TE-J.1.2.2 IGSA Responsibilities.pdf

TE-J.1.2.2

CSU IGSA

Jan 2023

Electrical Appendix 8

Fort Carson Directorate of Public Works (DPW) Intergovernmental Support Agreement (IGSA) with Colorado Springs Utilities (Utilities)

1.0 General

Pursuant to this IGSA, Utilities shall:

1. Operate and maintain Fort Carson existing electric substations, distribution system up to and including switch gear, and transformers, and including Street Lights fed from transformers (No more than 2 in 10 Continuous lights out) in accordance with utilities best practices.

2. Repair streetlights as identified in DMOs from Base Maintenance Contractor (surveys to be performed by Base Maintenance Contractor-Low Volt Shop).

3. Notify the IGSA-TR and Electrical Engineering Tech of the status of any outage or repair work, the area or building affected, and estimated down time if repairs cannot be completed at that time and ensure danger or risk is eliminated.

4. Provide an outage report to the Government within 12 hours that gives a brief description of the outage, cause, and repairs made and duration of the outage. (Deliverable) All power outages will be reported to the IGSA-TR verbally within 30 minutes.

5. Schedule and perform outages IAW Fort Carson Regulation 420-19 and perform scheduled outages upon request of the Government.

6. Provide electrical support to others with isolating an electrical line or service, opening vaults, pits or manholes or locating an electrical line

7. Install and maintain asset identification labels on all major electric system components to include but not be limited to poles, transformers, switches, vaults, manholes, capacitor banks, streetlights.

Provide update information to the government within 7 days after work is completed.

8. Trim all trees as necessary in order to maintain at least 10 feet between any portion of the tree and power lines. Maintain conductors free of debris and extraneous items (e.g., boots, kites or debris).

2.0 Scada

Utilities will also operate and maintain the electric substation SCADA systems, to include the SCADA

Master HMI server located in the electric shop and the SCADA remote terminal located in the 24 hours, seven days a week utility monitoring section; and maintain all SCADA equipment located in the three

Fort Carson electric substations to include but not be limited to RTU’s, DDIO, Positron units, modems and various other items, to ensure the system is fully functional. It is the intent of Utilities to bring their

SCADA into Fort Carson. As part of these activities, Utilities will ensure Fort Carson has view-only access to any SCADA system operated by Utilities on behalf of Fort Carson under this IGSA. Prior to any termination of this IGSA, Fort Carson will pay for the installation of an independent SCADA system. If the agreement is terminated Utilities will ensure Fort Carson has all operational control and responsibility for the independent SCADA system.

3.0 Raptor Protection

Utilities will maintain and install raptor protection as needed on overhead power lines. The Government will provide details if raptor protection is necessary on any overheard utility pole. Utilities will notify

IGSA-TR and Electrical Engineering Tech when an issue arises with a raptor.

4.0 Deliverables

Utilities will:

1. Provide an outage report to the Government within 12 hours that gives a brief description of the outage, cause, and repairs made and duration of the outage. (Deliverable)

2. Provide an annual line patrol inspection report on all overhead circuits. (Deliverable)

5.0 Demarcation Points

Utilities will have responsibility up to the following points of demarcation:

Point of Demarcation Applicable Scenario

Secondary terminal of a transformer inside of a structure.

Transformer located inside a structure and an isolation device is in place with or without a meter.

Note: Public Partner will be granted 24-hour access to transformer room.

Secondary terminal of the transformer inside of the structure.

Transformer located inside a structure with no isolation device in place.

Note: Public Partner will be granted 24-hour access to transformer room.

If a pulser is attached to the meter, the POD is the connection point of the communication leads to the pulser.

Service with a meter that has an external pulser attached to the meter exterior.

Where the overhead conductor is connected to the service entrance mast.

Electric power is provided to a water facility via an overhead service drop.

This configuration could be found at facilities dedicated to the water utility such as a water well, pump station, or storage facility.

The secondary terminal of the transformer. Electric power is provided to a water facility via an underground service connection. This configuration could be found at facilities dedicated to the water utility such as a water well, pump station, or storage facility.

Point of Demarcation Applicable Scenario

The overhead conductor is connected to the service entrance mast.

Electric power is provided to a wastewater facility via an overhead service drop. This configuration could be found at facilities dedicated to the wastewater utility such as a lift station or wastewater treatment plant.

The secondary terminal of the transformer. Electric power is provided to a wastewater facility via an underground service connection. This configuration could be found at facilities dedicated to the wastewater utility such as a lift station or wastewater treatment plant.

Point of Demarcation Sketch / Applicable Scenario

The load side terminals of the Utilities-owned pad-mounted primary meter stations. There are two (2) meter stations at each substation.

O’Connell, Minick and Titus Substations

The load side terminals of the Utilities’ pole-mounted primary meter.

