to the solved base cases
and associated ACSII output data on compact disk in the format associated with the power
flow program used by the respondents in the course of their transmission studies, as described
above.
6. For Line 1, enter the case name.
7. For Line 2, enter the year studied in this power flow case.
8. For Line 3, enter the case number assigned by respondent.
10

U.S. Department of Energy
Form Approved
COORDINATED BULK POWER
Energy Information Administration
OMB No. 1905-0129
SUPPLY PROGRAM REPORT
Form EIA-411 (2007)
Approval Expires:
9. For Line 4, column a, enter the name of a prospective facility included on the power flow case.
10. For Line 4, column b, enter the type of facility, e.g., line, transformer, etc.
11. For Line 4, column c, enter the projected in-service date of the proposed facility. Please
provide month and year (e.g., 12-2004).
12. For Line 4, column d and e, enter the number and name respectively of each bus to which the
facility is connected. Use one line for each bus.
13. Repeat Instructions 9 through 12 for each prospective facility.
SCHEDULE 9. COMMENTS

GLOSSARY

Identify each comment by the appropriate schedule, part, line number, column identifier and page
number. Use additional sheets, as required. (Any comment referencing sensitive information will
be considered sensitive.)
The glossary for this form is available online at the following URL:
http://www.eia.doe.gov/glossary/index.html

SANCTIONS

The timely submission of Form EIA-411 by those required to report is requested under Section
13(b) of the Federal Energy Administration Act of 1974 (FEAA) (Public Law 93-275), as amended.
Failure to respond may result in a penalty of not more than $2,750 per day for each civil violation, or
a fine of not more than $5,000 per day for each criminal violation. The government may bring a civil
action to prohibit reporting violations, which may result in a temporary restraining order or a
preliminary or permanent injunction without bond. In such civil action, the court may also issue
mandatory injunctions commanding any person to comply with these reporting requirements. Title
18 U.S.C. 1001 makes it a criminal offense for any person knowingly and willingly to make to
any Agency or Department of the United States any false, fictitious, or fraudulent statements
as to any matter within its jurisdiction.

REPORTING
BURDEN

Public reporting burden for this collection of information is estimated to be 12,960 hours or 960
hours per council response, including the time of reviewing instructions, searching existing data
sources, gathering and maintaining the data needed, and completing and reviewing the collection
of information. The burden includes not only the hours needed by the Councils and NERC, but also
for the members within each council. Send comments regarding this burden estimate or any other
aspect of this collection of information, including suggestions for reducing this burden, to the
Energy Information Administration, Statistics and Methods Group, EI-70, 1000 Independence
Avenue S.W., Forrestal Building, Washington, D.C. 20585-0670; and to the Office of Information
and Regulatory Affairs, Office of Management and Budget, Washington, D.C. 20503. A person is
not required to respond to the collection of information unless the form displays a valid OMB
number.
The information reported on Form EIA-411 will be treated as non-sensitive and may be publicly
released in identifiable form, except as noted below.
The information contained on SCHEDULE 5, Bulk Electric Transmission System Maps, and
SCHEDULE 8, Bulk Transmission Facility Power Flow Cases, will be treated as sensitive and
protected to the extent that it satisfies the criteria for exemption under the Freedom of Information
Act (FOIA), 5 U.S.C. §552, the DOE regulations, 10 C.F.R. §1004.11, implementing the FOIA, and
the Trade Secrets Act, 18 U.S.C. §1905.
The Federal Energy Administration Act requires the EIA to provide company-specific data to other
Federal agencies when requested for official use. The information reported on this form may also
be made available, upon request, to another component of the Department of Energy (DOE) to any
Committee of Congress, the Government Accountability Office, or other Federal agencies
authorized by law to receive such information. A court of competent jurisdiction may obtain this
information in response to an order. The information may be used for any nonstatistical purposes
such as administrative, regulatory, law enforcement, or adjudicatory purposes.
Disclosure limitation procedures are applied to the sensitive statistical data published from
SCHEDULES 5 and 8, EIA-411 survey information to ensure that the risk of disclosure of
identifiable information is very small.

