Rate 300

Applicability:

To any Applicant who enters into a Service Contract with the Company to use the Company's natural gas distribution network for the transportation to a single Terminal Location of a specified maximum daily volume of natural gas. The Company reserves the right to limit service under this schedule to customers whose maximum contract demand does not exceed 600,000 m³. The Service under this rate requires Automatic Meter Reading (AMR) capability. Service under this schedule is firm unless a customer is currently served under interruptible distribution service or the Company, in its sole judgment, determines that existing delivery facilities cannot adequately serve the load on a firm basis.

The unitized Monthly Contract Demand Charge is also applicable to volumes delivered to any Applicant taking service under a Curtailment Delivered Supply contract with the Company. The unitized rate equals the applicable Monthly Contract Demand Charge times 12/365.


Character of Service:

The service shall be continuous (firm) except for events as specified in the Service Contract including force majeure. The Applicant is neither allowed to take a daily quantity of gas greater than the Contract Demand nor an hourly amount in excess of the Contract Demand divided by 24, without the Company's prior consent. Interruptible Distribution Service is provided on a best efforts basis subject to the events identified in the service contract including force majeure and, in addition, shall be subject to curtailment or discontinuance of service when the Company notifies the customer under normal circumstances 4 hours prior to the time that service is subject to curtailment or discontinuance. Under emergency conditions, the Company may curtail or discontinue service on one-hour notice. The Interruptible Service Customer is not allowed to exceed maximum hourly flow requirements as specified in Service Contract.


Distribution Rates:

The following rates and charges, as applicable, shall apply for deliveries to the Terminal Location.

Billing Month Jan. to Dec.
Monthly Customer Charge $500.00
Monthly Contract Demand Charge Firm 26.4239 ¢/m³
Interruptible Service:
Minimum Delivery Charge 0.3850 ¢/m³
Maximum Delivery Charge 1.0425 ¢/m³
Firm Interruptible
Cap and Trade Customer Related Charge 3.3181 ¢/m³ 3.3181 ¢/m³
Cap and Trade Facility Related Charge 0.0290 ¢/m³ 0.0290 ¢/m³
Direct Purchase Administration Charge $75.00
Forecast Unaccounted For Gas (UFG) Percentage 0.7%
Monthly Minimum Bill: The Monthly Customer Charge plus the Monthly Contract Demand Charge.

 

Site Restoration Clearance

The Site Restoration Clearance refund is 2.7992 ¢/m³ of contract demand and 0.0718 ¢/m³ for interruptible customers, effective until December 31, 2017. It reflects changes in an estimate of ongoing and future site restoration costs. Site restoration costs are incurred when gas distribution pipelines are replaced or retired over the life of the gas distribution system.

Rate Adjustment

The OEB has also previously approved a Rate Adjustment. It is a credit of 5.0354 ¢/m³ per contract demand to reflect the difference between the amount you paid for volumes consumed from January 1, 2016 to December 31, 2016 and the actual costs incurred. The total amount of the credit will be split over two months and appear on your October and November bills in two equal installments.

Terms and Conditions of Service

  1. To the extent that this Rate Schedule does not specifically address matters set out in PARTS III and IV of the Company's HANDBOOK OF RATES AND DISTRIBUTION SERVICES then the provisions in those Parts shall apply, as contemplated therein, to service under this Rate Schedule.

  2. Unaccounted for Gas (UFG) Adjustment Factor:

    The Applicant is required to deliver to the Company on a daily basis the sum of: (a) the volume of gas to be delivered to the Applicant's Terminal Location; and (b) a volume of gas equal to the forecast unaccounted for gas percentage as stated above multiplied by (a).

  3. Nominations:

    Customer shall nominate gas delivery daily based on the gross commodity delivery required to serve the customer's daily load plus the UFG, net of No-Notice Storage Service provisions under Rate 315, if applicable. The amount of gas delivered under No-Notice Storage Service will also be reduced by the UFG adjustment factor for delivery to the customer's meter.

    Customers may change daily nominations based on the nomination windows within a day as defined by the customer contract with TransCanada PipeLines (TCPL) or Union Gas Limited.

    Schedule of nominations under Rate 300 has to match upstream nominations. This rate does not allow for any more flexibility than exists upstream of the EGD gas distribution system. Where the customer's nomination does not match the confirmed upstream nomination, the nomination will be confirmed at the upstream value.

