PROJECT NO. 35077
INFORMATIONAL FILING OF ERCOT § PUBLIC UTILITY OF COMMISSION INTERCONNECTION AGREEMENTS § PURSUANT TO SUBST. R. §25.195(e) § OF TEXAS
Jason Ryan CenterPoint Energy Service Company, LLC P.O. Box 61867 Houston, TX 77208 Tel. No.: 713.207.7261 Fax: 713.574.2661 fax Email: [email protected]
September 24, 2015
TABLE OF CONTENTS
Description Page
Amended and Restated ERCOT Standard Generation Interconnection Agreement, effective September 23, 2015 between CenterPoint Energy Houston Electric, LLC and Friendswood Energy Genco, LLC……………...... 2-122
1 CenterPoint Energy Contract # INTI 5-260A CenterPoint. Energy
AMENDED AND RESTATED ERCOT STANDARD GENERATION INTERCONNECTION AGREEMENT
Between
Friendswood Energy Genco, LLC
and
CenterPoint Energy Houston Electric, LLC
for
Friendswood Energy Generation Project, Harris County, Texas
September 2015
2 CenterPoint Energy Contract# INT15-260A
TABLE OF CONTENTS
ERCOT STANDARD GENERATION INTERCONNECTION AGREEMENT ...... 3
EXHIBIT 'A' -TERMS AND CONDITIONS OF THE ERCOT STANDARD GENERATION INTERCONNECTION AGREEMENT ...... 5 ARTICLE I. DEFINITIONS ...... 5 ARTICLE 2. TERMINATION...... 7 ARTICLE 3. REGULATORY FILINGS ...... 8 ARTICLE 4. INTERCONNECTION FACILITIES ENGINEERING, PROCUREMENT, AND CONSTRUCTION...... 9 ARTICLE 5. FACILIT/ESANDEQUIPMENT...... 13 ARTICLE 6. OPERATION AND MAINTENANCE ...... 17 ARTICLE 7. DATA REQUIREMENTS ...... 20 ARTICLE 8. PERFORMANCE OBLIGATION ...... 22 ARTICLE 9. INSURANCE ...... 23 ARTICLE 10. MISCELLANEOUS ...... 26 EXIl!BIT 'B' -TIME SCHEDULE ...... 35 EXII!BIT 'C' - INTERCONNECTION DETAILS ...... 37 Plant Name ...... 37 Point of Interconnection Location ...... 37 DeliveIJ' Voltage ...... 3 7 N11111ber and Size o.f Generating Units ...... 37 T)pe a/Generating Unit ...... 37 Metering and Tele111etJ)' Equip111ent ...... 37 Generator Interconnection Facilities ...... 38 TSP Interconnection Facilities ...... 39 Con11nunications Facilities ...... 40 SJ'Ste1n Protection Equipn1ent ...... 40 Inputs to Tele1nef1J' Equip111ent ...... 40 Supple1nental Ter1ns and Conditions ...... 41 Special Operating Conditions ...... 42 Cost Estimate Differences ...... 43 EXII!BIT 'D' - NOTICE AND EFT INFORM ATTON ...... 44 EXII!BIT 'E' - SECURITY ARRANGEMENT DETAILS ...... 45 EXIl!BIT 'F' -OUTAGE AND CLEARANCE COORDINATION PROCEDURE ...... I EXII!Bfl' 'G' - TELEMETRY SPECIFICATION ...... I EXIl!BIT 'H' -ATTACHED DRAWINGS ...... I EXHIBIT'!' -SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN ...... I
2 3 CenterPoint Energy Contract# INTl5-260A
ERCOT STANDARD GENERATION INTERCONNECTION AGREEMENT
This Standard Generation Interconnection Agreement is made and entered into between CenterPoint Energy Houston Electric, LLC ("Transmission Service Provider"), and Friendswood Energy Genco, LLC ("Generator"), hereinafter individually referred to as "Party," and collectively referred to as "Parties." In consideration of the mutual covenants and agreements herein contained, the Parties hereto agree as follows:
Transmission Service Provider represents that it is a public utility that owns and operates facilities for the transmission and distribution of electricity. Generator represents that it will own and operate the Plant. Pursuant to the terms and conditions of this Agreement, Transmission Service Provider shall interconnect Generator's Plant with Transmission Service Provider's System consistent with the Facilities Study Agreement executed between the Parties on December 5, 2014.
This Agreement applies only to the Plant and the Pmiies' interconnection facilities as identified in Exhibit "C".
This Agreement shall become effective on the date of the last signature executing this Agreement below, subject to Governn1ental Authority approval, if required, and shall continue in full force and effect until te1minated in accordance with Exhibit "A".
This Agreement will be subject to the following, all of which are incorporated herein:
A. The "Terms and Conditions of the ERCOT Standard Generation Interconnection Agreement" attached hereto as Exhibit "A"; B. The ERCOT Requirements (unless expressly stated herein, where the ERCOT Requirements are in conflict with this Agreement, the ERCOT Requirements shall prevail); C. The PUCT Rules (where the PUCT Rules are in conflict with this Agreement, the PUCT Rules shall prevail); D. The Time Schedule attached hereto as Exhibit "B"; E. The Interconnection Details attached hereto as Exhibit "C"; F. The notice requirements attached hereto as Exhibit "D"; G. The Security Arrangement Details attached hereto as Exhibit "E"; H. The Transmission Service Provider's "Outage and Clearance Coordination Procedure", as it may be updated from time to time, the current version of which is attached hereto as Exhibit "F"; I. The Transmission Service Provider's "Telemetry Specification", specification 007-400-02, as it may be updated from time to time, the cmTent version of which is attached hereto as Exhibit "G"; and J. Selected drawings related to the interconnection between Plant and Transmission Service Provider's System, attached hereto as Exhibit "H".
3 4 CenterPoint Energy Contract# INT15-260A
K. The Transmission Service Provider's "Specification for Customer 138 kV Substation Design", specification 007-231-14, as it may be updated from time to time, the current version of which is attached hereto as Exhibit "I".
IN WITNESS WHEREOF, the Parties have executed this Agreement in duplicate originals, each of which shall constitute and be an original effective Agreement between the Parties. 7/li)l
4 5 CenterPoint Energy Contract# INT15-260A
Exhibit "A" Terms and Conditions of the ERCOT Standard Generation Interconnection Agreement
ARTICLE 1. DEFINITIONS
Capitalized terms shall have the meanings as set forth below, except as otherwise specified in the Agreement:
1.1 "CCN" shall mean a Certificate of Convenience and Necessity issued by the
PUCT.
1.2 "Commercial Operation" shall mean the date on which Generator declares that the constrnction of the Plant has been substantially completed, Trial Operation of the Plant has been completed, and the Plant is ready for dispatch.
1.3 "Control Area" shall have the meaning ascribed thereto in PUCT Rule 25.5(8) or its successor.
1.4 "ERCOT" shall mean the Electric Reliability Council of Texas, Inc.
1.5 "ERCOT Requirements" means the ERCOT Operating Guides, ISO Generation
Interconnection Procedures as well as any other documents adopted by the ISO or
ERCOT relating to the interconnection and operation of generators and transmission systems in ERCOT as amended from time to time, and any successors thereto. Any requirement in the foregoing documents imposed upon generation entities or generation facilities shall become the responsibility of the Generator, and any requirements imposed on transmission providers or transmission facilities shall become the responsibility of the
TSP.
1.6 "Facilities Study" shall have the meaning as described in PUCT Rule 25.198(g) or its successor.
5 6 CenterPoint Energy Contract# INTl 5-260A
1.7 "Facilities Study Agreement" shall mean an agreement executed by the Parties
relating to the performance of the Facilities Study.
1.8 "GIF" shall mean Generator's interconnection facilities as described in Exhibit
"C."
1.9 "Good Utility Practice" shall have the meaning described in PUCT Rule 25.5(23) or its successor.
1.10 "Governmental Authority(ies )" shall mean any federal, state, local or municipal body having jurisdiction over a Party.
1.11 "In-Service Date" shall be the date, as reflected in Exhibit "B," that the TIF will be ready to connect to the GIF
1.12 "ISO" shall mean the ERCOT Independent System Operator.
1.13 "Plant" shall mean the electric generation facility owned and operated by the
Generator, as specified in Exhibit "C."
1.14 "Point of Interconnection" shall mean the location(s) where the GIF connects to the TIF as negotiated and defined by the Parties and as shown on Exhibit "C" of this
Agreement.
1.15 "PUCT" shall mean the Public Utility Commission of Texas.
1.16 "PUCT Rules" shall mean the Substantive Rules of the PUCT.
1.17 "Reasonable Efforts" shall mean the use of Good Utility Practice and the exercise of due diligence (pursuant to PUCT Rule 25.196(e)).
1.18 "System Protection Equipment" shall mean those facilities located within the TIF and the GIF as described in Section 5.6 and Exhibit "C."
6 7 CenterPoint Energy Contract# INT15-260A
1.19 "System Security Study" shall have the meaning as described in PUCT Rule
25.198(±) or its successor.
1.20 "TCOS" shall mean the TSP's transmission cost of service as allowed by the applicable Governmental Authority.
1.21 "TIF" shall mean the TSP's interconnection facilities as described in Exhibit "C" to this Agreement.
1.22 "Trial Operation" shall mean the process by which the Generator is engaged in on-site test operations and cmmnissioning of the Plant prior to Cmmnercial
Operation.
1.23 "TSP" shall mean the Transmission Service Provider.
1.24 "TSP System" shall mean the electric transmission facilities, including the
TIF, and all associated equipment and facilities owned and/or operated by the TSP.
ARTICLE 2. TERMINATION
2.1 Termination Procedures. This Agreement may be tenninated as follows:
A. the Generator may terminate this Agreement after giving the TSP thi11y
(30) days advance written notice; or
B. the TSP may terminate this Agreement (subject to Governmental
Authority approval, if required) on written notice to the Generator if the Generator's
Plant has not achieved Commercial Operation within one year after the scheduled
Commercial Operation date reflected in Exhibit "B"; or
C. either Party may terminate this Agreement in accordance with Section
10.6.
2.2 Termination Costs. If a Party elects to terminate the Agreement pursuant to
7 8 CenterPoint Energy Contract# INTI 5-260A
Section 2.1 above, the Generator shall pay all costs incurred (or committed to be incurred) by TSP, as of the date of the other Party's receipt of such notice ofteimination, that are the responsibility of the Generator under this Agreement. In the event of termination by either Party, both Pmiies shall use commercially reasonable efforts to mitigate the damages and charges that they may incur as a consequence of termination.
The provisions of the Sections 2.2 and 2.3 shall survive termination of the Agreement.
2.3 Disconnection. Upon tem1ination of this Agreement, the Pmiies will disconnect the GIP from the TIF.
ARTICLE 3. REGULATORY FILINGS
3 .1 Filing. The TSP shall file this executed Agreement with the appropriate
Governmental Authority, if required. Any portions of this Agreement asserted by
Generator to contain competitively sensitive commercial or financial information shall be filed by the TSP identified as "confidential" under seal stating, for the TSP's showing of good cause, that Generator asserts such information is confidential information and has requested such filing under seal. If requested by the TSP, Generator shall provide the
TSP, in writing, with the Generator's basis for asserting that the info1mation refe1rnd to in this Section 3.1 is competitively sensitive information, and the TSP may disclose such writing to the appropriate Governmental Authority.
3.2 Regulatory Approvals. Unless exempt, the TSP shall timely request ISO and all regulatory approvals necessary for it to carry out its responsibilities under this
Agreement. Such approvals shall include any CCN required for the construction of the
TIF.
8 9 CenterPoint Energy Contract# INTI 5-260A
ARTICLE 4. INTERCONNECTION FACILITIES ENGINEERING, PROCUREMENT, AND CONSTRUCTION
4.1 Options. The Generator shall select one of the following options (subsection A or
subsection B) and include the selected option in Exhibit "B" for completion of the TIF:
A. The TSP shall design, procure, and construct the TIF, using Reasonable
Efforts to complete the TIF by the In-Service Date reflected in Exhibit "B." The TSP will
utilize its own resources and will contract for additional resources, as reasonably
necessary, to meet the In-Service Date. Such resources shall include, as the TSP believes
is reasonable, use of other contractors, other equipment suppliers, other material
suppliers, additional contract personnel, additional payments to contractors for expedited
work, and premiums paid to equipment and material suppliers for expedited delivery.
The TSP shall not be required to undertake any initiative which is inconsistent with its
standard safety practices, its material and equipment specifications, its design criteria and
construction procedures, its labor agreements, applicable laws and regulations, and
ERCOT Requirements. In the event the TSP reasonably expects that it will not be able to
complete the TIF by the In-Service Date, the TSP will promptly provide written notice to
the Generator and will undertake Reasonable Efforts to meet the earliest date thereafter.
B. (i) The TSP shall design, procure, and construct the TIF by the In-Service
Date reflected in Exhibit "B." The Parties acknowledge that the In-Service Date was either agreed upon through good faith negotiations or designated by the Generator upon failure of the Parties to agree. In the process of negotiating the In-Service Date, Generator will request a date upon which it reasonably expects it will be ready to begin use of the
TIF and upon which it reasonably expects to begin doing so. Any date designated by the
Generator shall in no event be less than fifteen months from the date that all conditions of
9 10 CenterPoint Energy Cona·act # INTI 5-260A
Sections 4.2 and 4.3 have been satisfied. The designated In-Service Date will be extended day for day for each day that the ISO refuses to grant clearances to install equipment. If the TSP fails to complete the TIF by the In-Service Date reflected in Exhibit "B," the TSP shall pay the Generator liquidated damages in accordance with this Section 4.1.B.
(ii) The Pmiies agree that actual damages to the Generator, in the event the
TIF are not completed by the In-Service Date, may include Generator's fixed operation
and maintenance costs and lost oppmiunity costs. Such actual damages are uncertain and
impossible to dete1mine at this time. The Parties agree that, because of such unce1iainty,
any liquidated damages paid by the TSP to the Generator shall be an amount equal to Yz
of 1% of the actual cost of the TIF, per day. However, in no event shall the total
liquidated damages exceed 20% of the actual cost of the TIF. The Parties agree that such
liquidated damages are less than the Generator's actual damages. The Parties agree that the foregoing payments will be made by the TSP to the Generator as just compensation
for the damages caused to the Generator, which actual damages are unce1iain at1d
impossible to determine at this time, and as reasonable liquidated damages, but not as a
penalty or a method to secure performat1ce of this Agreement.
(iii) The TSP shall apply to have the full costs of the TIF included in TCOS. If
the PUCT issues a final, appealable order excluding from TCOS any portion of the TIF
costs, including higher contractor and vendor costs due to liquidated damage provisions
in those contracts and insurance costs to cover liquidated damages, which costs may have
been reasonably incurred but which the PUCT finds should not be recovered through
TCOS, the Generator shall reimburse the TSP for such costs in an amount not to exceed
the difference between the TSP's estimate of the cost of the TIF under section 4.1.A and
10 11 CenterPoint Energy Contract# INTI 5-260A the TSP's estimate of the cost of the TIF under Section 4.1.B as reflected in Exhibit "C."
Such costs shall be estimated using Good Utility Practice.
(iv) No liquidated damages shall be paid to Generator if the Generator is not ready to commence use of the TIF for the delivery of power to the Plant for Trial
Operation or export of power from the Plant on the In-Service Date, unless the Generator would have been able to commence use of the TIF for the delivery of power to the Plant for Trial Operation or export of power from the Plant but for TSP's delay.
(v) If the In-Service Date has been designated by the Generator upon a failure of the Parties to agree on the In-Service Date, the TSP may, at its option, require the
Generator to subcontract with the TSP for all or part of the design, procurement and construction of the TIF in accordance with the TSP's standard subcontractor agreements.
In such event, the TSP shall be subject to the payment of liquidated damages to the
Generator only if the In-Service Date is not met solely due to the TSP's failure to complete the pmiion of the TIF for which the TSP has retained responsibility. It is the intent of this subsection to give the TSP full control of the contents and quality of the
TIF. To the extent the Generator acts as a subcontractor to the TSP, the following will apply: 1) The Generator shall engineer, procure equipment, and construct the TIF (or pmiions thereof) using Good Utility Practice and using standards and specifications provided in advance by the TSP; 2) In its engineering, procurement and construction of the TIF, the Generator shall comply with all requirements oflaw to which the TSP would be subject in the engineering, procurement or construction of the TIF; 3) The TSP shall review and approve the engineering design, acceptance tests of equipment, and the construction of the TIF; 4) The TSP shall have the right to approve and accept for
II 12 CenterPoint Energy Contract# INTl5-260A operation the TIF in accordance with the standards and specifications provided in advance by the TSP, such approval and acceptance shall not be unreasonably withheld, conditioned, or delayed; 5) Should any phase of the engineering, equipment procurement, or construction of the TIF, including selection of subcontractors, not meet the standards and specifications provided by the TSP, and therefore be deemed unacceptable, then the
Generator shall be obligated to remedy that pmiion of the TIF or selection of subcontractors that is deemed unacceptable, the TSP's approval of the Generator's selection of subcontractors will not be unreasonably withheld, conditioned or delayed; and 6) Once the TIF is accepted for operation by the TSP, then the TSP shall reimburse the Generator for the reasonable and necessary costs incurred by the Generator to complete the TIF, not to exceed the amount specified in the subcontract. Such reimbursement shall be made within thirty days after receipt of the mvmce, unless otherwise agreed to by the Parties.
4.2 Equipment Procurement. If responsibility for construction of the TIF is borne by the TSP, then the TSP shall commence design of the TIF and procure necessary equipment within a reasonable time after all of the following conditions are satisfied:
A. The TSP has completed the Facilities Study pursuant to the Facilities
Study Agreement;
B. The TSP has received written authorization to proceed with design and procurement from the Generator by the date specified in Exhibit "B"; and
C. The Generator has provided security to the TSP in accordance with
Section 8.3 by the dates specified in Exhibit "B."
4.3 Construction Commencement. The TSP shall commence construction of the TIF
12 13 CenterPoint Energy Contract # INTI 5-260A as soon as practicable after the following additional conditions are satisfied:
A. Approval of the appropriate Governmental Authority has been obtained for any facilities requiring regulatory approval;
B. Necessary real prope1iy rights, if any, have been obtained;
C. The TSP has received written authorization to proceed with construction from the Generator by the date specified in Exhibit "B"; and
D. The Generator has provided security to the TSP in accordance with
Section 8.3 by the dates specified in Exhibit "B."
4.4 Work Progress. The Parties will keep each other advised periodically as to the progress of their respective design, procurement and construction efforts. If, at any time, the Generator becomes aware that the completion of the TIF will not be required until after the specified In-Service Date, the Generator will promptly provide written notice to the TSP of a new, later In-Service Date.
4.5 Conditions Precedent Delay. To the extent this Agreement incorporates a specified In-Service Date and the Generator fails to satisfy conditions precedent under
Sections 4.2 and 4.3 so that the TSP may meet the In-Service Date, the Parties will negotiate in good faith to establish a new schedule for completion of the TIF.
ARTICLE 5. FACILITIES AND EQUIPMENT
5.1 Information Exchange. The Pmiies shall exchange information and mutually agree upon the design and compatibility of the Parties' interconnection facilities. The
Pmiies shall work diligently and in good faith to make any necessary design changes to ensure compatibility of the GIF to the TSP System.
13 14 CenterPoint Energy Contract# INTI 5-260A
5.2 GIF Construction. Generator agrees to cause the GIF to be designed and constructed in accordance with Good Utility Practice, ERCOT Requirements and the
National Electrical Safety Code in effect at the time of construction. Within one-hundred and twenty (120) days after Commercial Operation, unless the Pmiies agree on another mutually acceptable deadline, the Generator shall deliver to the TSP the following "as built" drawings, information and documents for the GIF: a one-line diagram, a site plan showing the Plant and the GIF, plan and elevation drawings showing the layout of the
GIF, a relay functional diagram, relaying AC and DC schematic wiring diagrams and relay settings for all facilities associated with the Generator's main-power transformers, the facilities connecting the Generator to the main power transformers and the GIF, and the impedances (determined by factory tests) for the associated main power transformers and the generators.
5.3 TIF Construction. The TSP agrees to cause the TIF to be designed and constructed in accordance with Good Utility Practice, ERCOT Requirements and the
National Electrical Safety Code in effect at the time of construction.
5.4 Equipment Changes. For facilities not described in Exhibit "C," if either Party makes equipment changes to the Plant, the GIF, the TIF or the TSP System which it knows will affect the operation or perfmmance of the other Party's interconnection facilities, the Pmiies agree to notify the other Pmiy, in writing, of such changes. Such changes shall be made in accordance with ERCOT Requirements and coordinated between the Pmiies.
5.5 Metering, Telemetry and Conununications Requirements.
14 15 CenterPoint Energy Contract# INTl5-260A
A Metering and telemetry of data will be accomplished in accordance with
ERCOT Requirements. The specific metering, telemetry and communications equipment to be installed and data to be telemetered are described in Exhibit "C."
B. At the Point of Interconnection, the metering and telemetry equipment shall be owned by the TSP. However, the TSP shall provide the Generator with metering and telemetry values in accordance with ERCOT Requirements.
C. A minimum set of inputs to the telemetry equipment are specified in
Exhibit "C." Additional sets of inputs may be subsequently mutually agreed upon.
D. The TSP will notify the Generator at least five (5) working days m advance of any planned maintenance, inspection, testing, or calibration of the metering equipment, unless otherwise agreed to in writing. The Generator, or its designated representative, shall have the right to be present for these activities and to receive copies of any documents related to the procedures and results.
E. Prior to the connection of the GIF to the TIF, acceptance tests will be performed by the owning Patty to ensure the proper functioning of all metering, telemetry and communications equipment associated with the Point of Interconnection and both
Patties' interconnection facilities, and to verify the accuracy of data being received by the
TSP, the Control Area(s) in which the Plant and the TSP are located and the Generator.
All acceptance tests will be performed consistent with ERCOT Requirements.
F. The TSP shall, in accordance with Good Utility Practice and ERCOT
Requirements, specify communications facilities, including those necessary to transmit data from the metering equipment to the TSP, that are necessary for the effective operation of the Plant and the GIF with the TSP System. Such communication facilities
15 16 CenterPoint Energy Contract# INTl5-260A shall be included in Exhibit "C." The Generator shall make arrangements to procure and bear the cost of such facilities.
G. Any changes to the meters, telemetry equipment, voltage transformers, current transformers, and associated panels, hardware, conduit and cable, which will affect the data being received by the other Party must be mutually agreed to by the
Parties.
H. Each Party will promptly advise the other Party if it detects or othe1wise learns of any metering, telemetry or communications equipment errors or malfunctions that require the attention and/or c01rnction by the other Pmiy. The Pmiy owning such equipment shall c01Tect such error or malfunction as soon as reasonably feasible in accordance with ERCOT Requirements.
5.6 System Protection and Other Controls Requirements.
A. Each Party's facilities shall be designed to isolate any fault, or to c01Tect or isolate any abnormality, that would negatively affect the other Party's system or other entities connected to the TSP System.
B. The Generator shall be responsible for protection of its facilities consistent with ERCOT Requirements.
C. Each Party's protective relay design shall incorporate the necessary test switches to perform the tests required in Section 5.6.F. The required test switches will be placed such that they allow operation of lockout relays while preventing breaker failure schemes from operating and causing unnecessmy breaker operations and tripping the
Generator's units.
16 17 CenterPoint Energy Contract# INTI 5-260A
D. Recording equipment shall be installed to analyze all system disturbances in accordance with ERCOT Requirements.
E. Each Party will test, operate and maintain System Protection Equipment in accordance with ERCOT Requirements. Each Party will provide reasonable notice to the other Party of any testing of its System Protection Equipment allowing such other Party the opportunity to have representatives present during testing of its System Protection
Equipment.
F. Prior to the In-Service Date, and again prior to Commercial Operation, each Party or its agent shall perfo1m a complete calibration test and functional trip test of the System Protection Equipment. At intervals suggested by Good Utility Practice or at intervals described in the ERCOT Requirements if so defined therein, and following any apparent malfunction of the System Protection Equipment, each Party shall perform both calibration and functional trip tests of its System Protection Equipment. These tests do not require the tripping of any in-service generation unit. These tests do, however, require that all protective relays and lockout contacts be activated.
5.7 No A1111exation. Any and all equipment placed on the premises of a Party shall be
and remain the prope1iy of the Party providing such equipment regardless of the
mode and manner of annexation or attachment to real property, unless othe1wise
mutually agreed by the Pmiies.
ARTICLE 6. OPERATION AND MAINTENANCE
6.1 Operation and Maintenance of Interconnection Facilities. The Parties agree to operate and maintain their systems in accordance with Good Utility Practice, National
17 18 CenterPoint Energy Contract# INTl 5-260A
Electrical Safety Code, the ERCOT Requirements, PUCT Rules and all applicable laws and regulations. Subject to any necessary ISO approval, each Party shall provide necessary equipment outages to allow the other Paiiy to perform periodic maintenance, repair or replacement of its facilities. Such outages shall be scheduled at mutually agreeable times, unless conditions exist which a Party believes, in accordance with Good
Utility Practice, may endanger persons or property. No changes will be made in the normal operation of the Point of Interconnection without the mutual agreement of the
Parties except as otherwise provided herein. All testing of the Plant that affects the operation of the Point of Interconnection shall be coordinated between the TSP, the
Control Area(s) in which the Plant and the TSP are located, and the Generator and will be conducted in accordance with ERCOT Requirements.
6.2 Control Area Notification. At least six months before Trial Operation, the
Generator shall notify the TSP in writing of the Control Area in which it will be located.
If the Generator elects to be located in a Control Area other than the Control Area in which the TSP is located, all necessary agreements, including but not limited to remote control area generator interchange agreements, if applicable, and appropriate measures under such agreements, shall be executed and implemented prior to the placement of the
Plant in the other Control Area. The Parties will diligently cooperate with one another to enable such agreements to be executed and implemented on a schedule necessary to meet the Trial Operation date specified in Exhibit "B."
