Got a manufacturing client enrolled in OG&E's demand response program here in Oklahoma City. They're supposed to get bill credits for load reduction during peak events, but the interval data isn't matching up with our facility records. OG&E called a DR event on June 5th from 2-6pm, we documented dropping 250kW of non-critical loads, but their interval data only shows 180kW reduction. Missing 70kW somewhere and it's costing us $420 in lost credits per event. Anyone seen discrepancies like this with utility DR program measurements?
OG&E demand response intervals - something doesn't add up
Ramona, NorthWestern Energy has similar issues with their DR program baseline calculations. They use a rolling 10-day average which doesn't account for production schedule changes. If your client had lower baseline usage in the days before the event, it artificially reduces the calculated load drop. What baseline methodology is OG&E using?
Brian's spot on about baseline issues. Had PG&E in Modesto use a 5-of-10 day baseline that completely missed our client's weekend shutdown schedule. Manufacturing facilities need custom baselines that account for production patterns. You should be able to request OG&E's baseline calculation worksheets and challenge their methodology.
Lewis makes a good point. CPS Energy down here lets customers propose alternative baselines for DR programs. You need to show that standard statistical methods don't represent your actual load patterns. Document your production schedules, maintenance windows, and any other factors that affect baseline consumption. DR programs should incentivize actual load reduction, not penalize customers for efficient operations.
OG&E is using a 10-of-12 day baseline with weather normalization. Problem is our client runs 24/7 Monday-Thursday then shuts down Friday-Sunday for maintenance. The baseline calculation includes weekend intervals when we're already at minimum load. Hard to show 250kW reduction when baseline assumes we're running full production. This is a fundamental flaw in their DR measurement.
Ramona, that's exactly the problem we had with We Energies. Their standard baseline methodology doesn't work for facilities with non-standard operating schedules. File a formal request for custom baseline methodology. Most utility tariffs allow for alternative measurement approaches when standard methods don't reflect actual operations. You'll need to provide at least 12 months of production data to support your case.
Mia's right about the custom baseline request. MLGW here in Memphis approved an alternative methodology for a steel plant with similar operating patterns. Key is showing that your facility's load profile is fundamentally different from typical commercial/industrial customers. The 70kW discrepancy you're seeing could be worth $15K annually if you can get it corrected.
Chris brings up a good point about annual value. Even if OG&E won't change the baseline methodology retroactively, getting it fixed going forward is worth the effort. Document everything - production schedules, energy consumption patterns, maintenance windows. DR programs are voluntary so utilities should be working with customers, not against them.
Thanks everyone. I'm putting together a comprehensive data package with 18 months of production records, energy consumption, and detailed analysis of why the standard baseline doesn't work. The client's production manager is also documenting actual equipment shutdowns during each DR event. If OG&E won't approve custom methodology, we'll escalate to Oklahoma Corporation Commission.
Good strategy Ramona. Also consider requesting interval-by-interval comparison data for the June 5th event. Sometimes utilities have meter reading errors or data processing issues that cause discrepancies. I found a 15-minute timestamp offset in PG&E's system that was reducing measured DR performance by 20%. Simple fix once identified.
Lewis raises an important point about data processing errors. Black Hills Energy had a similar timestamp issue that took months to discover. Make sure to cross-reference your facility's data logger timestamps with OG&E's interval records. Even a 5-minute offset can significantly impact DR measurement accuracy.
Joanne, that's brilliant - hadn't thought about timestamp synchronization issues. Our facility SCADA system logs equipment shutdowns to the minute. I'll cross-reference those timestamps with OG&E's interval data to see if there's an offset. Could explain the 70kW discrepancy if their system is capturing load reduction in different 15-minute buckets than actual shutdown times.
Perfect approach Ramona. We found a 12-minute offset with We Energies that was causing similar issues. Their AMI system was time-stamping intervals at the end of the measurement period while our equipment logs used start-of-period timestamps. Small difference but it made DR performance look much worse than reality.
Excellent troubleshooting work everyone. Timestamp synchronization is often overlooked in DR program disputes but it's critical for accurate measurement. Ramona, make sure to document the exact timestamps in your filing with OCC. Utilities need to maintain accurate interval data if they're going to use it for financial settlements. This kind of systematic error affects program integrity for all participants.