    Customer may nominate gas to a contractually specified Primary Delivery Area that may be EGD's Central Delivery Area (CDA) or EGD's Eastern Delivery Area (EDA). The Company may accept deliveries at a Secondary Delivery Area such as Dawn, at its sole discretion. Quantities of gas nominated to the system cannot exceed Contract Demand, unless Make-up Gas or Authorized Overrun is permitted.

    Customers with multiple Rate 300 contracts within a Primary Delivery Area may combine nominations subject to system operating requirements and subject to the Contract Demand for each Terminal Location. For combined nominations the customer shall specify the quantity of gas to each Terminal Location and the order in which gas is to be delivered to each Terminal Location. The specified order of deliveries shall be used to administer Load Balancing Provisions to each Terminal Location. When system conditions require delivery to a single Terminal Location only, nominations with different Terminal Locations may not be combined.

  4. Authorized Demand Overrun:

    The Company may, at its sole discretion, authorize consumption of gas in excess of the Contract Demand for limited periods within a month, provided local distribution facilities have sufficient capacity to accommodate higher demand. In such circumstances, customer shall nominate gas delivery based on the gross commodity delivery required to serve the customer's daily load, including quantities of gas in excess of the Contract Demand, plus the UFG. The Load Balancing Provisions and/or No-Notice Storage Service provisions under Rate 315 cannot be used for Authorized Demand Overrun. Failure to nominate gas deliveries to match Authorized Demand Overrun shall constitute Unauthorized Supply Overrun.

    The rate applicable to Authorized Demand Overrun shall equal the applicable Monthly Demand Charge times 12/365 provided, however, that such service shall not exceed 5 days in any contract year. Requests beyond 5 days will constitute a request for a new Contract Demand level, with retroactive charges based on terms of Service Contract.

  5. Unauthorized Demand Overrun:

    Any gas consumed in excess of the Contract Demand and/or maximum hourly flow requirements, if not authorized, will be deemed to be Unauthorized Demand Overrun gas. Unauthorized Demand Overrun gas will establish a new Contract Demand and shall be subject to a charge equal to 120% of the applicable monthly charge for twelve months of the current contract term, including retroactively based on terms of Service Contract. Unauthorized Demand Overrun gas shall also be subject to Unauthorized Supply Overrun provisions. Where a customer receives interruptible service hereunder and consumes gas during a period of interruption, such gas shall be deemed Unauthorized Supply Overrun. In addition to charges for Unauthorized Supply Overrun, interruptible customers consuming gas during a scheduled interruption shall pay a penalty charge of $18.00 per m³.

  6. Unauthorized Supply Overrun:

    Any volume of gas taken by the Applicant on a day at the Terminal Location which exceeds the sum of:

    • any applicable Load Balancing Demand pursuant to Rate 300 and/or provisions of Rate 315, plus
    • the volume of gas delivered by the Applicant on that day shall constitute Unauthorized Supply Overrun Gas.

    The Company may also deem volumes of gas to be Unauthorized Supply Overrun gas in other circumstances, as set out in the Load Balancing Provisions of Rate 300.

    Any gas deemed to be Unauthorized Overrun gas shall be purchased by the customer at a price (Pe), which is equal to 150% of the highest price in effect for that day as defined below*.

  7. Unauthorized Supply Underrun:

    Any volume of gas delivered by the Applicant on any day in excess of the sum of:

    • any applicable Rate 300 Load Balancing Provision pursuant to Rate 300 and/or provisions of Rate 315 plus
    • the volume of gas taken by the Applicant at the Terminal Location on that day shall be classified as Supply Underrun Gas.

    The Company may also deem volumes of gas to be Unauthorized Supply Underrun gas in other circumstances, as set out in the Load Balancing Provisions of Rate 300.

    Any gas deemed to be Unauthorized Supply Underrun Gas shall be purchased by the Company at a price (Pu) which is equal to fifty percent (50%) of the lowest price in effect for that day as defined below**.

    * where the price Pe expressed in cents / cubic metre is defined as follows:
    Pe = (Pm * Er * 100 * 0.03769 / 1.055056) * 1.5

    Pm = highest daily price in U.S. $/mmBtu published in the Gas Daily, a Platts Publication, for that day under the column "Absolute", for the Niagara export point if the terminal location is in the CDA delivery area, and the Iroquois export point if the terminal location is in the EDA delivery area.

    Er = Noon day spot exchange rate expressed in Canadian dollars per U.S. dollar for such day quoted by the Bank of Canada in the following days Globe & Mail Publication.