6.3 Land Rights ai1d Easements. Terms and conditions addressing the rights of the
TSP and the Generator regarding any facilities located on the other Party's property shall be addressed in a separate, duly executed and recorded easement agreement between the
18 19 CenterPoint Energy Contract# INTl5-260A
Pmiies. Prior to Commercial Operation, the Parties will mutually agree upon procedures
to govern access to each other's property as necessary for the Pmiies to fulfill their
obligations hereunder.
6.4 Service Interruption. The Pmiies recogmze that the interruption of service
provisions of the PUCT Rules give TSP the right to disconnect the TSP System from the
Plant under the conditions specified therein. The Generator will promptly disconnect the
Plant from the TSP System when required by and in accordance with the PUCT Rules
and ERCOT Requirements.
6.5 Switching and Clearance.
A. Any switching or clemances needed on the TIF or the GIF will be done in
accordance with ERCOT Requirements.
B. Any switching and clearance procedure necessary to comply with Good
Utility Practice or ERCOT Requirements that may have specific application to the Plant
shall be addressed in Exhibit "C."
6.6 Stmi-Up and Synchronization. Consistent with ERCOT Requirements and the
Pmiies' mutually acceptable procedure, the Generator is responsible for the proper
synchronization of the Plant to the TSP System.
6. 7 Routine Operational Communications. On a timely basis, the Parties shall
exchange all information necessary to comply with ER COT Requirements.
6.8 Blackstar! Operations. If the Plant is capable of blackstmi operations, Generator
will coordinate individual Plant stmi-up procedures consistent with ERCOT
Requirements. Any blackstart operations shall be conducted in accordance with the
blackstart criteria included in the ERCOT Requirements and the TSP Blackstar! Plan on
19 20 CenterPoint Energy Contract# INT15-260A file with the ISO. Notwithstanding this section, the Generator is not required to have blackstart capability by virtue of this Agreement. If the Generator will have blackstart capability, then Generator shall provide and maintain an emergency communication system that will interface with the TSP during a blackstart condition.
6.9 Power System Stabilizers. The Generator shall procure, install, maintain and operate power system stabilizers if required to meet ERCOT Requirements and as described in Exhibit "C."
ARTICLE 7. DATA REQUIREMENTS
7.1 Data Acquisition. The acquisition of data to realistically simulate the electrical behavior of system components is a fundamental requirement for the development of a reliable interconnected transmission system. Therefore, the TSP and the Generator shall be required to submit specific information regarding the electrical characteristics of their respective facilities to each other as described below in accordance with ERCOT
Requirements.
7.2 Initial Data Submission by TSP. The initial data submission by the TSP shall occur no later than 120 days prior to Trial Operation and shall include transmission system data necessary to allow the Generator to select equipment and meet any system protection and stability requirements.
7.3 Initial Data Submission by Generator. The initial data submission by the
Generator, including manufacturer data, shall occur no later than 90 days prior to the
Trial Operation and shall include a completed copy of the following forms contained in the ISO's Generation Interconnection Procedure: (!) Plant Description/Data and (2)
Generation Stability Data. It shall also include any additional data provided to the ISO
20 21 CenterPoint Energy Contract# INT15-260A for the System Security Study. Data in the initial submissions shall be the most current
Plant design or expected performance data. Data submitted for stability models shall be compatible with the ISO standard models. If there is no compatible model, the Generator will work with an ISO designated consultant to develop and supply a standard model and associated data.
7.4 Data Supplementation. Prior to Commercial Operation, the Pmiies shall supplement their initial data submissions with any and all "as-built" Plant data or "as tested" performance data which differs from the initial submissions or, alternatively, written confirmation that no such differences exist. Subsequent to Commercial
Operation, the Generator shall provide the TSP any data changes due to equipment replacement, repair, or adjustment. The TSP shall provide the Generator any data changes due to equipment replacement, repair, or adjustment in the directly co1111ected substation or any adjacent TSP-owned substation that may affect the GIF equipment ratings, protection or operating requirements. The Pmiies shall provide such data no later than 30 days after the date of the actual change in equipment characteristics. Also, the
Parties shall provide to each other a copy of any additional data later required by the ISO concerning these facilities.
7.5 Data Exchange. Each Party shall furnish to the other Party real-time and forecasted data as required by ERCOT Requirements. The Parties will cooperate with one another in the analysis of disturbances to either the Plant or the TSP's System by gathering and providing access to any information relating to any disturbance, including information from oscillography, protective relay targets, breaker operations and sequence of events records.
21 22 CenterPoint Energy Contract# INTI 5-260A
ARTICLE 8. PERFORMANCE OBLIGATION
8.1 Generator's Cost Responsibility. The Generator will acquire, construct, operate, test, maintain and own the Plant and the GIF at its sole expense. In addition, the
Generator may be required to make a contribution in aid of construction in the amount set out in and for the facilities described in Exhibit "C," if any, in accordance with PUCT
Rules.
8.2 TSP's Cost Responsibility. The TSP will acquire, own, operate, test, and maintain the TIP at its sole expense, subject to the provisions of Section 4.1.B and the conh·ibution in aid of construction provisions of Section 8.1 of this Agreement.
8.3 Financial Security Arrangements. The TSP may require the Generator to pay a reasonable deposit or provide another means of security, to cover the costs of planning, licensing, procuring equipment and materials, and constructing the TIP. The required security arrangements shall be specified in Exhibit "E." Within five business days after the Plant achieves Commercial Operation, the TSP shall return the deposit or security to the Generator. However, the TSP may retain an amount to cover the incremental difference between the TSP's actual out of pocket costs associated with the choice of
Section 4.1.B over Section 4.1.A, pending a final PUCT Order as contemplated in
Section 4.1.B(iii). If the Plant has not achieved Commercial Operation within one year after the scheduled Commercial Operation date identified in Exhibit "B" or if the
Generator terminates this Agreement in accordance with Section 2.1 and the TIF are not required, the TSP may, subject to the provisions of Section 2.2, retain as much of the deposit or security as is required to cover the costs it incmred in planning, licensing, procuring equipment and materials, and constructing the TIP. If a cash deposit is made
22 23 CenterPoint Energy Contract# INT15-260A pursuant to Exhibit "E," any repayment of such cash deposit shall include interest at a rate applicable to customer deposits as established from time to time by the PUCT or other Governmental Authority.
ARTICLE 9. INSURANCE
9 .1 Each Party shall, at its own expense, maintain in force throughout the period of this Agreement and until released by the other Party the following minimum insurance coverages, with insurers authorized to do business in Texas:
A. Employers Liability and Worker's Compensation Insurance providing statutory benefits in accordance with the laws and regulations of the State of Texas. The minimum limits for the Employer's Liability insurance shall be One Million Dollars
($1,000,000) each accident bodily injury by accident, One Million Dollars ($1,000,000) each employee bodily injury by disease, and One Million Dollars ($1,000,000) policy limit bodily injury by disease.
B. Commercial General Liability Insurance including premises and operations, personal injury, broad form property damage, broad form blanket contractual liability coverage (including coverage for the contractual indemnification) products and completed operations coverage, coverage for explosion, collapse and underground hazards, independent contractors coverage, coverage for pollution to the extent normally available and punitive damages to the extent normally available and a cross liability endorsement, with minimum limits of One Million Dollars ($1,000,000) per occun-ence/One Million Dollars ($1,000,000) aggregate combined single limit for personal injury, bodily injury, including death and property damage.
23 24 CenterPoint Energy Contract# INTl5-260A
C. Comprehensive Automobile Liability Insurance for coverage of owned, non-owned and hired vehicles, trailers or semi-trailers designed for travel on public roads, with a minimum combined single limit of One Million Dollars ($1,000,000) per occunence for bodily injury, including death, and propetiy damage.
D. Excess Public Liability Insurance over and above the Employer's
Liability, Commercial General Liability and Comprehensive Automobile Liability
Insurance coverage, with a minimum combined single limit of Twenty Million Dollars
($20,000,000) per occurrence/Twenty Million Dollars ($20,000,000) aggregate.
E. The Commercial General Liability Insurance, Comprehensive Automobile
Liability Insurance, and Excess Public Liability Insurance policies shall name the other
Party, its parent, associated and affiliated companies and their respective directors, officers, agents, servants and employees ("Other Party Group") as additional insured. All policies shall contain provisions whereby the insurers waive all rights of subrogation in accordance with the provisions of this Agreement against the Other Party Group and provide thirty (30) days advance written notice to Other Patiy Group prior to anniversary date of cancellation or any material change in coverage or condition.
F. The Commercial General Liability Insurance, Comprehensive Automobile
Liability Insurance and Excess Public Liability Insurance policies shall contain provisions that specify that the policies are primary and shall apply to such extent without consideration for other policies separately carried and shall state that each insured is provided coverage as though a separate policy had been issued to each, except the insurer's liability shall not be increased beyond the amount for which the insurer would
24 25 CenterPoint Energy Contract# INT15-260A have been liable had only one insured been covered. Each Party shall be responsible for its respective deductibles or retentions.
G. The Commercial General Liability Insurance, Comprehensive Automobile
Liability Insurance and Excess Public Liability Insurance policies, if written on a Claims
First Made basis, shall be maintained in full force and effect for two (2) years after termination of this Agreement, which coverage may be in the form of tail coverage or extended reporting period coverage if agreed by the Parties.
H. The requirements contained herein as to the types and limits of all insurance to be maintained by the Parties are not intended to and shall not in any manner, limit or qualify the liabilities and obligations assumed by the Parties under this
Agreement.
I. Within ten (I 0) days following execution of this Agreement, and as soon as practicable after the end of each fiscal year or at the renewal of the insurance policy and in any event within ninety (90) days thereafter, each Party shall provide ceitification of all insurance required in this Agreement, executed by each insurer or by an authorized representative of each insurer.
J. Notwithstanding the foregoing, each Pmiy may self-insure to the extent it maintains a self-insurance program; provided that, such Party's senior secured debt is rated at investment grade, or better, by Standard & Poor's. For any period of time that a
Party's senior secured debt is unrated by Standard & Poor's or is rated at less than investment grade by Standard & Poor's, such Party shall comply with the insurance requirements applicable to it under Sections 9.1.A through 9.1.I. In the event that a Patty
25 26 CenterPoint Energy Contract# INTl 5-260A is pennitted to self-insure pursuant to this Section 9.1.J, it shall not be required to comply with the insurance requirements applicable to it under Sections 9. I.A through 9. I. I.
K. The Paities agree to repoti to each other in writing as soon as practical all accidents or occurrences resulting in injuries to any person, including death, and any property damage arising out of this Agreement.
ARTICLE 10. MISCELLANEOUS
10.1 Governing Law and Applicable Tariffs.
A. This Agreement for all purposes shall be construed in accordance with and governed by the laws of the State of Texas, excluding conflicts of law principles that would refer to the laws of another jurisdiction. The Parties submit to the jurisdiction of the federal and state courts in the State of Texas.
B. This Agreement is subject to all valid, applicable rules, regulations and orders of, and tariffs approved by, duly constituted Governmental Authorities.
C. Each Party expressly reserves the right to seek chai1ges in, appeal, or otherwise contest any laws, orders, rules, or regulations of a Governmental Authority.
10.2 No Other Services. This Agreement is applicable only to the interconnection of the Plmt to the TSP System at the Point of Interconnection and does not obligate either
Party to provide, or entitle either Party to receive, any service not expressly provided for herein. Each Party is responsible for making the arrangements necessary for it to receive my other service fuat it may desire from the other Party or any third party. This
Agreement does not address the sale or purchase of any electric energy, transmission service or ancillary services by either Party, either before or after Commercial Operation.
26 27 CenterPoint Energy Contract# INT l 5-260A
I 0.3 Entire Agreement. This Agreement, including all Exhibits, Attachments and
Schedules attached hereto, constitutes the entire agreement between the Pmiies with reference to the subject matter hereof, and supersedes all prior m1d contemporaneous understandings or agreements, oral or written, between the Pmiies with respect to the subject matter of this Agreement. There are no other agreements, representations, warranties, or covenants which constitute any pmi of the consideration for, or any condition to, either Party's compliance with its obligations under this Agreement.
Notwithstanding the other provisions of this Section, the Facilities Study Agreement, if any, is unaffected by this Agreement.
I 0.4 Notices. Except as otherwise provided in Exhibit "D," any formal notice, demand or request provided for in this Agreement shall be in writing and shall be deemed properly served, given or made if delivered in person, or sent by either registered or certified mail, postage prepaid, overnight mail or fax to the address or number identified on Exhibit "D" attached to this Agreement. Either Pmiy may change the notice information on Exhibit "D" by giving five business days written notice prior to the effective date of the change.
10.5 Force Majeure.
A. The term "Force Majeure" as used herein shall mean any cause beyond the reasonable control of the Party claiming Force Majeure, and without the fault or negligence of such Pmiy, which materially prevents or impairs the performallce of such
Party's obligations hereunder, including but not limited to, storm, flood, lightning, earthquake, fire, explosion, failure or imminent threat of failure of facilities, civil
27 28 CenterPoint Energy Contract# INTI 5-260A disturbance, strike or other labor disturbance, sabotage, war, national emergency, or restraint by any Governmental Authority.
B. Neither Party shall be considered to be in Default (as hereinafter defined) with respect to any obligation hereunder (including obligations under Article 4), other than the obligation to pay money when due, if prevented from fulfilling such obligation by Force Majeure. A Party unable to fulfill any obligation hereunder (other than an obligation to pay money when due) by reason of Force Majeure shall give notice and the full pmiiculars of such Force Majeure to the other Party in writing or by telephone as soon as reasonably possible after the occurrence of the cause relied upon. Telephone notices given pursuant to this Section shall be confamed in writing as soon as reasonably possible and shall specifically state full pmiiculms of the Force Majeure, the time and date when the Force Majeure occurred and when the Force Majeure is reasonably expected to cease. The Pmiy affected shall exercise due diligence to remove such disability with reasonable dispatch, but shall not be required to accede or agree to any provision not satisfactory to it in order to settle and te1minate a strike or other labor disturbance.
10.6 Default
A. The term "Default" shall mean the failure of either Party to perfmm any obligation in the time or manner provided in this Agreement. No Default shall exist where such failure to discharge an obligation (other than the payment of money) is the result of Force Majeure as defined in this Agreement or the result of an act or omission of the other Party. Upon a Default, the non-defaulting Pmiy shall give written notice of such Default to the defaulting Party. Except as provided in Section 10.6.B, the defaulting
28 29 CenterPoint Energy Contract# INTl 5-260A
Party shall have thitty (30) days from receipt of the Default notice within which to cure such Default; provided however, if such Default is not capable of cure within 30 days, the defaulting Party shall commence such cure within 30 days after notice and continuously and diligently complete such cure within 90 days from receipt of the Default notice; and, if cured within such time, the Default specified in such notice shall cease to exist.
B. If a Default is not cured as provided in this Section, or if a Default is not capable of being cured within the period provided for herein, the non-defaulting Party shall have the right to tenninate this Agreement by written notice at any time until cure occurs, and be relieved of any further obligation hereunder and, whether or not that Pmty terminates this Agreement, to recover from the defaulting Pmty all amounts due hereunder, plus all other damages and remedies to which it is entitled at law or in equity.
The provisions of this Section will survive termination of this Agreement.
10.7 Intrastate Operation. The operation of the Plant by Generator shall not cause there to be a synchronous or an asynchronous interconnection between ERCOT and any other transmission facilities operated outside of ERCOT unless ordered by the Federal
Energy Regulatory Commission under Section 210 of the Federal Power Act. The Parties recognize and agree that any such interconnection will constitute an adverse condition giving the TSP the right to immediately disconnect the TIP from the GIP, until such interconnection has been disconnected. The Generator will not be prohibited by this
Section from interconnecting the Plant with facilities operated by the Comision Federal de Electricidad of Mexico, unless such interconnection would cause ERCOT utilities that are not "public utilities" under the Federal Power Act to become subject to the plenary jurisdiction of the Federal Energy Regulatory Commission.
29 30 CenterPoint Energy Contract# INTI 5-260A
10.8 No Third Party Beneficiaries. This Agreement is not intended to and does not create rights, remedies, or benefits of any character whatsoever in favor of any persons, corporations, associations, or entities other than the Patiies, and the obligations herein assumed are solely for the use and benefit of the Parties, their successors in interest and, where pe1mitted, their assigns.
10.9 No Waiver. The failure of a Party to this Agreement to insist, on any occasion, upon strict performance of any provision of this Agreement will not be considered a waiver of obligations, rights, or duties imposed upon the Parties. Termination or Default of this Agreement for any reason by the Generator shall not constitute a waiver of the
Generator's legal rights to obtain an interconnection from the TSP under a new interconnection agreement.
10.10 Headings. The descriptive headings of the various articles and sections of this
Agreement have been inserted for convenience of reference only and are of no significance in the interpretation or construction of this Agreement.
10.11 Multiple Counterpmis. This Agreement may be executed m two or more counterparts, each of which is deemed an original but all constitute one and the same instrument.
10.12 Amendment. This Agreement may be amended only upon mutual agreement of the Pmiies, which amendment will not be effective until reduced to writing and executed by the Parties.
10.13 No Partnership. This Agreement shall not be interpreted or construed to create an association, joint venture, agency relationship, or patinership between the Pmiies or to impose any pminership obligation or liability upon either Party. Neither Party shall have
30 31 CenterPoint Energy Contract# INT15-260A any right, power or authority to enter into any agreement or undertaking for, or act on behalf of, or to act as or be an agent or representative of, or to otherwise bind, the other
Party.
I 0.14 Further Assurances. The Pmiies agree to (i) furnish upon request to each other such further information, (ii) execute and deliver to each other such other documents, and
(iii) do such other acts and things, all as the other Party may reasonably request for the purpose of carrying out the intent of this Agreement and the documents refetTed to in this
Agreement. Without limiting the generality of the foregoing, the TSP shall, at the
Generator's expense, when reasonably requested to do so by the Generator at any time after the execution of this Agreement, prepare and provide such infonnation in connection with this Agreement (including, if available, resolutions, certificates, opinions of counsel or other documents relating to the TSP's corporate authorization to enter into this Agreement and to undertake the obligations set out herein) as may be reasonably required by any potential lender to the Generator under a proposed loan agreement. The
TSP will use commercially reasonable efforts to obtain any opinion of counsel reasonably requested by Generator, but the TSP shall not be in Default of any obligation under this
Agreement if the TSP is unable to provide an opinion of counsel that will satisfy any potential lender to the Generator. Specifically, upon the written request of one Party, the other Pmiy shall provide the requesting Party with a letter stating whether or not, up to the date of the letter, that Party is satisfied with the perfotmance of the requesting Party under this Agreement.
10.15 Indemnification and Liability. The indemnification and liability provisions of the
PUCT Rule 25.202(b)(2) or its successor shall govern this Agreement.
31 32 CenterPoint Energy Contract# INTI 5-260A
10.16 Consequential Damages. OTHER THAN THE LIQUIDATED DAMAGES
HERETOFORE DESCRIBED, IN NO EVENT SHALL EITHER PARTY BE LIABLE
UNDER ANY PROVISION OF THIS AGREEMENT FOR ANY LOSSES,
DAMAGES, COSTS OR EXPENSES FOR ANY SPECIAL, INDIRECT,
INCIDENT AL, CONSEQUENTIAL, OR PUNITIVE DAMAGES, INCLUDING BUT
NOT LIMITED TO LOSS OF PROFIT OR REVENUE, LOSS OF THE USE OF
EQUIPMENT, COST OF CAPITAL, COST OF TEMPORARY EQUIPMENT OR
SERVICES, WHETHER BASED IN WHOLE OR IN PART IN CONTRACT, IN
TORT, INCLUDING NEGLIGENCE, STRICT LIABILITY, OR ANY OTHER
THEORY OF LIABILITY; PROVIDED, HOWEVER, THAT DAMAGES FOR
WHICH A PARTY MAY BE LIABLE TO THE OTHER PARTY UNDER ANOTHER
AGREEMENT WILL NOT BE CONSIDERED TO BE SPECIAL, INDIRECT,
INCIDENTAL, OR CONSEQUENTIAL DAMAGES HEREUNDER.
10.17 Assignment. This Agreement may be assigned by either Party only with the written consent of the other; provided that either Party may assign this Agreement without the consent of the other Party to any affiliate of the assigning Party with an equal or greater credit rating and with the legal authority and operational ability to satisfy the obligations of the assigning Party under this Agreement; and provided further that the
Generator shall have the right to assign this Agreement, without the consent of the TSP, for collateral security purposes to aid in providing financing for the Plant, provided that the Generator will require any secured patiy, trustee or m01igagee to notify the TSP of any such assignment. Any financing arrangement entered into by the Generator pursuant to this Section will provide that prior to or upon the exercise of the secured party's,
32 33 CenterPoint Energy Contract# INT l 5-260A trustee's or mortgagee's assignment rights pursuant to said arrangement, the secured creditor, the trustee or mortgagee will notify the TSP of the date and particulars of any such exercise of assignment right(s). Any attempted assignment that violates this Section is void and ineffective. Any assignment under this Agreement shall not relieve a Party of its obligations, nor shall a Party's obligations be enlarged, in whole or in part, by reason thereof. Where required, consent to assigmnent will not be unreasonably withheld, conditioned or delayed.
10.18 Severability. If any provision 111 this Agreement is finally determined to be invalid, void or unenforceable by any court having jurisdiction, such determination shall not invalidate, void or make unenforceable any other provision, agreement or covenant of this Agreement; provided that if the Generator (or any third-party, but only if such third party is not acting at the direction of the TSP) seeks and obtains such a final determination with respect to any provision of Section 4.1.B, then none of the provisions of Section 4.1.B. shall thereafter have any force or effect and the Pmties' rights and obligations shall be governed solely by Section 4.1.A.
10.19 Comparability. The Parties will comply with all applicable comparability and code of conduct laws, rules and regulations, as amended from time to time.
10.20 Invoicing and Payment. Unless the Pmties otherwise agree (in a manner permitted by applicable PUCT Rules and as specified in writing in an Exhibit "E" attached hereto), invoicing and payment rights and obligations under this Agreement shall be governed by PUCT Rules or applicable Governmental Authority. Invoices shall be rendered to the paying Party at the address specified on, and payments shall be made in accordance with the requirements of, Exhibit "D."
33 34 CenterPoint Energy Contract# INTI 5-260A
10.21 Confidentiality.
A. Subject to the exception in Section 10.21.B, any information that a Party claims is competitively sensitive, commercial or financial information under this
Agreement ("Confidential Information") shall not be disclosed by the other Party to any person not employed or retained by the other Party, except to the extent disclosure is (i) required by law; (ii) reasonably deemed by the disclosing Party to be required to be disclosed in connection with a dispute between or among the Pmiies, or the defense of litigation or dispute; (iii) otherwise pe1mitted by consent of the other Party, such consent not to be umeasonably withheld; or (iv) necessary to fulfill its obligations under this
Agreement or as a tratismission service provider or a Control Area operator including disclosing the Confidential Information to the ISO. The Party asse1iing confidentiality shall notify the other Party in writing of the information it claims is confidential. Prior to any disclosures of the other Party's Confidential Information under this subsection, or if any third pmiy or Governmental Authority makes any request or demand for any of the information described in this subsection, the disclosing Party agrees to promptly notify the other Party in writing and agrees to assert confidentiality atid cooperate with the other
Pmiy in seeking to protect the Confidential Infonnation from public disclosure by confidentiality agreement, protective order or other reasonable measures.
B. This provision shall not apply to any information that was or is hereafter in the public domain (except as a result of a breach of this provision).
34 35 CenterPoint Energy Contract# INTl5-260A
Exhibit "B" Time Schedule
1) Interconnection Option chosen by Generator (check one): X Section 4.1.A. or Section 4.1.B
A) If Section 4.1.B is chosen by Generator, the In-Service Date(s) was determined by (check one): (1) NIA good faith negotiations, or (2) N/A designated by Generator upon failure to agree.
2) October 16, 2015 is the date ("NTP Need Date") by which Generator must provide a written Notice to Proceed with design, procurement, and construction of the TIF and provide security, as specified in Exhibit "A", Section 4.2 and 4.3, so that TSP may maintain schedule to meet the In-Service Date. A) If Generator does not provide a written Notice to Proceed to TSP by the above NTP Need Date, the designated TIF In-Service Date, Scheduled Generation Trial Operation Date, and Scheduled Generation Commercial Operation Date, identified below, will each be extended day for day for each day after the NTP Need Date that the Notice to Proceed is delayed. B) If Generator does not provide a written Notice to Proceed (or provide security in accordance with Exhibit "E") to TSP by 12 months after the above date ("NTP Deadline"), such non-provision of the Notice to Proceed shall constitute a Default, in accordance with Section 10.6.A of Exhibit "A", by the Generator and written notice of Default shall be deemed to have been given by TSP to Generator on the NTP Deadline. If such Default is not cured in accordance with Section 10.6 of Exhibit "A", then TSP may terminate this Agreement in accordance with the provisions of Section 10.6.B of Exhibit "A".
TIF In-Service Date: 15 months after Notice to Proceed is given, this agreement is executed and security is provided.
Scheduled Generation Commercial Operation Date: 3 months after the TIF In-Service Date.
3) In addition to day-for-day delays caused by the Generator not providing a written Notice to Proceed by the NTP Need Date, the designated TIF In-Service Date and Scheduled Commercial Operation Date will each be extended day-for-day for: A) each day after 180 calendar days after the date that Notice to Proceed was given that real property access rights for TSP to access the substation property are not in place; and B) each day after the date that Notice to Proceed was given that security arrangements outlined in Exhibit "A", Article 8, Paragraph 8.3, Financial Security Arrangements, and Exhibit "E" are not in place. C) each day that ERCOT does not grant outages as required by TSP to perform work that must be accomplished to connect the Generator to the ERCOT transmission system.
35 36 CenterPoint Energy Contract# INTI 5-260A
4) Due to the nature of the subject of this Agreement, the Patties may mutually agree to change the dates and times of this Exhibit B.
36 37 CenterPoint Energy Contr·act # INTI 5-260A
Exhibit "C" Interconnection Details
1) Name: Friendswood Energy Generation Project ("Plant").
2) Point oflnterconnection Location A) TSP system side of Generator's terminating structure near TSP's H. 0. Clarke Substation, located at 12100 Hiram Clarke Road, Houston, Haffis County, Texas.
