Inactive
Notice ID:N33191ROTA_ELECTRIC
The United States Government is anticipating the release of a solicitation for the requirements outlined below no later than February 2021 through the United States Government’s solicitation portal (b...
The United States Government is anticipating the release of a solicitation for the requirements outlined below no later than February 2021 through the United States Government’s solicitation portal (beta.sam.gov). This sources sought (SS) and request for information (RFI) is for planning purposes only and shall not be considered as an invitation for bid (IFB), request for quotation (RFQ), request for proposal (RFP), or as an obligation on the part of the Government to acquire any products or services. The government will not award a contract on the basis of this notice, or otherwise pay for information solicited by it. No entitlement to payment of direct or indirect costs or charges by the Government will arise as a result of contractor submission of responses to this announcement nor the Government's use of such information. Interested parties are responsible for adequately marking proprietary or competition sensitive information contained in their response. The requested information is for planning and market research purposes only and will not be publicly released. Responses to this RFI are not offers and cannot be accepted by the Government to form a binding contract. The Naval Facilities Engineering Command (NAVFAC) Europe Africa Southwest Asia (EURAFCENT) Command is seeking comments on draft requirements, market research, potential sources, and best practice information for the supply of high voltage electricity at Naval Station (NS) Rota whose location on the electrical grid is identified by the NIF/CIF N4001073H and CUPH EH0031102555053001GD0F and is located in Rota. The annual electricity consumption of this base is approximately 95,000 MWh per year. NAVFAC EURAFCENT is requesting information on alternative pricing structures for the electricity supply component of NS Rota’s electric utility bill. The base is currently served by the following pricing structure and is considering a similar structure: A firm-fixed Offer Price including a EUR/MWh price for each year of the performance period (1-3 year period) at every Time Band (P1-P6) as denoted by the Access Tariff 6.2 time of use (TOU) schedule. The energy supply offer price includes the following components: Costs associated with the application of Directive 2009/29/EC and Orden IET/697/2015. Cost associated with the application of the Directive 2012/27/UE. Mercados de Compra de Energía y Hervicios Complementarios y Restricciones (Energy including Ancillary Services). Imbalance costs and any other dispatch costs related to scheduling of deliveries; and, costs relevant to holding the necessary authorizations, in accordance with current legislation, to subscribe on behalf of the Government, to purchase transportation rights, production capacity to national level and import of energy from foreign markets. Supplier margin The following costs are not included in the energy offer price but are charged as pass through costs with no markup applied: Peajes de Acceso (Access Tariffs). Término de Potencia (Power Demand Term) (kW). Término de Energia (Energy Cost Term) (kWh). Pago por Capacidad (Capacity Payments). Retribución del Operador del Mercado (Remuneration of the Market Operator). Retribución del Operador del Sistema (Remuneration of the System Operator). Coste del Servicio de Interrumpibilidad (Interruptibility Service Cost). Pérdidas (Losses). Alquiler de Medidores (Meter Rental). Complemento por Consumo de Reactiva (Supplement for Reactive Power Consumption). Penalizaciones por Excesos de Potencia (Excess Demand Penalty). Offer Price shall also NOT include any taxes to which the United States Government is exempt (e.g. Impuesto Municipal (Municipal Tax)). Constructive feedback, suggestions, and solutions are requested. The U.S. Government would like contractors to submit responses to the following by 16 November 2020: Do you offer large industrial customers a similar “6 band” product? Are there any differences between the pricing formula described above and the structure of your offer? Do you offer large industrial customers a “floating price” product that is indexed to a Spanish wholesale electricity market price? If so, please describe the components of that price: What is the electricity market index/ticker used for the “floating price” portion of the energy supply charge (E.g. MIBEL Day Ahead Hourly Price)? What are the other components that will be applied to or embedded inside the “floating price” portion of the energy supply charge (e.g. a fixed transaction fee per kWh)? What are the items outside of the energy supply charge that would be included in the bill (e.g. access rate, losses coefficient, capacity payments, system operator charges, market operator charges)? Is there a markup or transaction fee applied to items outside of the energy supply charge (e.g. a fixed transaction fee per kWh of losses)? Do you offer large industrial customers a full-requirements “fixed price” product that is one single price per kWh across every hour of the year? If so, please describe all of the components of that price: What are the other components that will be applied to or embedded inside the “fixed price” portion of the energy supply charge (e.g. a fixed transaction fee per kWh)? What are the items outside of the “fixed price” energy supply charge (e.g. access rate, losses coefficient, capacity payments, system operator charges, market operator charges)? Is there a markup or transaction fee applied to items outside of the energy supply charge (e.g. a fixed transaction fee per kWh of losses)? Do you offer large industrial customers the ability to combine fixed and floating rate contract structures to create a “blended rate” or “block and index” (e.g. use the “6-band” TOU pricing structure but index to a floating rate for periods P6 and P5 while offering a fixed price for periods P1-P4)? What are the other components that will be applied to or embedded inside the “time of use” portion of the energy supply charge (e.g. a fixed transaction fee per kWh)? What are the items outside of the “fixed price” energy supply charge (e.g. access rate, losses coefficient, capacity payments, system operator charges, market operator charges)? Is there a markup or transaction fee applied to items outside of the energy supply charge (e.g. a fixed transaction fee per kWh of losses)? What pricing format would your company prefer to submit to the U.S. Navy in a competitive power market solicitation (for example: market-indexed “floating price”, full-requirements “fixed price”, “6-band” TOU prices, or a “blended rate” approach)? What is the preferred contract duration? 1, 2, or 3-years and why is that option most preferable to you? What are considerations the USN should be aware of when your company forecasts the bid price for longer term contracts (beyond 2 years)? For example: Does it take more time to formulate solicitation bid? Does your company have to buy additional hedging or risk products? Is a higher risk premium incorporated into the price? Would your company bid on a multi-year contract with the U.S. Navy, with interim price adjustments? If so: What is the preferred number of years of the contract (1 yr, 2 yr, 3 yr or more)? Please specify and include the reasons why. What is preferred cadence of price adjustments (every 6 months, every 12 months)? Please specify and include the reasons why. Which index would your company prefer be used to calculate the interim price adjustments (ICE, EEX, GME, other)? Please specify and include the reasons why. Is your company able to offer a lower price (per unit) than a published market index for the commodity only?
