Use a power quality analyzer or harmonic analyzer to capture voltage and current waveforms at the electrical entrance. Modern instruments such as the Fluke 435-II or Hioki PQ3198 can log data continuously and compute harmonic indices automatically.
- THD-V (Voltage THD): Ratio of the RMS of all harmonic voltages to the RMS of the fundamental. Typically should remain below 5% per IEEE 519.
- THD-I (Current THD): Similar metric for current. Limits depend on the short-circuit ratio at the PCC.
- Individual harmonic magnitudes: Capture 2nd through at least 25th harmonic orders.
- Harmonic phase angles: Used to determine direction of harmonic power flow.
Record data over a minimum of 24 horas (ideally 7 día) to capture variations tied to production shifts, lighting schedules, and utility load cycles.
Simultaneously or sequentially measure harmonics at the three key reference points in the power distribution chain:
- Point of Common Coupling (PCC): The boundary between the utility network and your facility — typically the primary terminals of the service transformer or the revenue meter.
- Main Distribution Panel (MDP): The first switchboard or panelboard inside the facility, downstream of the service entrance.
- Individual Loads: Sub-panels, motor control centers, and specific equipment terminals (VFD, UPS, lighting panels).
La rising THD trend moving from the PCC toward loads indicates internal generation. La high THD at the PCC that decreases downstream points to external injection from the utility grid.
THD increases moving downstream from the PCC. Common sources: VFD, rectificadores, switching power supplies, hornos de arco, LED lighting.
THD is elevated at the PCC but decreases or stays stable moving downstream. Fuente: utility network or neighboring industrial consumers on the same feeder.
| Load Type | Dominant Harmonics | Typical THD-I | Notas |
|---|---|---|---|
| 6-pulse VFD / Correcto | 5ª, 7ª, 11ª, 13ª | 25–40% | Most common industrial source |
| 12-pulse Drive | 11ª, 13ª, 23rd, 25ª | 8–15% | 5ª & 7th largely cancelled |
| Single-phase SMPS | 3rd, 5ª, 7ª (odd) | 60–120% | 3rd adds in neutrals (zero-sequence) |
| Arc Furnace / Welding | 2nd, 3rd (even & odd) | Highly variable | Also generates inter-harmonics |
| LED Drivers / CFLs | 3rd, 5ª | 15–30% | Cumulative impact in large installs |
| UPS (Double-conversion) | 5ª, 7ª | 25–35% | Input rectifier; inverter output is clean |
With the harmonic analyzer connected at the MDP, de-energize suspected loads one at a time and observe changes in THD and individual harmonic magnitudes. A significant drop when a load is switched off confirms it as a primary contributor.
- Allow 2–5 minutes after switching for readings to stabilize before recording.
- Perform tests under normal operating conditions — not during unusually light or heavy periods.
- Document percentage change in THD-I for each load; a drop of >3% is considered significant.
- If full shutdowns are not possible, utilizar current harmonic decomposition on branch circuits with a clamp-on harmonic probe.
Harmonic phase angles reveal the direction of harmonic power flow using the harmonic active power method.
\(P_n < 0\) → harmonic power flows fuera de the facility(internal source)
- Consistent phase angles across measurements: The source is stationary and likely internal (por ejemplo, a running VFD).
- Fluctuating or random phase angles: Multiple sources are contributing, possibly including external, time-varying sources on the utility network.
- Compare phase angles of the same harmonic order at PCC vs. load terminals — significant divergence indicates multiple independent sources.
Contact your utility provider and request harmonic measurement data at the MV feeder supplying your facility. Many utilities conduct periodic power quality surveys and may share aggregated data.
- THD-V and individual harmonic voltage levels at the primary side of the distribution transformer serving your site.
- Load profiles of neighboring industrial customers on the same feeder — heavy non-linear consumers can inject harmonics that affect all connected facilities.
- Any recent power quality incidents or known feeder resonance conditions.
Each category of non-linear load produces a characteristic harmonic spectrum — its “fingerprint.” Matching the measured spectrum against known signatures allows rapid source identification.
- Dominant 5th & 7ª, with 11th & 13ª: Classic 6-pulse drive or 3-phase bridge rectifier (characteristic harmonics = 6k ± 1, k = 1,2,3…).
- Dominant 3rd (and triplens — 9th, 15ª): Single-phase non-linear loads — zero-sequence currents that sum in the neutral conductor.
- Incluso los armónicos (2nd, 4ª): Asymmetrical waveform clipping — transformer saturation, half-wave rectification, or geomagnetically induced currents (GIC).
- Flat-top voltage with high 5th harmonic: System impedance interacting with a heavily loaded VFD bus — suspect resonance.
Positive harmonic active power at the PCC meter. The utility or neighboring facilities are the dominant source. Mitigation must be coordinated with the utility.
Negative harmonic active power at PCC. Your facility is injecting harmonics into the grid — you are responsible for mitigation per IEEE 519.
- When power factor correction capacitors are installed, parallel resonance between the capacitor bank and system inductance can amplify even small harmonic sources dramatically.
- Resonant harmonic order: \( h_{\mathrm{res}} = \sqrt{kVA_{sc} \;/\; kVAr_{cap}} \)
- If h_res coincides with a characteristic harmonic (5th or 7th), resonance amplification is likely the culprit — not a large harmonic source.
Defines harmonic current limits at the PCC based on the short-circuit ratio (I_sc / I_L). Voltage distortion limits: 5% THD-V for systems ≤69 kV, 2.5% for 69–161 kV, 1.5% para >161 kV.
European/international standard for emission limits of individual customers in MV and HV networks. Uses a compatibility level and allocation approach for planning levels and equipment emission limits.
\(h_{\mathrm{res}}\) = resonant harmonic order when PFC capacitors are installed
Once the source is confirmed, select the appropriate mitigation strategy and re-measure harmonics after implementation to verify compliance.
| Mitigation Solution | Best For | Reduction | Limitation |
|---|---|---|---|
| Passive Harmonic Filter (tuned) | Fixed loads, single dominant harmonic | 50–80% of target order | Can cause resonance; fixed tuning |
| Filtro armónico activo (AHF) | Cargas variables, multiple harmonics | THD-I < 5% | Higher cost; requires sizing |
| 12-pulse or 18-pulse Drive | New VFD installations | Eliminates 5th & 7ª | Requires phase-shifting transformer |
| Line Reactor (3–5%) | Individual VFD inputs | THD-I from ~40% → ~25% | Modest reduction; voltage drop |
| K-rated / Drive-isolation Transformer | Protecting sensitive loads | Limits harmonic propagation | Does not eliminate the source |
- Re-measure THD-V and THD-I at the PCC and confirm compliance with the applicable standard limit.
- Verify individual harmonic orders are below their respective limits — not just overall THD.
- Check for unintended consequences: filter resonance, increased losses, or capacitor stress.
- Log a full 7-day post-mitigation dataset and compare against the pre-mitigation baseline.
Content drafted with AI assistance and validated by the author based on 30 years of experience in the Power Quality field.