3) Delivery Voltage: 138 kV
4) Number and Size of Generating Units A) Plant will be comprised of one generator with a total net rating of 129 MW ("Planned Capacity"), which is projected to be the Plant's Net Dependable Capability, as defined by ERCOT Requirements.
5) Type of Generating Unit A) One Westinghouse 501D5 natural gas fired combustion turbine generator rated at approximately 129 MW. The electric generating unit has its own 13.8 kV - 138 kV step-up (main power) transformer, with the 13.8 kV winding connected to plant auxiliary transformers as well as the units generator through a generator breaker. B) Each step-up transformer will have a circuit breaker for isolation from the TIF. C) Electrical characteristics of Plant's generating unit(s) shall be in accordance with the most recent version of data that Generator has provided to TSP and shall be consistent with data provided to ERCOT.
6) Metering and Telemetry Equipment A) TSP will provide and install ERCOT Polled Settlement (EPS) primary and check meters, 138 kV instrument transformers and associated wiring required for measuring the output of the Plant generation and the Plant auxiliary electrical load. TSP will install and maintain the metering system's components in a manner consistent with ERCOT Requirements and the PUC Substantive Rules. B) TSP shall furnish a substation Supervisory Control & Data Acquisition (SCADA) Remote Terminal Unit (RTU) at the H. 0. Clarke Substation. The RTU will be multi-pmi equipped and operate with protocols compatible with TSP. The RTU will be equipped to monitor the H. 0. Clarke Substation as outlined in Paragraph 11 and control circuit breakers in the H. 0. Clarke Substation. TSP shall also furnish the RTU inputs, such as contacts and transducers, in the H. 0. Clarke Substation. Selected real-time data of the H. 0. Clarke Substation will be available at TSP's RTU for Generator's use. TSP's RTU will be equipped with a MODBUS "Master" communications port for this purpose. TSP shall furnish the fiber optic cable between the H. 0. Clarke Substation and the Plant RTU/DCS "Slave" communications port for this purpose as specified in section 8)G of this Exhibit "C''.
37 38 CenterPoint Energy Contract # INTI 5-260A
C) Generator shall furnish Plant data to TSP's RTU connnunication pmi at the H. 0. Clarke Substation as referenced in Paragraph 11 below. The Generator's RTU/DCS will be equipped with a MODBUS "Master" conununications port for this purpose. TSP shall furnish the fiber optic cable between the Plant and the H. 0. Clarke Substation RTU "Slave" communications port for this purpose as specified in section 8)G of this Exhibit "C".
7) Generator Interconnection Facilities A) Generator shall furnish, operate and maintain a complete generation facility capable of generating the Planned Capacity, including, but not limited to, all generators, power system stabilizers, generator step-up transformers, protective devices, and other transformers and associated foundations, the terminating structures, all relays necessary for the protection, synchronization and coordination of the generators, generator auxiliary equipment and the disconnect switches and foundations at the Point ofintercormection. B) The Generation unit(s) shall meet all voltage and reactive requirements as outlined in the ERCOT Protocols and ERCOT Operating Guides. C) Generator shall provide the foundations for Plant's terminating structure(s)/disconnecting device(s). Generator shall design and install the Plant's tenninating structure(s)/dead-end rack(s)/ disconnecting device(s) in accordance with TSP's conductor loading requirements. D) Generator shall connect its generating Plant ground mat to TSP's transmission tower static wires at the Plant's terminating structure(s). E) Electrical characteristics of Plant's Generator Interconnection Facilities shall be in accordance with the most recent version ofTSP's "Specification for Customer 138 kV Substation Design" attached as Exhibit "I" and in patiicular, the section pe1iaining to "Generation". F) Generator shall provide a disconnect switch located on Generator's dead-end structure for connection to TSP System. G) Generator shall provide ground and aerial easements, in a form acceptable to TSP, as requested by TSP, from Plant's terminating structure(s)/high-side disconnecting device(s) to the H. 0. Clarke Substation. H) Generator shall provide and maintain two separate conduits in one or more duct banks for the two separate fiber optic cables ("Control Duct Bank") to the Generator's terminating structure located at the point of interconnection. I) Generator shall own all protective relays, insh·ument transformers, instrumentation, and control equipment physically located on Plant side of the Point( s) of Interconnection.
38 39 CenterPoint Energy Contract# INTl5-260A
8) TSP Interconnection Facilities A) TSP shall complete its entire scope of work on the H. 0. Clarke Substation (except for Punch List Items) including, but not limited to, bus works, supports, structures, circuit breakers, disconnect switches, relays and other equipment necessary for protection and coordination, controls, and wiring all as necessary to provide an interconnection between Plant's generation facilities and TSP's System; energize the same, and interconnect with Plant, all as provided herein. 1) Punch List Items are defined as those non-material items of work that remain to be perfmmed in order to ensure full compliance with this Agreement. Punch List Items do not include any items of work, alone or in the aggregate, non-completion of which (i) prevents the H. 0. Clarke Substation from being used for its intended purposes as described in this Agreement or in accordance with applicable Jaws; (ii) prevents the H. 0. Clarke Substation from being legally, safely and reliably placed in commercial operation; or (iii) in the exercise of reasonable engineering judgment could have an adverse effect on the operation, efficiency or reliability of the H. 0. Clarke Substation, or its ability to transmit the Plant's power to the ERCOT grid. B) TSP shall furnish, own and maintain the connection from TSP's equipment to Plant's terminating structure/discom1ecting device, including phase conductors, static conductors, structure( s ), tower fittings, suspension insulators, dead-end clamps and line conductor tetminal fittings. C) TSP shall furnish, own and maintain the connection from H. 0. Clarke Substation to TSP's transmission system. D) TSP shall develop and install transmission improvements that it dete1mines, in its sole discretion, are foreseeable and reasonably necessary to safely, reliably, and economically integrate Plant's generation into TSP's Transmission System. TSP MAKES NO PROMISE, REPRESENTATION, OR WARRANTY AS TO WHETHER TSP'S TRANSMISSION SYSTEM WILL BE FREE OF CONSTRAINTS AT ANY TIME, INCLUDING BUT NOT LIMITED TO TIMES WHEN THE TRANSMISSION IMPROVEMENTS UNDER THIS AGREEMENT ARE BEING MADE OR AFTER THEIR COMPLETION. E) TSP shall expand its existing H. 0. Clarke Substation as shown on drawing entitled "Basic Offer CenterPoint Energy 138 kV Development Plan For Friendswood Energy/H.O. Clarke Project dated 09/16/15 ("H. 0. Clarke Substation Development Plan"). F) TSP shall request from Generator ground and aerial easements, in a form acceptable to TSP, from Plant's terminating structure(s)/high-side disconnecting device(s) to the H. 0. Clarke Substation. G) TSP shall provide two separate fiber optic communication cables for communication, instrumentation, and protective relaying circuits of sufficient length to connect from TSP's H.O. Clarke Substation to Generator's fiber termination panel. TSP shall only be responsible for pulling fiber optic communication cables from the H.O. Clarke Substation to the Generator's terminating structure located at the Point of Interconnection.
39 40 CenterPoint Energy Contract# INT15-260A
9) Communications Facilities A) TSP shall order and pay for and maintain a communication circuit for real-time data transmittal via SCADA equipment from the H. 0. Clmke Substation to TSP's Energy Management System. B) Generator shall provide fiber optic communication interface device on their end of the fiber and TSP will provide a fiber optic commw1ication interface device on their end associated with the RTU inputs between Plant and the H. 0. Clarke Substation. C) Generator will furnish RTU inputs identified in Exhibit "C", Paragraph l l)A) from the Plant to the H. 0. Clarke Substation's communication interface point. D) Generator shall provide a voice telephone extension outlet in close proximity to Plant's relay panel that is located within the Plant. Such telephone extension outlet shall be connected to the local exchange carrier's telephone system and not go through the Generator's main switchboard or extension; however, the telephone extension outlet may be connected to Plant's internal telephone system, provided Plant's internal telephone system is equipped with an nninterruptible power supply system. E) TSP shall furnish RTU inputs identified in Exhibit "C", Pmagraph l l)D) from the H. 0. Clarke Substation to Plant's communication interface termination point.
10) System Protection Equipment A) Generator shall provide two sets of protective relaying accuracy (C800) current transformers on Generator's 138 kV circuit breaker associated with the protective relaying between Plant and the H. 0. Clarke Substation. Each set of cunent transformers will provide signals to independent sets of primary and backup protective relays for the interc01mecting lead between the GIF and the H. 0. Clarke substation. The current transformer ratio will be specified on the one-line relaying and metering diagram.
11) Inputs to Telemetry Equipment A) Generator will provide to TSP at TSP's H. 0. Clarke Substation the following signals originating at Generator's Plant: 1) Analog Data From Plant (i) Kilovolts for the generator bus (one phase only). (ii) Frequency of the generating unit, if available. (iii)Net megawatts for the generating unit. (iv)Net megavars for the generating unit. 2) Status Data From Plant (i) Status of the 138 kV transmission voltage circuit breaker, 13.8 kV generator circuit breaker. (ii) Status of generator automatic voltage regulator (automatic/manual) for the generating unit. B) TSP will provide to Generator the following data originating at TSP's H. 0. Clarke Substation: 1) Analog Data From TSP Substation Devices (i) Kilovolts for the Point of Interconnection (one phase).
40 41 CenterPoint Energy Contract# INTI 5-260A
(ii) Megawatts, megavars, and megawatt-hour data from TSP EPS meter. 2) Status Data From TSP Substation Devices (i) For instance, status of transmission voltage circuit breakers (ii) Alarm for failure of fiber optic relaying communication channels.
12) Supplemental Terms and Conditions A) The following drawings are attached and made a patt of this agreement as Exhibit "I" - Attached Drawings. (Note: The drawings contain a line of demarcation between TSP provided facilities and Generator provided facilities). 1) Basic Offer CenterPoint Energy 138 kV Development Plan For Friendswood Energy/H.O. Clarke Project dated09/16/2015. 2) Basic Offer 138 kV CenterPoint Energy One Line Relaying & Metering Diagram for Friendswood Energy/I-LO. Clarke Project dated 09/16/15. B) Cost Responsibility: 1) Notwithstanding the provisions of Exhibit "A", Section 8.1, the amount of the contribution in aid of construction, if any, which Generator may be required to make, shall be specified in Exhibit "E", Security Arrangement Details. 2) The Generator does not desire any enhancements to TSP's basic offer interconnection facilities and therefore no contribution in aid of construction ("CIAC") of the Transmission Interconnection Facilities is required. 3) The TIF described herein is designed based on the generating capacity provided by the Generator. It is assumed that the generating facility will be capable of generating the Planned Capacity by the Scheduled Conunercial Operation Date specified in Exhibit "B". Within the first 12 months following Commercial Operation, if the highest level of Actual Capacity is less than the Planned Capacity, the Generator shall be responsible for TIF costs, if any, that are determined, solely by the TSP, to have been incurred to accommodate Generator's Planned Capacity, but are then determined to not be necessary to accommodate Generator's Actual Capacity. As used here, "Actual Capacity" shall mean the Plant's total Net Dependable Capability, as determined or accepted by ERCOT, in accordance with ERCOT Requirements. Generator shall pay such costs determined herein within thirty (30) days following the receipt ofTSP's invoice. C) Clarifications to Exhibit "A" 1) The Patties agree that at the time of executing this Agreement the references to the PUCT Rules contained within certain definitions set fmth in Exhibit "A", "A1ticle 1. Definitions" have the meanings ascribed to such terms as established in the current PUCT Rules. The Parties recognize that the PUCT Rules are amended from time to time by the PUCT. The patties also acknowledge that ERCOT issues ERCOT Requirements in which terms are redefined from time to time. When the PUCT Rules or ERCOT Requirements are amended and terms defined in Exhibit "A", "A1ticle I. Definitions" are affected by such amendments, the Patties agree that such terms shall have the meanings as amended by the PUCT or ERCOT. The term "System Security Study" shall have the same definition as "Security Screening Study" in the ERCOT Requirements.
41 42 CenterPoint Energy Contract# JNT15-260A
D) Miscellaneous 1) Each Party shall be solely responsible for keeping itself informed of, and understanding its respective responsibilities under, all applicable North American Electric Reliability Corporation ("NERC") Standards and ERCOT Requirements and all valid, applicable laws, rules, regulations and orders of, and tariffs approved by, duly constituted Governmental Authorities. 2) Generator will provide on its property, access roads to the TIF and such access roads will be maintained by Generator in such a manner and condition to allow passage of heavy utility vehicles. 3) Each Party's personnel, contractors, subcontractors and agents shall abide by and comply with the other Party's safety requirements and procedures while in areas designated as under that other Pmty' s control. 4) In the event that Generator's personnel, contractors, subcontractors, or agents cause delays in the work schedule of TSP, Generator shall reimburse to TSP the additional costs associated with such delays within 30 days of receipt of an invoice for such costs. 5) Generator understands and agrees that identification of any stability or oscillation condition that may affect Generator's Plant, and implementation of any associated protective measures, are the sole responsibility of Generator. 6) ERCOT Requirements. (i) Unless expressly stated herein, where the ERCOT Requirements are in conflict with TSP's specifications or procedures, the ERCOT Requirements shall prevail. (ii) ERCOT requirements cun-ently require installation of power system stabilizers on generators. (iii)Prior to commercial operation ERCOT may verify that the Generator is meeting ERCOT requirements including complying with reactive standards, the provision of accurate stability models and the installation of power system stabilizers, if required. Failure to meet these ERCOT requirements may result in delays to commercial operation. Additionally, ERCOT recommends that wind fmms fulfill the NERC/FERC under-voltage ride through capability requirements. 7) All generator data including data for stability studies (transient, voltage, etc ... ) and subsynchronous resonance (SSR) data, as required by the ERCOT Requirements, will be provided to ERCOT and the TSP before commercial operation. This data shall be updated when the Plant goes into commercial operation. Any updates to this information will be provided within 60 days to ERCOT and the TSP as changes or upgrades are made during the life of the Plant. This requirement applies to all future owners of the Plant. The Generator and any future owners of the Plant shall comply with these data requirements along with all applicable NERC requirements. Such requirements m·e subject to change from time to time, and such changes shall automatically become applicable based upon the effective date of the approved change. 13) Special Operating Conditions, if any, attached:
42 43 CenterPoint Energy Contract# INTI 5-260A
14) Cost Estimate Differences, if applicable: A) The difference between the estimated cost of the TIF under 4.1.A ($_NIA___) and the estimated cost of the TIF under 4.1.B ($_NIA is: NIA , if applicable.
43 44 DA TE: September 2015 Exhibit "D" Notice and EFT Information of the ERCOT Standard Generation Interconnection Agreement
(a) All notices of an OPERATIONAL nature shall be in writing and/or may be sent between the Parties via electronic means including facsimile as follows: Ifto Friendswood Energy Genco, LLC Ifto CenterPoint Energy Houston Electric, LlC
Friendswood Project CenterPoint Energy Houston Electric, LLC Attn: Kenny Koncaba Attn: Real Time Operations Address 19 11 Creekwood Lane P.O. Box 1700 City, State, Zip Friendswood, TX 77546 Houston, Texas 77251 24 Hour Telephone (28 1) 73 1-6323 24 Hour Telephone 713-207-2393 Operational/Confirmation Fax (28 1) 482-1 637 Operational/Confirmation Fax 713-207-2349 E-mail kenny.koncaba@friendswoodcapita l.com
(b) Notices of an ADMINISTRATIVE nature: If to Friendswood Energy Genco, LLC lfto CenterPoint Energy Houston Electric, LLC
Company Name Friendswood Energy Genco, LLC CenterPoint Energy Houston Elech·ic, LLC Attn: Kenny Koncaba Manager, Transmission Accounts Address 1911 Creek wood Lane P.O. Box 1700 City, State, Zip Friendswood, TX 77546 Houston, TX 7725 l Phone: (28 l) 731-6323 Phone 713-207-7617 Fax: (28 1) 482-1637 Fax: 713-207-9122 E-mail [email protected] E-mail: [email protected]
(c) Notice for STATEMENT AND BILLING purposes: Ifto Friendswood Energy Genco, LLC lfto CenterPoint Energy Houston Electric, llC
Company Name Friendswood Energy Genco, LLC Accounts Payable Attn: Kenny Koncaba P.O. Box 1374 Address 1911 Creekwood Lane Houston, TX 77251-1 374 City, State, Zip Friendswood, TX 77546 Phone 713-207-7888 Phone: (28 1) 73 1-6323 Fax: 7 13-207-9986 E-mail [email protected] E-mail: AP.i [email protected] Mark Invoices with WF022096 (d) Info rmation concerning ELECTRONIC FUNDS TRANSFERS: Ifto Friendswood Energy Genco, LlC Ifto CenterPoint Energy Houston Electric, LLC
Bank Name Texan Bank Chase Bank of Texas City, State Sugar Land, Texas Houston, Texas ABA No. 11 3194162 ABA No. 113000609 For credit to: CenterPoint Energy Houston Electric, LLC Account No. 0010-097-0798
44 45 Exhibit "E" Security Arrangement Details
Letter of Credit 1) Securitization of Project: A) The total estimated project cost to construct the TIF as described in Exhibit "C" is approximately$ 5,658,000 ("Secured Cost"). B) Tn accordance with Exhibit "A", A1iicle 8, Paragraph 8.3 Financial Security Arrangements, Generator shall provide a financial security instrument in the form of an irrevocable letter of credit in favor of TSP, in the amount of the Secured Cost, in a form and substance acceptable to TSP to secure Generator's obligations outlined in Exhibit "A", Article 2. Such letter of credit shall be with a financial institution reasonably acceptable to TSP having a long term debt rating by Moody's Investor Services of"A2" or better, and/or Standard & Poor's long tenn debt rating of"A" or better. C) Generator's obligation to pay amounts set forth in this Agreement will survive any termination of this Agreement.
45 46 Exhibit "F" Outage and Clearance Coordination Procedure
47 CenterPoint. Energy Transmission & Substation Outage and Clearance Coordination Procedures
Real Time Operations Department Revised May 05, 2015
48 • CenterPoint .. Energy Transmission & Substation Outage and Clearance Coordination Procedures
CENTERPOINT ENERGY TELEPHONE NUMBERS ...... 3
1 INTRODUCTION •••••••••••••••••••• ••••••••••••••••••••••••••••••••••••••••••••••••• ••• ••••••••••••••••••••••••••••••••••••••••••• 4 1.1 APPLICABILITY ••••••••••••••••••••••••••••••••••••••••••••• ••••••• •••••• ••••••.•••••••••••••••••••.•••..••.....•.••••••• ••••• 4 1.2 PURPOSE ...... •.••...... 4 1.3 COPIES OF THIS PROCEDURE •••••••••••••••••••••••• ••• •••••••••••••••••••••••••••••••..•••••..•••••••••••••• ••• •••• 4 1.4 FACILITY OWNERSHIP OR NAME CHANGE .•• •• .•••••. .•..•.•••• •••••••••••••• •••• ••• •••••••••••••••••••••••••• 4 1.5 PROCEDURE CONFLICTS •••••••••••••••••••••••••••••••••••••••••••••••••••••••••..•••••••••••••••••••••••••••••••• ••• •• 4 1.6 MAINTENANCE RESPONSIBILITY ...... 4 1.7 EQUIPMENT CHANGES ...... 4 1.8 GENERATION INSTALLATION AND OPERATION •••••••••••••••••.•• ••••••••••••••••••••••••.••••. •• •••••••••• 5 1.9 POWER FACTOR ...... 5 1.10 VOLTAGE FLUCTUATIONS .•..•••••••••••••••••••••• ••••••••••...•••••••••••••••••••••••••••••••••••• •••• ••••••••••••••• 5 1.11 EMERGENCY RESPONSE •••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••• 5 2 CNP ACCESS TO THE CUSTOMER'S FACILITIES ...... 5
2.1 AUTHORIZED REPRESENTATIVE OF CNP ...... 5 3 COMMUNICATIONS WITH CNP •••••••••..•••••••• ••• ••• ••••. •• •••••••••••••••• •••• •.••••••••••••••••••••••••••••••••• 6
3.1 REAL TIME OPERATIONS DEPARTMENT ...... 6 3.2 SCHEDULING TRANSMISSION EQUIPMENT OUTAGES ••••••••• •••• •• •••••••••••••••••••••••••••••••••••• 6 3.3 TRANSMISSION ACCOUNTS DIVISION ••••••••••••••••••••••.•••••••••••••••••••••••••••••••••••••••••••• ••••••••• 7 3.4 SUBSTATION AND EQUIPMENT IDENTIFICATION •••••••••••••••••• •••••••••••••••••••••••••••••••••••••••••• 7 3.5 TELEPHONE LINES AND DATA COMMUNICATION •••••••••••• ••••••••••••••••••••••••••••..•••••••• •• •• ••• • 8 3.6 ALARM RESPONSE ••••••••••••••••.•••••••••.••••••••••••••••••••••• •• ••••••••••••••••••••••••••••••••••••••••••••••••••••• 8 4 SWITCHING, CLEARANCES, GROUNDING ••••••••••..••.•••••••.••••.••••••• •••• ••••• •••••••••••••••••• •• 10
4.1 BILLABLE COSTS ••••••••••• ••••• •••• •••••••·••••••••••••• •••••••••••••••••••••••••••••• ••• ••••••••••••••••••••••••••••••· 10 4.2 SWITCHING ••••••••••••••••• •••••••••••••••••••••••••••••••••• •••..•.•..••••.•••••••••••••••• ••• •.••••••••••••••••••••• ••••••• 10 4.3 CLEARANCES ••••••••••••••• ••••• •••••• ••••••••••••••••••• ••• ••••••• •••••••••••••••••••••••••••••••••••••••••••••••••••••••• 11 4.4 GROUNDING •••••••••••••••••••••••••••••••••••••••••••• •••••• •••• •• •••• •••••.•••••.•••••••••.•••••....••••••••••••••••••••••• 11 4.5 SWITCHING 345 KV FACILITIES EQUIPPED WITH FERRORESONANCE PROTECTION •• 12 4.6 TERMINOLOGY FOR SWITCHING ORDERS •• ••••••••.•.•••••.•••••••••.••.••.••.•.•..••••••••.•••.•.•••••••••• 12 4.7 SWITCHING ORDER ...... 14 4.8 TRANSMISSION SWITCHING CHECK LIST •.••••••••••.••••••••••••••••.•••••••.• •••••••••••••••••.. •• ••••••••• 15 5 OUTAGE SCHEDULING CHECK LIST ••••••••••• •• •••••••••••••••••••••••••••••••••••••••••••••••••••••• ••••••• 16 5.1 OUTAGE SCHEDULING CHECK LIST •••• •• ••• ••••••••••••••••••••••••••••••••••••••••••••••••••••• ••••••• ••••••• 16 6 UNPLANNED OUTAGES ••••••••••••••••••••••••••••••••••••••• •••••••••••••••••••• •••• ••••••••••••••••••••••••••••••••••• 17
6.1 UNPLANNED OUTAGES ...... 17 6.2 UNPLANNED OUTAGES OF 345 KV FACILITIES EQUIPPED WITH FERRORESONANCE PROTECTION ...... 17 6.3 EMERGENCY SWITCHING ••••••••••••••••••••••••••••••••••••••••••••••••••••• •••••••••••••••••••••••••••••••••••••••• 18 6.4 EMERGENCY SWITCHING CHECK LIST ...... 19
49 • CenterPoint~ Energy Transmission & Substation Outage and Clearance Coordination Procedures
6.5 OTHER EMERGENCY CONDITIONS ...... 19 7 GENERATION OPERATION ••.•.••••••..••...... •••..••...... •...•.••••••••..•..•. •...... •.•••••.•• 19 7 .1 APPLICABILITY ...... 19 7.2 UNIT OPERATION ...... 19 8 PROTECTIVE RELAYING AND CONTROL ...... 20 8.1 SETTINGS FOR RELAYS INSTALLED FOR THE PROTECTION AND AUTOMATIC RECLOSING OF CNP TRANSMISSION LINES •...... •..••.•••...•••••••••••••••..••••...... ••.•••.• 20 8.2 APPLICABLE RELAY SETTINGS ...... 20 8.3 COMMUNICATIONS CONNECTIONS TO ELECTRONIC DEVICES ...... 20 9 EQUIPMENT ADDITIONS, REPLACEMENT, UPGRADES AND REMOVAL ••••..•. 21 9.1 EQUIPMENT CHANGES •••••••••••••••••••••••.•.••••.••.... .•...•.••••...... ••.•••••.•••••••••••••.•..••.••••••••• 21 9.2 MODIFICATION, REPAIR, AND REPLACEMENT OF CUSTOMER EQUIPMENT ...... 21 10 EQUIPMENT MAINTENANCE ...... 23 10.1 CNP MAINTENANCE ...... 23 10.2 CUSTOMER MAINTENANCE ••••..•••••••••...•...•••••••••••••.••..•..•.••..•..••.•••...... •••••••••••••••••..•.•••.• 23 10.3 MONTHL y INSPECTIONS······························································································· 23 10.4 QUARTERLY, SEMI-ANNUAL TESTING, AND INSPECTION ...... 24 10.5 DC BATTERY SYSTEM ...... 24 10.6 FUNCTIONAL TESTING ...... 24 10.7 SPECIAL INSPECTION AND TESTING ...... 24 11 PLANT DESIGN CONSIDERATIONS ...... 25 11.1 EMERGENCY SYSTEMS ...... 25 11.2 AUTOMATIC RECLOSING •••..•.•.••••...... •••••••••••••••••••••••••••••..•••••..•••••..••••••••••••••••.••..••••••••• 25 11 .3 SYSTEM VOLTAGE ...•...•....•..•••.•.•...•..•.•.•.....•...... •••...••.•.••.••..••.•....•.••.•.•..•••••••.••••.••• 25 11.4 ELECTRICAL PROTECTION COORDINATION STUDIES •••••••••••••••••••••••••••• ••.•••••.••••.•••••••• 25 11 .5 SUBSTATION DESIGN SPECIFICATIONS ...... 26
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50 e CenterPoint.. Energy Transmission & Substation Outage and Clearance Coordination Procedures
CenterPoint Energy Telephone Numbers
Real Time Operations Department ("RTO")
RTO System Controller 281-894-0491 (24 hours) RTO HOTLINE (Emergency) 281-894-1625 (24 hours)
Outage Scheduling:
Submit request to: [email protected]
Outage Questions call 713/207-2714 (Primary) or 713-207-2196
Metering Department:
High Voltage Metering 713-945-6689
Metering Engineering 713-207-4155
Transmission Accounts Representatives:
Gary Dwyer 713-207-3621 Arodi Gonzalez 713-207-3512 Joe (Cliff) Teaster 713-207-2263 Gary Shadwell 713-207-3538
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51 • CenterPoint .. Energy Transmission & Substation Outage and Clearance Coordination Procedures
1 Introduction
1.1 Applicability 1.1.1 This procedure applies to entities ("the Customers") who own high voltage transmission and/or generation facilities interconnected to CenterPoint Energy Houston Electric, LLC's ("CNP") 69 kV, 138 kV, or 345 kV transmission system. Customer, as used in this document, includes the Customer's authorized contractors or agents. The Customer shall ensure that the provisions in this document are applied to facilities that may be owned by others and that are interconnected to the Customer's facility at the same voltage at which the Customer's facility is interconnected to CNP's transmission system.