PROVISIONS
REGARDING THE
CONFIDENITALITY
OF INFORMATION

U.S. Department of Energy
Energy Information Administration
Form EIA-411 (2007)

COORDINATED BULK POWER
SUPPLY PROGRAM REPORT

Form Approved
OMB No. 1905-0129
Approval Expires:

NOTICE: This report is mandatory under the Federal Energy Administration Act of 1974 (Public Law 93-275). Failure to
comply may result in criminal fines, civil penalties and other sanctions as provided by law. For further information
concerning sanctions and data protections see the provision on sanctions and the provision concerning the confidentiality of
information in the instructions. Title 18 USC 1001 makes it a criminal offense for any person knowingly and willingly
to make to any Agency or Department of the United States any false, fictitious, or fraudulent statements as to any
matter within its jurisdiction.

SCHEDULE 1. IDENTIFICATION
Survey Contact
Last Name:_________________

First Name:________________
Title:______________________________
Telephone (include extension):______________
E-mail:_______________________________

Fax:__________________

Supervisor of Contact Person for Survey
First Name:____________________
Last Name:_____________________
Title:___________________________
Telephone (include extension):______________
Fax:__________________
E-mail:________________________________
Report For
Council:_________________________________________________
Reporting Party:___________________________________________
For questions about the data requested on Form EIA-411, contact the Survey Manager:
John Makens
Telephone Number: (202) 586-4059
FAX Number: (202) 287-1934
E-mail: [email protected]

U.S. Department of Energy
Energy Information Administration
Form EIA-411 (2007)

Form Approved
OMB No. 1905-0129
Approval Expires:

COORDINATED BULK POWER
SUPPLY PROGRAM REPORT

Council:_________________________________________________
Reporting Party:___________________________________________
SCHEDULE 2. PART A. HISTORICAL AND PROJECTED PEAK DEMAND AND ENERGY MONTHLY

LINE
NO.

1
2
3
4
5
6
7
8
9
10
11
12

MONTH

YEAR
2008
2009
2010
NET ENERGY
NET ENERGY
PEAK HOUR (THOUSANDS OF PEAK HOUR (THOUSANDS OF PEAK HOUR
NET ENERGY
DEMAND
DEMAND
DEMAND
MEGAMEGA(THOUSANDS OF
(MEGAWATTS)

WATTHOURS)

(MEGAWATTS)

WATTHOURS)

(MEGAWATTS)

MEGA-WATTHOURS)

(a)

(b)

(a)

(b)

(a)

(b)

January
February
March
April
May
June
July
August
September
October
November
December

SCHEDULE 2. PART B. HISTORICAL AND PROJECTED PEAK DEMAND AND ENERGY - ANNUAL
LINE
NO.

2008

2009

2010

2008/09

2009/10

2010/11

2008

2009

2010

YEAR
2011

2012

2013

2011/12

2012/13

2013/14

2011

2012

2013

Summer Peak
Hour Demand,
1 June September
(Megawatts)
Winter Peak
Hour Demand,
2 December March
(Megawatts)
Net Annual
Energy
3 (Thousands of
Megawatthours)

U.S. Department of Energy
Energy Information Administration
Form EIA-411 (2007)

COORDINATED BULK POWER
SUPPLY PROGRAM REPORT

Form Approved
OMB No. 1905-0129
Approval Expires:

Council:_________________________________________________
Reporting Party:___________________________________________
SCHEDULE 3. PART A. HISTORICAL AND PROJECTED DEMAND AND CAPACITY - SUMMER
LINE
NO.
1
2
3
4
5

2008

2009
2010
DEMAND (IN MEGAWATTS)

Internal Demand
Standby Demand
Total Internal Demand
(sum of lines 1 and 2)
Direct Control Load
Management
Interruptible Demand

Net Internal Demand
(line 3, less line 4, less line 5)

7
7a
7a1
7a1.1
7a1.2
7a2
7a2.1
7a2.2
7a3
7a3.1
7a3.2
7b
7b1
7b1.1
7b1.2
7b1.3
7b2
7b2.1

