65- 407 C.M.R. ch. 140, § 1

Current through 2024-25, June 19, 2024

Section 407-140-1 - GENERAL PROVISIONS

A. Applicability of Rule. This Chapter applies to all gas utilities, electric transmission and distribution (T&D) utilities, water utilities, incumbent local exchange carriers (ILECs), competitive local exchange carrier (CLEC) telephone utilities that are designated as eligible telecommunications carriers (ETCs) by the Commission pursuant to 47 U.S.C. §214(e), and interexchange carriers (IXCs) with facilities in Maine. The requirements of § 2 (Service Area Exchange, and Wire Center Boundary Maps) do not apply to IXCs. The requirements of § 3 (Infrastructure Maps) do not apply to T&D utilities that provide service only on offshore islands.

B. Definitions

1. "Distribution Infrastructure" for electric transmission and distribution (T&D) utilities means infrastructure that meets the seven indicators of local distribution determined by the Federal Energy Regulatory Commission, Order No. 888, 75 FERC ¶ 61,080 (Apr. 24, 1996) at 230:

a. Local distribution facilities are normally in close proximity to retail customers.

b. Local distribution facilities are primarily radial in character.

c. Power flows into local distribution systems; it rarely, if ever, flows out.

d. When power enters a local distribution system, it is not reconsigned or transported on to some other market.

e. Power entering a local distribution system is consumed in a comparatively restricted geographical area.

f. Meters are based at the transmission/local distribution interface to measure flows into the local distribution system.

g. Local distribution systems will be of reduced voltage.

The above indicators apply as further defined by the Commission for individual utilities in Maine Public Utilities Commission Investigation of Retail Electric Transmission Services and Jurisdictional Issue, Docket No. 99-185.

2. "Key Infrastructure" means:

a. for electric transmission and distribution (T&D) utilities: transmission lines, switching substations, static var compensators, primary local distribution circuits, and system operation dispatch facilities.

b. for gas utilities: mains, valves for which annual safety inspections are required pursuant to federal rules in 49 CFR 192.745 and 192.747, service taps, meter stations, regulator stations, propane-air plants, LNG plants, and compressor stations.

c. for telephone utilities: tandem and local switching offices including remote switches, interoffice and host-remote umbilical facilities, digital line carrier field equipment, SONET nodes, presence of TSP or TESP circuits, IXC POPs and facilities, key SS7 elements (i.e., links, SC and STP locations), operator centers, and E-911 PSAPs.

d. for water utilities: water mains, groundwater wells, surface water intake structures, treatment facilities, treated water storage facilities, hydrants, and pumping stations.

3. "Key Infrastructure Attributes" means:

a. for all utilities: Maine standard geocode data to at least Minor Civil Division (five digit) levels.

b. for electric transmission and distribution (T&D) utilities: infrastructure type, street address or physical location, route or line identification, voltage, phasing, and year placed in service.

c. for gas utilities: infrastructure type, street address or physical location, equipment name or number identifier, size, material, maximum allowable operating pressure, and year placed in service.

d. for telephone utilities: infrastructure type including any tandem functionality, street address or physical location, circuit capacity (low, medium, or high capacity, with medium capacity being 1.5 Mbps to 45 Mbps), the percentage of interoffice network capacity leased from or to another LEC or IXC on each interoffice route (identifying each such carrier), CLLI code and V&H coordinates if they have been assigned, backup power capability, and year placed in service.

e. for water utilities: infrastructure type, street address or physical location, size, material, static operating pressure, backup power capability, and year placed in service.

C. Paper Copy Maps. Paper copy maps required by this Chapter must be prepared using base data with locational accuracy of at least 1:24,000 that shows features within ±40' (±12.2m) of their actual location on the ground. If necessary for clarity, certain of key infrastructure attributes may be shown on separate pages. The name of the utility, a description of the information shown on the map, the date on which the map was prepared, and the scale of the information shown on the map, must be clearly shown at the bottom right corner of the map. Paper copy maps must bear the file name and date of any companion electronic copy maps. Paper copy maps must be prepared at a size of 24"x36" unless a utility determines a different size is necessary to adequately show required information, but must not be smaller than 11"x17" nor larger than 30"x40". Notwithstanding the requirements stated above, gas utility maps of their local distribution infrastructure must provide detail at a scale of no less than 1:12,000 with features within ±20' (±6.1m) of their actual location on the ground.

D. Electronic Copy Maps. Electronic copy maps required by this Chapter must be prepared using base data with locational accuracy of at least 1:24,000 that shows features within ±40' (±12.2m) of their actual location on the ground. Electronic copy maps must be prepared using standard georeferenced interexchange formats: .E00 Arc/Info Export format (preferred), shape files, or .DXF format. Electronic copy maps must be prepared in a projected coordinate system, preferably UTM Zone 19 meters, and referenced to the North American Datum of 1983, unless a utility determines a different projection is necessary because of its software limitations, in which case a State Plane projection may be used, with the zone clearly specified. A metadata file conforming to the Federal Geographic Data Committee Metadata Standard (FGDC-STD-001-1998) must be submitted with each electronic copy map. Notwithstanding the requirements stated above, gas utility maps of their local distribution infrastructure must provide detail at a scale of no less than 1:12,000 with features within ±20' (±6.1m) of their actual location on the ground.

E. Additional Technical Specifications. Except as otherwise established by this Chapter, the Commission delegates to the Director of the Technical Analysis Division the responsibility to establish additional technical specifications for maps filed with the Commission pursuant to this Chapter. Before establishing or changing such specifications, the Director must consult with the Maine Office of GIS, the Maine Department of Transportation, and the Maine Drinking Water Program, about those specifications. The Director must provide notice of proposed additional or changed specifications to all utilities 30 days prior to their effective date. The notice must state that utilities may provide comments to the Director of Technical Analysis no later than 10 days prior to the effective date.

F. Utility Responsibility. All utilities subject to this Chapter must create and maintain reasonably accurate records, maps, and data required by this Chapter. Any utility that becomes aware of an error in data on file with the Commission must correct all such known errors in a timely manner and provide corrected information to the Commission.

65- 407 C.M.R. ch. 140, § 1