1.2 Purpose 1.2.1 The purpose of this document is to facilitate the coordinated operation, outage coordination, maintenance, design, and modification of the Customer's high voltage transmission or generation facilities with CNP facilities.
1.3 Copies of This Procedure 1.3.1 The Customer shall keep copies of this procedure in applicable Customer substation control houses and plant operating centers. This procedure, including forms, may be reproduced.
1.4 Facility Ownership or Name Change 1.4.1 The Customer shall inform CNP of any change in ownership or name of their interconnected facilities or facilities owned by others that are interconnected to their facilities.
1.5 Procedure Conflicts 1.5.1 Any conflicts between this procedure and the Customer's procedures shall be thoroughly discussed with appropriate CNP rep resentatives and resolved before beginning any work.
1 .6 Maintenance Responsibility 1.6.1 The Customer is responsible for the operation and periodic preventive maintenance of all substation facilities owned by the Customer except for equipment designated by CNP to be maintained by CNP. The Customer shall not perform preventive maintenance on equipment maintained by CNP.
1.7 Equipment Changes 1.7.1 The Customer shall provide all equipment, in accordance with CNP specifications, whenever changes in CNP transmission system, including monitoring and protection devices, require changes in the Customer's interconnected facilities to maintain compatibility.
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52 • CenterPoint .. Energy Transmission & Substation Outage and Clearance Coordination Procedures
1.7.2 The Customer shall provide sufficient notice to CNP of any proposed changes to their facilities as specified in Section 9. This notification shall include providing necessary details, so that CNP can provide comments based upon a general, functional review. The Customer shall not procure any equipment or materials or begin any work until all CNP comments are incorporated or resolved.
1.8 Generation Installation and Operation 1.8.1 Customers desiring to connect generation that will operate in parallel to CNP's transmission system shall file an application with the Electric Reliability Council of Texas ("ERGOT") requesting interconnection in accordance with ERCOT's Generation Interconnection Procedure.
1.8.2 The Customer's generation facility must be operated in accordance with the ERGOT Protocols and Operating Guides available at: http://www.ercot.com/mktrules/nprotocols/current http://www.ercot.com/mktrules/guides/noperating/cur
1.9 Power Factor 1.9.1 The Customer shall provide suitable apparatus to maintain power factor consistent with the requirements of CNP's Tariff for Retail Delivery Service.
1.1 O Voltage Fluctuations 1.10.1 The Customer shall provide suitable apparatus to mitigate voltage fluctuations to reasonable limits should the Customer's equipment cause voltage fluctuations that interfere with CNP's transmission system.
1.11 Emergency Response 1.11 .1 In an emergency, the Customer shall switch substation equipment, reduce MW output, change reactive output, or perform other measures as directed by ERGOT or CNP's Real Time Operations Department ("RTO"), to help alleviate the emergency. 1.11.2 CNP may interrupt transmission service to and deliveries from the Customer in the event of an emergency. 2 CNP Access to the Customer's Facilities 2.1 Authorized Representative of CNP 2.1.1 An authorized representative of CNP shall have access to the Customer's premises for the purpose of inspecting CNP's wiring and apparatus, repairing , erecting, removing, or replacing CNP owned equipment, reading CNP meters, and for all other purposes related to the interconnection including switching CNP equipment. The Customer shall provide necessary equipment outages to
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53 CenterPoint .. Energy Transmission & Substation Outage and Clearance Coordination Procedures
allow CNP to perform periodic maintenance on equipment that CNP owns or to repair or replace equipment that CNP owns.
3 Communications with CNP 3.1 Real Time Operations Department 3.1.1 RTO operates CNP's transmission system and coordinates the operation of interconnected high voltage facilities. RTO provides routine and emergency switching instructions, issues clearances, and dispatches CNP personnel in response to electrical outages and problems. The Customer shall schedule planned outages with RTO and obtain from RTO switching instructions for any equipment at the Customer's substation that is directly interconnected with CNP's transmission system. Switching in the Customer's facilities that are remote to the Customer's substation directly interconnected with CNP's transmission system does not need to be scheduled. CNP will notify the Customer one or more days in advance if switching is required in the Customer's substation for planned transmission line outages or if the Customer's substation will be placed in a single-ended condition.
3.2 Scheduling Transmission Equipment Outages 3.2.1 CNP's substation equipment outage scheduling and reporting requirements have been developed to support ERCOT requirements for scheduling outages on circuit breakers, bus sections, transmission lines, and transformers that have an operating voltage of 60 kV and higher and to support requirements for scheduling outages of ERCOT Polled-Settlement ("EPS") metering equipment. 3.2.2 The Customer shall contact the RTO Outage Scheduler as shown in Table 1 at the end of this section to coordinate outages in the substation that is directly interconnected with CNP's transmission system. Requests are considered in the order they are received. 3.2.3 Switching Orders, Clearances - The Customer shall follow switching instructions provided by the RTO System Controller prior to initiating any switching to remove equipment from service or return equipment to service in the Customer's facilities. The Customer shall request a clearance from the RTO System Controller when required. A "Switching Order" form and a "Transmission Switching Check List" form are included in this document. The RTO System Controller can be contacted at 281-894-0491. 3.2.4 Unplanned Outages, Emergencies - The Customer shall contact the RTO System Controller as soon as possible whenever any unplanned tripping of any circuit breaker operating at a voltage of 60 kV and higher occurs. An "Unplanned Outage Check List" form is included in this document. In the event of an unplanned generation outage, the Customer or his designated representative shall advise CNP's RTO System Controller as soon as possible. In emergency situations, switching may be performed by a qualified person, which is authorized by the Customer, based upon switching instructions
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54 • CenterPoint .. Energy Transmission & Substation Outage and Clearance Coordination Procedures
provided by the RTO System Controller. An "Emergency Switching Check List" form is included in this document. The RTO System Controller can be contacted at 281-894-0491 or at the RTO HOTLINE 281-894-1625. 3.2.5 ERCOT Approvals - The RTO System Scheduler will coordinate a review and notifies the Customer whether the outage can be scheduled for the desired day. Transmission line outages and the energization of new equipment require the approval of ERCOT. The Customer shall notify the RTO System Scheduler as soon as possible if an outage is canceled prior to the outage date. The Customer shall immediately notify the RTO System Controller if an outage is canceled on the day of the outage. CNP endeavors to notify the Customer as soon as possible when it is deemed necessary to cancel an outage. 3.2.6 Customer Substation Evacuations - During emergencies requiring evacuation of the Customer's facility, the Customer shall contact RTO prior to the evacuation and provide information regarding the operational status of their substation and associated support facilities, such as substation station service power, battery and battery charger, and ability for CNP to access the substation. The Customer's substation is an integral part of the interconnected transmission system and disabling them has an impact on the electrical grid.
3.3 Transmission Accounts Division 3.3. 1 CNP's Transmission Accounts Division is responsible fo r coordinating the Customer's service needs within CNP. Transmission Accounts representatives endeavor to inform the Customer of long range planned switching and projects that may affect the Customer's facility. 3.3.2 The Customer shall notify the Transmission Accounts representative as specified in Section 9 when equipment additions or removals are planned or when high voltage equipment 60 kV and higher or associated equipment requires modification or replacement. The Customer shall contact a Transmission Accounts representative to request cu rrent CNP specifications and applicable bills of material for substation equipment additions and replacement. 3.3.3 Transmission Accounts representatives may be contacted for any questions concerning the operation of the Customer's substation. The Transmission Accounts representatives are listed on Page 1 of this document.
3.4 Substation and Equipment Identification 3.4.1 CNP assigns a substation name, or a Substation ID of six characters or less, to identify the Customer's substation facility. The Substation ID is also referred to as the six character mnemonic name in which some characters may be blank. CNP mounts signs with the substation name or the Substation ID on a substation control house door and on a substation entrance gate at the Customer's facility.
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55 • CenterPoint .. Energy Transmission & Substation Outage and Clearance Coordination Procedures
3.4.2 The Customer's high voltage circuit breakers switches, transformers, and certain low side equipment shall be identified with CNP's assigned numbers. CNP develops a substation basic one-line diagram that includes these assigned numbers. CNP or the Customer shall mark these numbers on the substation equipment. CNP may stencil identification numbers on substation equipment and mount signs, labels, drawings, telephone numbers, and instructions on the Customer's facilities. 3.4.3 The Customer shall use CNP's assigned substation name, or Substation ID, and equipment identification numbers in discussions with the RTO System Controller and the RTO System Scheduler.
3.5 Telephone Lines and Data Communication 3.5.1 The Customer shall maintain a telephone in the substation control house connected to an outside telephone line that is independent from the Customer's telephone system. 3.5.2 The Customer shall maintain data acquisition equipment to provide real-time data to RTO when it has been installed at electric generating facilities . 3.5.3 CNP maintains a communication circuit for real time data if CNP Supervisory Control and Data Acquisition ("SCADA") equipment is installed at the Customer's facility.
3.6 Alarm Response 3.6.1 CNP responds to alarms for communication equipment installed to protect CNP transmission circuits. 3.6.2 The Customer shall report substation alarms to the RTO System Controller and respond to alarms pertaining to their equipment. A "Loss of DC" alarm shall be immediately reported to the RTO System Controller and investigated by the customer.
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56 • CenterPoint .. Energy Transmission & Substation Outage and Clearance Coordination Procedures
Outage Scheduling Requirements
Per ERCOT and CNP outage reporting requirements: planned outages on circuit breakers, transmission lines, and autotransformers that are rated 60 kV and higher must be submitted to the ERCOT Outage Coordinator by the CNP RTO Outage Coordinator.
Per ERCOT Protocols, planned outages on ERCOT Polled Settlement (" EPS" ) meters and the equipment to which they are connected require a 5 day m inimum notice. A 10 calendar-day minimum notice is required for any modifications to approved EPS equipment.
Table 1 Planned Outage Scheduling
Equipment Being Minimum Advance Notice Contact Requested 69 kV and 138 kV lines, No later than 1200 hours Outage Scheduler single load transformers, Wednesday two weeks @ individual breakers and bus before the Planned Outage 713-207-2196 outages of no more than is to take place. or one day in duration. 713-207-2714 All transmission line 35 Calendar Days Outage Scheduler outages and equipment @ outages, including busses, 713-207-2196 of up to four contiguous or days duration (daily or 713-207-2714 continuous outages). Any transmission line 90 Calendar Days Outage Scheduler outages and/or equipment @ outages, including busses, 713-207-2196 of 5 days or longer duration or (daily or continuous) 713-207-2714
Amount of ti me between the request fo r approval of ERC OT shall app rove or reject no later than : the proposed O utage and the scheduled start date of the proposed Outage: Three days 1800 hours, two days before the start of the proposed Outage Between four and eight days 1800 hours, three days before the statt of the proposed Outage Between nine days and 45 days Four days before the start of the proposed Outage Between 46 and 90 days 30 days before the start of the proposed Outage Greater than 90 days 75 days before the start of the proposed Outage
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57 • CenterPoint.. Energy Transmission & Substation Outage and Clearance Coordination Procedures
4 Switching, Clearances, Grounding
4.1 Billable Costs 4.1.1 Grounding and switching requested by the Customer to be performed during other than normal working hours is billable to the Customer. 4.1.2 Grounding and switching charges will be waived under the following conditions: 4.1.2.1 The Customer requesting switching or grounding activities by CNP is a transmission voltage service customer that is interconnected to CNP's transmission system through a customer-owned substation; and
4.1.2.2 The requested activities are to allow the Customer to perform maintenance activities or equipment upgrades on its transmission voltage facilities within the Customer's substation; and
4.1 .2.3 The switching and grounding field activities are requested to occur on a normal CNP work day, with outages commencing no earlier than 0800, and outages concluding no later than 1600.
4.1 .3 Outages extending beyond the timeframes identified in Section 4.1.2.3 on a forced basis may result in billing for associated switching and grounding activities, as determined on a case-by-case basis. 4.1.4 Outages with switching or grounding activities requested for more than two consecutive days may be subject to charges for each additional consecutive day, even if the outages occur within the timeframes identified in Section 4.1.2.3, unless early or intermittent outage restoration is required by ERCOT or for CNP system requirements. 4.1.5 Questions regarding charges should be directed to the Transmission Accounts representative.
4.2 Switching 4.2.1 CNP performs necessary switching at the remote end of a CNP transmission line for outages at the Customer's substation that require switching of CNP transmission lines. CNP provides switching instructions for the high voltage devices in the Customer's substation that is directly interconnected with CNP's transmission system. Switching instructions are not provided for remote facilities interconnected to the Customer's substation that is directly interconnected with CNP's transmission system. A "Switching Order" form and a "Transmission Switching Check List" form are included in this document. 4.2.2 The Customer shall follow switching instructions provided by the RTO System Controller prior to initiating any switching to remove equipment from service or return equipment to service in the Customer's facilities. The Customer shall implement specific procedures for the switching of its facilities. These procedures shall include a visual check that all phases have fully opened or
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58 • CenterPoint .. Energy Transmission & Substation Outage and Clearance Coordination Procedures
closed. A device bearing a Hold Tag shall not be operated under any circumstances. 4.2.3 The Customer shall provide a Hold Order to RTO for switching at generation facilities for equipment that interconnects with CNP.
4.3 Clearances 4.3. 1 A clearance is required for applicable work on high voltage apparatus connected to CNP transmission lines when switching at the remote end of a CNP transmission line is necessary. Clearances are also issued when the Customer and CNP will be working on apparatus within the same isolated area at the Customer's facilities. Each party will be issued an individual clearance. 4.3.2 The Customer shall request a clearance from the RTO System Controller when required. Personnel authorized by CNP will perform either "trip & hold" or "check for trip & hold" on necessary devices before a clearance will be issued. 4.3.3 A clearance cannot be released by anyone other than the person to whom it was issued unless uncontrollable circumstances make that impossible. In this situation, the person's supervisor may, after informing each member of the crew that such action is being taken, contact the RTO System Controller to release the clearance. For field personnel shift changes, the person assuming the leadership of the work will be issued a new clearance and the person to whom the clearance was originally issued will then release the clearance.
4.4 Grounding 4.4.1 CNP issues clearances indicating that high voltage devices have been opened, locked, and tagged to prevent the devices from operating. The Customer shall verify that the apparatus is de-energized before protective grounding is attached or work on high voltage facilities begins. 4.4.2 The Customer shall install protective grounds on all de-energized electrical apparatus before applicable work is performed on it. When more than one party (e.g., the Customer and CNP) will be working on apparatus within the same isolated area at the Customer's facilities, each party shall install their own individual grounds before applicable work is performed. 4.4.3 Work may be performed on the control circuits and mechanisms of a device without grounding the apparatus, if such work can be performed without risk of contact with primary voltages. Grounds may be temporarily removed if required by testing procedures. 4.4.4 Before a grounding device is attached to any conductor, the conductor shall first be tested to confirm that it is de-energized. Grounds shall be placed such that the operation of a switching device cannot remove their protection. 4.4.5 The clamps and conductors of grounding devices shall be designed for the available fault current. Grounding devices must be inspected for broken
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59 • CenterPoint .. Energy Transmission & Substation Outage and Clearance Coordination Procedures
strands and loose connections. The surface of the ground clamps shall be clean of corrosion and oxides. 4.4.6 Grounding devices for transmission voltage conductors shall be installed and removed with the use of applicable live line tools. Grounding devices shall be securely connected at the ground end before connection is made to the conductor. Grounds shall be removed by first detaching the connection at the conductor and, then, detaching the connection at the ground end. When grounding to a steel structure, the ground shall not be applied to a flat surface unless an appropriate flat surface clamp is used. 4.4.7 CNP does not ground Customer-owned substation equipment except for work being performed by CNP.
4.5 Switching 345 kV Facilities Equipped with Ferroresonance Protection 4.5.1 Ferroresonance protection is installed whenever a wound potential transformer ("PT") is connected to 345 kV and the possibility of a ferroresonance condition occurring exists. If applicable, the Customer shall implement specific procedures for switching 345 kV equipment that has ferroresonance protection installed. Procedures shall include the following: • Place the sync handle in position for the last breaker that will be opened. • Monitor the potential lights on all three phases before and after the last breaker is opened. If one or more of the lights do not dim immediately but gets brighter: • immediately close the last breaker opened to reenergize th e bus • investigate the ferroresonance protection • If all three lights dim immediately: • reset the targets (flags) on the ferroresonance protection relays • If relay targets did not operate: • investigate the ferroresonance protection circuit
4.6 Terminology for Switching Orders
Time - Military time, or 24 hour clock, based on prevailing Central Time.
Check Ring for Close - Verify by visual inspection that all devices in the ring are in the closed position.
Remove I Roll Loads - Remove all loads connected to a power transformer. This may be done by tripping applicable low side breakers or by rolling load to an adjacent transformer and tripping applicable low side breakers.
Trip - Initiate and complete an opening operation on a device.
Close - Initiate and complete a closing operation on a device.
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60 • CenterPoint.. Energy Transmission & Substation Outage and Clearance Coordination Procedures
Hold Tag - A tag placed on a device to indicate the equipment shall not be allowed to change operating state. The tag shall indicate the party who placed the tag.
Trip and Hold - Trip device, physically or mechanically (e.g., affix padlock) disable device from closing, and place a Hold Tag on the device.
Check for Trip and Hold - Verify by visual inspection that a device is in the trip position and place a Hold Tag on the device.
Secure Against Operation (SAO) - Physically, mechanically, or electrically disable a device (e .g., a motor operated disconnect switch) to prevent it from operating.
Secondary Potential Fuse (SPF) - Remove and tag fuses on the secondary side of potential devices to prevent the possibility of back energizing isolated equipment.
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61 • CenterPoint. Energy Transmission & Substation Outage and Clearance Coordination Procedures
4. 7 Switching Order
SWITCHING
CLEARANCE#
SUBSTATION ______ISSUED RELEASED
EQUIPMENT ______~ DISP. _____ DJSP. ______
OUT RESTORE TIME ___ __ TIME ______
DISP _____ DISP. ______DATE ___ __DAT E ______
TIME _ _ ___ TlME ______ISSUED TO ______
DATE_ ___ _ DATE ______NUMBER OF MEN ---AND GROUNDS----
EXEC. BY__ __ EXEC. BY______ON______~
TlME - - --- TIME
INSTRUCTIONS
SWITCIDNG PROCEDURES DlSCUSSED WITH ALL MEMBERS OF CREW: Y N
CREW INITIALS------
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62 • CenterPofntft Energy Transmission & Substation Outage and Clearance Coordination Procedures
4.8 Transmission Switching Check List 4.8.1 The following basic procedures are for the day of the switching after the outage has been scheduled with and authorized by the RTO System Scheduler (713-207- 2196). This applies to the Customer's substation that is directly interconnected with CNP's transmission system.
o Call the RTO System Controller at 281-894-0491 and request a Switching Order O Provide name, company affiliation, and telephone number o Provide Substation ID O Describe reason for request O Fill out Switching Order fJ Record the Switching Order number n Record start time provided by the RTO System Controller o Record the RTO System Controller's name o Record the instructions to take equipment OUT o Repeat the instructions n Execute the Switching Order placing Hold Tags where appropriate o Call the RTO System Controller when the instructions have been completed o Report the actual completion time 0 Record the completion time provided by the RTO System Controller on Switching Order o Request a Clearance if necessary o Provide the number of personnel in the crew D Provide the number of and location of grounds o Verify apparatus is de-energized with a hot line indicator o Install protective grounds when required o Perform work o Remove protective grounds if installed o Call the RTO System Controller to request to RESTORE equipment O Report whether more than one Hold Tag is on any device o Provide Clearance number if applicable o Provide the number of personnel in the crew clear of the apparatus o Provide the number of grounds removed o Provide the Switching Order number o Fill out Switching Order o Record start time provided by the RTO System Controller o Record the RTO System Controller's name o Discuss performing Switching Order instructions in reverse order o Alert all personnel to move to a safe distance from apparatus being energized o Execute the Switching Order removing Hold Tags where appropriate o Call the RTO System Controller when restoration has been completed O Report the actual completion time 0 Record the completion time provided by the RTO System Controller on Switching Order
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63 • CenterPoint~ Energy Transmission & Substation Outage and Clearance Coordination Procedures
5 Outage Scheduling Check List
5.1 Outage Scheduling Check List 5.1.1 The following instructions are for scheduling transmission equipment outages. This applies to the Customer's substation that is di re ctly interconnected with CNP's transmission system. Please refer to the "Outage Scheduling Requirements" outlined in Section 3 of these procedures. 5.1 .2 D Submit the following form to [email protected] 5.1.3 D For outage questions, call 713-207-2714 (Primary) or 713-207-2196. D Please provide the following information:
CENTERPOINT ENERGY OUTAGE REQUEST FORM FOR TRANSMISSION CUSTOMERS SUBMITTAL VERSION CUSTOMER Substation DATE: # NAME MNEMONIC: REQUESTED Office# ON SITE Office# BY: Cell Ph# CONTACT Cell Ph# CNP TO START START END END DAILY· D EMERGENCY EQUIPMENT KV GROUND REASON FOR OUTAGE/REMARKS DATE TIME DATE TIME CONT·C RESTORE TIME line Y/N
l
All Outage Requests should be e-mailed to OutageRegue st~cent e!:J!ointene!i~·com For Questions call 713·207·2714 (fax# 713·207·2571)
Please make a courtesy phone call if a revision has changed the original submittal. CNP will contact the "Requester" if additional data is required.
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64 • CenterPoint~ Energy Transmission & Substation Outage and Clearance Coordination Procedures
6 Unplanned Outages
6.1 Unplanned Outages 6.1 .1 ERCOT Protocols require that CNP notify ERCOT of all unplanned transmission outages. 6.1.2 The Customer shall contact the RTO System Controller as soon as possible whenever any unplanned tripping of any high voltage (60 kV and higher) circuit breaker occurs. CNP crews will be dispatched when high voltage circuit breakers remain open in the Customer's substation that is directly interconnected with CNP's transmission system. CNP crews will reset relay targets except in emergency situations. An "Unplanned Outage Check List" form is included in this procedure. 6.1.3 CNP crews are not dispatched when high voltage circuit breakers remain open in a remote, non-CNP substation connected to the Customer's substation, but not directly interconnected with the CNP system. In such a case, the Customer shall discuss and evaluate the event with the RTO System Controller. The Customer shall notify the RTO System Controller prior to any switching. 6.1.4 In the event of an unplanned generation outage, the Customer or his designated representative shall advise CNP's RTO System Controller as soon as possible.
6.2 Unplanned Outages of 345 kV Facilities Equipped with Ferroresonance Protection 6.2.1 Ferroresonance protection is installed whenever a wound potential transformer ("PT") is connected to a 345 kV and the possibility of a ferroresonance condition occurring exists. If applicable, the Customer shall implement specific procedures for unplanned tripping of 345 kV equipment that has ferroresonance protection installed. Procedures shall include the following:
o Visually inspect the potential transformer lights on all three phases o If one or more of the lights are bright and not dim o Open all the breaker disconnect switches to isolate the potential transformers o Disconnect/Remove the PTs from service on the phases with the bright lights D If one or more of the lights are dark and not dim o Open all the breaker disconnect switches along the affected bus o Disconnect/Remove the PTs from service on the phases with the dark lights o If remote monitoring of potential transformer voltages indicated a ferroresonance condition occurred o Open all the breaker disconnect switches to isolate the potential transformers ·o Disconnect/Remove the PTs from service on the phases that indicated ferroresonance o If all three lights are dim o Reset the targets on the ferroresonance protection relays D If relay targets do not indicate proper action o Investigate the ferroresonance protection circuit
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65 CenterPoint~ Energy Transmission & Substation Outage and Clearance Coordination Procedures
6.3 Emergency Switching 6.3. 1 In emergency situations, switching may be performed prior to a CNP crew arriving at the Customer's substation. A qualified person, authorized by the Customer, may operate breakers and switches based upon switching instructions provided by the RTO System Controller. Prior to switching, all relay trip targets shall be reset after the Customer has recorded them and reported them to the RTO System Controller. All personnel shall move to a safe distance from apparatus being energized prior to switching. An "Emergency Switching Check List" form is included in this procedure. 6.3.2 UNPLANNED OUTAGE CHECK LIST 6.3.3 The following instructions are for whenever an unplanned tripping of a transmission service voltage breaker occurs.
o Call the RTO System Controller at 281-894-0491 n Provide the following information to the RTO System Controller o Your name, company affiliation, and telephone number D Substation ID o Nature of the problem o Time of outage o Status of all breakers and switches (i.e. , open, closed, tagged) o Cause of the event if known o Fault location and faulted equipment if known o Fires and their proximity to energized equipment o Plant and substation entry constraints (e.g., chemical releases) o Record the RTO System Controller' s name o Investigate and provide the following information to the RTO System Controller o Cause of the event if found during investigation D Fault location and faulted equipment if found during investigation o Number of trip operations for each breaker (i.e., change in breaker veeder reading) o Relay trip targets - Do not reset targets n Discuss outage with CNP crews D CNP crews record and reset relay trip targets D CNP crews record breaker veeder readings D Resolve outage and complete any necessary corrective action o Call the RTO System Controller at 281-894-0491 to request to RESTORE equipment D Record the instructions to RESTORE equipment D Repeat the instructions D Execute the instructions D Call the RTO System Controller when instructions have been completed
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66 • CenterPoint. Energy Transmission & Substation Outage and Clearance Coordination Procedures
6.4 EMERGENCY SWITCHING CHECK LIST 6.4.1 The following basic procedures are for emergency situations. Contact the RTO System Controller at one of the following telephone numbers.