Total Internal Capacity
Existing Capacity
Committed
Operable
Inoperable
Uncommitted
Operable
Inoperable
Energy Only
Operable
Inoperable
Planned Capacity Additions
Under Construction
Committed
Uncommitted
Energy Only
Not Under Construction
Committed

CAPACITY (IN MEGAWATTS)

7b2.2
7b2.3
7c

7c1

7c2

7c3

Uncommitted
Energy Only
Capacity Rerating,
Retirements and
Adjustments
Planned Positive
Reratings of Existing
Capacity
Planned Negative
Reratings of Existing
Capacity
Planned Retirements of
Existing Operable
Capacity

YEAR
2011

2012

2013

U.S. Department of Energy
Energy Information Administration
Form EIA-411 (2007)

COORDINATED BULK POWER
SUPPLY PROGRAM REPORT

Form Approved
OMB No. 1905-0129
Approval Expires:

Council:_________________________________________________
Reporting Party:___________________________________________
SCHEDULE 3. PART A. HISTORICAL AND PROJECTED DEMAND AND CAPACITY - SUMMER
YEAR

LINE
NO.
7c4
7c5
7c6

7c7
8
9
10
10a
10b
10c
11
12
13
14
15
16
17
17a

17a.1

17b
18

2008
2009
2010
CAPACITY (IN MEGAWATTS)
Planned Retirement of
Existing Inoperable Capacity
Return to Service of Existing
Inoperable Capacity
Existing Net Purchases from
Non-reporting parties within
Region - Subregion
Planned Net Purchases from
Non-reporting parties within
Region - Subregion
Total Inoperable Capacity
Operable Total Internal
Capacity
Derates and Decreases in
Seasonal Rated Capacity
Conditional Derates
Hydro Derates
Wind Capacity
Planned Outages or Scheduled
Maintenance of Existing
Capacity
Derated Operable Total Internal
Capacity
Operable Energy-only and
Uncommitted Resources
Derated Operable Internal
Capacity
Transmission-Limited
Resources
Deliverable Internal Capacity
Capacity Purchases and
Incoming Adjustments
Purchases from Entities
Outside the Region Subregion
Full-Responsibility
Purchases (portion of total
purchases)
Owned Capacity - Entitlement
Located Outside the Region Subregion
Sales and Outgoing
Adjustments

2011

2012

2013

U.S. Department of Energy
Energy Information Administration
Form EIA-411 (2007)

COORDINATED BULK POWER
SUPPLY PROGRAM REPORT

Form Approved
OMB No. 1905-0129
Approval Expires:

LINE
NO.
18a
18a1

18b

19
20
21
22
23

Sales to Entities Outside the
Region -Subregion
Full-Responsibility Sales
(portion of total sales)
Capacity Owned by Entitlement Held by Entity
Outside the Region Subregion
Net Capacity Resources
Total Potential Resources
Distributed Generator
Capacity less than 1 MW
Other Capacity less than 1
MW
Distributed Generator
Capacity greater than or
equal to 1 MW

EIA-860 Capacity Total

Existing Capacity
Difference - Line 24 less
Total Internal Capacity
(Line 7)

2012

2013

U.S. Department of Energy
Energy Information Administration
Form EIA-411 (2007)

COORDINATED BULK POWER
SUPPLY PROGRAM REPORT

Form Approved
OMB No. 1905-0129
Approval Expires:

Council:_________________________________________________
Reporting Party:___________________________________________
SCHEDULE 3. PART B. HISTORICAL AND PROJECTED DEMAND AND CAPACITY - WINTER
LINE
NO.

2008/09

2009/10

2010/11

DEMAND (IN MEGAWATTS)
1
2
3
4
5
6

Internal Demand
Standby Demand
Total Internal Demand (sum
of lines 1 and 2)
Direct Control Load
Management
Interruptible Demand
Net Internal Demand
(line 3, less line 4, less line 5)

CAPACITY (IN MEGAWATTS)
7
7a
7a1
7a1.1
7a1.2
7a2
7a2.1
7a2.2
7a3

Total Internal Capacity
Existing Capacity
Committed
Operable
Inoperable
Uncommitted
Operable
Inoperable
Energy Only

