Load Shifting (Peak to Off-Peak) is the practice of moving electricity use from high‑cost peak periods to lower‑cost off‑peak periods so commercial and industrial facilities can lower power costs without touching their critical path. In this episode, we break down how time‑of‑use rates, demand charges, and your actual schedule fit together so you can see when load shifting is a real financial lever and when it is just a slide in a vendor deck.

This is Energy Decision #11 in the complete C&I energy management series from Tactical Energy Group. 100 decisions. Every one that matters.

In this episode, Daniel Burke covers:
• The core idea of load shifting for operators and how it differs from efficiency
• How time‑of‑use rates and demand charges create the incentive to cut peak demand
• Common shiftable loads by sector: HVAC, batch processes, pumps, forklifts, and non‑critical computing tasks
• Implementation methods: manual scheduling, BMS and EMS automation, Thermal Energy Storage, and Battery Energy Storage Systems
• Key metrics like peak demand in kW, energy (kWh) by TOU period, load factor, and shiftable load percentage
• Capital cost ranges, simple payback period, and ROI for TES, BESS, and advanced controls
• The gap between theoretical “shiftable” loads and what your production schedule will actually allow
• The practical difference between load shifting and peak shaving in vendor conversations

Who this is for: plant managers, facility managers, superintendents, COOs, and energy managers at manufacturers, commercial buildings, warehouses, water treatment plants, and agricultural operations who are tired of reacting to the bill and want a clear path to using load shifting on their terms.

If you're trying to figure out how your facility can implement load shifting to minimize energy costs and still protect operational schedules, this episode is built for you.

Read the full breakdown on Load Shifting (Peak to Off-Peak) at tacticalenergygroup.com/load-shifting-peak-to-off-peak.

If you're an Indiana C&I operator actively evaluating this decision, get your free Energy Decision Blueprint at blueprint.tac-nrg.com.

Visit tacticalenergygroup.com for more practical tools and the Energy Decision Blueprint for qualified Indiana C&I operators.

Timestamps:
0:00 – What is load shifting from peak to off‑peak
3:05 – How time‑of‑use rates and demand charges create the opportunity
7:20 – Shiftable loads by sector in C&I facilities
11:40 – Implementation tiers from manual schedules to TES and BESS
16:10 – Capital costs, payback, and real‑world constraints
20:30 – Load shifting vs peak shaving explained
24:10 – Metrics, decision rules, and team questions

Utility Bill Audits and Error Recovery is about taking a forensic look at your past utility invoices to find billing errors, get money back, and stop overpaying going forward.
This is Energy Decision #8 in the complete C&I energy management series from Tactical Energy Group. 100 decisions. Every one that matters.
In this episode, Daniel Burke covers:

• What a utility bill audit is and how it differs from your normal invoice review
• The step-by-step mechanics of a forensic bill audit across multiple years of invoices
• How auditors check tariff compliance, demand and energy calculations, and meter constants
• The kinds of billing errors that routinely show up for large healthcare, manufacturing, and public sector accounts
• How tax exemptions, power factor penalties, and rate misclassification quietly drain your budget
• Typical recovery ranges and what a 1–5% refund means on a multi-million-dollar utility spend
• Why most audits are done on a contingency fee basis and what that means for your risk
• The difference between a utility bill audit and ASHRAE energy audits (Levels 1, 2, and 3)
• When to schedule a bill audit in the life of a facility or portfolio
• How to decide whether to build basic audit skills in-house or bring in a specialist

Who this is for: finance leaders, plant managers, facilities directors, superintendents, and energy managers in healthcare, manufacturing, government, large commercial real estate, educational institutions, and data centers who manage large utility budgets and want to stop leaving money on the table.

If you’re asking whether you should invest in a utility bill audit to identify and recover potential energy overcharges and optimize future billing, this episode is for you.

Read the full breakdown on Utility Bill Audits and Error Recovery at tac-nrg.com/utility-bill-audits-and-error-recovery.
If you're an Indiana C&I operator actively evaluating this decision, get your free Energy Decision Blueprint at blueprint.tac-nrg.com.
Visit tac-nrg.com to learn more and get practical tools for your facilities.

0:00 – What is a utility bill audit and why it matters for large C&I users
3:30 – How a forensic utility bill audit actually works step by step
9:20 – Common billing errors and where money is usually hiding
16:10 – Realistic recovery ranges and how contingency fees are structured
22:40 – Utility bill audits vs. ASHRAE energy audits
29:15 – When to schedule a bill audit in your facility’s lifecycle
35:40 – Building basic audit skills in-house vs. hiring a specialist
42:10 – Morning huddle questions and the Energy Decision Blueprint offer

FERC Order 2222 and DER Aggregation (Part 1 of 2) is about turning distributed energy resources at commercial and industrial facilities into revenue‑generating assets by giving them structured access to wholesale electricity markets through aggregators. This episode explains what the order actually does, what counts as a DER, and how C&I operators fit into the aggregation model.

This is Energy Decision #08 in the complete C&I energy management series from Tactical Energy Group. 100 decisions. Every one that matters.

In this episode, Daniel Burke covers:
• What FERC Order 2222 changes in wholesale electricity markets for distributed energy resources
• Which assets at C&I facilities qualify as DERs: batteries, CHP, backup generators, rooftop solar, flexible loads, and more
• How DER aggregation works, why minimum bid size matters, and where the 100 kW threshold fits
• The role of the DER aggregator in technical integration, market interface, optimization, and risk management
• Core wholesale market categories: energy, capacity, and ancillary services like frequency regulation
• Revenue ranges for capacity payments, regulation services, and demand charge reduction, plus typical aggregator revenue share
• Key risks: operational constraints, loss of direct control, performance penalties, cybersecurity exposure, and regulatory uncertainty
• A seven‑step implementation sequence from DER audit to contract negotiation and ongoing monitoring

Who this is for: plant managers, facility managers, superintendents, COOs, and energy managers at manufacturers, data centers, hospitals, universities, large retail, and municipalities who want to know, “how does FERC Order 2222 affect my facility” and whether wholesale market access is worth the complexity.

If you're trying to figure out how to strategically aggregate distributed energy resources so your operation can participate in wholesale markets and optimize energy costs under FERC Order 2222, this episode is built for you.

Read the full breakdown on FERC Order 2222 and DER Aggregation (Part 1 of 2) at tacticalenergygroup.com/ferc-order-2222-and-der-aggregation-part-1-of-2.

If you're an Indiana C&I operator actively evaluating this decision, get your free Energy Decision Blueprint at blueprint.tac-nrg.com.

Visit tacticalenergygroup.com for more practical tools and the Energy Decision Blueprint for qualified Indiana C&I operators.