D Call the RTO System Controller HOTLINE at 281-894-1625 D Provide the following information to the RTO System Controller D Your name, company affiliation, and telephone number D Substation IDD Nature of the problem D Time of outage o Status of all breakers and switches (i.e., open, closed, tagged) o Cause of the event if known o Fault location and faulted equipment if known D Fires and their proximity to energized equipment D Plant and substation entry constraints (e.g., chemical releases) D Relay trip targets o Record the RTO System Controller's name o Record the instructions to RESTORE equipment D Reset relay trip targets D Execute the instructions D Call the RTO System Controller at 281-894-0491 when instructions have been completed
6.5 Other Emergency Conditions 6.5.1 Customer substations are an integral part of the interconnected transmission system and disabling them has an impact on the electrical grid. In certain emergency situations, the Customer may evacuate or shut down their facility. In such cases, the Customer shall endeavor to keep the portion of their substation that is directly connected to the transmission grid in service, unless specifically directed otherwise by ERCOT or CNP's RTO System Controller. 7 Generation Operation
7 .1 Applicability 7 .1 .1 Th is section applies only if the Customer operates electric generating facilities and participates in the wholesale transmission market. The Customer shall follow the ERCOT Operating Guides and ERCOT Protocols or other regulatory requirements that apply to their facilities
7.2 Unit Operation 7.2.1 Where CNP owns the interconnecting substation and there is not an in -line breaker to synchronize a generating unit, the Customer has control of CNP's
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67 • CenterPoint .. Energy Transmission & Substation Outage and Clearance Coordination Procedures
substation breakers that are functioning as generator breakers. CNP has operational control of the disconnect switches associated with these breakers. 7.2.2 The Customer shall have generation control personnel on duty at the generating unit site at all times that the generating units are on-line. 7.2.3 The Customer or Customer's representative shall notify the RTO System Controller (281-894-0491) immediately before a unit is synchronized and connected to CNP's transmission system. 7.2.4 The Customer shall operate units to support the transmission system voltage by regulating reactive power output up to levels demonstrated in the ERCOT tests as required in the ERCOT Protocols. The Customer shall maintain the ERCOT specified voltage level unless otherwise directed by the RTO System Dispatcher or ERCOT. 7.2.5 The Customer's voltage regulators, speed governors, and power system stabilizers, if required by ERCOT, shall be in service whenever generating units are on-line. The Customer shall immediately notify ERCOT whenever a voltage regulator, speed governor, or power system stabilizer is taken out of service or placed back in service. The Customer shall maintain settings as close as practical to five percent speed regulation. 7.2.6 The Customer shall maintain generating units on-line during system frequency and voltage excursions per ER COT Operating Guides: www.ercot.com/mktrules/guides/noperating/cur.
8 Protective Relaying and Control
8.1 Settings for Relays Installed for the Protection and Automatic Reclosing of CNP Transmission Lines 8.1.1 CNP calculates and implements all settings for the Customer's relays installed for the protection and automatic reclosing of CNP transmission lines and for the Customer's relays installed to prevent back-energizing CNP's system from generation installed on the low side of the Customer's power transformers. On a case-by-case basis, CNP may issue settings for other relays owned by the Customer. The relay settings implemented by CNP for the Customer's relays will be provided to the Customer upon request.
8.2 Applicable Relay Settings 8.2.1 The Customer shall provide CNP with the settings of the Customer's relays that trip or close the Customer's high voltage (60 kV and higher) circuit breakers. The Customer shall provide to the Transmission Accounts representative any proposed settings changes for such relays for CNP's review.
8.3 Communications Connections to Electronic Devices 8.3.1 An electronic device that can directly or indirectly trip a circuit breaker connected to a CNP transmission circuit is not allowed to be monitored through mutable protocol communication (i.e. Ethernet) or dial-up communication. Monitoring of
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68 • CenterPoint~ Energy Transmission & Substation Outage and Clearance Coordination Procedures
this electronic device for metering data or event data or any communications processor connected to this electronic device is only allowed through a serial port, such as Modbus, DNP3, or SEL Fast Meter. Control commands are not allowed through the serial port.
9 Equipment Additions, Replacement, Upgrades and Removal
9.1 Equipment Changes 9.1.1 The Customer shall notify the Transmission Accounts representative with sufficient notice to meet the timeline and data reporting requirements in Table 2 below when equipment additions or removals are planned or when high voltage equipment or associated equipment requires modification or replacement. The Customer shall notify the Transmission Accounts representative prior to performing functional testing and allow CNP to witness the testing. 9.1.2 The Customer shall provide equipment and installation, including testing and inspections, per applicable CNP specifications and bill of materials. The Customer shall provide necessary details, such as drawings, specifications, and manufacturer type and catalog number, for CNP's review. All CNP comments must be incorporated or resolved before any equipment or materials are procured or any work is begun. 9.1 .3 ERGOT Protocols require that all changes to equipment rated at 60 kV and above be communicated by CNP to ERGOT prior to the in-service date as specified in Table 2 below. 9.1.4 ERGOT only approves energization requests when the transmission element is satisfactorily modeled in the ERGOT Network Operations Model.
9.2 Modification, Repair, and Replacement of Customer Equipment 9.2.1 CNP notifies the Customer of problems in their facilities of which CNP becomes aware. The Customer shall provide any needed equipment modifications, repairs, or replacement within an appropriate time frame. The Customer shall replace equipment that CNP demonstrates is no longer maintainable. On a case-by-case basis, the Customer and CNP shall develop the responsibilities for the modification, repair, and replacement of this equipment. 9.2.2 Industry experience may dictate that certain equipment be modified, repaired, or replaced due to manufacturing defects or unacceptable failure rates and consequences. The Customer shall, within an appropriate time frame, modify, repair, or replace equipment based on manufacturer issued product service advisories or CNP issued advisories.
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69 • CenterPoint~ Energy Transmission & Substation Outage and Clearance Coordination Procedures
Customer Substation Equipment Additions, Relocations, Upgrades and/or Removals
When installing, relocating, or upgrading transmission system equipment, Customers must contact their appropriate CNP Transmission Accounts representative with sufficient notice to meet the timelines and data requirements shown below. ERCOT Nodal Protocols Section 3.10.1 requires that all changes to transmission equipment energized at 60 kV and above be communicated by CNP to ERCOT using the Network Operations Model Change Request ("NOMCR") process as summarized below: Table 2
Target Physical Equipment Deadline Timeline to Submit initial information to Submit In-Service Month to RTO to Transmission Accounts Rep Month of January Sept. 1 June 1 (prior year) Month of February Oct. 1 July 1 (prior year) Month of March Nov. 1 August 1 (prior year) Month of April Dec.1 September 1 (prior year) Month of May Jan. 1 October 1 (prior year) Month of June Feb.1 November 1 (prior year) Month of July Mar.1 December 1 (prior year) Month of August Apr.1 January 1 Month of September May 1 February 1 Month of October June 1 March 1 Month of November July 1 April 1 Month of December Aug. 1 May 1
(1) Pursuant to the ERCOT Nodal Protocols, CNP requires the following information to meet the deadlines shown above. The NOMCR data requirements include, but are not limited to:
• Completed project expected in-service date • Equ ipment ratings • Device nomenclature will be provided by CNP • Engineering drawings showing the final configuration. • Construction sequence with expected energization dates for each piece of equipment. • Identification of SCADA data points • Additional data as may be determined by ERCOT
(2) Known outage req uests must be submitted by Real Time Operations with the NOMCR's for each expected energization date.
(3) ERCOT only approves energization requests when th e Transmission Element is satisfactorily modeled in the ERCOT Network Operations Model.
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70 • CenterPoint .. Energy Tra nsmission & Substation Outage and Clearance Coordination Procedures
10 Equipment Maintenance
10.1 CNP Maintenance 10.1.1 CNP will perform periodic testing of certain of the Customer's equipment if the equipment is installed for the protection of CNP transmission lines. This includes power line carrier tuning and testing of wave traps, tuners, and carrier sets and calibration and testing of relays and fiber optic communication equipment. CNP will perform periodic calibration and testing of SCADA transducers that provide real time data to CNP. CNP may designate additional equipment of the Customer for maintenance by CNP. CNP will label equipment maintained by CNP. 10.1.2 CNP will endeavor to coordinate CNP maintenance with the Customer's maintenance outages. 10.1.3 CNP transmission line outages are required for CNP to perform testing of applicable wave traps of the Customer. 10.1.4 Outages of approximately ten hours duration for certain of the Customer's facilities are required for CNP's periodic maintenance of CNP high voltage metering instrument transformers. Transformer outages are required for metering instrument transformers installed on the high side of transformers. A total separation from CNP's system may be required for certain substation configurations.
10.2 Customer Maintenance 10.2.1 The Customer shall perform periodic inspections and preventive maintenance on all structures and equipment owned by the Customer except for equipment designated by CNP for maintenance by CNP. The Customer shall not perform preventive maintenance on the equipment maintained by CNP. The Customer shall maintain equipment logs and test reports, which shall be provided to CNP upon request. 10.2.2 Depending upon ownership, equipment maintained by the Customer may include the following: line surge arresters, potential and current transformers not owned by CNP, coupling capacitors, coupling capacitor potential devices, switches (including auxiliary contacts and motors if installed), breakers (bushings, mechanism, tanks), transformers (bushings, surge arresters, main tank, load tap changer, alarms), relays not tested by CNP, and DC battery system equipment. 10.2.3 The Customer shall notify the RTO System Scheduler at least ten (10) business days in advance before performing maintenance on potential or current transformers connected to CNP meters.
10.3 Monthly Inspections 10.3.1 The Customer shall perform monthly inspections to include the following as applicable. D Visual inspection of outdoor equipment including inside control cabinets D Verify oil levels n Verify transformer nitrogen blanket pressure
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71 • CenterPoint. Energy Transmission & Substation Outage and Clearance Coordination Procedures
D Verify transformer fan operation o Verify breaker compressor or hydraulic pump operation n Drain condensate from breaker mechanism air tanks o Verify operation of control house heating and air conditioning 10.4 Quarterly, Semi-annual Testing, and Inspection 10.4.1 CNP recommends Total Combustible Gas ('TCG") testing once every three months on transformers equipped with a nitrogen blanket. 10.4.2 Infrared thermography of high voltage equipment is recommended once every six months. 10.5 DC Battery System 10.5.1 The Customer shall perform periodic DC battery system equipment inspections and maintenance to include the following as applicable. n Every Month o Visually inspect batteries (corroded connections, leaks, cracked cases) D Visually inspect chargers D Verify and correct water levels o Record and verify float voltage D Record and verify ground reference voltage
D Every Six Months n Clean battery surfaces o Check charger ventilation o Record and verify cell voltages D Perform internal cell resistance testing D Measure inter-cell connection resistance D Record and verify specific gravity reading D Verify float and equalize voltage settings o Verify proper operation of chargers and alarms o Verify proper operation of high voltage shutdown circuits
10.6 Functional Testing 10.6.1 The Customer shall perform functional trip testing of each high voltage circuit breaker by tripping and closing the breaker from the breaker control switch at least once every year. This breaker tripping may be coordinated with the switching required for maintenance outages. 10.6.2 High voltage circuit breakers equipped with dual trip coils that use a common actuating shaft (e.g., Allis Chalmers, Westinghouse) require special functional testing. The Customer shall perform a test on each breaker by applying trip voltage simultaneously to both trip coils. If the breaker does not immediately trip, the voltage must be quickly removed to avoid damaging the coils. After verifying the wiring, the Customer shall appropriately label the control wiring. The Customer's maintenance procedures shall include tagging and properly reconnecting trip coil wiring. The Customer shall perform this test whenever a trip coil is replaced or breaker control wiring is modified.
10.7 Special Inspection and Testing
24
72 • CenterPoint. Energy Transmission & Substation Outage and Clearance Coordination Procedures
10.7.1 Industry experience may dictate that certain equipment requires special inspection and testing due to manufacturing defects or unacceptable failure rates and consequences. The Customer shall perform special inspection and testing based on manufacturer issued product service advisories and CNP issued advisories. 11 Plant Design Considerations
11 .1 Emergency Systems 11 .1. 1 Continuous electric service from utility power systems cannot be guaranteed even for facilities that are connected to a large number of transmission lines. The possibility exists that a total power outage or separation from the utility system may occur. It is important to consider this when plant emergency systems are designed.
11 .2 Automatic Reclosing 11.2.1 CNP utilizes automatic reclosing of high voltage circuit breakers following unplanned tripping of CNP transmission lines. CNP endeavors to intentionally delay the initial reclose attempt by at least one second. The Customer is responsible for the separation of necessary motors or other equipment within one second of the tripping.
11.3 System Voltage 11 .3. 1 Electric service from a utility power system cannot be guaranteed against fluctuations. Voltage sag is a common fluctuation that occurs during the time of a fault. The large majority of faults on a utility transmission system are single line to-ground faults. With automatic reclosing of circuit breakers, several voltage sags can occur within a one-minute period. Most voltage sags from faults on transmission systems have a very short duration of less than ten cycles with high speed fault clearing. Another common fluctuation is a transient voltage oscillation that occurs each time a capacitor bank is energized. Equipment, such as motor contractors, adjustable speed drives, programmable logic controllers, and high intensity discharge lamps, can be sensitive to these short duration voltage sag and transient voltage oscillation. 11 .3.2 It is important to consider voltage sag "ride-through" for equipment applied to critical processes where nuisance tripping can cause a whole process to shut down. Plant power systems and equipment control systems can be designed or modified to ride-through the most common voltage sags and transient voltage oscillations on utility power systems. CNP will provide additional information upon request.
11.4 Electrical Protection Coordination Studies 11.4.1 If the Customer performs plant electrical protection coordination studies, the Customer may contact a Transmission Accounts representative to request the available CNP system fault current and system impedance at the Customer's facility.
25
73 • CenterPoint. Energy Transmission & Substation Outage and Clearance Coordination Procedures
11.5 Substation Design Specifications 11 .5.1 The Customer can contact a Transmission Accounts representative to request current CNP specifications and applicable bills of material for new substations and substation equipment additions and replacement.
26
74 Exhibit "G" Telemetry Specification
75 SPECIFICATION
FOR
REMOTE TELEMETRY OF A CUSTOMER OWNED FACILITY ,CenterPoint . 9w Energy
ELECTRIC ENGINEERING DEPARTMENT
P.O. BOX 1700 HOUSTON, TEXAS 77251
REFERENCE DRAWINGS: Latest Revisions of CenterPoint Energy, CNP Drawing No.BSC-007-400-01 SH.3. CenterPoint Energy, Substation Telecom Board Design. CenterPoint Energy: T1 Cabinet Installation
REFERENCE SPECIFICATIONS: Latest Revisions of CenterPoint Energy, CNP Specification No. 007-231-14, Customer 138kV Substation Design.
REFERENCE DOCUMENTS: Latest Revisions of CenterPoint Energy, Transmission & Substation Outage and Clearance Coordination Procedures. CenterPoint Energ'4 Substation IFC Process.
CenterPoint Energy Houston Electric riNi.'J~ WRITTEN 12/30/03 C.W. Mogannam 8 12118/2014 Revised sections 2, 3, 8. CWM TVT I/ MOB CHECKED 12/30/03 R.M. Secrest 7 10123/2014 Revised References, Sec.2, 4, 5,87, CWM TVT MOB AP ROVED 12/30/03 M.W. Furnish Removed Fig 1,2 6 3126/2012 Revised Sec.2, 3, 5, 7, Fig 1,2 CWM WAC MOB PaQe 1of10 NO DATE REVISION BY CH APP SPC I 007 l-400 I 02 76 CONTENTS
TITLE PAGE NO.
SCOPE 3
GENERAL 3
SCADA SYSTEM 4
DESIGN, LAYOUT AND PHYSICAL CRITERIA 5
COMMUNICA TTON LINES 6
CALIBRATION AND MAINTENANCE 6
CURRENT TRANSFORMERS AND POTENTIAL TRANSFORMERS 7
DRAWING APPROVAL 7
TABLE I -ACCEPTABLE TRANSDUCERS AND TEST SWITCHES 8
LIST OF ABBREVIA TTONS USED IN FIGURES 9
FIGURE I -BREAKER CONTROL AND STATUS WlRING 10
CenterPoint Energy Houston Electric WRITTEN 12130103 C.W. Mogannam CHECKED 12130103 R.M. Secrest APROVED 12130103 M.W. Furnish Page 2 of 10 SPC I 001 I 400 I 02
77 1. SCOPE 1.1. This specification defines the requirements for the engineering, installation, calibration, and con1missioning of a Supervisory Control and Data Acquisition (SCADA) Remote Terminal Unit (RTU) and Metering Telemetry, as applicable, at a custorner owned facility on the CenterPoint Energy (CNP) transmission system.
2. GENERAL 2.1. Installation of a CNP SCAD A RTU in customer-owned facilities is required for all new transmission substations that have a circuit breaker that sectionalizes a CNP trans1nission line. 2.2. All equipment and work covered by this specification shall be designed, constructed, and tested in accordance \Vith the latest revisions or editions of industry requirements in effect at the time of fabrication. Industry requirements include the applicable codes, standards, specifications, regulations, tests, and procedures of all federal, state and local laws, and include (but are not limited to) the following: 2.2.1. American National Standards Institute (ANSI) 2.2.2. IEEE formerly the Institute ofEleetrical and Electronics Engineers, Inc. 2.2.3. National Electrical Manufacturers Association (NEMA) 2.2.4. Occupational Safety and Health Administration (OSHA) 2.2.5. Federal Communications Commission (FCC) 2.3. In the event of conflicting requirements, the order of precedence shall be this specification, other referenced CNP specifications, and the standards referenced in section 2.2. 2.4. CNP will specify the SCADA RTU and associated SCAD A equipment. The SCADA RTU will be in either a standalone cabinet or wall mounted cabinet to be installed in the Customer substation control building. The customer must provide interface equipment such as electronic panel meters, transducers, status and alarm contacts, cabling, terminal blocks, and conduit to provide the data required in this specification. Co1n1nunication equiptnent must also be installed and wired by Customer in the Customer substation control cubicle. Metering cabinets will be installed in accordance with the CNP Customer 138kV Substation Design Specification. 2.5. Co1nmunications between substation devices shall be serial. Routable protocol communication (i.e., Ethernet) or dial-up con1n1unication shall not be used for the CNP transmission systetn protection devices. 2.6. Equip111ent specified may be substituted with written approval from CNP Substation Projects and System Protection. 2. 7. All equipment, engineering and installation shall be furnished by the Customer unless otherwise noted in this specification or separate agreetnents. 2.8. Generating facilities will have additional data that is covered below and will be defined in the Standard Generating Interconnection Agreetnent.
CenterPoint Energy Houston Electric WRITTEN 12/30/03 C.W. Mogannam CHECKED 12/30/03 R. M. Secrest AP ROVED 12/30/03 M.W. Furnish Paqe 3 of 10 SPC I 001 I 400 I 02
78 3. SCADA SYSTEM 3.1. The SCADA RTU is composed of three subsystems: (1) analog, (2) status, and (3) control. 3 .2. Analog Subsystem: Analog Data is typically gathered from Intelligent Electronic Devices (IEDs) or transducers. IEDs include Electronic Meters and n1icroprocessor relays. Communication to various IEDs shall be serial, via DNP3 or Modbus protocols. If transducers are used, CNP will detennine the transducer electrical requirements. See Table 1 for acceptable transducer models. Meter test switches are required for the transducer current and voltage connections. The Customer shall provide an electrical relaying and inetering one-line diagratn of the proposed Customer-owned substation for review by CNP. 3.2.1. Customer Substation Analog Tele1netry Requirements 3.2. I .1. Kilovolts for each substation bus, A0 3.2. I .2. Megawatts for each line position, 30 3.2.1.3. Megavars for each line position, 30 3.2.1.4. Megawatts for each substation load and/or substation transmission level transfonner, 30 3.2.1.5. Megavars for each substation load and/or substation trans111ission level transformer, 30 3.2.2. CNP will require the following additional analog data from a Generating facility: 3.2.2.1. Generator terminal voltage for each generator bus, A phase only 3.2.2.2. Megawatts (net preferred) for each generator unit, 30 3.2.2.3. Megavars (net preferred) for each generator unit, 30 3.2.2.4. Frequency for each generator unit 3.2.2.5. Data from the plant electrical load EPS meters (watts, vars, watt-hour from each meter) 3.3. Status Subsystem: The status subsystem of the SCADA RTU shall consist of the following. 3.3. I. Status of selected transmission voltage circuit breakers or other devices directly affecting the CNP electrical syste1n, as detern1ined by CNP RTO. Status shall be derived from either an isolated auxiliary na 11 contact in the breaker or monitoring a trip coil of the breaker. Refer to Figure 1 for Breaker Status Connections. 3.3.2. Indication oflow voltage and battery charger failure is required for the 130 VDC battery system(s). Typical charger alanns include the following: low voltage, high voltage, loss of AC input, and loss of charger. All these indications shall be combined so that an occurrence of any one of these shall cause a single battery alann (normally open contact) to the SCAD A RTU. 3.3.3. SCADA Close Inhibit (SCI) indication is required of breakers controlled by SCAD A whenever a lockout relay can inhibit breaker closure by SCAD A. A dry, normally open, contact from that relay shall be supplied for SCI indication. Indication contacts from all lockout relays shall be wired in parallel for a single indication in the SCAD A cabinet, see Figure I. 3.3.4. Indication of Carrier Tester (CAR) or Pilot (PIL) relaying failure. 3.3.5. Indication for the loss ofa potential to a line relay (PT!) that could cause a misoperation of the zone relaying under high load conditions. This alarm is typically generated by a contact from the line relay. Indications from separate relays will be co1nbined for a single alarm. 3.3 .6. Indication of a failed self-check diagnostic of a microprocessor based relay. Designated Relay CPU Fail (RCPU). This alann is typically generated by a contact fro1n the line relay. Indications fro1n separate relays will be combined for a single CenterPoint Energy Houston Electric alarm. WRITTEN 12/30/03 C.W. Mogannam CHECKED 12/30/03 R.M. Secrest APROVED 12/30/03 M.W. Furnish Page 4 of 10 SPC I 007 I 400 I 02
79 3.3.7. CNP will require the following additional status signals from the Generating facility: 3.3.7.1. Generator Breaker for each unit 3.3.7.2. Motor operated switches for each unit 3.3.7.3. Generator auto1natic voltage regulator status (Autotnatic/Manual). 3.4. Control Subsystem: The control subsystem of the SCADA RTU shall consist of the following: 3.4.1. CNP shall have remote control of all transmission (69kV, 138kV, 345kV) circuit breakers that directly affect the CNP transmission systen1. Dual remote control (control of a breaker by both the Custo1ner's control system and CNP RTO) is not permitted. Figure 1 illustrates how SCAD A control will interface with a typical breaker control scheme. 3.4.2. CNP shall have remote control, automatic carrier removal (ATCR), of each pilot relaying scheme. A control contact from the SCADAR TU shall be installed in each pilot circuit. See Figure 1 for typical carrier control circuit.
4. DESIGN, LAYOUT AND PHYSICAL CRITERIA 4.1. SCADA Set Designation: The type of SCAD A RTU installed by CNP will depend on the number of controlled breakers. 4.1.1. At ring bus substation or breaker and half substations CNP will typically install a free-standing cabinet 24" wide by 18" deep and 72'1 tall, with front access. Clearance of 30" in fi·ont of the door shall be reserved for maintenance access. Substations with more than four transmission breakers may require a larger cabinet(s). Refer to latest Customer RTU drawing submitted by CNP at the project kick-off. 4.1.2. Tap substations will generally require a smaller wall n1ounted cabinet. The wall mount cabinet is 3011 wide by 12" deep and 4211 tall. Clearance of 30 11 in front of the door shall be reserved for maintenance access. 4.2. Connections to the RTU: The Construction Contractor shall install all interconnections between the SCADA RTU and the substation panels. 4.2.1. The Customer shall provide a 120 VAC, fifteen (15) amp, dedicated AC power circuit, protected by a fifteen (15) amp circuit breaker, to the SCAD A RTU Cabinet for lighting and a convenience outlet. 4.2.2. The Customer shall provide a 130 VDC, fifteen (15) amp, dedicated DC power circuit, protected by a fifteen (15) amp circuit breaker, to the SCADA RTU Cabinet for the main RTU power. 4.2.3. All cable shields shall be grounded at a location other than the SCADA RTU Cabinet. Cable shields shall be grounded at one end only. 4.3. Cabling: The Customer shall size and install all conduit or cable troughs in accordance with ANSJ/NFPA 70 (National Electrical Code). 4.3.1. Polyethylene Polyvinylchloride (PEPVC) insulated shielded 2/C #16 cable with stranded copper conductors shall be used for tenninations for all transducer outputs. 4.3.2. Breaker controls shall use seven conductor (#12) PEPVC insulated cable with stranded copper conductors for terminations. 4.3 .3. Two conductor(# I 0 or larger) PEPVC insulated cable with stranded copper conductors shall be used for terminations of the AC and DC power circuit. CenterPoint Energy Houston Electric WRITTEN 12/30/03 C.W. Mogannam CHECKED 12/30/03 R.M. Secrest AP ROVED 12/30/03 M.W. Furnish Page 5 of 10 SPC I 001 I 4oo I 02
80 4.3.4. Status and alarms shall be terminated with two conductor (#16) PEPVC insulated cable with stranded copper conductors. 4.3.5. The Customer shall install the necessary conduit or cable management between the SCADA RTU and the relay panels.
4.4. Every breaker with 130 VDC SCADA control circuits shall have breaker coil surge suppression. A one hundred (100) ohm, eleven (11) watt resistor (Ohmite style 995-IOA) and a zener diode (Motorola type JN305 IA) or equivalent shall be used for this suppression. The series combination of the zener diode and the resistor shall be parallel to each breaker trip and breaker close coil. States slider-link tenninal blocks shall be installed in the breakers for terminating the resistors and zener diodes. CNP will verify breaker coil surge suppression. See Figure I.