7a3.1

Operable

7a3.2

Inoperable

7b
7b1
7b1.1
7b1.2
7b1.3
7b2
7b2.1
7b2.2
7b2.3

Planned Capacity Additions
Under Construction
Committed
Uncommitted
Energy Only
Not Under Construction
Committed
Uncommitted
Energy Only

YEAR
2011/12

2012/13

2013/14

U.S. Department of Energy
Energy Information Administration
Form EIA-411 (2007)

COORDINATED BULK POWER
SUPPLY PROGRAM REPORT

Form Approved
OMB No. 1905-0129
Approval Expires:

LINE
NO.
7c
7c1
7c2
7c3
7c4
7c5
7c6

7c7
8
9
10
10a
10b
10c
11
12

Capacity Rerating, Retirements
and Adjustments
Planned Positive Reratings
of Existing Capacity
Planned Negative Reratings
of Existing Capacity
Planned Retirements of
Existing Operable Capacity
Planned Retirement of
Existing Inoperable Capacity
Return to Service of Existing
Inoperable Capacity
Existing Net Purchases from
Non-reporting parties within
Region - Subregion
Planned Net Purchases from
Non-reporting parties within
Region - Subregion
Total Inoperable Capacity
Operable Total Internal
Capacity
Derates and Decreases in
Seasonal Rated Capacity
Conditional Derates
Hydro Derates
Wind Capacity
Planned Outages or Scheduled
Maintenance of Existing
Capacity
Derated Operable Total Internal
Capacity

2012/13

2013/14

U.S. Department of Energy
Energy Information Administration
Form EIA-411 (2007)

COORDINATED BULK POWER
SUPPLY PROGRAM REPORT

Form Approved
OMB No. 1905-0129
Approval Expires:

LINE
NO.
13
14
15
16
17
17a

17a.1

17b

18
18a
18a1

18b

19
20
21
22
23

Operable Energy-only and
Uncommitted Resources
Derated Operable Internal
Capacity
Transmission-Limited
Resources
Deliverable Internal Capacity
Capacity Purchases and
Incoming Adjustments
Purchases from Entities
Outside the Region Subregion
Full-Responsibility
Purchases (portion of total
purchases)
Owned Capacity Entitlement Located
Outside the Region Subregion
Sales and Outgoing
Adjustments
Sales to Entities Outside
the Region -Subregion
Full-Responsibility Sales
(portion of total sales)
Capacity Owned by Entitlement Held by Entity
Outside the Region Subregion
Net Capacity Resources
Total Potential Resources
Distributed Generator
Capacity less than 1 MW
Other Capacity less than 1
MW
Distributed Generator
Capacity greater than or
equal to 1 MW

EIA-860 Capacity Total

Existing Capacity
Difference - Line 24 less
Total Internal Capacity
(Line 7)

2012/13

2013/14

U.S. Department of Energy
Energy Information Administration
Form EIA-411 (2007)

Form Approved
OMB No. 1905-0129
Approval Expires:

COORDINATED BULK POWER
SUPPLY PROGRAM REPORT

Council:_________________________________________________
Reporting Party:___________________________________________
SCHEDULE 4. PART A. HISTORICAL AND PROJECTED CAPACITY PURCHASES/INCOMING
TRANSFERS (MEGAWATTS) - SUMMER
YEAR

LINE
NO.

1
2
3
4
5
6
7
8
9
10
11

OTHER
PARTY
EIA
CODE
(a)

PLANT ID

UNIT ID

2008
(b)

2009
(c)

2010
(d)

2011
(e)

2012
(f)

2013
(g)

Total

SCHEDULE 4. PART B. HISTORICAL AND PROJECTED CAPACITY PURCHASES/INCOMING
TRANSFERS (MEGAWATTS) - WINTER
YEAR

LINE
NO.