    1.055056 = Conversion factor from mmBtu to GJ.

    0.03769 = Conversion factor from GJ to cubic metres.

    ** where the price Pu expressed in cents / cubic metre is defined as follows:
    Pu = (Pi * Er * 100 * 0.03769 / 1.055056) * 0.5

    Pi = lowest daily price in U.S. $/mmBtu published in the Gas Daily, a Platts Publication, for that day under the column "Absolute", for the Niagara export point if the terminal location is in the CDA delivery area, and the Iroquois export point if the terminal location is in the EDA delivery area.

  8. Term of Contract:

    A minimum of one year. A longer-term contract may be required if incremental assets/facilities have been procured/built for the customer. Migration from an unbundled rate to bundled rate may be restricted subject to availability of adequate transportation and storage assets.

    Right to Terminate Service:

    The Company reserves the right to terminate service to customers served hereunder where the customer's failure to comply with the parameters of this rate schedule, including interruptible service and load balancing provisions, jeopardizes either the safety or reliability of the gas system. The Company shall provide notice to the customer of such termination; however, no notice is required to alleviate emergency conditions.

    Load Balancing:

    Any difference between actual daily-metered consumption and the actual daily volume of gas delivered to the system less the UFG shall first be provided under the provisions of Rate 315 - Gas Storage Service, if applicable. Any remaining difference will be subject to the Load Balancing Provisions.

    LOAD BALANCING PROVISIONS:

    Load Balancing Provisions shall apply at the customer's Terminal Location.

    In the event of an imbalance any excess delivery above the customer's actual consumption or delivery less than the actual consumption shall be subject to the Load Balancing Provisions.

    Definitions:

    Aggregate Delivery:
    The Aggregate Delivery for a customer's account shall equal the sum of the confirmed nominations of the customer for delivery of gas to the applicable delivery area from all pipeline sources including where applicable, the confirmed nominations of the customer for Storage Service under Rate 316 or Rate 315 and any available No-Notice Storage Service under Rate 315 for delivery of gas to the Applicable Delivery Area.

    Applicable Delivery Area:
    The Applicable Delivery Area for each customer shall be specified by contract as a Primary Delivery Area. Where system-operating conditions permit, the Company, in its sole discretion, may accept a Secondary Delivery Area as the Applicable Delivery Area by confirming the customer's nomination of such area. Confirmation of a Secondary Delivery Area for a period of a gas day shall cause such area to become the Applicable Delivery Area for such day. Where delivery occurs at both a Terminal Location and a Secondary Delivery Area on a given day, the sum of the confirmed deliveries may not exceed Contract Demand, unless Demand Overrun and/or Make-up Gas is authorized.

    Primary Delivery Area:
    The Primary Delivery Area shall be delivery area such as EGD's Central Delivery Area (CDA) or EGD's Eastern Delivery Area (EDA), or other Delivery Area as specified in the applicable Service Contract.

    Secondary Delivery Area:
    A Secondary Delivery Area may be a delivery area such as Dawn where the Company, at its sole discretion, determines that operating conditions permit gas deliveries for a customer.

    Actual Consumption:
    The Actual Consumption of the customer shall be the metered quantity of gas consumed at the customer's premise.

    Net Available Delivery:
    The Net Available Delivery shall equal the Aggregate Delivery times one minus the annually determined percentage of Unaccounted for Gas (UFG) as reported by the Company.

    Daily Imbalance:
    The Daily Imbalance shall be the absolute value of the difference between Actual Consumption and Net Available Delivery.

    Cumulative Imbalance:
    The Cumulative Imbalance shall be the sum of the difference between Actual Consumption and Net Available Delivery.

    Maximum Contractual Imbalance:
    The Maximum Contractual Imbalance shall be equal to 60% of the customer's Contract Demand.

    Winter and Summer Seasons:
    The winter season shall commence on the date that the Company provides notice of the start of the winter period and conclude on the date that the Company provides notice of the end of the winter period. The summer season shall constitute all other days. The Company shall provide advance notice to the customer of the start and end of the winter season as soon as reasonably possible, but in no event not less than 2 days prior to the start or end.

    Operational Flow Order:
    An Operational Flow Order (OFO) shall constitute an issuance of instructions to protect the operational capacity and integrity of the Company's system, including distribution and/or storage assets, and/or connected transmission pipelines.