5. COMMUNICATIONLINES 5.1. The Customer shall provide and 1naintain a full business (JFB) phone line and telephone for voice communications tenninating inside the substation control cubicle. This phone shall be direct dial and not go through the Customer's main switchboard or extension. This phone shall have a cord extendable such that the front of the relay panels and SCADA RTU are visible from the phone. This line inay also be used by CNP for remote interrogation of tneters. 5.2. CNP shall provide additional communication Iine(s) from the telephone company for EPS Generation metering and SCADA as required, terminating at the Custo1ner's telephone de111arcation point.
5.3. The Customer shall supply the name and telephone number of a representative for purposes of co~ordinating the installation of these line(s). 5 .4. The Customer shall provide communication cable with multiple pairs between the telephone service provider demarcation point and the substation control cubicle for use by CNP. If there are not enough pairs the customer shall install new cable to provide the needed pairs. 5.5. The customer shall provide wall space for the installation of a CNP Telecom1nunications cabinet and telephone board . The CNP Telecom cabinet shall be 3' x 3' x 3' and swing out. Clearance of30 11 in fi·ont of the door shall be reserved for maintenance access. See the CNP Substation Teleco1n Board Design specification for details on the Telecom board .. 5.6. The telephone communication circuit(s) shall be specified to operate in the event of power failure. The conununication line shall remain operational in the event a line conditioner or loopback device fails.
6. CALIBRATION AND MAINTENANCE 6.1. After all equipment necessary for remote telemetry has been installed, CNP personnel will calibrate and verify operation of all equipment installed per this specification.
6.2. The RTU and transducers installed per this specification will be maintained by CNP unless otherwise noted in an agreement with the Customer. Maintenance will include accuracy checks, recalibration and replacement/repair of equipn1ent when needed. 6.3. CNP shall furnish locks that will remain in series with Customer locks to permit access to all switchyard gates, substation control CenterPoint Energy Houston Electric cubicle door(s), and disconnect switches. WRITTEN 12/30/03 C.W. Mogannam CHECKED 12/30/03 R.M. Secrest AP ROVED 12/30/03 M.W. Furnish Page 6of10 SPC I 007 I 400 I 02
81 7. CURRENT TRANSFORMERS AND POTENTIAL TRANSFORMERS 7.1. The current transfonners (CTs) and potential transformers (PTs) necessary for transducers and 1neter circuits ite1nized in this specification shall be provided according to CNP specification 007-231-14. If a particular application is not covered by this specification. then CNP will designate the necessary PT(s) and CT(s) on the substation one-line diagram that the Customer submits for con1ment and approval. 7 .2. For some substation layouts a potential rollover circuit shall be needed. If a potential rollover circuit is needed, it will be designated by CNP on the one-line diagratn that the Customer submits for comment and approval.
8. DRAWING APPROVAL 8.1. The Engineering Contractor shall provide electronic and paper copies of all drawings showing equipment connections and structural details of all equipment associated with SCADA installation as per the CenterPoint Energy Substation IFC Process document. 8.2. Drawings required by this specification include: 1. Substation one-line relaying and metering diagrams illustrating the overall telemetry scheme, 2. Substation control cubicle layout(s) and floor plan(s), 3. Conduit and cable lists 4. Conduit Layout or Plan and Profile 5. RTU manufacturers prints and Customer connections 6. AC Schematics for all power and control circuits, 7. AC Relaying Schematics (Electrical Three-Line), 8. Relay panel layouts, 9. Bill ofn1aterial for items required by this specification, I 0. Battery charger alarm relay(s) schematics, 11. AC & DC Distribution Panels, 12. Communication cable and conduit routing through Customer facility, 13. Customer Facility Plot Layout,
CenterPoint Energy Houston Electric WRITTEN 12/30/03 C.W. Mogannam CHECKED 12/30/03 R.M. Secrest APROVED 12/30/03 M.W. Furnish Paae 7 of 10 SPC I 007 I 400 I 02
82 DESCRIPTION MANUFACTURER MODEL NO. MONITORING POINTS
AMETEK ONE PER SUBSTATION VOLTAGE TRANSDUCER VTI IOA4 SCIENTIFIC COLUMBUS BUS
TEST SWITCH ONE PER EACH DURHAM 2-I022F-03 SINGLE PHASE TRANSDUCER
WATT/VAR TRANSDUCER AMETEK ONE PER EACH LINE OR XLWV5C5 SINGLE PHASE SCIENTIFIC COLUMBUS LOAD
WATT/VAR TRANSDUCER AMETEK ONE PER EACH LINE, XLWV342K5A4 THREE PHASE SCIENTIFIC COLUMBUS GENERA TOR OR LOAD
TESTSWJTCH ONE PER EACH DURHAM 2-I058F-00 THREE PHASE TRANSDUCER
Table 1 ACCEPTABLE TRANSDUCERS AND TEST SWITCHES
CenterPoint Energy Houston Electric WRITTEN 12/30/03 C.W. Mogannam CHECKED 12/30/03 R.M. Secrest APROVED 12/30/03 M.W. Furnish Paae 8 of 10 SPC I 001 I 400 02
83 LIST OF ABBREVIATIONS USED IN FIGURES
aN4, aN14 ~TYPICAL WIRE NAMES IN CNP CARRIER RELAYING SCHEMES
ATCR ~AUTOMATIC CARRIER REMOVAL
C~CLOSE
CS~ CONTROL SWITCH
CVE ~ SYNCRO-VERIFIER RELAY
!CR~ INDICATION CONTROL RELAY
N 11, N21 ~TYPICAL WIRE NAMES IN CNP RECLOSE REMOVAL SCHEMES
NO ~NORMALLY OPEN
OC ~BREAKER CLOSE COTL
RC~ AUTOMATIC RECLOSING RELAY
RR~ RECLOSE REMOVAL LATCHING RELAY
TC ~BREAKER TRIP COIL
X, Y ~AUXILIARY COILS OF RC RELAY
SSS ~SLIDER-LINK TERMINAL
R~RESISTOR
DDD ~ZENER DIODE CenterPoint Energy Houston Electric AMS ~AUTOMATIC/MANUAL THROWOVERSWITCH WRITTEN 12/30/03 C.W. Mogannam CHECKED 12/30/03 R. M. Secrest APROVED 12/30/03 M.W. Furnish Paae 9 of 10 SPC I 007 I 400 I 02
84 Pl +130VC£
Nl !30VOC RETURN ANS AMS RELAY MANUAL r'lOJ TRIP c_s ,I:_u_:_o______.I cs T yRCI ----- __791 J L 1__ !2_U___ _ ~ ~l~ I
s Nl l wofl~ ~5c~gPROCESSOR• RELAY I I CVE RECLOSE R RELAY INPUT FOR I I RE~OVRL I, I P l T I I RELAY BLOCK I 86 c I I I SCAD/\H NOTE! I c--o~v I ~ 1 CLOSE I RR I INHIBIT Nll ~ I I I Nl~I 1r------:.r----- 2 --I ., 8 I I TO {---aNl'=c:JI.rm l c0· CilRR!ER I I REL'YING I I J: I -- aN4 I ~ I cc I I I ~ I I SCRDR ,------I I N.O. I CLGSE ,------«D----t _ 1 INHIBIT J_ BS ;I 1,ovoc I l I 1... ______1 INDICATION I IC I LEGEND BR ERKER L______I
RR = RECLOSE REMOVAL LilTCHI~'!l RELAY INSIDE SCi\Dil RTCR = Alff0.'1ATIC CARRIER REMOVf\L !CR = J''!l!CAT!ON CONTROL RELAY MC,!TORS STATUS OF A SH!TCH ;a m - SCI = SCADA CLOSE INHIBIT 0~1~1 (") -I~ OISCONNECTING TERMINRL BLOCK;
86 138KV CKT
138KV CKT 05 WllP
0 0:
_J _J Z =====1 I w I (fl
REMOVE ROAD
I I
0 0:
LL 0 z 8 I- APPROX IMATE 750 ' GENERATOR PRELI MINARY LEAD lNSTALLED AND OWNED BY CNP NO T FOR CONSTRUCTION PURPOSES POINT OF INTE RCONNEC T I ON~ BASIC OFFER APPROACH SPAN llND TERM l NAT l NG ,,,,,. STRUCT URE INSTllLLED AND OWNED ~ CENTERPO INT ENERGY BY GENERATOR 138KV DEVELOPMENT PLAN FOR TO GENER/I TOR FRIENDSWOOD/H.O.CLARKE ENERGY GENERAT ION STEP-UP TRF STANDARD GENERATOR INTERCONNECTION AGREEMENT Generation lnterconnocttons 8re considered m8rkel sensitive ln f orm8 tton . To preserve the lnt.ergrll'd LEGEND of the m8rketpl8ce .. It Is essentia l tha t this lnform8llon not be ~ade EXISTING CNP H.O. CLARKE FACILITIES pub lic or di sc los 87 I ~-~.''·. .!•,~~ -~~~ ii~] !Ii------, il~ "_, •~ ;I I H jt·-F .. "0 88 Exhibit "I" Specification for Customer 138 kV Substation Design I 89 5-8-2006 Addendum to Spec. No. 007-231-14 Rev. 14 7-22-2005 SPECIFICATION FOR CUSTOMER 138 kV SUBSTATION DESIGN CENTERPOINT ENERGY SUBSTATION OPERATION DEPARTMENT P .. O. BOX 1700 HOUSTON, TEXAS 77251 Date Original Version Revision Comments 5-8-06 a. Table of Contents (TOC) a. Added missing TOC items 4 a. Updated Table of Contents b. REFERENCE DRAWINGS not &8 b. Reference drawings included in this document b. Added drawings to end of this included document I 90 SPECIFICATION FOR CUSTOMER 138 kV SUBSTATION DESIGN CENTERPOINT ENERGY SUBSTATION OPERATIONS DEPARTMENT P.O. BOX 1700 HOUSTON, TEXAS 77251 REFERENCE DRAWINGS: Latest revision of CenterPoint Energy 004-241-01, Customer-Owned Substation Line Termination Standard CenterPoint Energy 171-190-06, 138 kV Standard, Instrument Transformer Standard CenterPoint Energy 581-500-01, 138 kV Potential Transformer Schematic and Wiring Diagram REFERENCE DOCUMENT: Latest revision of Operation of a Customer Owned Substation on CenterPoint Energy's Transmission System REFERENCE SPECIFICATIONS: Latest revision of CenterPoint Energy 007-231-78, Specification for Cogenerator Connected to CenterPoint Energy Trans. System CenterPoint Energy 007-400-02, Specification for Remote Telemetry of a Customer-Owned Facility REFERENCE STANDARDS: Latest revision of AASHTO IEEE C57.12.00 AC! 318 IEEE C57.13 AISC, "Manual of Steel Construction" IEEE C2 (NESC) ASCE 10 IEEE Std. 80 ANSI Cl2.l IEEE Std. 519 ANSI C37.32 IEEE Std. 837 ANSI C37.06 IEEEStd.1119 IEEE C37.04 IEEE Std. 998 IEEE C37.40 IEEE Std. 142 IEEE C37.60 NEMACC 1 CENTERPOINT ENERGY HOUSTON, TEXAS WRITTEN 419174 E. C. Reid CHECKED 4110174 L.G.Pond APPROVED 7/17/74 C. S. Kayser I 14 I 7-22-2005 I Change to 4000A and other updates I Var I Var I DRS SHEET I I OF I 26 INO I DATE I ITEMS REVISED I BY I CH I APP SPECIFICA TJON NO. 007 231 14 91 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN TABLE OF CONTENTS TITLE 1. SCOPE ...... 3 2. GENERAL ...... 3 3. CENTERPOINT ENERGY SYSTEM CHARACTERISTICS ...... 4 4. ELECTRICAL DESIGN CRITERIA ...... 4 s. STRUCTURAL AND MECHANICAL DESIGN CRITERIA ...... 6 6. SITE CRITERIA ...... 8 7. HIGH VOLTAGE EQUIPMENT ...... 9 8. CONTROL HOUSE ...... 12 9. METERING EQUIPMENT ...... 12 10. FUSING ...... 15 11. PROTECTIVE RELAYING ...... 16 12. UNDER-FREQUENCY LOAD SHEDDING ...... 18 13. REMOTE TELEMETRY ...... 19 14. GENERATION ...... 19 15. DRAWING COMPLIANCE REVIEW & COMMENTS ...... 20 16. EQUIPMENT INSTALLATION ...... 21 17. REQUIRED TESTS AND INSPECTIONS ...... 22 18. RECOMMENDED TESTS AND INSPECTIONS ...... 24 REFERENCE DRAWINGS ...... 26 Rev Date Items Revised Specification No Page File !4 7-22-2005 4000A and other updates 007-231-14 2 CNP _007-231-14revl4_7-22-2005 Addendum 5-8-2006.doc 92 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN 1. SCOPE I.I. This specification covers design criteria for 138 kV customer-owned substations connected to the CenterPoint Energy Houston Electric, LLC (CenterPoint Energy) transmission system. 2. GENERAL 2. I. Any customer that is approved by CenterPoint Energy to receive service from the CenterPoint Energy 138 kV transmission system is required to provide a substation capable of accepting that service from CenterPoint Energy. The customer's substation becomes an integral part of the CenterPoint Energy transmission system network and therefore has a significant impact on overall system reliability. Consequently, the customer is obligated not only to meet present CenterPoint Energy specifications, but also to modify the substation in the future as the CenterPoint Energy transmission system continues to evolve. When deemed necessary by CenterPoint Energy, changes may be needed to conform to industry standards, transmission system characteristics, and CenterPoint Energy practices or to take advantage of technological advances which will maintain the present reliability of the substation. 2.2. All equipment shall be in accordance with designated standards of this specification, the American National Standards Institute (ANSI), the Institute of Electrical and Electronic Engineers (IEEE), the American Society of Civil Engineers (ASCE), the American Institute of Steel Construction (AISC), National Electrical Manufacturing Association, (NEMA) and the American Concrete Institute (AC!). In the event of conflicting requirements, the order of precedence shall be this specification, ANSI, IEEE, ASCE, AISC, NEMA and AC! Standards. All electrical clearances shall comply with the latest version of the National Electric Safety Code (NESC). 2.3. This specification is not intended to be totally comprehensive. To ensure the efficient coordination between CenterPoint Energy and the customer during the design and construction of the customer's substation, CenterPoint Energy requires that engineering documents be submitted to CenterPoint Energy for review before ce11ain equipment is ordered or construction begins. All items requiring CenterPoint Energy review are listed in A11icle 15.0 of this specification and shall be submitted in writing to the designated Project Coordinator, or designated representative. 2.4. Any deviations from this specification or CenterPoint Energy reviewed project drawings shall require written acceptance by the responsible CenterPoint Energy Project Coordinator. 2.5. All labor and equipment shall be furnished by the customer unless otherwise noted in this specification. 2.6. Unless otherwise stated in this specification: 2.6.1. CenterPoint Energy will provide only functional reviews of complete and final drawings and schematics, 2.6.2. CenterPoint Energy will not verify or correct customer's point-to-point wiring, and 2.6.3. CenterPoint Energy will require specific tests which are to be conducted by the customer to verify the proper operation and coordination of the substation's protection and control equipment. 2.7. CenterPoint Energy reserves the right to refuse to energize any service which fails to meet this specification. Rev Da tc Items Revised Specification No Page File 14 7-22-2005 4000A and other updates 007-231-14 3 CNP _007-23 l-!4revl4_7-22-2005 Addendum 5-8-2006.doc 93 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN 2.8. The customer will coordinate the operation of their high voltage facilities with CenterPoint Energy's Real Time Operations Division per CenterPoint Energy's "Transmission & Substation Outage and Clearance Coordination Procedures" document. 2.9. It is the customer's responsibility to comply with the applicable laws, ordinances, codes, rules, and regulations established by the appropriate government entities. 2.10. Because the customer's substation becomes an integral part of the CenterPoint Energy transmission system network CenterPoint Energy requires access to the substation 7 days-a-week, 24 hours-a-day, 365 days-a-year. Access to the substation by CenterPoint Energy personnel should be considered when determining the location and plant operating procedures. 3. CENTERPOINT ENERGY SYSTEM CHARACTERISTICS 3.1. CenterPoint Energy's phase rotation is designated C-B-A counterclockwise and the customer shall phase his equipment accordingly. Connection of the customer's H 1-H2-H3 power transformer leads to CenterPoint Energy's C-B-A, B-A-C or A-C-B, respectively, is recommended. 3.2. The steady-state nominal system voltage is 138 kV +/- 5%, wye effectively grounded. Transient conditions exceeding this range may be encountered. See Sub-articles 3.4, 4.6 and 7.1.4 for additional relevant information. 3.3. Frequency, which ERCOT is responsible for maintaining, is nominally 60 Hz. Refer to ERCOT (www.ercot.com) Operating Guides and Protocols for information regarding frequency regulation. 3.4. The customer's equipment "voltage dip ride through" design criteria, that CenterPoint Energy suggests the customer utilize when designing and selecting plant equipment is illustrated in figure 3.1. Vr0% . T ' v = 100% J_ -- . - 12 cycles "V" represents the phase-to-neutral voltage at the customer's "load side" of a delta wye transformer for a phase-to-ground fault at the "high side" of the transformer. Figure 3.1 3.5. Multiple shot, staggered, relay supervised, automatic reclosing is utilized on the CenterPoint Energy transmission system. The first automatic reclosing attempt on CenterPoint Energy transmission line will occur a minimum of one second after the fault has cleared. The number of automatic reclosing attempts varies, but the total duration of the automatic reclosing sequence is typically one minute. The customer shall accordingly coordinate operation and protection of electric motors, computers and other plant equipment. 4. ELECTRICAL DESIGN CRITERIA Rev Date Items Revised Snecification No, Page File 14 7-22-2005 4000A and other updates 007-231-14 4 CNP _007-231-14revl4_7-22-2005 Addendum 5-8-2006.doc 94 CenterPoint Energy SPECIFICATION FOR CUSTOMER 13 8 KV SUBSTATION DES I GN 4.1. The minimum acceptable electrical design characteristics are listed below: Bus, Switch and Insulator Impulse Level 650 kV BIL in a non-contaminated area 750 kV BIL or 650 kV BIL with extra creep in a contaminated area Note: CenterPoint Energy shall make determination of contaminated or non-contaminated area. Transformer Winding Impulse Level 550 kV BIL Bus and Switch Insulator Leakage Distance 132 in. creep (equivalent to 750 kV BIL or extra creep 650 kV BIL) Apparatus Bushing Leakage Distance 92 in. creep (equivalent to 650 kV BIL) (circuit breakers, bushings, transformer bushings, etc.) Phase to Ground Clearance 52 in. (Metal to Metal) Phase to Phase Bus Spacing 63 in. (Metal to Metal) (including vertical spacing at crossover point of high and low bus) Phase to Phase Bushing Spacing (138 kV) 84 in. (Center Line to Center Line) Phase to Phase Horizontal Spacing 144 in. (Center Line to Center Line, regardless of at Incoming Line Dead End Structure the line angle) 4.2. "Full loop" (ring bus or breaker-and-a-halt) or "loop tap" are standard substation configurations allowed by CenterPoint Energy. 4.3. For "full loop" substations, "loop tap" substations or substations arranged for future "loop" service, the continuous current rating of all equipment in the substation "loop" and incoming transmission line positions (transmission line disconnect switches, line traps, etc.) shall be 4,000 A minimum, unless otherwise specified by CenterPoint Energy. For substations with four or more 138 kV transmission lines, the continuous current rating of equipment in the substation may be required to be greater than 4,000 A. The 138 kV substation shall be designed for a short circuit current of 63 kA rms symmetrical, with X/R ratio of 15. 4.4. A key interlock system is not permitted on I 38 kV equipment. 4.5. The customer's connected load and equipment shall be designed and operated to adhere to the recommended harmonic limits of IEEE Std. 519. 4.6. The CenterPoint Energy flicker limit criteria for I 38 kV customers is as follows: 4.6.1. The operation of customer's equipment (starting of motors, furnaces, etc.) shall not produce a voltage dip greater than 2.0% at the customer's high side bus with one transmission line segment directly associated with the electrical supply to the customer substation out-of-service. Rev Date Items Revised Specification No. Page File 14 7-22-2005 4000A and other updates 007-231-14 5 CNP _007-23 l-14revl4_7-22-2005 Addendum 5-8-2006.doc 95 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN 4.6.2. If the starting of the customer's equipment produces a voltage dip greater than 1.5% at the customer's high side bus with all transmission line segments in-service, the customer shall contact CenterPoint Energy for further evaluation. 4.7. The substation ground mat shall be designed for a short circuit current of 63 kA rms symmetrical with X/R ratio of 15 and duration of 0.25 seconds and comply with IEEE Std. 80 and IEEE C2 (NESC). Ground mat connections shall comply with IEEE Std. 837. 4.8. The substation direct lightning stroke shielding design shall comply with IEEE Std. 998. 5. STRUCTURAL AND MECHANICAL DESIGN CRITERIA 5.1. The customer shall provide a complete structural and foundation design package for the dead-end structures (supporting the CenterPoint Energy transmission lines connected to the customer's 138 kV substation) and the instrument transformer stands in accordance with Atticle 15.0. The design package shall be signed and sealed by a registered professional engineer and shall include design references/codes, computer analysis, member design, connection design, foundation design, structural and foundation drawings, and all other information that documents the design of the structure(s). 5.2. Design shall be based upon loadings realistically combiued to cause the most unfavorable effect upon the structure or component. Refer also to Sub-Article 5.4 and 5.5.5. 5.3. Structures shall meet the Strength Requirements of IEEE C2 (NESC), Section 26, for grade B construction. 5.4. The minimum acceptable structural design loading criteria shall be the more severe of the following two cases: 5.4.1. Case 1 - Combined Ice and Wind Loading: Reference specification IEEE C2 (NESC); minimum allowable strength factors per Section 26, Table 261-lA or Table 261-1 B; loading requirements per Section 25, Rule 250.B and Table 250-1; and loading components to be applied to the structure shall be according to Fig.5.1. i----_.1 Transverse ~ Longitudinal Wind . Direction St-+ St ~ Tt Tt Tt S1 S1 T1 T1 T1 Wind and Ice loads are specified in Section 25 of ANSI/IEEE C2 Static Wire Conductor Wire Si = 6.00 kips/wire longitudinally Tl= 10.0 kips/phase longitudinally St= 3.00 kips/wire transversely Tt = 5.00 kips/phase transversely Sv = 0. 50 kips/wire vertically Tv = 1.50 kips/phase vertically CASE 1 - Combined Ice and Wind Loading - Overhead View. Static wire and conductor wire loading component (Overload capacity factors not included.) Figure 5.1 Rev Date Items Revised Specification No Page File 14 7-22-2005 4000A and other updates 007-231-14 6 CNP_007-231- l 4rev 14 _ 7-22-2005 Addendum 5-8-2006.doc 96 CenterPoint Energy SPECIFICATION FOR CUSTOMER I38 KV SUBSTATION DESIGN 5.4.2. Case 2 - Extreme Wind Loading: Reference specification; IEEE C2 (NESC) Section 25, Rule 250.C; minimum allowable strength factors per IEEE C2 (NESC), Section 26, Rule 260.C; and magnitude and direction of static wire and conductor wire loading components to be applied to the structure shall be according to Fig.5.2. ir----• Transverse Longitudinal Wind Direction For Case 2 the following shall apply: Basic Wind speed determined from wind map in, Exposure category C, Importance factor 1.0, Design wind pressure equation and coefficients per IEEE C2 (NESC) Rule 250.C in latest version. Static Wire Conductor Wire SI = 6.00 kips/wire longitudinally Tl= 15.0 kips/phase longitudinally St= 3.00 kips/wire transversely Tt = 7.50 kips/phase transversely Sv = 0.50 kips/wire vertically Tv = 1.50 kips/phase vertically CASE 2 - Extreme Wind Loading - Overhead View. Static wire and conductor wire loading component: (Overload capacity factors not included.) Refer to Sub-Article 8.1.2.4.1 Figure 5.2 5.5. DEAD-END STRUCTURES 5.5.1. In the absence of specifically defined criteria by CenterPoint Energy, the following design criteria shall be used as default design values for dead-end structures. 5.5.1.1. The conductor height at attachment shall be 35 feet above the finished substation grade. 5.5.2. Customer shall design all attachment points to ensure that sufficient electrical clearance is maintained to the customer's structure ground and equipment. CenterPoint Energy will extend the load carrying conductor to the first item of customer's equipment or bus and will furnish, own and maintain all necessary fittings for terminating the line conductors including the tower fittings, suspension insulators, dead-end clamps and line conductor terminal fittings with NEMA standard four-hole flat pads (0.5625 in. diameter holes, 1.75 in. centers) for attachment to the first item of equipment or bus in the customer's substation. CenterPoint Energy will also furnish stirrup clamps or other similar devices (such as a bar on the NEMA pad for ACSS conductors) on the line conductors as required for com1ection of surge arresters and potential transformers. 5.5.3. Customers shall provide pull-off plates (0.625 in. minimum thickness) for terminating the line conductors and which have a 0.8125 in. diameter chamfered hole at the center of a 1.50 in. radius rounding of the end of the plate. In addition, the customer shall provide pull-off plates (0.375 in. minimum thickness) for terminating the static wires and which have a 0.8125 in. diameter chamfered hole on a 1.50 in. radius rounding of the end of the plate. All pull-off plates must satisfy Equation 4.6-1 and 4.6-2 in ASCE 10. Details for division of ownership shall be in accordance with CenterPoint Energy Drawing 004-24 I -0 I. Rev Date Items Revised Snecification No Page File 14 7-22-2005 4000A and other updates 007-231-14 7 CNP _007-23 l-14rcvl4_7-22-2005 Addendum 5-8-2006.doc 97 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN 5.5.4. The height of the dead-end structure's conductor attachment shall be in accordance with the National Electric Safety Code (IEEE C2) or 35 ft whichever is greater, unless otherwise specified by CenterPoint Energy. The static wire height at attachment shall be at a sufficient elevation and position to provide a shield angle to the outside conductors of 30° and 45° between two adjacent static wires (see IEEE Std.142). 5.5.5. The installation of fiber optic cable may be required for transmission protective relaying and/or control purposes. The fiber optic cable installations will normally be installed underground. However, should an overhead installation be required, additional loadings will be imposed on the customer's dead end structure. Additional design information concerning the fiber optic cable will be supplied by CenterPoint Energy when fiber optic cable is to be used. Typically the connection for the fiber optic cable is at least 8 ft from the nearest conductor. 5.6. INSTRUMENT TRANSFORMER STANDS When high side metering is utilized, the customer shall provide stands for mounting CenterPoint Energy furnished instrument transformers and design and build foundations to support the stands. The design shall be in accordance with Sub-Articles 5.1 - 5.4 of this specification. The necessary design parameters are indicated on CenterPoint Energy Drawing 171-190-06. 6. SITE CRITERIA 6.1. Site preparation and plot plan drawings shall be submitted to CenterPoint Energy for comment. Facilities that must be shown on this drawing include dimensions of the substation site, access roadways, space between the substation and access roadways, walks, culve1is and ditches. Refer to Article 15.0 Rev Date Items Revised Snecification No. Page File 14 7-22-2005 4000A and other updates 007-231-14 8 CNP_007-231-!4revl4_7-22-2005 Addendum 5-8-2006.doc 98 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN 6.2. The customer shall stake the location of the dead-end structures according to Figure 6.1. CenterPoint Energy phasing SWITCH GEAR A BUILDING #2 A #1 LD -- CUSTOMER TO STAKE DEADEND W RACKS AT THESE LOCATIONS Staking Requirements for Typical Customer Substation Figure 6.1 6.3. An all weather access roadbed shall be provided to the substation capable of supporting heavy construction vehicles. The areas in substations that need to support heavy vehicular traffic should conform to AASHTO H20 loading. 