Application of dielectric response measurement on power cable systems

Water treeing is one of the factors leading to failure of medium voltage XLPE cables in long-term service. Increased moisture content inside oil-paper insulated cable is not desirable. To identify water tree degraded XLPE cables or oil-paper cables with high moisture content, diagnostic tests based on dielectric response (DR) measurement in time and frequency domain are used. Review of individual DR measurement techniques in the time and frequency domains indicates that measurement of one parameter in either domain may not be sufficient to reveal the status of the cable insulation. But a combination of several DR parameters can improve diagnostic results with respect to water trees present in XLPE cables or increased moisture content in oil-paper cables. DR measurement is a very useful tool that reveals average condition of cable systems. However, it is unlikely that DR measurement will detect few, but long water trees. In addition, DR cannot locate the defect or water tree site within the cable system. Combination of DR and partial discharge (PD) measurements can improve diagnostic results with respect to global and local defects. However, it is doubtful whether PD test can identify the presence of water trees inside a cable in a nondestructive manner. Further research is needed for more detailed conclusions regarding the status of a particular insulation and for predicting the remaining life of the insulation system.     

Development of extruded ethylene propylene rubber insulated superconducting cable

A superconducting power cable is one of the promising ways of underground transmission of huge electric power in the future. The authors have long proposed the idea of the extruded polymer insulation for superconducting cables. The prominent features of the design are to exploit the excellent electrical properties of polymer in the cryogenic temperatures and to separate the helium coolant from the electrical insulation. Although the extruded cross-linked polyethylene cable has proved ability at the liquid nitrogen temperature, the cable insulation cracked due to mechanical stress during cooling to the liquid helium temperature. To overcome this problem, ethylene propylene rubber (EPR) was selected as a new insulating material considering the good results of mechanical and electrical tests of EPR samples at cryogenic temperatures. An extruded EPR insulated superconducting cable 15 m in length was fabricated and a cooling test down to the liquid helium temperature and a voltage test at the liquid helium temperature were carried out with fair success. This is a breakthrough in terms of the electrical insulation design of cryogenic cables.     

Stress induced electrochemical degradation of the inner semiconlayer of XLPE-insulated cables and model samples

A degradation phenomenon of the inner semicon layer of extruded cable insulation occasionally has been observed in different service aged as well as in laboratory aged polymer insulated cables. To investigate this effect, accelerated aging tests on XLPE-insulated cable cores as well as on a new type of model sample (aluminum wires, semicon and XLPE insulation layer) were performed. It is shown that under the influence of an electrolyte and mechanical strain, channel-like structures develop in the semicon of both test objects, and that vented trees are initiated when these structures reach the interface to the insulation. Thus, this type of degradation also is of particular importance for the long time aging behavior and testing procedures of polymer insulated cables. It is demonstrated that the newly developed model sample test arrangement is a valuable tool for the study of aging of insulation systems     

Development of a 69kV High-Pressure Gas-Filled Pipe-Type Cable System for an Arctic Environment

A high-pressure gas-filled (HPGF) pipe-type cable system rated 69kV has been developed for operation at Prudhoe Bay, Alaska, which is at the North Slope above the Arctic Circle. A minimum ground ambient of -10°C is applicable to the major portion of the circuit which is buried. The cables installed in pipes across a 46 m (150 foot) long bridge, the terminal riser cables and the cable terminals experience a minimum air ambient of -48°C. The cable design for each of these ambient temperatures required special consideration with regard to the insulation structure and impregnant to be employed for the paper insulation. This paper describes the investigation of materials, cable models and prototype cables to achieve the physical and electrical properties required for the application. For the buried cable, a polybutene impregnant having a viscosity lower than normally employed for HPGF cable was used. For the cables exposed to the lower ambient air temperature, a phenylmethyl polysiloxane silicone fluid was selected as the impregnant. A transition joint between the polybutene and silicone impregnated cables was developed. Standard gas-filled terminals were modified for service at the low ambient air temperature. The successful completion of this R&D project has provided a rugged, reliable high voltage cable system suitable for transmitting power in an arctic environment.     

挤包绝缘高压直流电缆应用现状与研究展望

挤包绝缘高压直流电缆已成为远距离、大容量输电线路建设的主要装备之一,现阶段广泛应用的挤包绝缘直流电缆以交联聚乙烯(XLPE)绝缘为主.针对XLPE绝缘高压直流电缆研发和应用中的绝缘空间电荷特性、副产物脱气等主要问题进行全面综述,指出在工业化生产方式下,超纯净体系XLPE绝缘材料是目前用来缓解空间电荷问题和实现电缆批量化...     