    Enbridge Gas Distribution, acting reasonably, may call for an OFO in the following circumstances:

    • Capacity constraint on the system, or portions of the system, or upstream systems, that are fully utilized;
    • Conditions where the potential exists that forecasted system demand plus reserves for short notice services provided by the Company and allowances for power generation customers' balancing requirements would exceed facility capabilities and/or provisions of 3rd party contracts;
    • Pressures on the system or specific portions of the system are too high or too low for safe operations;
    • Storage system constraints on capacity or pressure or caused by equipment problems resulting in limited ability to inject or withdraw from storage;
    • Pipeline equipment failures and/or damage that prohibits the flow of gas;
    • Any and all other circumstances where the potential for system failure exists.

    Daily Balancing Fee:
    On any day where the customer has a Daily Imbalance the customer shall pay a Daily Balancing Fee equal to:

    (Tier 1 Quantity X Tier 1 Fee) + (Tier 2 Quantity X Tier 2 Fee) + (Applicable Penalty Fee for Imbalance in excess of the Maximum Contractual Imbalance X the amount of Daily Imbalance in excess of the Maximum Contractual Imbalance)

    Where Tier 1 and 2 Fees and Quantities are set forth as follows:

    Tier 1 = Daily Imbalance of greater than 2% but less than 10% of the Maximum Contractual Imbalance and shall be subject to a charge of 0.9370 ¢/m³

  9. Tier 2 = Daily Imbalance of greater than 10% but less than Maximum Contractual Imbalance shall be subject to a charge of 1.1244 ¢/m³

    The customers shall also pay any Load Balancing Agreement (LBA) charges imposed by the pipeline on days when the customer has a Daily Imbalance provided such imbalance matches the direction of the pipeline imbalance. LBA charges shall first be allocated to customers served under Rate 125 and 300. The system bears a portion of these charges only to the extent that the system incurs such charges based on its operation excluding the operation of customers under Rates 125 and 300. In that event, LBA charges shall be prorated based on the relative imbalances.

    A Daily Imbalance in excess of the Maximum Contractual Imbalance shall be deemed to be Unauthorized Supply Overrun or Underrun gas, as appropriate.

    Customer's Actual Consumption cannot exceed Net Available Delivery when the Company issues an Operational Flow Order in the winter. Net nominations must not be less than consumption at the Terminal Location. Any negative Daily Imbalance on a winter Operational Flow Order day shall be deemed to be Unauthorized Supply Overrun. Customer's Net Available Delivery cannot exceed Actual Consumption when the Company issues an Operational Flow Order in the summer. Actual Consumption must not be less than net nomination at the Terminal Location. Any positive Daily Imbalance on a summer Operational Flow Order day shall be deemed to be Unauthorized Supply Underrun.

    The Company will waive Daily Balancing Fee and Cumulative Imbalance Charge on the day of an Operational Flow Order if the customer used less gas than the amount the customer delivered to the system during the winter season or the customer used more gas than the amount the customer delivered to the system during the summer season. The Company will issue a 24-hour advance notice to customers of Operational Flow Orders and suspension of Load Balancing Provisions.

    Cumulative Imbalance Charges:
    Customers may trade Cumulative Imbalances within a delivery area.

    Customers shall be permitted to nominate Make-up Gas, subject to operating constraints, provided that Make-up Gas plus Aggregate Delivery do not exceed Contract Demand. The Company may, on days with no operating constraints, authorize Make-up Gas that, in conjunction with Aggregate Delivery, exceeds Contract Demand.

    The customer's Cumulative Imbalance cannot exceed its Maximum Contractual Imbalance. The excess imbalance shall be deemed to be Unauthorized Overrun or Underrun gas, as appropriate.

    The Cumulative Imbalance Fee applicable daily, is 0.6974 ¢/m³ per unit of imbalance.

    The customer's Cumulative Imbalance shall be equal to zero within five (5) days from the last day of the Service Contract.

    Effective Date:

    To apply to bills rendered for gas delivered on and after October 1, 2017. This rate schedule is effective October 1, 2017 and replaces the identically numbered rate schedule that specifies implementation date, July 1, 2017 and that indicates the Board Order, EB-2017-0181, effective July 1, 2017.


EFFECTIVE DATE:
  October 1, 2017

IMPLEMENTATION DATE:
  October 1, 2017

BOARD ORDER:
  EB-2017-0281

REPLACING RATE EFFECTIVE:
  July 1, 2017