6.4. Access for CenterPoint Energy to attach line conductors to the dead-end structures shall be provided by either: 6.4. 1. A 25 ft wide, level, and unobstructed access outside the substation site from a main road to the CenterPoint Energy right-of-way and in front of the dead-end structures with fencing a maximum of 20 ft from the attaclunent point of the dead-ends and a 13 ft (minimum) wide gate for access into the substation. 6.4.2. A 25 ft wide access inside the substation from the substation access gate (20 ft wide minimum) to the front of the dead-ends with fencing a minimum of 25 ft from the attachment point. 6.5. Access and space shall be provided for installation and future replacement of high voltage equipment including metering instrument transformers. 7. HIGH VOLTAGE EOUIPMENT 7.1. POWER TRANSFORMERS 7.1.1. Power transformers shall conform to IEEE C57.12.00. In addition, sudden pressure and low oil level should be connected for alarming and tripping. 7.1.2. Power transformers shall have a minimum of two 600:5 A multi-ratio current transformers (CT's) per 138 kV bushing. Each CT shall have IEEE C57.13 accuracy C400 or better. Where Rev Date Items Revised Specification No Page File 14 7-22-2005 4000A and other updates 007-231-14 9 CNP _007-23 l-14rcvl4_7-22-2005 Addendum 5-8-2006.doc 99 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN applications require additional CT's and/or different ratios, CenterPoint Energy shall provide ratios to support equipment purchase schedule. The secondary resistance of power transformer bushing CT's shall not exceed 0.0025 n per turn. CT secondary rated continuous current shall be 10 A minimum. Rating Factor (R.F.) shall equal 2.0. 7.1.3. High side surge arresters shall be provided in accordance with Sub-Article 7.4. 7.1.4. The customer shall determine the need for, and if applicable, settings for a tap changer for de energized operation and/or on-load tap changer. CenterPoint Energy recommends automatic on-load tap changer. 7.2. CIRCUIT BREAKERS 7.2.1. Circuit breakers shall be of the three-pole, outdoor type, 138 kV nominal, in accordance with ANSI C37.06 and IEEE C37.60, C37.04 and C37.40. 7.2.2. Continuous current rating of 138 kV circuit breakers shall be 4,000 A, with a three phase symmetrical short circuit interrupting capability of 63 kA rms symmetrical. For substations with four or more 138 kV transmission lines, circuit breakers may be required to have a higher continuous rating. The rated interrupting time of the circuit breakers shall be three cycles or less. In some applications, the installation of TRY shaping capacitors may be required in order to achieve the circuit breaker interrupting capability of 63 kA nns symmetrical for line faults. CenterPoint Energy shall determine the placement of TRV shaping capacitors, when required. 7.2.3. Each 138 kV circuit breaker shall be equipped with two 4,000:5 A multi-ratio CT's per 138 kV bushing. Each CT shall have an accuracy of C800 on the 3,000:5 A tap in accordance with IEEE C57 .13. The secondary resistance of circuit breaker bushing CT' s shall not exceed 0.0025 n per turn. CT secondary rated continuous current shall be 10 A minimum. Rating Factor (R.F.) shall equal 2.0. 7.2.4. Two trip coils shall be provided with independent 125 VDC control circuits. If both trip coils operate a single armature, both coils shall be designed or marked in such a way as to prevent their being connected in a manner that would result in the breaker not tripping in the event that both coils are energized simultaneously. 7.2.5. Trip and close DC currents shall not exceed 15 A per coil and shall not be less than 4 A per coil. 7.2.6. Trip circuits shall not be fused inside the circuit breaker control cabinet. 7.2.7. Surge suppression shall be provided on each trip and close coil. Reference CenterPoint Energy Specification, 007-400-02. 7.2.8. The circuit breaker operating mechanism shall be both mechanically and electrically trip-free in any position. For oil circuit breakers, a latch check switch shall be provided. 7.2.9. Circuit breakers with air closing mechanisms shall have stored energy for 5 close-open operations. Circuit breakers with spring closing mechanisms shall have the spring charging motor circuit connected to a 125 VDC battery source utilizing a DC supply cable dedicated for this purpose. Voltage rollover from AC to DC shall not be installed for the spring charging motor circuit for circuit breakers. 7.2.10. Gas circuit breakers shall have low gas pressure alarm and close inhibit contacts. Rev Date Items Revised Specification No Page File 14 7-22-2005 4000A and other updates 007-231-14 I 0 CNP_007-23 l- l 4rcv 14 _ 7-22-2005 Addendum 5-8-2006.doc 100 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN 7.2. l J. Circuit breaker internal time delay circuitry for reclosing shall not be utilized. External time delayed automatic reclosing, when utilized, shall be wired/connected directly to the circuit breaker close circuit. External time delay for reclosing circuit is to be provided by other relays. 7.2.12. CenterPoint Energy recommends that the control circuitry of circuit breakers be equipped for operation response monitoring. 7.3. AIR BREAK SWITCHES 7.3.1. Transmission line disconnect switches and all disconnect switches in the substation "loop" shall be of the outdoor, three pole, gang operated type rated I 38 kV nominal, 4,000 A continuous, I 64 kA peak withstand minimum, unless otherwise specified by CenterPoint Energy. For substations with four or more 138 kV transmission lines, contact CenterPoint Energy for the required rating of switches. The switch air gap BIL shall coordinate with the BIL rating of the switch insulators. 7.3.2. Transmission line disconnect switches are required for "full loop" substations or "loop tap" substations conve11ed to "full loop". 7.3.3. "Loop tap" substations must be configured and designed with equipment to permit switching for the scheduled outage of either transmission line section without interrupting service to the customer's load. An interrupting device attached to a disconnect switch in a "loop tap" substation for transmission line load breaking, loop switching or line dropping is not acceptable. 7.3.4. Two auxiliary "a" contacts shall be provided on the disconnect switch between transformers in a three circuit breaker, two transformer substation and the disconnect switch between lines in a two circuit breaker substation. 7.4. SURGE ARRESTERS 7.4.1. All surge arresters shall be metal oxide varsistor type I 08 kV class minimum, with a maximum continuous over voltage (MCOY) rating of 88 kV minimum. The minimum required energy absorption capability is 7 kilojoules/ kV of MCOY rating. The minimum required pressure relief capability is 63 kA nns symmetrical. 7.4.2. To allow for grading/ leakage current monitoring, CenterPoint Energy recommends that surge arresters be mounted on plates using insulated spacers and associated hardware. The insulated ground conductor from the bottom flange of the arrester must be isolated from any other ground until it passes the point where a tong ammeter reading can be taken. The independent, insulated ground leads should be adequately marked to indicate A, B, and C phases. 7.5. COUPLING CAPACITORS AND LINE TUNERS 7.5.1. CenterPoint Energy shall specify vendor and vendor style number for the coupling capacitor devices and line tuners. 7.6. LINE TRAPS 7 .6. I. CenterPoint Energy shall specify vendor and vendor style number for line trap devices. Rev Date Items Revised Specification No Page File 14 7-22-2005 4000A and other updates 007-231-14 11 CNP _007-231-14revl4_7-22-2005 Addendum 5-8-2006.doc 101 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN 8. CONTROL HOUSE 8.1. The control house shall be a permanent, weatherproof structure constructed on a concrete foundation and scheduled for completion well in advance of the remainder of the substation to allow for adequate check out and testing. The ambient conditions inside the control house shall not exceed 32°C (90°F) and 85% relative humidity. Fluorescent lighting shall be provided. 8.2. TELEPHONE CIRCUITS: 8.2.1. A touch tone telephone, connected to a commercial, full business direct (lFB) line shall be installed in the control house as soon as practical upon completion of the house. The location of the telephone shall be such that the front of protective relay panels is visible from the telephone. Intercoms and intra-company telephones are not acceptable for this purpose. 8.2.2. A separate, dedicated telephone line shall be installed in the control house to be utilized for remotely interrogating metering for revenue billing purposes. An intra-company telephone line with direct inward dialing is acceptable. 8.2.3. If CenterPoint Energy Supervisory Control and Data Acquisition (SCADA) equipment is installed, additional telephone circuits may be required. Refer to CenterPoint Energy specification 007-400-02 for details. 8.3. Wall space for metering cabinets shall be provided in accordance with Sub-Article 9.1.3.1. 8.4. If line relaying with power line catTier and/or fiber optic communication is utilized, space for the power line carrier transmitter/receiver sets and/or fiber optic fiber optic cable distribution box shall be provided. 8.5. If CenterPoint Energy Supervisory Control and Data Acquisition (SCADA) equipment is installed space for the SCADA set and intertie panel shall be provided in accordance with Sub-Article 13.1. 8.6. A separate 120 V AC, 20 A circuit shall be provided to each of the following: (a) the metering cabinet, (b) the power line carrier transmitter/receiver sets location, and (c) the SCAD A intertie panel cabinet, if installed. 8.7. One single-phase, three wire, 240 V, 30 A outlet shall be located in the substation control house (Crouse Hinds #AR 321 or equivalent) for relay testing equipment. 9. METERING EQUIPMENT 9.1. METERING 9.1.1. CenterPoint Energy's metering practices conform to ANSI Cl2.l. Any patt of the metering system that is installed by the customer or his agent shall also conform to ANSI Cl2.l at minimum, unless otherwise directed by CenterPoint Energy. 9.1.2. The customer shall submit a one-line diagram of the proposed substation configuration to CenterPoint Energy in accordance with Article 15.0 of this specification. CenterPoint Energy will designate on the one-line diagram the location of all metering instrument transformers (including, without limitation, quantity, transfonnation ratios, voltage class - high side or low side m1d ratings). The metering instrument transformers shall be connected to the transformer low side or to the 138 kV substation bus by the customer as specified by CenterPoint Energy. Rev Date Items Revised Snecification No Page File 14 7*22-2005 4000A and other updates 007-231-14 12 CNP _007-231-14revl4_7-22-2005 Addendum 5-8-2006.doc 102 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN 9.1.3. Metering cabinets shall be located inside an environmentally controlled house. 9.1.3.1. Wall space 3.0 ft wide and 8.0 ft high measured from the floor with 4.0 ft front clearance shall be provided for installation of each metering cabinet which will be furnished by CenterPoint Energy and installed by the customer. The number of metering cabinets will be determined by the metering scheme to be used. 9.1.3.2. Customers requesting metering pulses shall provide all conduit and wiring necessary to connect to a junction box provided by CenterPoint Energy and mounted on the metering installation. 9.1.3.3. The customer shall provide a conduit from the telephone board to the metering cabinet. 9.1.4. CenterPoint Energy personnel will make all meter connections. For metering equipment details, consult the CenterPoint Energy project representative. 9. 1.5. When high side metering is used, a "full loop" customer shall provide two "a" contacts from the tie breaker and a single "a" contact for each side breaker. A two-breaker "loop tap" customer shall provide two "a" contacts from the tie switch and a single "a" contact from each side breaker. These contacts shall be routed from their associated relay panels to the metering location for rollover of the metering potential to a second set of potential transformers 9.1.6. Where low side metering is used, the customer shall provide space for CenterPoint Energy specified instrument transformers in their switchgear. 9.1.7. When lowside metering is utilized, 138 kV coupling capacitor potential devices shall be provided and installed by the customer in accordance with Sub-Article 7.5, when specified by CenterPoint Energy. 9.2. SWITCHGEAR MOUNTED METERING INSTRUMENT TRANSFORMERS 9.2.1. CenterPoint Energy shall specify all instrument transformers used for CenterPoint Energy metering. 9.2.1.1. The switchgear manufacturer shall purchase and install the CenterPoint Energy specified instrument transformers and the customer shall invoice CenterPoint Energy for the actual cost of the metering instrument transformers. 9.2. 1.2. Original certified test data shall be provided to CenterPoint Energy for each instrnment transformer supplied. 9.2.2. Metering current transformers (CT's) shall be located in the incoming main breaker cubicle. The CT's shall be installed by the customer. 9.2.3. Metering potential transformers (PT's) shall be located in roll-out boxes. The PT's shall be installed by the customer. 9.2.3.1. The secondary windings shall be used only for CenterPoint Energy metering. 9.2.3.2. PT's shall be equipped with l A, current limiting primary fuses. Rev Date Items Revised Snecification No Pape File 14 7-22-2005 4000A and other updates 007-231-14 13 CNP _007-23 l-14rev14_7-22-2005 Addendum 5-8-2006.doc 103 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN 9.2.4. The customer shall install a 1.5 in. rigid galvanized steel conduit with pull strings from each instrument transformer cubical to the meter cabinet. 9.2.5. CenterPoint Energy personnel shall supply wiring and make all secondary instrument transfonners connections. 9.2.6. The customer shall supply copper ground wire from the customer's switchgear to the CenterPoint Energy meter cabinet. 9.3. 138 kV METERING INSTRUMENT TRANSFORMERS 9.3.1. CenterPoint Energy will furnish all 138 kV instrument transformers used for CenterPoint Energy revenue metering. 9.3.2. CenterPoint Energy personnel will mount the instrument transformers on stands provided by the customer in accordance with Atticle 15.0 of this specification. The customer shall furnish flexible connections from the substation bus to the instrument transformers with NEMA CC 1 standard four-hole terminals (0.5625 in. diameter holes on 1.75 in. centers). CenterPoint Energy personnel will bolt the flexible connections to the instrument transformers. 9.3.3. The customer shall install both flexible and rigid galvanized steel conduit with pull string from the instrument transformer stands to the metering cabinet location. 9.3.3.1. At the instrument transformer stands, 1.50 in. steel conduit shall be used to connect the individual instrument transformers to a common junction box. The 1.50 in. conduit shall terminate within 12 in. from the top of each pedestal. A 2.00 in. conduit shall be used from the common junction box located at the instrument transformer stands to the metering cabinet. 9.3.3.2. All 2.00 in. steel conduits shall terminate at the base of the primary metering cabinet. No more than four conduits are to be terminated in a metering cabinet. Contact CenterPoint Energy if additional conduits are required. 9.3.3.3. Flexible metallic conduit shall be used to complete the installation to the instrument transfmmers and the metering cabinets. 9.3.4. Potential transformers (PT's) located in the 138 kV substation yard shall be furnished and installed by CenterPoint Energy and rated 80,500/115-67.08 V for use on 138 kV grounded neutral system in accordance with IEEE C57.13. 9.3.4.1. The PT's shall have two secondary windings. The "X" winding will be used for relaying, SCADA and the customer's equipment. The "Y" winding will be used only for CenterPoint Energy metering. 9.3.4.2. The secondary windings shall be separately fused at the PT junction box to provide circuit isolation and shmt circuit protection; except that neutrals shall not be fused (brass or copper dummy fuses required). 9.3.4.3. CenterPoint Energy shall supply and install color-coded cable to connect the PT's "Y" winding to the meter location. CenterPoint Energy shall install and connect customer supplied cable between each PT "X" winding and the common junction box. If customer does not supply this cable then CenterPoint Energy will install CenterPoint Energy supplied Rev Date Items Revised Specification No. Page File 14 7-22-2005 4000A and other updates 007-231-14 14 CNP _007-231-!4rev I4_7-22-2005 Addendum 5-8-2006.doc 104 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN cable and color code. The PT cable shall be com1ected as shown on CenterPoint Energy drawing 581-500-0 I. 9.3.4.4. The PT primary shall be wye com1ected with a solid ground connection at the PT location. The PT secondary windings shall be wye connected with one neutral conductor carried to the relay panel and another neutral conductor carried to the meter box, as shown on CenterPoint Energy Drawing 581-500-01. These neutral conductors shall be grounded at the relay panel and meter box only. 9.3.5. Metering cm1'ent transfmmers (CT's) located in the 138 kV substation yard shall be furnished and installed by CenterPoint Energy. 9.3.5.1. CenterPoint Energy personnel will furnish and install the control cable from the CT's to the metering cabinet in the customer supplied steel conduit and will make all CT secondary connections. 9.3.6. The customer shall provide a copper bond wire from the ground mat to the case of each instrument transformer. The wire shall be sized equal to the ground mat. CenterPoint Energy will terminate and connect the wire to the instrument transformer case. 10. FUSING IO.I. Bussman type KWN-R fuses shall be used for fusing of 138 kV potential transformers (PT's) secondary relaying and metering circuits of less than 250 V AC as follows: 10.1.1. 138 kV PT's secondary "X" winding shall be fused with 30 A fuses at the PT junction box in the yard except that neutrals shall not be fused (brass or copper dummy fuses required). 10.1.2. 138 kV potential PT's secondary "Y" windings shall be fused with 60 A fuses at the PT junction box in the yard except that neutrals shall not be fused (brass or copper dummy fuses required). 10.1.3. 15 A fuses shall be used for protective relaying potential branch circuits when specified by CenterPoint Energy. 10.1.4. 6 A fuses shall be used for instrumentation potential branch circuits. 10.2. Bussman type KWN-R fuses shall be used for fusing of 138 kV coupling capacitor voltage transformers (CCVT's) secondary relaying and instrumentation circuits of less than 250 V AC as follows: 10.2.1. Coupling capacitor voltage transformers secondary windings shall be fused with 6 A secondary fuses at the CCVT junction box in the yard except that neutrals shall not be fused. 10.2.2. 3 A fuses shall be used for protective relaying potential branch circuits when specified by CenterPoint Energy and for instrumentation potential branch circuits. 10.3. Bussman type KWN-R fuses shall be used for fusing of relaying DC circuits of less than 250 V DC as follows: 10.3.1. The trip circuit connection from the control house panel to each 138 kV breaker trip coil shall be fused with a 15 A panel mounted fuse located on the appropriate control house panel. Rev Date Items Revised Specification No Page File 14 7-22-2005 4000A and other updates 007-231-14 15 CNP_007-231-14revl4_7-22-2005 Addendum 5-8-2006.doc 105 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUB STATJON DESIGN 10.3 .2. 30 A fuses shall be used for the CenterPoint Energy SCADA control positive. 10.4. The voltage drop from the control house to the trip circuit at the circuit breakers shall not exceed 10% of rated battery voltage under normal operating conditions. 11. PROTECTIVE RELAYING 11.1. Protective relaying will normally consist of primary and backup schemes. Whenever possible, the relays associated with the primaiy scheme shall be connected to a different set of CT's than the relays associated with the backup scheme. The DC circuit associated with the primary relaying scheme shall be connected to a different DC circuit than the DC circuit associated with the backup relaying scheme. The primary and backup schemes shall energize different trip coils in the same breaker. 11.2. CenterPoint Energy will furnish typical AC and DC schematics and minimum required bill of materials for the transmission line relaying schemes to ensure coordination with other transmission relaying. The customer shall indicate line relaying schemes (when the substation design requires so) and proposed relaying schemes for 138 kV bus and transformer protection on a substation relaying & metering one line diagram. Once CenterPoint Energy has reviewed these schemes, the customer shall submit the appropriate relaying drawings and bill of materials to CenterPoint Energy for functional review. After these drawings and bill of materials are reviewed by CenterPoint Energy, the customer shall order the appropriate equipment and install these schemes. CenterPoint Energy personnel will calculate set points, apply the settings and test the transmission line relays after the customer has completed the installation and has satisfactorily performed the system operational tests provided in Article 17.0. The customer shall calculate set points for the 138 kV bus and transfonner protection relays and submit this information to CenterPoint Energy for review. After CenterPoint Energy has reviewed the 138 kV bus and transformer protection set points the customer will apply the settings and test the relays after the customer has completed the installation and satisfactory performed the system operational tests provided in A1ticle 17.0. IT SHALL BE CUSTOMERS RESPONSIBILITY TO PERFORM ANY POlNT-TO-POINT WIRING CHECKS. 11.3. CenterPoint Energy will determine the automatic reclosing scheme, and furnish typical AC and DC schematics and bill of materials to implement the scheme. The customer shall prepare drawings and bill of materials (which must be submitted to CenterPoint Energy for review) based on this information. Once the drawings and bill of materials are reviewed by CenterPoint Energy, the customer shall order the appropriate equipment and install the automatic reclosing scheme. CenterPoint Energy personnel will calculate set points, apply the settings and test the automatic reclosing scheme relays after the customer has completed the installation and has satisfactorily performed the system operational tests provided in Article 17.0. IT SHALL BE CUSTOMERS RESPONSIBILITY TO PERFORM ANY POINT-TO-POlNT WIRING CHECKS. 11.4. The following ai·e specified for bus and transformer protection: 11.4.1. Bus protection shall include primary and backup instantaneous bus relaying. 11.4.2. Power transformers should be protected by a differential relay, which shall be connected to the power transformer high side bushing current transformers. Low side circuit breaker bushing current transformers to be positioned so as to minimize the area of protection. 11.4.3. The three-line AC schematic showing transformer differential relay connections should clearly indicate polarity markings on all CT's and power transformer windings so that delta connections can be easily verified. Rev Date Items Revised Snecification No Page File 14 7-22-2005 4000A and other updates 007-231-14 16 CNP _007-231-l 4rcvl4_7-22-2005 Addendum 5-8-2006.doc 106 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN 11.4.4. Power transformers should also be protected by transformer overload relaying which shall be connected to a different power transformer high side bushing CT than the transformer differential relay. The transformer overload relaying should have instantaneous and inverse ti1ne overcurrent ele1nents. 11.4.5. Power transformer sudden pressure and oil level devices should be connected for alarming and tripping. I 1.4.6. Two auxiliary tripping relays should be used in the protection scheme for each transfonner. 1 I .5. When deemed necessary by CenterPoint Energy, local breaker failure relaying will be required. CenterPoint Energy will furnish typical AC and DC one line diagrams, schematics, and bill of materials for the local breaker failure relaying. CenterPoint Energy personnel will calculate set points, apply the settings and test the breaker failure scheme relays after the customer has completed the installation and has satisfactorily performed the system operational tests provided in Article 17.0. IT SHALL BE CUSTOMERS RESPONSIBILITY TO PERFORM ANY POINT-TO-POINT WIRING CHECKS. 11.6. The following are specified for control cable connections: 11.6.1. Connections from one panel to another panel should be made from the terminal blocks on one panel to terminal blocks on the other panel (rather than directly from device to device). 11.6.2. Control cables should be color-coded and clearly marked to facilitate wire checking and troubleshooting. 11.6.3. CT control cables shall be grounded only at the relay panels on the non-polarity side of the wye connected CT. 11.7. CenterPoint Energy encourages the use of Sequence of Events Recorders (SER's) and Digital Fault Recorders. The application of these systems involves trade-offs between the desire to monitor and record as much information as possible and the need to minimize the number of devices in protective relaying circuits to ensure reliable operation. Any customer planning to install one of these systems is encouraged to discuss their application philosophy with CenterPoint Energy early in the project and to show these devices in the appropriate relaying and SCADA AC and DC schematics when those drawings are submitted for CenterPoint Energy review. 11.8. The following are specified for protective relay communication channel: 11.8.1. If line relaying with power line carrier communication is utilized, the carrier transmitter/receiver sets shall be located inside the substation control house. The associated power line carrier coaxial cable utilized for connecting the line tlll1er to the carrier set location shall be type RG-8/U with a polyethylene jacket (Belden type YR-23384 coaxial or Beldon 9888 triaxial). 11.8.2. When power line carrier communication is utilized, CenterPoint Energy shall determine the frequency for the carrier sets. CenterPoint Energy shall provide automatic carrier testers. CenterPoint Energy may relocate existing carrier sets to coordinate frequencies. 