Research and development of electrical insulation ofsuperconducting cables by extruded polymers

This is a review to show the importance of electrical insulation in ac superconducting cables. An attractive superconducting cable has to be designed for the voltage range of 60-270 kV. Therefore, a reliable insulation design is imperative. Two types of insulation have been compared. One is composite insulation, namely laminar paper or plastic tape, impregnated with coolant. The other is solid insulation of extruded polymer on the conductor. The composite insulation has a lengthy history and, in the constructions to date, has been the insulation design used for superconducting cables. Some prototype superconducting cables with this type of insulation have been developed and successfully tested. However, the partial discharge in butt gaps may affect their long-term reliability. The solid insulation, on the other hand, can separate the coolant from the electrical insulation and can exploit the benefit of the super electrical insulation characteristics of polymers in the cryogenic region. Some attempts have been made to use this design with liquid nitrogen and liquid helium. One example incorporating extruded ethylenepropylene rubber (EPR) for insulation was found to satisfactorily go through the cool-down to a liquid helium temperature and to endure the simultaneous voltage and current tests. EPR, and possibly some other polymers, seem to be promising materials for solid insulation in the cryogenic region     

Severe degradation of the conductor screen of service and laboratory aged medium voltage XLPE insulated cables

The main purpose of this paper is to show the strong correlation between corrosion of the metallic aluminum conductor and the formation of interconnected cracks / voids in the conductor screen, creating initiation sites for vented water trees in service aged medium voltage XLPE cables. The results show that porous structures in the conductor screen previously reported for laboratory aged insulation systems, also develop in the conductor screen in service aged medium voltage XLPE cables. These structures can bridge the screen and serve as path for contaminants and corrosion products from the aluminum conductor and initiate water trees. A prerequisite for the formation of such structures is the presence of liquid water at the interface between the conductor and conductor screen causing corrosion. The initiation site of such structures has been identified, and is likely caused by environmental stress cracking (ESC). Initiation sites were determined in all cables, but porous structures in the conductor screen were only observed in the cable suffered from service failure, where liquid water had entered the cable conductor between the strands. Severe degradation of the XLPE insulation was observed at the initiation sites for water trees growing from these structures.     

Condition assessment of 12- and 24-kV XLPE cables installed during the 80s. Results from a joint Norwegian/Swedish research project

This paper reports the results from the condition assessment of 12- and 24-kV cross-linked polyethylene (XPLE) cables using a technique based on dielectric spectroscopy initially developed at KTH in Sweden. The work aims to examine whether the method could detect water tree degradation for the second generation medium voltage (MV) cables with long, but not bridging, water trees. While the overall cable condition was better than expected for second generation XPLE cables, water trees were found in most of the selected cables. The diagnostic method based on the measurement of the dielectric response could only detect water tree degradation in the examined second generation cables when the water trees bridged the insulation wall. Condition assessment above service stress may, in some cases, be required to detect bridging water trees. The results indicate that there is a correlation between the voltage level and the breakdown voltage of the cable. This can be used as a diagnostic criterion for this group of cables.     

交联聚乙烯电缆水树缺陷的修复方法研究

采用硅氧烷修复液修复交联聚乙烯电缆老化试样中的水树,进而分析修复效果及机理。将介质损耗因数为4%～6%,绝缘电阻7 500～10 000 MΩ的短电缆在7.5 kV 450 Hz交流电压下老化至介质损耗因数达到20%左右,绝缘电阻3 500～5 000 MΩ。然后用压力注入式修复装置把修复液注入缆芯对水树缺陷进行修复。以介质损耗因数、绝缘电阻和击穿电压为指标对修复效果进行评判;通过显微镜切片观察修复前后水树微观形态;通过仿真修复前后水树附近电场分布来分析和验证水树的修复机理。实验结果证明,修复液可以充分与电缆水树中的水发生反应生成胶状聚合物填充水树通道;修复后电缆介质损耗因数、绝缘电阻和击穿电压恢复到新电缆水平;改善了绝缘层电场分布;有效地抑制了水树生长。实验表明,该修复液可有效修复电缆中的水树缺陷,提高电缆绝缘水平。     

挤包绝缘电缆电压击穿试验的数理统计

本文叙述了威布尔数理统计的基本方法,用以对挤包绝缘电缆的电压击穿试验进行数据处理;评定各项威布尔参数和电缆寿命指数N值;从一系列比较分散的击穿电压数值中,可以找到一个正确可靠的试验结果。     

