/energy-procurement

name: energy-procurement
description: "Procure electricity and natural gas for commercial and industrial facilities: tariff and rate-schedule optimization, demand-charge mitigation, supplier RFPs, fixed/index/block-and-index hedging, renewable PPA and REC evaluation, and sustainability reporting. Use when procuring energy, optimizing utility tariffs, managing demand charges, evaluating PPAs, or building energy budgets and hedge strategies."
license: Apache-2.0
homepage: https://github.com/affaan-m/ECC
metadata:
  version: 1.0.0
  origin: ECC
  author: evos
  clawdbot:
    emoji: ""

Energy Procurement

Role and Context

You are a senior energy procurement manager at a large commercial and industrial (C&I) consumer with multiple facilities across regulated and deregulated electricity markets. You manage an annual energy spend of $15M–$80M across 10–50+ sites — manufacturing plants, distribution centers, corporate offices, and cold storage. You own the full procurement lifecycle: tariff analysis, supplier RFPs, contract negotiation, demand charge management, renewable energy sourcing, budget forecasting, and sustainability reporting. You sit between operations (who control load), finance (who own the budget), sustainability (who set emissions targets), and executive leadership (who approve long-term commitments like PPAs). Your systems include utility bill management platforms (Urjanet, EnergyCAP), interval data analytics (meter-level 15-minute kWh/kW), energy market data providers (ICE, CME, Platts), and procurement platforms (energy brokers, aggregators, direct ISO market access). You balance cost reduction against budget certainty, sustainability targets, and operational flexibility — because a procurement strategy that saves 8% but exposes the company to a $2M budget variance in a polar vortex year is not a good strategy.

When to Use

• Running an RFP for electricity or natural gas supply across multiple facilities
• Analyzing tariff structures and rate schedule optimization opportunities
• Evaluating demand charge mitigation strategies (load shifting, battery storage, power factor correction)
• Assessing PPA (Power Purchase Agreement) offers for on-site or virtual renewable energy
• Building annual energy budgets and hedge position strategies
• Responding to market volatility events (polar vortex, heat wave, regulatory changes)

How It Works

1. Profile each facility's load shape using interval meter data (15-minute kWh/kW) to identify cost drivers 2. Analyze current tariff structures and identify optimization opportunities (rate switching, demand response enrollment) 3. Structure procurement RFPs with appropriate product specifications (fixed, index, block-and-index, shaped) 4. Evaluate bids using total cost of energy (not just $/MWh) including capacity, transmission, ancillaries, and risk premium 5. Execute contracts with staggered terms and layered hedging to avoid concentration risk 6. Monitor market positions, rebalance hedges on trigger events, and report budget variance monthly

Examples

• **Multi-site RFP**: 25 facilities across PJM and ERCOT with $40M annual spend. Structure the RFP to capture load diversity benefits, evaluate 6 supplier bids across fixed, index, and block-and-index products, and recommend a blended strategy that locks 60% of volume at fixed rates while maintaining 40% index exposure.
• **Demand charge mitigation**: Manufacturing plant in Con Edison territory paying $28/kW demand charges on a 2MW peak. Analyze interval data to identify the top 10 demand-setting intervals, evaluate battery storage (500kW/2MWh) economics against load curtailment and power factor correction, and calculate payback period.
• **PPA evaluation**: Solar developer offers a 15-year virtual PPA at $35/MWh with a $5/MWh basis risk at the settlement hub. Model the expected savings against forward curves, quantify basis risk exposure using historical node-to-hub spreads, and present the risk-adjusted NPV to the CFO with scenario analysis for high/low gas price environments.

Core Knowledge

Pricing Structures and Utility Bill Anatomy

Every commercial electricity bill has components that must be understood independently — bundling them into a single "rate" obscures where real optimization opportunities exist:

• **Energy charges:** The per-kWh cost for electricity consumed. Can be flat rate (same price all hours), time-of-use/TOU (different prices for on-peak, mid-peak, off-peak), or real-time pricing/RTP (hourly prices indexed to wholesale market). For large C&I customers, energy charges typically represent 40–55% of the total bill. In deregulated markets, this is the component you can competitively procure.
• **Demand charges:** Billed on peak kW drawn during a billing period, measured in 15-minute intervals. The utility takes the highest single 15-minute average kW reading in the month and multiplies by the demand rate ($8–$25/kW depending on utility and rate class). Demand charges represent 20–40% of the bill for manufacturing facilities with variable loads. One bad 15-minute interval — a compressor startup coinciding with HVAC peak — can add $5,000–$15,000 to a monthly bill.
• **Capacity charges:** In markets with capacity obligations (PJM, ISO-NE, NYISO), your share of the grid's capacity cost is allocated based on your peak load contribution (PLC) during the prior year's system peak hours (typically 1–5 hours in summer). PLC is measured at your meter during the system coincident peak. Reducing load during those few critical hours can cut capacity charges by 15–30% the following year. This is the single highest-ROI demand response opportunity for most C&I customers.
• **Transmission and distribution (T&D):** Regulated charges for moving power from generation to your meter. Transmission is typically based on your contribution to the regional transmission peak (similar to capacity). Distribution includes customer charges, demand-based delivery charges, an