Houston Lighting & Power Company Tariff for Transmission Service To, From
FERC Electric Tariff And Over Certain HVDC Interconnections
Second Revised Original Volume No. 1 Contract #TFN97-133A
ATTACHMENT B
FORM OF SERVICE AGREEMENT
NON-FIRM TRANSMISSION SERVICE
1.0 This Service Agreement (“Agreement”), dated as of ____________________, is entered into by and between Houston Lighting & Power Company (the “Transmission Provider”), and NP Energy, Inc. (the “Transmission Customer”).
2.0 The Transmission Customer has been determined by the Transmission Provider to be a Transmission Customer under the Transmission Provider’s TFO Transmission Service Tariff (“Tariff”) and has filed a Completed Application for Non-Firm Transmission Service in accordance with Section 16 of the Tariff.
3.0 Service under this Agreement shall be provided by the Transmission Provider upon request by the Transmission Customer subject to all terms and conditions of the Tariff. Individual transactions may be scheduled telephonically (or in writing) by a designated representative of Transmission Customer, with notice given to the appropriate ERCOT Security Center.
4.0 The Transmission Customer agrees to supply information the Transmission Provider deems reasonably necessary in accordance with Good Utility Practice in order for it to provide the requested service.
5.0 The Transmission Provider agrees to provide and the Transmission Customer agrees to take and pay for Non-Firm Transmission Service in accordance with the provisions of the Tariff and this Agreement.
6.0 Any notice or request made to or by either Party regarding this Agreement shall be made to the representative of the other Party as indicated below.
Transmission Provider:
Houston Lighting & Power Company
P. O. Box 1700
Houston, TX 77251-1700
Attention: Manager of Control Area Services (EC/DC)
Fax: (713) 207-2802
Phone: (713) 207-2801
Physical address for courier only: 16303 Tomball Pkwy., Houston, TX 77064
Transmission Customer:
NP Energy, Inc. |
3650 National City Tower, 101 South Fifth Street, Louisville, KY 40202 |
3650 National City Tower, 101 South Fifth Street, Louisville, KY 40202 |
Attention: David G. Schwartz |
Fax: 502-560-5310 |
Phone: 502-560-5300 |
7.0 The Tariff and attached Scheduling Specifications are incorporated herein and made a part hereof.
IN WITNESS WHEREOF, the Parties have caused this Service Agreement to be executed by their respective authorized officials.
Transmission Provider:
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Transmission Customer:
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SCHEDULING SPECIFICATIONS FOR NON-FIRM
TRANSMISSION SERVICE
1.0 Term of Transaction: Transactions of less than one month duration - As scheduled through the ERCOT ISO and, where applicable, any entity(ies) responsible for scheduling outside of ERCOT.
Start Date: As scheduled through the ERCOT ISO and, where applicable, any entity(ies) responsible for scheduling outside of ERCOT.
Termination Date: As scheduled through the ERCOT ISO and, where applicable, any entity(ies) responsible for scheduling outside of ERCOT.
2.0 Description of capacity and/or energy to be transmitted by Transmission Provider including the electric Control Area in which the transaction originates.
To be described upon scheduling with the ERCOT ISO and, where applicable, any entity(ies) responsible for scheduling outside of ERCOT.
3.0 Point(s) of Receipt: Various - Receipt Point to be described upon scheduling.
Delivering Party: Various - Delivering Party to be described upon scheduling.
4.0 Point(s) of Delivery: Various - Delivery Point to be described upon scheduling.
Receiving Party: Various- Receiving Party to be described upon scheduling.
5.0 Maximum amount of capacity and/or energy to be transmitted (Reserved Capacity):
Up to 600 MW To/From and 200 MW Over the East Tie; Up to 220 MW To/From and 0 MW Over the North Tie as approved upon scheduling with the ERCOT ISO and, where applicable, any entity(ies) responsible for scheduling outside of ERCOT.
6.0 Name(s) of any Intervening Systems providing transmission service:
To be provided to ERCOT ISO and, where applicable, any entity(ies) responsible for scheduling outside of ERCOT.
7.0 Service under this Service Agreement may be subject to some combination of the charges detailed below. (The appropriate charges for individual transactions will be determined in accordance with the terms and conditions of the Tariff.)
7.1 Transmission Charges Pursuant to Schedule I: To be applied to transactions as scheduled.
7.2 System Impact and/or Facilities Study Charge(s): No HL&P charges anticipated - Customer shall be responsible for any fees assessed by the ISO .
7.3 Ancillary Services Charges: Arranged only for transfers which involve the HL&P control area as either the source control area, or the HL&P load as the delivery point as follows: (1) Static Scheduling in accordance with Schedule 3 of the Tariff ; (2) Generation Schedule Imbalance, if source is within HL&P’s control area, in accordance with Schedule 6 of the Tariff. Customer may contract separately for other services offered under the Tariff.