Evaluation of Locomotive Cable Insulation Life Under Varying Temperature Loading

A method is described for evaluating the life of cable insulation subjected to the varying temperature and time electrical service conditions of a locomotive. This type of evaluation becomes more important as the current ratings of higher fuel efficiency locomotives are increased, subjecting cable insulation materials to higher operating temperatures. Insulations evaluated by this proposed technique are first tested at several elevated constant temperatures to determine their thermal aging characteristics. Based on the material performance data, the insulation life consumed by the thermal stresses imposed by the locomotive duty cycle is calculated. This method can be readily applied to measure the effects of temperature cycles on cable life, objectively compare the performance of different insulations, and assess the design margin of locomotive cables. It may also be used to establish Association of American Railroads (AAR) specification requirements for thermal aging tests based on the conditions of actual field application. A method for evaluating cable life through testing and duty cycle analysis has been developed and verified by examination of cables in service. A new high performance insulation developed by the General Electric Wire and Cable Business Department is shown to offer reliable service life under the varied and demanding operating conditions of today's higher performance locomotives.     

The ac superposition method,a new hot‐line diagnostic method for 6‐kV XLPE power cables

Water trees are the most hazardous factor affecting the life of XLPE distribution cables and the major cause of insulation failure. It is well known that insulation failure causes stoppages in electrical service and requires extensive repair work. Up to now, deterioration of cable insulation has been diagnosed mainly by the dc leakage current method. However, application of this method for diagnostic measurements requires interruption of electrical service. Several types of hot‐line diagnostic methods (including the dc component current and dc superposition methods) were developed to detect water tree deterioration. However, these methods have some shortcomings, such as being subject to effects of stray currents and the accuracy of measurements not being sufficiently high. Therefore, we have attempted to develop a new hot‐line diagnostic method. We investigated whether the signals produced by superposition of voltages of various frequencies to the cover layer of energized cables were correlated with deterioration by the water treeing. As a result, we found that a deterioration signal of 1 Hz was observed when we superposed an ac voltage (commercial frequency × 2 +1 Hz) on the cover layer of cable where the water tree had occurred in the insulation. © 1999 Scripta Technica, Electr Eng Jpn, 130(2): 49–58, 2000     

Electrical aging of extruded dielectric cables: review of existingtheories and data

Despite the huge amount of data on so-called electrical aging of extruded HV cables, the fundamental phenomena responsible for it or evolving with aging time, are still far from well understood. It is therefore not surprising why it is so difficult to predict reliable cable lifetimes in service from accelerated aging experiments in the laboratory. The objective of this paper is to review critically the existing theories of electrical aging of solid dielectric materials. A relatively large number of models and theories exist but none of the most often used is known to yield reliable life predictions. One conclusion is that there is a need for a more comprehensive model of electrical aging of extruded dielectric cables. In order to develop this model, an extensive review of existing literature data was undertaken. This paper summarizes the data collected from more than 200 papers on aging of PE, XLPE and EPR cables. It appears that cable breakdown strength should not be plotted on log field vs. log time graphs to yield long-time (i.e. low-field) values, since results obtained over a long time period do not obey an inverse power law. In fact, high-field results are better described by an exponential relation between time and field. The models of Simoni, Montanari and Crine seem to give the best fit to experimental results obtained under a wide variety of experimental conditions. It is also shown that the lower field limit for the exponential regime with XLPE cable is in the 8 to 15 kV/mm range, which corresponds to the onset of strong charge injection. The influence of environment, insulation nature and morphology, and testing temperature are discussed     

Performance of reduced wall EPR insulated medium voltage powercables. I. Electrical characteristics

Paper-insulated lead covered power cables (PILC) have had a long and successful heritage. After almost 100 years, this design of cable is still in operation and continues to be manufactured. However, electric utilities are now looking for a reliable replacement for PILC cables. This is due to two primary reasons: (1) the difficulty in installing and maintaining this type of cable; and (2) increasing pressure to replace these cables due to environmental concerns. To date, diameter limitations of conventional extruded dielectric cables has impeded their replacement in existing PILC conduits. This paper describes a study for the evaluation for reliably reducing the insulation thickness to achieve a lower diameter cable to effectively replace PILC cable in existing conduits. Part I of the investigation reviews the theory of insulation wall determination and the test program carried out to evaluate electrical performance of reduced wall EPR cables. Additionally, cable design concepts and constructions are discussed     