Wildlife Area primary delivery point

The generation side primary terminals of pad-mounted sectionalizing switches SW0121 and SW0122. These switches are located south of Titus Substation.

Carson Solar I Photovoltaic Station

The low-voltage terminals of the pad-mounted transformers interconnecting the photovoltaic generation equipment with the 12.47 kV distribution grid. There are two (2) pad-mount transformers at this site.

Consolidated Solar Butts PhotoVoltaic Station

The point of connection of the SPIDERS system communication and control leads to the following 12.47 kV primary equipment: pad-mounted circuit breaker LS-5 and pad-mounted sectionalizing switches SW0051, SW0122, SW0333, SW0334, SW0335, SW0336 and

SW0337. Note: Utilities still has responsibility to the secondary side of the transformer.

SPIDERS microgrid

The secondary-voltage terminals of the service transformer(s).

Privately owned/leased facilities, including Fountain Fort

Carson School District, the Post car wash, the Post self-storage, Envisions Express, Green Bean Coffee Shop, the marquee billboard sign and cell-phone towers.

The point of demarcation is the terminal connection of the substation side of the switch.

Battery energy storage system

Point of Demarcation Sketch / Applicable Scenario

Housing (overhead) – the point of demarcation is the point where the overhead conductor connects at the weather head.

Housing will own the mast.

Housing (underground) – the point of demarcation is the upstream current side of the closest appurtenance (such as the first disconnect, meter, or main circuit breaker) at the building.

Unique Points of Demarcation

Electrical Distribution System, Fort Carson, Colorado

Point of Demarcation Sketch / Applicable Scenario

The load side terminals of the CSU-owned pad-mounted primary meter stations. There are two (2) meter stations at each substation.

O’Connell, Minick and Titus Substations

The load side terminals of the Black Hills Energy pole-mounted primary meter.

Turkey Creek Ranch primary delivery point

The load side terminals of the CSU pole-mounted primary meter. Wildlife Area primary delivery point

Natural Gas Distribution & Cathodic Protection Appendix 9

Fort Carson Directorate of Public Works (DPW) Intergovernmental Support Agreement (IGSA) with Colorado Springs Utilities (Utilities)

1.0 OVERVIEW

Utilities shall maintain and service the natural gas distribution and regulation system. Work shall be in accordance with DOT (Department of Transportation) Pipeline Safety Regulations, 49-CFR 192 and the Guidance Manual for Operators of Small Gas Distribution Systems.

Specific tasks include, but are not limited to, adjusting pressure settings on regulating stations;

repairing/replacing building service regulators excluding Family Housing buildings; turning system valves on/off; survey/maintenance of cathodic protection systems; performing gas leak surveys including the individual building service lines in Family Housing buildings; raising and color coding valve boxes. Repairs shall be performed as routine operations and maintenance.

2.0 GAS MAINTENANCE PERSONNEL

At IGSA start date, submit to the IGSA-TR a list of persons to be notified when a natural gas emergency occurs during non-duty hours. As a minimum, the list shall contain names, position title, and phone numbers of Utilities personnel to be notified. This shall be updated as personnel changes.

3.0 NOTIFICATION

Upon notification of a natural gas emergency, Utilities shall respond and take action to safeguard life and property. Utilities shall continue work until the problem is corrected, if possible. If repairs cannot be completed at that time, Utilities shall ensure danger or risk is eliminated and shall notify the IGSA-TR as to the status of the repair work. Utilities shall notify the IGSA-TR

& TECHNICAL MONITOR immediately upon receiving an emergency natural gas call (such as, but not limited to: gas smell, line break) during duty hours and by 0730 the following duty morning for non-duty hours emergency calls. Utilities shall notify the Government

TECHNICAL MONITOR & IGSA-TR of the area, the approximate time and length of gas turn off for all outages. Also, Utilities shall contact the Fire Department, and facility occupants of all outages and approximate times of outages.

4.0 MAINTENANCE PLAN

Submit to the IGSA-M & IGSA-TR a plan for accomplishing scheduled natural gas maintenance work described in this IGSA. This plan shall be prepared in accordance with DOT Pipeline

Safety Regulations, 49 CFR 192 and the Guidance Manual for Operators of Small Gas

Distribution Systems.

5.0 LEAK SURVEY

Perform periodic gas leakage surveys in accordance with DOT Pipeline Safety Regulations, currently Part 192.723 and report the results to the IGSA-TR annually after IGSA start date.