12
13
14
15
16
17
18
19
20
21
22

OTHER
PARTY
EIA
CODE
(a)

PLANT ID

UNIT ID

2008/2009
(b)

2009/2010
(c)

Total

2010/2011
(d)

2011/2012
(e)

2012/2013
(f)

2013/2014
(g)

U.S. Department of Energy
Energy Information Administration
Form EIA-411 (2007)

COORDINATED BULK POWER
SUPPLY PROGRAM REPORT

Form Approved
OMB No. 1905-0129
Approval Expires:

Council:_________________________________________________
Reporting Party:___________________________________________
SCHEDULE 4. PART C. HISTORICAL AND PROJECTED CAPACITY SALES/OUTGOING
TRANSFERS (MEGAWATTS) - SUMMER
YEAR
LINE
NO.

OTHER
PARTY
EIA CODE
(a)

PLANT
ID

UNIT ID

2008
(b)

2009
(c)

2010
(d)

2011
(e)

2012
(f)

2013
(g)

1
2
3
4
5
6
7
8
9
10

Total

SCHEDULE 4. PART D. HISTORICAL AND PROJECTED CAPACITY SALES/OUTGOING
TRANSFERS (MEGAWATTS) - WINTER
YEAR
LINE
NO.

12
13
14
15
16
17
18
19
20
21
22

OTHER
PARTY
EIA CODE
(a)
PLANT ID

UNIT ID

2008/2009 2009/2010 2010/2011 2011/2012 2012/2013
(b)
(c)
(d)
(e)
(f)

Total

2013/2014
(g)

U.S. Department of Energy
Energy Information Administration
Form EIA-411 (2007)

COORDINATED BULK POWER
SUPPLY PROGRAM REPORT

Form Approved
OMB No. 1905-0129
Approval Expires:

Council:_________________________________________________
Reporting Party:___________________________________________
SCHEDULE 5. BULK ELECTRIC TRANSMISSION SYSTEM MAPS
LINE
NO.

1
2

Specify the Number of Maps
Provided:
For each map provide file name, coverage, and map software:
MAP NUMBER
FILE NAME
YEARS PROJECTED
(a)
(b)
(c)

MAP SOFTWARE
(d)

U.S. Department of Energy
Energy Information Administration
Form EIA-411 (2007)

COORDINATED BULK POWER
SUPPLY PROGRAM REPORT

Form Approved
OMB No. 1905-0129
Approval Expires:

Council:_________________________________________________
Reporting Party:___________________________________________
SCHEDULE 6. PROJECTED TRANSMISSION LINES
TRANSMISSION LINE
(a)
TRANSMISSION LINE IDENTIFICATION

TRANSMISSION LINE
(b)

LINE
NO.

Terminal Location (From)

Terminal Location (To)

TRANSMISSION LINE OWNERSHIP
3
Company Name
4
EIA Company Code
5
Type of Organization
6
Percent Ownership
TRANSMISSION LINE DATA
7
Line Length (miles)
[ ]
[ ]
[ ]
[ ]
[ ]
[ ]
8
Line Type
OH
UG
SM
OH
UG
SM
[ ]
[ ]
[ ]
[ ]
9
Voltage Type
AC
DC
AC
DC
Voltage Operating
10
(Kilovolts)
Voltage Design
11
(Kilovolts)
12
Conductor Size (MCM)
Conductor Material
13
Type (Select codes
from legend below)
Bundling Arrangement
14
(Select codes from
legend below)
Circuits per Structure
15
Present
Circuits per Structure
16
Ultimate
Pole/Tower Type
Pole Material: [
]
Pole Material: [
]
Pole Type: [
]
Pole Type: [
]
17
(Select codes from
legend below)
Capacity Rating
18
(Megavoltamperes)
Projected In-Service
19
Date (e.g., 12-2004)
LEGEND
Line Type

Voltage Type

Conductor Material
Type

Bundling Arrangement

OH=Overhead
UG=Underground
SM=Submarine

AC=Alternating
Current
DC=Direct Current

1 = Single
AL = Aluminum
2 = Double
ACCR = Aluminum
3 = Triple
Composite Conductor 4 = Quadruple
Reinforced
OT = Other
ACSR = Aluminum
Core Steel Reinforced
CU = Copper
OT = Other

TRANSMISSION LINE
(c)

[ ]
OH
[ ]
AC

[ ]
UG
[ ]
DC

Pole Material: [
Pole Type: [

[ ]
SM

]
]