高压XLPE电力电缆绝缘老化状态评价研究进展

高压交联聚乙烯（XLPE）电力电缆的绝缘老化状态关系到供电可靠性,故电缆绝缘老化状态检测及评价方法的研究意义重大。对于高压电缆的绝缘老化状态检测及评价,国内外已有相关研究成果,文中总结了目前常用的高压电缆绝缘状态离线、在线检测及评价方法。离线检测手段准确性高,但不适于对在役电缆进行大面积取样检测;在线监测的环境干扰因素太多,存在的干扰会对监测结果产生影响,有一定检测局限性,且缺乏大量的实验数据支撑;而对于电缆绝缘老化状态评价方法,尚未有广泛认可的评价标准和体系。文中在总结概述现有方法的基础上,提出了目前电缆老化绝缘状态综合评价方法存在的难点及未来电缆绝缘老化评价研究可提升的方向。     

Effects of voltage surges on extruded dielectric cable life projectupdate

Electric utility engineers have commented that extruded distribution cables frequently fail during or shortly after a thunder storm. These engineers also comment that failures often reoccur on cable circuits where previous failures were located with a thumper. Linemen at Georgia Power often make similar comments. To investigate this observation, crosslinked (XLPE) and tree retardant crosslinked (TRXLPE) power cable designs were subjected to accelerated water treeing tests. Samples were subjected to simulated lightning surges or simulated thumping surges. Crosslinked cables removed after 15 years of service operation were also subjected to these surges. The results show that, in some cases, lightning surges do reduce extruded distribution cable life. Also, high level thumping surges appear to reduce cable life once cables are well aged     

Electrical stress enhancement of contaminants in XLPE insulation used for power cables

The use of XLPE as the insulation for power cables has grown steadily since it first introduction more than 30 years ago. Today XLPE is rapidly becoming the preferred insulation system for even the highest transmission voltages. This preference is due to the high reliability, low dielectric losses, and low environmental impact that can be achieved with XLPE. The positive effects of high quality insulation materials on improved cable performance have been well known since the start of cable making. The purpose of this paper is to investigate the technical background for the cleanliness levels and to quantify the level of performance required from clean materials. The advantages of clean insulation materials are seen at all voltages. However, this work focuses on the technical basis for the benefits for HV and EHV cables, which typically are designed with a water impervious layer to ensure that the cable remains dry throughout its entire lifetime. The presence of metallic contaminants in MV cable is known to enhance the growth of trees by raising the electric stress level locally. The singular impact of cleanliness on the performance of MV cables is somewhat more complicated as it is influenced both by the cleanliness of the insulation and the ability of the insulation material to resist the growth of water trees.     

Investigation of Water Tree Degradation in Dry‐Cured and Extruded Three‐Layer (E‐E Type) 6.6‐kV Removed XLPE Cables

Dry‐cured and extruded three‐layer (E‐E type) 6.6‐kV cross‐linked polyethylene (XLPE) cables were introduced into electric power systems more than 30 years ago, but they do not experience failures because of water tree degradation. Also, the degradation index of water treeing for these cables has not been established. Therefore, investigating results of residual breakdown voltage and water tree degradation of these cables will help us plan for cable replacement and determine water tree degradation diagnosis scheduling, and will be fundamental data for cable lifetime evaluation. In this study, the authors measured the ac breakdown voltages of dry‐cured and E‐E type 6.6‐kV XLPE cables removed after 18 to 25 years of operation and observed the water trees in their XLPE insulation. As a result, it was observed that breakdown voltages were larger than the maximum operating voltage (6.9 kV) and the ac voltage for the dielectric withstanding test (10.3 kV). Water trees were mainly bow‐tie water trees and their maximum length was approximately 1 mm. Although the number of measured cables was limited, the lifetime of this type of cable was estimated to be approximately 40 years, even experiencing water immersion.     

Ageing mechanisms and diagnostics for power cables - an overview

This paper describes briefly the main ageing and failure mechanisms and will indicate the advantages and limitations of the diagnostic tests available for the different insulation systems used in distribution and transmission cable systems. SC21 of CIGRE has addressed the subject of ageing factors and diagnostics of cable systems and has published three reports covering both fluid-filled and extruded cables. The reports describe ageing factors and several diagnostic methods, their purpose, and guidelines for use     

一种新型陶瓷化高分子复合耐火硅橡胶耐火电缆的研制

概述了一种新型的陶瓷化硅橡胶耐火电缆的研制。陶瓷化硅橡胶耐火材料由硅橡胶基料中加入无机硅粉末填充物、结构控制剂和其他的助剂材料等组成,可用于不同电线电缆产品的制造。这种材料在常态下仍然具备硅橡胶的特性,经500℃高温和750℃以上的火焰烧蚀,耐火硅橡胶将形成坚硬的陶瓷化防火保护层,起着隔绝火焰的作用,在火灾情况下保证电力和通信的传输功能。