Coupled Thermal-Fluid Field Modeling and Insulation Aging Risk Assessment of Oil-immersed 750 kV Power Transformer under OFAF Cooling Mode

MA Longtao; SONG Zhaohui; XIE Zuibing; WANG Jili; ZENG Linping; ZHANG Qiaogen

doi:10.20204/j.sp.2026.02014

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Coupled Thermal-Fluid Field Modeling and Insulation Aging Risk Assessment of Oil-immersed 750 kV Power Transformer under OFAF Cooling Mode

更新时间：2026-02-28

- Coupled Thermal-Fluid Field Modeling and Insulation Aging Risk Assessment of Oil-immersed 750 kV Power Transformer under OFAF Cooling Mode
- Vol. 54, Issue 2, Pages: 115-123(2026)
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- DOI：10.20204/j.sp.2026.02014
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- Published：2026
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马龙涛,宋朝晖,谢醉冰,王吉利,曾林平,张乔根.OFAF冷却模式下油浸式750 kV电力变压器热-流场耦合建模与绝缘老化风险评估[J].智慧电力,2026,54(2):115-123.

doi:10.20204/j.sp.2026.02014
马龙涛,宋朝晖,谢醉冰,王吉利,曾林平,张乔根.OFAF冷却模式下油浸式750 kV电力变压器热-流场耦合建模与绝缘老化风险评估[J].智慧电力,2026,54(2):115-123. DOI： 10.20204/j.sp.2026.02014.

doi:10.20204/j.sp.2026.02014 DOI：

摘要

针对强迫油循环-强迫风冷冷却模式下油浸式电力变压器的内部热场分布不清、绝缘老化风险尚缺乏精确评估的问题，以1台750 kV超高压变压器为研究对象，建立了其热-流场耦合仿真模型及绝缘老化风险量化评估模型。首先，通过用户自定义函数实现了油流速度实时调控，并对比理论计算与仿真结果，验证了模型的准确性。其次，对不同负荷率下变压器的热场分布进行了计算，对比了绕组内部以及不同绕组间的温度差异，分析了负荷率变化对热点温升及整体热场分布的影响规律。最后，建立了负荷率和老化率的映射关系，对绕组绝缘老化风险进行了评估。仿真结果表明，绕组温度沿轴向油道先升后降，中上部区域为热点高发区；随着负荷率提升，绕组热损耗增大，绝缘温升加剧；高压绕组热点温升最为显著，是其绝缘失效风险最高的主要原因。本研究为超高压变压器的绝缘状态评估与运行寿命预测提供了理论依据。

Abstract

Aiming at the unclear internal thermal field distribution and the lack of precise assessment for insulation aging risk in oil-immersed power transformers under the oil-forced air-forced (OFAF) cooling mode

this study takes a 750 kV ultra-high voltage transformer as the research object. Models for coupled thermal-fluid field simulation and quantitative assessment of insulation aging risk were established. Firstly

real-time regulation of oil flow velocity was achieved through a user-defined function

and the accuracy of the model was verified by comparing theoretical calculations with simulation results. Secondly

the thermal field distribution of the transformer under different load ratios was calculated. The temperature differences within the windings and between different windings were compared

and the influence of load ratio variation on the hotspot temperature rise and the overall thermal field distribution was analyzed. Finally

a mapping relationship between load ratio and aging rate was established to assess the winding insulation aging risk. Simulation results indicate that the winding temperature initially increases and then decreases along the axial oil duct

with the middle-upper region being a high-incidence area for hotspots. As the load ratio increases

the winding thermal losses rise

leading to intensified insulation temperature rise. The hotspot temperature rise is most significant in the high-voltage winding

which is the primary reason for its highest risk of insulation failure. This research provides a theoretical basis for the insulation condition assessment and operational life prediction of ultra-high voltage transformers.

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