6.0 GAS LEAK REPORTS

Respond to detection or reports of gas leaks. Gas leaks reported to Utilities shall be responded to by Utilities as Priority 1. Utilities shall submit a gas leak report to the IGSA-TR &

TECHNICAL MONITOR no later than 24 duty hours after gas leak response. Upon responding to gas leaks, Utilities shall classify gas leaks using the following criteria:

Grade 1: A gas leak that represents an existing or probable hazard to life or property and requires immediate and continuous action until conditions are no longer hazardous. The immediate action in some instances may require one or more of the following: evacuating premises, blocking off an area, rerouting traffic, eliminating sources of ignition, venting the area, or stopping the flow of gas by closing valves or other means. Gas leaks that require immediate action and are classified as Grade 1 include but are not limited to any positive indication of gas in, under or around a building; any positive indication of gas in a confined space; any positive indication of gas under a wall-to-wall paved area within a building; escaping gas that has ignited or which can be seen, heard or felt at the ground surface; and any leak which, in the judgment of

Fire Department personnel at the scene, is regarded as an immediate hazard. (Grade 1 gas leaks shall be reported to the Government within 1 hour of classification.)

Grade 2: A leak that is recognized as being nonhazardous at the time of detection but justifies scheduled repair based on potential hazard. These leaks shall be monitored in accordance with industry standards. Monitoring shall include but not be limited to amount and migration of gas;

proximity of gas to buildings and subsurface structures; extent of pavement; and soil type and conditions such as frost cap, moisture, and natural venting.

Grade 3: A leak that is non-hazardous at the time of detection and can reasonably be expected to remain non-hazardous. These leaks shall be reevaluated at monthly intervals until the leak is regraded. Leaks requiring reevaluation will be executed utilizing industry standards and are classified as Grade 3 include but are not limited to any positive indication of less than 4% gas in small associated substructures, such as small meter boxes or gas valve boxes, and any positive indications of leakage below 5% under a street where it is unlikely the gas could migrate to the outside wall of a building.

7.0 GAS VALVES

Maintain gas distribution valves and records in accordance with DOT Pipeline Safety

Regulations, currently 49 CFR Part 192.

8.0 GAS PRESSURE REDUCING VALVES (PRV’s)

Utilities shall maintain PRV vaults and records. Utilities shall maintain inspection records for

PRV and gas valve maintenance. The inspection and maintenance report shall be due to the

IGSA-TR in accordance with industry standards.

9.0 CATHODIC PROTECTION

Utilities shall establish procedures to implement requirements of the Department of

Transportation (DOT) Pipeline Safety Regulations, currently Part 192.451 thru Part 192.491.

CSU Shall:

Ensure these procedures, including those for the operation and maintenance of cathodic protection systems, are carried out by, or under the direction of, a person accredited by the

National Association of Corrosion Engineers (NACE) as a Corrosion Technician. Prompt remedial action for correction of low potentials within 1 year not to exceed 15 months. In accordance with DOT Part 192.451 thru Part 192.491 a Gas Corrosion Survey report shall be submitted to the IGSA-TR annually.

10.0 DEMARCATION POINTS

Utilities will have responsibility up to the following points of demarcation:

Point of Demarcation Applicable Scenario Sketch

The point of demarcation is the downstream side of the natural gas meter.

Natural gas service to the building is metered (no regulator exists on the service line).

The point of demarcation is the downstream side of the pressure regulator.

Natural gas service to the building is regulated but not metered.

Point of demarcation is the downstream side of the closest apparatus to the exterior of the facility.

More than one apparatus is connected to the service line feeding the facility.

downstream side of the closest shutoff valve to the exterior of the building.

No meter or regulator exists at the facility. Shutoff valve located within 25 feet from the exterior of the building.

Structure

Service

Line

Meter

Point of Demarcation

Distribution Line

Distribution Line

Structure

Service

Line

Point of

Demarcation

Distribution Line

Distribution Line

Pressure

Regulator

Structure

Service

Line

Meter

Point of Demarcation

Distribution Line

Distribution Line

Pressure

Regulator

Structure

Service

Line

Point of Demarcation

Distribution Line

Distribution Line

Shutoff

Valve

Point of Demarcation Applicable Scenario Sketch five-foot line exterior to building footprint.

No meter, regulator or shutoff valve exists at the facility.

connection point to the meter for the communication leads.

Service with a meter. Meter must have communication capabilities.

If a pulser is attached to the meter, the point of demarcation is the connection point of the communication leads to the pulser.

Service with a meter that has an external pulser attached to the meter exterior.

Point of Demarcation Applicable Scenario / Sketch

The upstream side of the first valve downstream of the Utilities-owned pressure regulator station. The valve is located outside the fence.

Gates 5 and 6 delivery points - Utilities meter-regulator stations R277 and R275.

Stations are normally enclosed by a fence or bollards with distinctive markings.

The downstream side of the Utilities-owned insulated tees.

Gate 4 delivery points - Utilities regulator station R144. The tees are located inside the fence line of Utilities’ regulator station

R144.

Point of Demarcation Applicable Scenario / Sketch

Housing - The point of demarcation will be the discharge side of the gas meter.

The outlet side of the meter on the exterior of the structure. See exhibit B of MSA located in the

Technical Library.

IHG Rest Easy natural gas supply.