Pole/Power Type
Pole Material

Pole Type

W = Wood
C = Concrete
S = Steel
B = Combination
P = Composite
O = Other

P = Single pole
H = H-frame
T = Tower
U = Underground
O = Other

U.S. Department of Energy
Energy Information Administration
Form EIA-411 (2007)

COORDINATED BULK POWER
SUPPLY PROGRAM REPORT

Form Approved
OMB No. 1905-0129
Approval Expires:

Council:_________________________________________________
Reporting Party:___________________________________________
SCHEDULE 7. PART A, ANNUAL DATA ON TRANSMISSION LINE OUTAGES FOR EHV A.C.
LINES
(Report following data for each applicable EHV Voltage Class)
LINE
NO.

2
3
4

5
6
7
8
9
10
11
12
13
14

Applicable A.C. Voltage Class

230 kV

345 kV

500 kV

765 kV

(a)

(b)

(c)

(d)

Scheduled Outages for Specified Voltage Class
Number of Scheduled Outages
Number of Circuits Involved
Scheduled Circuit-Hours Out of
Service
Unscheduled Outages for Specified Voltage Class
Number of Non-Momentary
Unscheduled Outages
Number of Circuits Involved
Unscheduled Circuit-Hours Out of
Service
Causal Categories for Unscheduled Outages of Specified Voltage Class (Percent)
Weather
Animals, Fire and Smoke, Human
Accidents
Vegetation
Operator Action
Equipment Failure
Unknown
Other

Other (specify)
(e)

U.S. Department of Energy
Energy Information Administration
Form EIA-411 (2007)

COORDINATED BULK POWER
SUPPLY PROGRAM REPORT

Form Approved
OMB No. 1905-0129
Approval Expires:

Council:_________________________________________________
Reporting Party:___________________________________________
SCHEDULE 7. PART B, ANNUAL DATA ON TRANSMISSION LINE OUTAGES FOR EHV D.C.
LINES
(Report following data for each applicable EHV Voltage Class)
LINE
NO.

1
2
3
4

5
6
7
8
9
10
11
12
13
14

Applicable D.C. Voltage Class

± 100-199
kV
(a)

± 200-299
kV
(b)

± 300-399
kV
(c)

± 400-499
kV
(d)

Number of Scheduled Outages
Number of Circuits Involved
Scheduled Circuit-Hours Out of Service
Unscheduled Outages for Specified Voltage Class
Number of Non-Momentary
Unscheduled Outages
Number of Circuits Involved
Unscheduled Circuit-Hours Out of
Service
Causal Categories for Unscheduled Outages of Specified Voltage Class (Percent)
Weather
Animals, Fire and Smoke, Human
Accidents
Vegetation
Operator Action
Equipment Failure
Unknown
Other

± 500 kV or
greater
(e)

U.S. Department of Energy
Energy Information Administration
Form EIA-411 (2007)

COORDINATED BULK POWER
SUPPLY PROGRAM REPORT

Form Approved
OMB No. 1905-0129
Approval Expires:

Council:_________________________________________________
Reporting Party:___________________________________________
SCHEDULE 8. BULK TRANSMISSION FACILITY POWER FLOW CASES
LINE
NO.

1
2
3

Case Name:
Year of Study:
Case Number:

NAME OF
FACILITY
(a)

PROSPECTIVE FACILITIES AND CONNECTIONS
PROJECTED
IN-SERVICE
DATE
CONNECTIONS
TYPE OF
FACILITY
(e.g., 12-2004)
BUS NUMBER
BUS NAME
(b)
(c)
(d)
(e)

U.S. Department of Energy
Energy Information Administration
Form EIA-411 (2007)

COORDINATED BULK POWER
SUPPLY PROGRAM REPORT

Form Approved
OMB No. 1905-0129
Approval Expires:

Council:_________________________________________________
Reporting Party:___________________________________________
SCHEDULE 9. COMMENTS
LINE
NO.

SCHEDULE
(a)

PART
(b)

LINE NO.
(c)

COLUMN
(d)

PAGE
(e)

1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27

COMMENT
(f)

File Type	application/pdf
Author	LJSpencer
File Modified	2007-10-03
File Created	2007-10-03