Анализ растворенных газов (DGA) является важным инструментом для оценки внутреннего состояния силовых трансформаторов. Водород (H₂) — один из наиболее распространенных характерных газов, но его источники разнообразны — от обычных химических реакций материалов до зарождающихся неисправностей, таких как частичный разряд и перегрев. Точное определение источника водорода необходимо для оценки состояния трансформатора и принятия решений по техническому обслуживанию.
This article systematically reviews the main sources, generation mechanisms, and identification methods for hydrogen in transformer oil, and highlights the drawbacks of relying solely on single‑gas hydrogen monitoring.
В зависимости от механизмов образования газа и связанных с ними характеристик источники водорода делятся на три категории: внутренние неисправности, химические реакции материалов и внешние факторы.
Mechanism: Weak discharge causes oil molecule cracking → H₂ generation.
Gas signature: H₂ dominates (>80%), trace CH₄ and C₂H₆ possible, almost no C₂H₂.
Key indicator: Isolated H₂ rise with very low other hydrocarbons.
Mechanism: Thermal breaking of C‑H bonds releases H₂.
Gas signature: CH₄, C₂H₆, C₂H₄ appear depending on temperature; H₂ level usually lower than in discharge cases.
Key indicator: H₂ rise accompanied by significant hydrocarbon gases (especially C₂H₄).
| Type | Mechanism | Typical Scenario | Gas Signature |
|---|---|---|---|
| Moisture‑involved reaction | Fe + H₂O → FeO + 2H → H₂ | High humidity, poor sealing | H₂↑ + moisture↑ |
| Cyclohexane catalytic dehydrogenation | Cyclohexane → Benzene + H₂ (Ni catalyst) | Stainless steel bellows expanders | Isolated H₂↑ (up to thousands ppm) |
| Metal corrosion | Electrochemical rusting produces H₂ | Rust in tank, core, coolers | Isolated H₂↑, possible moisture↑ |
Residual hydrogen in new oil: Dissolved during refining, transport, or filling – common in newly commissioned transformers, decreases with operation.
Improper oil treatment: Insufficient vacuum, short processing time, or poor temperature control can increase dissolved gases including H₂.
Core principle: Never rely on hydrogen concentration alone – combine multi‑dimensional information.
| H₂ Trend | Accompanying Gases | Moisture | Most Likely Source | Action |
|---|---|---|---|---|
| Isolated rise | No hydrocarbons, CO normal | Normal | Cyclohexane dehydrogenation, residual H₂ | Monitor only |
| Isolated rise | No hydrocarbons, CO normal | Elevated | Moisture‑related corrosion | Check sealing, treat moisture |
| Rise | CH₄, C₂H₄ etc. | Normal or elevated | Overheating | Electrical tests, plan inspection |
| Rise (dominant) | Trace CH₄, C₂H₆, no C₂H₂ | Normal | Partial discharge | PD measurement, consider outage |
| Rise | C₂H₂ present | Normal | Arcing (severe) | Immediate outage |
H₂↑ + влага↑ → Реакция влаги или коррозия
H₂↑ + влага нормальная → Выброс, каталитическое дегидрирование или остаточная H₂
Rapid continuous increase → Active fault, need outage
Peak then stable/declining → Commissioning “break‑in” or catalytic equilibrium
Seasonal fluctuation → Moisture‑related reactions
High PD, ультразвуковые аномалии → Частичный разряд
Несбалансированное сопротивление постоянному току, аномальный ток заземления сердечника, ИК-горячие точки → Перегрев
Все тесты в норме + короткий срок службы → Материал/процесс факторы
Principle: CO is a specific byproduct of solid insulation (cellulose) thermal decomposition. Material/chemical hydrogen sources do not involve insulation heating, so CO remains normal.
Решение логика:
H₂↑ + CO нормальный → доброкачественный водород (материал/процесс) – нет ненужных простоев. alert.
CO↑ + H₂ нормальный → Нормальное термическое старение – не чрезвычайная ситуация.
3. Тематические исследования
Practical value: Using H₂ and CO as a paired indicator significantly reduces false alarms and avoids costly unnecessary inspections.
Situation: 220kV transformer, 3 months in service, H₂ = 1500 μL/L, other gases <1 μL/L, moisture normal, all electrical tests normal.
Diagnosis: Cyclohexane catalytic dehydrogenation.
Outcome: After 1 year, H₂ stabilized at ~800 μL/L – no action needed.
Situation: 110kV transformer, 10 years in service, H₂ = 380 μL/L, CH₄ = 45 μL/L, C₂H₄ = 28 μL/L, moisture rose from 12 to 25 mg/L.
Diagnosis: Moisture‑induced rust reaction with mild overheating.
Outcome: Internal inspection revealed core rusting; after treatment, H₂ returned to normal.
Relying solely on hydrogen monitoring carries significant false‑alarm risks because:
Данные по одному газу не могут определить тип, серьезность или местоположение неисправности.
Рекомендации:
It can lead to two extremes: missing major faults (assuming benign) or frequent false alarms → unnecessary outages and wasted resources.
Допускать повышенный уровень H₂ в новых трансформаторы введены в эксплуатацию, но отслеживайте тенденции и проверяйте CO.
Prefer multi‑component DGA (at least H₂ + CH₄ + C₂H₂ + CO + moisture).
FAQ
For isolated H₂ rise with normal CO – do not rush to outage; enhance monitoring or perform degassing.
Q: What is the typical alarm threshold for hydrogen in transformer oil?
A: Usually >150 μL/L warrants attention, but thresholds vary by voltage class and asset type – trend analysis is more important.
Q: How long does it take for hydrogen to drop in a new transformer?
A: Typically 1‑3 months of operation or hot oil circulation. If H₂ remains high with hydrocarbon gases, further investigation is needed.
Q: Are single‑gas hydrogen monitors still useful?
A: They can provide basic early warning for distribution‑class transformers, but for critical assets, upgrade to multi‑component DGA is strongly recommended.
HERTZINNO’s online DGA systems (DGA900, DGA500, DGA300) support multi‑component gas plus moisture monitoring, effectively avoiding false alarms caused by single‑gas hydrogen monitoring. Learn more →