Schedule I
HL&P Facilities Charges
Non-Firm Service
To, From, And Over the East DC Tie
Effective February 1, 1997
Scheduled Transfer |
Impact on HL&P System (MW-Mile)1 |
Monthly Charge @ $6.61/MW-mi per mo. ($/MW)2 |
Weekly Charge @ $1.53/MW-mi per wk. ($/MW)2 |
Daily Charge @ $0.22/MW-mi per day. ($/MW)2 |
Hourly Charge @ $0.009/MW-mi per hour. ($/MW)2 |
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Control Area |
MW |
|||||
To the following Control Areas --From the East DC Tie (Southbound Transfer) |
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TUEC |
100 |
228.7 |
$15.12 |
$3.50 |
$0.50 |
$0.02 |
HLP |
100 |
9585.2 |
$633.58 |
$146.65 |
$21.09 |
$0.86 |
CPSB |
100 |
4769.7 |
$315.28 |
$72.98 |
$10.49 |
$0.43 |
LCRA |
100 |
4115.1 |
$272.01 |
$62.96 |
$9.05 |
$0.37 |
CSWS |
100 |
4167.8 |
$275.49 |
$63.77 |
$9.17 |
$0.38 |
COA |
100 |
3627.2 |
$239.76 |
$55.50 |
$7.98 |
$0.33 |
TMPP |
100 |
430.3 |
$28.44 |
$6.58 |
$0.95 |
$0.04 |
STEC/MEC |
100 |
5588.6 |
$369.41 |
$85.51 |
$12.29 |
$0.50 |
COB |
100 |
5539.6 |
$366.17 |
$84.76 |
$12.19 |
$0.50 |
From the following Control Areas --- To the East DC Tie (Northbound Transfer) |
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TUEC |
100 |
261.6 |
$18.44 |
$4.27 |
$0.61 |
$0.03 |
HLP |
100 |
3703.2 |
$228.26 |
$52.84 |
$7.60 |
$0.31 |
CPSB |
100 |
3842.9 |
$279.37 |
$64.66 |
$9.30 |
$0.38 |
LCRA |
100 |
3046.0 |
$215.92 |
$49.98 |
$7.19 |
$0.29 |
CSWS |
100 |
3153.7 |
$222.59 |
$51.52 |
$7.41 |
$0.30 |
COA |
100 |
3028.2 |
$215.00 |
$49.77 |
$7.16 |
$0.29 |
TMPP |
100 |
586.2 |
$67.51 |
$15.63 |
$2.25 |
$0.09 |
STEC/MEC |
100 |
3787.4 |
$279.74 |
$64.75 |
$9.31 |
$0.38 |
COB |
100 |
4527.4 |
$312.75 |
$72.39 |
$10.41 |
$0.43 |
1All impacts are determined using a 100 MW or 50 MW transfer level in accordance with the ERCOT Engineering Subcommittee Power Interchange Effects Task Force Procedures
2 (Annual Rate is $79.32/mw-mi) Wheeling Charges, as shown, do NOT include HL&P Losses, 3rd Party Impacts and/or 3rd Party Losses
Non-Firm Service
To, From, And Over the North DC Tie
Effective February 1, 1997
Scheduled Transfer |
Impact on HL&P System (MW-Mile)1 |
Monthly Charge @ $6.61/MW-mi per mo. ($/MW)2 |
Weekly Charge @ $1.53/MW-mi per wk. ($/MW)2 |
Daily Charge @ $0.22/MW-mi per day. ($/MW)2 |
Hourly Charge @ $0.009/MW-mi per hour. ($/MW)2 |
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Control Area |
MW |
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To the following Control Areas --From the NORTH DC Tie (Southbound Transfer) |
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TUEC |
100 |
105.3 |
$7.72 |
$1.79 |
$0.26 |
$0.01 |
HLP |
100 |
9499.3 |
$637.77 |
$147.62 |
$21.23 |
$0.87 |
CPSB |
100 |
4441.9 |
$293.70 |
$67.98 |
$9.78 |
$0.40 |
LCRA |
100 |
3801.7 |
$244.01 |
$56.48 |
$8.12 |
$0.33 |
CSWS |
100 |
3841.7 |
$250.10 |
$57.89 |
$8.32 |
$0.34 |
COA |
100 |
3327.3 |
$212.00 |
$49.07 |
$7.06 |
$0.29 |
TMPP |
100 |
468.9 |
$31.36 |
$7.26 |
$1.04 |
$0.04 |
STEC/MEC |
100 |
5291.4 |
$347.43 |
$80.42 |
$11.56 |
$0.47 |
COB |
100 |
5228.6 |
$346.91 |
$80.30 |
$11.55 |
$0.47 |
From the following Control Areas --- To the NORTH DC Tie (Northbound Transfer) |
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TUEC |
100 |
142.9 |
$8.45 |
$1.96 |
$0.28 |
$0.01 |
HLP |
100 |
3659.5 |
$224.24 |
$51.91 |
$7.46 |
$0.31 |
CPSB |
100 |
3599.5 |
$258.99 |
$59.95 |
$8.62 |
$0.35 |
LCRA |
100 |
2801.5 |
$195.81 |
$45.32 |
$6.52 |
$0.27 |
CSWS |
100 |
2900.2 |
$203.06 |
$47.00 |
$6.76 |
$0.28 |
COA |
100 |
2786.6 |
$194.83 |
$45.10 |
$6.48 |
$0.27 |
TMPP |
100 |
430.3 |
$75.40 |
$17.45 |
$2.51 |
$0.10 |
STEC/MEC |
100 |
3540.0 |
$259.64 |
$60.10 |
$8.64 |
$0.35 |
COB |
100 |
4284.2 |
$292.80 |
$67.77 |
$9.75 |
$0.40 |
1All impacts are determined using a 100 MW or 50 MW transfer level in accordance with the ERCOT Engineering Subcommittee Power Interchange Effects Task Force Procedures
2 (Annual Rate is $79.32/mw-mi) Wheeling Charges, as shown, do NOT include HL&P Losses, 3rd Party Impacts and/or 3rd Party Losses
CITY OF HOUSTON AS PROVIDED BY THE TEXAS PUBLIC
CITY OF HOUSTON CONTRACTOR OWNERSHIP DISCLOSURE ORDINANCE COMPLETION OF
CITY OF HOUSTON COUNCIL COMMITTEE ON BUDGET & FISCAL
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