11.8.3. If line relaying with fiber optics communication is utilized, the customer is required to provide a raceway for the fiber optic cable installation from the transmission line protective relay requiring fiber optic communication (relays located in the substation control house) to the base Rev Date Items Revised Sneciflcation No Page File 14 7-22-2005 4000A and other updates 007-231-14 17 CNP _007-23 l-14rcvl4_7-22-2005 Addendum 5-8-2006.doc 107 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN of the first CenterPoint Energy transmission line structure outside the substation. See Sub Article 5.5.5 for cases where fiber optic cable comes in overhead. A dedicated raceway (conduit) is required however; a dedicated inner duct installed in existing cable trenches or unused existing conduit is acceptable. The relays may to be installed in a separate cabinet or in the power line carrier cabinet, if the cabinet has the necessary depth and space available. 1f existing facilities are available, the customer is requested to submit drawings (sketches) showing the proposed routing and construction details. CenterPoint Energy shall be responsible for supplying, pulling and splicing of the fiber optic cable. The following guidelines are provided: 11.8.3.1. Flexible steel conduit 1.50 in. diameter, from the splice box (box provided and mounted by CenterPoint Energy at the base of the first CenterPoint Energy transmission structure outside of the substation) to the end of the underground conduit provided by the customer. 11.8.3.2. Below grade conduit shall be a minimum I.SO in. diameter PVC, Schedule 40 with "pull line" (continuous fiber polyolefin, 200 lbs. tensile strength) installed. Conduit shall be at least 18.00 in. below grade, with a protective concrete banier. Minimum bending radius shall be 24.00 in. 11.8.3.3. Pull boxes at grade level shall be provided along the cable route at intervals not more than 300 ft or two 90° bends. A cable pull box in the raceway is required just inside the substation fence. Pull box shall be 30 in. x 60 in. x 30 in. (Quazite Style No. PG3060BB30 and PG3060HA). 11.8.3.4. The customer shall provide 52 in. x 19 in. x 12 in. rack space close to the fiber optic relay to accommodate a fiber optic cable distribution box. CenterPoint Energy will provide and install the fiber optic cable distribution box. 11.8.3.5. In cases where railroad tracks exist between the substation and the first CenterPoint Energy structure, CenterPoint Energy will give site-specific requirements. 11.8.3.6. Customer shall submit drawings and other documents as necessary showing the routing and construction details of the conduit according to Article 15.0. 11.8.3.7. Actual designs shall be reviewed by CenterPoint Energy before construction starts. 12. UNDER-FREQUENCY LOAD SHEDDING 12.1. The transmission customer shall be responsible for installing protective relays to ensure under frequency load shedding as may be required by the ERCOT automatic firm load shedding requirements. The ERCOT automatic firm load shedding schedule is a 5% load block at 59.3 Hz, an additional 10% load block at 58.9 Hz and an additional 10% load block at 58.5. The under-frequency relays connected to each load will operate with a fixed time delay of no more than 30 cycles. Total time from the time when frequency first reaches one of the values specified above to the time load is interrupted should be no more than 40 cycles, including all relay and breaker operating times. Also, the customer shall make provisions to ensure no additional load is imposed on the CenterPoint Energy transmission system during an under-frequency load shedding condition. Verification of the implementation of this requirement shall be in accordance with Article 15.0 of this specification. Rev Date Items Revised Specification No Page File 14 7-22-2005 4000A and other updates 007-231-14 18 CNP_ 007-23 l- l 4rev l 4_ 7-22-2005 Addendum 5-8-2006.doc 108 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN 13. REMOTE TELEMETRY 13. I. A Supervisory Control and Data Acquisition (SCADA) cabinet shall be located inside substation control house for system observation. The customer shall provide a 36 in. x 36 in. floor space for the SCADA cabinet. The height of this cabinet is 90 in. Front and rear access shall be provided. 13.2. For further requirements, refer to CenterPoint Energy specification 007-400-02, "Specification for Remote Telemetry of a Customer-Owned Facility." 14. GENERATION 14.1. Customers desiring to install and/or operate generation rated more than IO MW shall make application with ERCOT as outlined at the ERCOT website (www.ercot.com). Generators shall comply with the ERCOT Operating Guides, the ERCOT Protocols, and CenterPoint Energy's engineering specifications and requirements. 14.2. For customers desiring to install and/or operate generation rated at 10 MW or less and connected to the low voltage side of the 138 kV substation the requirements for relay and generation /load islanding schemes are as follows: 14.2.1. The transmission customer shall be responsible for installing protective relays to ensure the customers generators do not become a sustained source of fault current for a fault on the CenterPoint Energy transmission system. In addition, customer generation shall not keep any portion of the CenterPoint Energy transmission system energized in the event that a portion of the CenterPoint Energy transmission system along with the customer's facilities becomes isolated from the rest of the CenterPoint Energy system. The transmission customer shall be responsible for installing protective relays to ensure the customer's generation does not interfere with the automatic reclosing system associated with the CenterPoint Energy transmission system. CenterPoint Energy will inform the customer of required changes to the automatic reclosing system at other substations associated with the CenterPoint Energy transmission system as a result of the operation of the customer's generators in parallel with the CenterPoint Energy transmission system. 14.2.2. The transmission customer shall be responsible for installing controls to synchronize the customer's generators with the CenterPoint Energy's system. 14.2.3. The transmission customer shall not intentionally impose additional load on the CenterPoint Energy transmission network during an under frequency disturbance (i.e., 59.95 to 57.5 Hz). 14.2.4. Customer may island their load from CenterPoint Energy in only the following manner: 14.2.4.1. All generators remain on line (i.e., operating in parallel with the transmission network) between 62.5 Hz and 57.5 Hz. 14.2.4.2. Measure frequency locally and initiate islanding scheme with provisions to ensure no additional load is imposed on the CenterPoint Energy transmission system. 14.2.4.3. Compare local frequency with telemeter frequency from other locations in CenterPoint Energy system and initiate islanding scheme when these frequencies indicate the customer has become separated from the rest of the CenterPoint Energy system. The customer shall make provisions to ensure no additional load is imposed on the CenterPoint Energy transmission system. Rev Date Items Revised Specification No Page File !4 7-22-2005 4000A and other updates 007-231-14 19 CNP_007-23 l- l 4rev 14_7-22-2005 Addendum 5-8-2006.doc 109 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN Verification of the implementation of the above requirements shall be in accordance with Article IS.O of this specification. 15. DRAWING COMPLIANCE REVIEW & COMMENTS IS.I. The following engineering documents shall be submitted in the order shown below for CenterPoint Energy comments, functional review, and compliance with CenterPoint Energy specifications in accordance with Sub-Articles l S.2 through 1S.6: I S.1.1. Substation plot plan. The plan must indicate the geographical base lines, center line of dead end structure and height of conductor pull off on the dead-end structure with coordinates. (See Article 6.0). l S.1.2. Relay and metering one-line diagram. CenterPoint Energy shall indicate incoming 138 kV transmission lines, power line carrier frequencies (if applicable), location and ratings of metering instrument transformers (high side or low side), CenterPoint Energy designations for circuit breakers, switches, power transformers, generators (if applicable) and the CenterPoint Energy assigned 6-character substation identification. The drawing shall then be revised to show the information provided by CenterPoint Energy and resubmitted to the CenterPoint Energy Project Coordinator. (See Articles 9.0 and 11.0). lS.1.3. Plan, profile and section views of substation structures, including bus and bus supp01is with material callouts. (See A1iicles 4.0 and S.0). l S.1.4. Final/complete relaying and SCADA one-line diagrams, including generator protection one-line diagram for customers with parallel generation. (See Article 10.0). IS. l.S. Information specified on the CenterPoint Energy "Customer Generation Data" form and "Generator Step-up Transformer Data" form if customer has parallel generation. Refer to CenterPoint Energy specification 007-231-78, A1iicle 13.0. I S.1.6. Equipment specification for all major pieces of equipment such as power transformers, 138 kV circuit breakers, surge arresters, disconnect switches, coupling capacitors and line traps. (See Articles 4.0 and 7.0). lS.1.7. Foundation location plan. (See A1iicles S.O and 6.0). l S.1.8. Design calculations, drawings and associated documents for the substation dead-end structures, instrument transformer stands, and foundations shall be submitted 30 days prior to the scheduled fabrication start. 15.1.9. Relaying and SCADA AC and DC schematics, including AC and DC panel drawings. These drawings shall be submitted after the documents indicated in Sub-Article l S.1.2 have been approved. lS.1.10. Power transformer AC schematic, breaker schematics and CT curves. 15.1. l l. Power transformer and 138 kV circuit breaker nameplate drawings. 15 .1.12. Relaying, control and SCAD A bill of material. These documents shall be submitted after the documents indicated in Sub-Article 15 .1.4 have been approved. Rev Date Items Revised Spccificntion No Page File 14 7-22-2005 4000A and other updates 007-231-14 20 CNP _007-231-14rev 14_7-22-2005 Addendum 5-8-2006.doc 110 CenterPoint Energy SPECIFJCA TION FOR CUSTOMER 138 KV SUB STA TJON DESIGN 15.1.13. Cable and conduit list and routing layout. 15.1.14. Front and Back View of high voltage relay and control panels including interconnections. 15.1.15. Substation control house layout drawing. (See Article 8.0). 15.1.16. Detail (point-to-point) wiring diagrams shall be submitted, not for approval, but for use in accordance with Alticle l 0.0. 15.1.17. Power transformer low side main breaker over current relay settings. Power transformer tap changer for de-energized operation set point (if applicable). 15.2. Three copies of the drawings indicated in Sub-Article 15.1, folded to 8.50 in. x 11.00 in., shall be submitted for review/comments to the CenterPoint Energy Project Coordinator. Certain types of engineering documents depend upon finalization of other documents. For example, relay panel drawings cannot be prepared until the relaying AC and DC schematics are finalized. Therefore, engineering docrnnents shall be submitted for CenterPoint Energy comments or approval in the proper sequence. 15.3. Customer drawings should be 100% complete when given to CenterPoint Energy to review. If a functional review cannot be done, CenterPoint Energy shall comment on compliance with CenterPoint Energy specifications and return to Customer. The drawings shall then be resubmitted with CenterPoint Energy comments incorporated when 100% complete. The customer shall then proceed with drawing submittal in accordance with Sub-Article 15.4. 15.4. Customer drawings that are 100% complete and marked "For Approval" shall be functionally reviewed by CenterPoint Energy for compliance with CenterPoint Energy specifications. If additional comments are made by CenterPoint Energy on the I 00% complete drawings, the customer may: 15.4.1. Incorporate the CenterPoint Energy comments and resubmit these drawings for fmther review of compliance with CenterPoint Energy specifications, or 15.4.2. Send a letter to the CenterPoint Energy Project Coordinator acknowledging that CenterPoint Energy comments were received and shall be incorporated into the "For Construction" drawings. 15.5. Should the customer disagree with comments by CenterPoint Energy, the customer shall send a letter to the CenterPoint Energy Project Coordinator explaining why revisions are not necessary. 15.6. Once all issues are resolved, the final set of drawings shall be marked "For Construction." After, the substation is energized two sets of complete "As Built" drawings of the substation shall be sent to the CenterPoint Energy Industrial Representative within one year. 16. EQUIPMENT INSTALLATION 16.1. The protective enclosure around the substation including gates and grounding shall be installed in accordance with the National Electrical Safety Code (IEEE C2), IEEE Std. 1119 and IEEE Std. 80. 16.2. CenterPoint Energy shall assign a 6-character substation identification to the customer's substation. CenterPoint Energy shall post the 6-character substation identification on the door of the substation Rev Date Items Revised Snecification No Page File 14 7-22-2005 4000A and other updates 007-231-14 21 CNP_007-231-14rev14_7-22-2005 Addendum 5-8-2006.doc 111 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN control house and on the entrance gate of the substation. The 6-character substation identification shall be used to identify the customer's substation for any communications or correspondence. 16.3. The customer shall make all equipment installation checks required by Article 17.0 of this specification and shall make all required measurements and readings available to CenterPoint Energy personnel if requested. 16.4. CenterPoint Energy personnel will verify that the 138 kV switches operate correctly. 16.5. CenterPoint Energy will have the sole responsibility for calculating relay set points, applying relay setting and "out of case" testing of the following relays: 16.5. I. Transmission line relaying and associated power line carrier equipment, 16.5.2. Relays for 138 kV automatic reclosing, and 16.5.3. Relays for 138 kV breaker failure protection when specified by CenterPoint Energy. Note: The appropriate operation of protective relays and control circuits by performing trip and close testing from devices of Sub-Articles 16_5,l through 16.5.3 above shall be conducted with CenterPoint Energy personnel present to direct and observe test (24 hr. advance notice required). 16.6. CenterPoint Energy will furnish locks which shall remain in series with customer locks for all 138 kV disconnect switches, substation control house doors and gates(s) to and from the substation. 16.7. The 138 kV circuit breakers, air switches and power transformers will be assigned numbers in accordance with CenterPoint Energy dispatching numbers. The numbers are to be shown on the one line diagram and shall be marked on the circuit breaker tanks, switch handles and power transformers. 16.8. CenterPoint Energy will coordinate and provide the procedures for energizing the customer substation 138 kV equipment. 17. REQUIRED TESTS AND INSPECTIONS 17.1. During installation but prior to energizing the equipment, the customer shall perform the following tests and inspections. CenterPoint Energy will observe the tests below that are marked with an asterisk (*). 17.1.1. Diagnostic testing (e.g., insulation power factor, insulation resistance ("meggar"), etc.) of all equipment (e.g., arresters, coupling capacitors, etc.) including all tests as specified by manufacturer. 17_1.2. CONTROL CABLES AND PANELS: I 7. I .2.1. Check continuity and perform insulation resistance test ("meggar") conductor to ground and conductor to conductor. 17.1.2.2. Perform a point-to-point wiring check of protective relaying and control panels. 17.1.2.3. Verify protective relaying control circuits by performing trip and close testing. See "Note" in Sub-Article 16.5.3. * Rev Date Items Revised Snecification No. Page File 14 7*22-2005 4000A and other updates 007-231-14 22 CNP _007-23l-l4revl4_7-22-2005 Addendum 5-8-2006.doc 112 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN 17.1.2.4. Pass current from CT's through relays. * 17.1.3. POWERCABLES: 17.1.3.1. Check continuity and phasing sequence. 17.1.3.2. Perform insulation resistance test ("meggar") of cables. 17.1.3.3. High-pot. 17.1.4. CIRCUIT BREAKERS: 17.1.4.1. Inspect and adjust main switch assembly per manufacturer's instructions. 17.1.4.2. Inspect, adjust and lubricate operating mechanism per manufacturer's instructions. 17.1.4.3. Ratio check, excitation test, perform insulation resistance test ("meggar") and check polarity on all CT's. Leave unused CT's sho1ted and grounded on secondary terminals. 17.1.4.4. Check resistance of close, trip and trip free coils. 17.1.4.5. Saturate close and trip coils when practical. 17.1.4.6. Obtain minimum and nominal trip and close voltage and current. 17 .1.4.7. Perform insulation resistance test ("meggar") of main contact assembly and bushings. 17.1.4.8. Make dielectric insulation and power factor tests on main contact assembly and bushings. 17.1.4.9. Perform insulation resistance test ("meggar") of control circuits conductor to ground. 17.1.4.10. Record all measurements and readings. 17.1.4.11. Make travel recordings to verify proper opening speed. 17.1.5. DISCONNECTS AND SWITCHES: 17.1.5.1. Check and adjust contact alignment and wipe. * 17.1.5.2. Adjust operating linkage to obtain full open and close positions and tighten all clamps and set screws. * 17.1.5.3. Check and tighten all electrical connections. 17.1.5.4. Lubricate linkage and bearings, ifrequired. 17.1.5.5. Clean all grease from contacts. 17.1.6. BATTERIES AND CHARGER: 17.1.6.1. Assemble batteries per manufacturer's instructions. Rev Date Items Revised Specification No. P:lgc File 14 7-22-2005 4000A and other updates 007-231-14 23 CNP _007-231-14revl4_7-22-2005 Addendun1 5-8-2006.doc 113 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN 17.1.6.2. Coat all connections on battery terminals with no-oxide grease. 17.1.6.3. Tin all copper com1ections to battery terminal. 17.1.6.4. Install, connect and adjust charger per manufacturer's instructions. 17.1.6.5. Put batteries on equalize charge until the specific gravity of all cells is within the limits set by manufacturer. 17.1.6.6. Read and record the float voltage and specific gravity of each cell. 18. RECOMMENDED TESTS AND INSPECTIONS 18.1. During installation but prior to energizing the equipment, CenterPoint Energy recommends that the customer perform the following tests and inspections as a minimum. List is not considered to be exhaustive or all-inclusive. 18.1.1. For low side equipment, test relays, check transformer and bus automatic reclosing and check operation of flags when tripping through the panel with current. Note: CenterPoint Energy will check high side relays, 138 kV transmission line protective relays and 138 kV circuit breaker automatic reclosing. 18.1.2. ALL SUBSTATION EQUIPMENT: 18.1.2.1. Clean rusted surfaces, prime all bare metal surfaces and touch up with paint matching the finish coat. 18.1.3. CONTROLWORK: 18.1.3.1. Wire check all cables to CT's and perform insulation resistance test ("meggar") of cables. 18.1.3.2. In the following order: 18.1.3.2.1. Polarity check CT's. 18.1.3.2.2. Ratio check CT's. 18.1.3.2.3. Excitation test CT's. 18.1.3.2.4. Insulation resistance test ("meggar") CT's. 18.1.3.3. Check cable connections to panels. 18.1.3.4. Wires check panels. 18.1.4. SWITCHGEAR: 18.1.4.1. Check bus work for continuity, phase sequence and adequate clearance. 18.1.4.2. Check all bolted bus connections. Rev Date Items Revised Specification No. Page File 14 7-22-2005 4000A and other updates 007-231-14 24 CNP _007-231-!4rcv !4_7-22-2005 Addendum 5-8-2006.doc 114 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN 18.1.4.3. High-pot cable with 25 kV DC. 18.1.4.4. Insure that all exposed bus work is properly insulated. 18.1.4.5. Bridge all bus work. 18.1.4.6. Perform dielectric insulation and power factor tests on all bus work. 18.1.4.7. Check breaker-lifting devices for aligmnent and adjust limit switches, ifnecessary. 18.1.4.8. Adjust auxiliary and cell switches. 18.1.4.9. Check continuity for all AC, DC control and CT circuits. 18.1.5. TRANSFORMERS: 18.1.5.1. Visually inspect for internal shipping damage and check all internal connections. 18.1.5.2. Install bushing and accessories per manufacturer's instructions. 18.1.5.3. Inspect LTC compartment and adjust per manufacturer's instruction and check L TC operation. 18.1.5.4. Bridge primary and secondary windings on all tap positions. 18.1.5.5. Ratio check, excitation test, perform insulation resistance test ("meggar") and check polarity on all CT's. Leave unused CT's shorted and grounded on the secondary. 18.1.5.6. Vacuum fill per manufacturer's instructions. 18.1.5.7. Check for oil and gas leaks. (This may be done prior to vacuum filling). 18.1.5.8. Test oil before and after filling. (Maximum power factor, minimum dielectric strength, color, acidity and interfacial tension). 18.1.5.9. Test oil for dissolved combustible gas and moisture content. Note: This test is to be performed 24 to 48 hours after the substation has been energized and periodically thereafter. 18.1.5.10. Check voltage regulating relay and controls. 18.1.5.11. Check cooling equipment and controls. 18.1.5.12. Check nitrogen-regulating equipment and adjust per manufacturer's instructions. 18.1.5.13. Check sudden pressure relay and associated circuits. 18.1.5.14. Check and com1ect desired alarm circuits. Rev Date Items Revised Suecific:ition No. Page File 14 7-22-2005 4000A and other updates 007-231-14 25 CNP_007-231-14rev [4_7-22-2005 Addendum 5-8-2006.doc 115 CenterPoint Energy SPECIFICATJON FOR CUSTOMER 138 KV SUBSTATION DESIGN 18.1.5. I5. Perform insulation resistance test ("meggar") and insulation power factor test of bushing and windings. 18.1.5.16. Check all bushings to bus connections. 18.1.5.17. Check all CT's and control circuit connections. 18.1.5.18. Record all measurements and readings. 18.1.5.19. Check Core Ground. REFERENCE DRAWINGS Rev Date lte1ns Revised Specification No. Page File 14 7-22-2005 4000A and other updates 007-231-14 26 CNP_007-231-l 4revl4_7-22-2005 Addendum 5-8-2006.doc 116 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN ., 0:" -"'0 Rev Date Items Revised Specification No. Page File 14 7-22-2005 4000A and other updates 007-231-14 27 CNP_007-231-14revl4_7-22-2005 Addendum 5-8-2006.doc 117 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN '>-P f: I • "'.. . . ~ DESIGN CONDITIONS: 1. LIMIT INSTRUMENT MOUNTING BOLT SPACING TO NO LESS THAN 15" CENTER TO CENTER. 2. SHOULD NOT EXCEED THESE VALUES: P - 2.S KIPS V = 0.7 KIPS M = 44.3 INCH KIPS FOUNDATION LOADS PR=2.BKIPS VR = !. 1 KIPS MR= 100.0 INCH KIPS M .. -·-·-····1··----=·::'.::;:::t=;:=:r---- v -z0 ' ~~::£ Ul7 . .J 0 10 ]~ NOTE: CUSTOMER MUST MAINTAIN ALL NESC PHASE TO GROUND AND PHASE TO PHASE CLEARANCES. Is '-0 HE I GHT I Rev Date Items Revised Specification No. Pngc File 14 7-22-2005 4000A and other updates 007-231-14 28 CNP _007-23l-14rev14_7-22-2005 Addendum 5-8-2006.doc 118 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN DESIGN CONDITIONS: !. LIMIT INSTRUMENT MOUNTING BOLT SPACING TO NO LESS THAN IS" CENTER TO CENTER. 2. SHOULO NOT EXCEED THESE VALUES: P" 2.5 KIPS V" 0.8 KIPS M ~ so.a INCH KIPS FOUNDATION LOADS r PR = 3. I KIPS I VR = 1.8 KIPS MR= 253.0 INCH KIPS M Clz -;;:: a I :x: I L 0.. (') :!: - MR 0 0 ------·-··---.. -- C:::::!::c__~- V R NOTE: CUSTOMER MUST MAINTAIN ALL "'- NESC PHASE TO GROUND ANO 113 PHASE TO PHASE CLEARANCES. ·-o HEIGHT I .-~~~~~~~~~~~--1 ..~ DESIGN CRITERIA 138KV STANDARD c INSTRUMENT TRANSFORMER STAND ~ POINTENERGY,INC. \)I H)~l(N l(ll'A.1' lo( ~ l_ -2 -94 R · W*lt NTS ~ -~~.!W.l: .. -81.!....~.l!L e ---·- -·------~---~~-lecmttr tJ>Wr~ ...... _11_ g -;;:;- ~rlO t 7119 06 u Rev Date Items Revised Specification No Page File 14 7-22-2005 4000A and other updates 007-231-14 29 CNP_007-231-14rcv14_7-22-2005 Addendum 5-8-2006.doc 119 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN .,-,..~, ~"" l •~••"" "''"'~;>ll ~II'-"• ~~~.,4:>4 ll~f'· l!h 14 4"'1 "'" "~H:. !.!~,, " 0 ---· DESIGN CDND IT IONS: !. LIMIT INSTRUMENT MOUNTING BOLT SPACING TO NO LESS THAN 1S" CENTER TO CENTER. 2. SHOULD NOT EXCEED THESE VALUES: p = 4.7 KIPS v = 0.9 KIPS M = 66.0 INCH KIPS FOUNDATION LOADS rr PR=S.OKIPS I VR = l. 3 KIPS MR= 130.0 INCH KIPS - - 1 pl" M r~- v I·- 0 - z - :;: - - 0 - J: I 0. . - :>: l/I I - 0 i'MR - 0 PR =:___..]_. ______J_ VR NOTE: ~ CUSTOMER MUST MR!NTA!N ALL :ll NESC PHASE TO GROUND ANO s·-o HEIGHT !! PHASE TO f'llASE CLf.ARANCcS. HEAVY DUTY S! ~ ' QES I {.?N t;R l TER Ill ~ 13BKV STANDARD c INSTRUMENT TRANSFORMER STAND 1' CENTERPOINT ENERGY, INC. ~ •OJ';fO"j lb~\ "' ~ 1 ~24-94 ;.;,.!( w..~ ~ S!!!!!.2.J.:24~~ _.JJ_Q4 ___ -t.:O I ~~ -;; (OW.(I ~l"'l ~· I I I - .g ~~-- ' ' ' ' .~ Rev Date Items Revised Specification No. Page File 14 7-22-2005 4000A and other updates 007-231-14 30 CNP_007-231-14revl4_7-22-2005 Addendum 5-8-2006.doc 120 CenterPoint Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN ,,..,.~. ""'" 1 !""""' '""a'"" r" f:, """' '1~~ r••"'• '"• 14• ~ ~ .. Mllfl'."· n,,_ n ... A~•· DESIGN CONDITIONS: !. LIMIT INSTRUMENT MOUNTING BOLT SPACING TO NO LESS THAN 15" CENTER TO CENTER. 2. SHOULD NOT EXCEED THESE VALUES: p = 4.7 KIPS v = 1.0 KIPS M = 74.0 INCH KIPS FOUNDATION LOADS PR= T 5.4 KIPS I VR = 2.0 KIPS MR= 307.0 INCH KIPS PIM - j__ v 1-- 0 -,_ z :;::: 0 1-- - I 1-- :x: . n. (") ::!: -"- - 0 °'MR 0 PR - I ---1-- - y VR NOTE: !'i ~ CUSTOMER ~UST MAINTAIN ALL NESC PHASE TO GROUND ANO 13'-0 HEIGHT '!!"' PHASE TO PHASE CLEARANCES. HEAVY DUTY Si \!! Iii Q!;;S!GN CRITERIA 'w I 3BKV STANDARD c INSTRUMENT TRANSFORMER STANO ~ v"'' • ""P.O.tl'jT ~J".oRGY, INC. 1<(11'f~, f(XA~ : - 1~2<1-94 1<:11.t NTS g .~:!:!it>, ~z.;::r d& •-~:, 4t;7. H ~ -·<~-·-·" 1-1~ ...... ~ I I I I I I I (-('.· - g. ~ : ..tt: r·~.., Q(•!I;;. ~' 117119006 " " ~ ' -- Rev Date Items Revised Specification No Page File 14 7-22-2005 4000A and other updates 007-231-14 31 CNP_007-231-14rev14_7-22-2005 Addendum 5-8-2006.doc 121 CenterPointr-·-·--··- Energy SPECIFICATION FOR CUSTOMER 138 KV SUBSTATION DESIGN i t --:·:::.... ' ' ,.,,.~ ~·· Ii !!.•...... ,.." .. ,...... ) !~ !\'J !~ !.;..: Ii I~ 15 !x IIIs •~~~~~~~~~~~~~~~~~~~~~~~~~~__jiu Rev Date Items Revised Specification No. Page File 14 7-22-2005 4000A and other updates 007-231-14 32 CNP_007-23 l-14rcvl4_7-22-2005 Addendum 5-8-2006.doc 122