Fault ride through compliance as imposed by grid codes prevents undesirable disconnection of renewable plants from the network even during fault. Diversified control schemes adopted in the converters associated with such plants modulate the voltage and current output significantly during a fault. This varies the fault characteristics of the renewable plant at times and thereby affects the performance of the distance relay protecting lines connected to such plants. In this paper, a distance protection method using local data is proposed for transmission lines connecting renewable plants. The proposed method calculates the phase angle of faulted loop current by determining the pure-fault impedance of the renewable plant at every instant following fault detection, irrespective of the control scheme associated with the plant. Utilizing the information, it calculates the line impedance up to fault point accurately. Performance of the proposed adaptive protection method is tested on renewable integrated modified 39-bus New England system using PSCAD/EMTDC simulated data and found to be accurate. Comparative assessment with the conventional distance relaying technique reveals its superiority.

/pdf/adaptive-distance-protection-for-lines-connecting-converter-112ftxj6ah.pdf

Adaptive Distance Protection for Lines Connecting Converter-Interfaced Renewable Plants

Voltage stability indices-A comparison and a review

Change in the network structure or operating condition in a power system affects the impedance as calculated by the distance relay during fault. Such changes may lead to malfunction of the distance relay at times. In this paper, an adaptive distance relay setting method using local data is proposed to prevent zone-1 malfunction following structural and operational changes. The performance of the proposed adaptive setting method is tested on a 39-bus New England system and a generic 12-bus power system using PSCAD/EMTDC simulation data, and a comparative assessment is also provided.

/pdf/adaptive-zone-1-setting-following-structural-and-operational-3eisntrak8.pdf

Adaptive Zone-1 Setting Following Structural and Operational Changes in Power System

Setting transmission line relays is fairly easy to learn—but takes years to master. With the proper education, tools, and references such as company standards available, a relatively inexperienced engineer can do good work with proper supervision and review. There are many references and training programs that provide the high-level basis for protective element setting criteria. But, the concepts have to be applied with care in context of the particular transmission line and system in question. The transmission network is complex, with many variations that must be identified to determine when deviations from cookbook guidelines are required. This paper looks at various commonly used transmission line protective elements and points out characteristics of the line and system to look for when standard reaches and margins cannot be used. While the subject is vast, the authors draw on their experience to point out some of the more common issues.

/pdf/transmission-line-setting-calculations-beyond-the-cookbook-1mx0bd0nns.pdf

Transmission line setting calculations - beyond the cookbook

New ground fault location method for three-terminal transmission line using unsynchronized current measurements

Classifying the length of a line is an important step in determining the transmission line protection philosophy and relay settings. The length of a line can be defined by physical distance, impedance, or its source impedance ratio (SIR). The SIR is the ratio of the source impedance, Z S , to the line impedance, Z L . The SIR is well established in the industry as the preferred method for classifying the electrical length of a line for the purpose of setting protective relays. Many references discuss setting criteria and performance specifications relative to the SIR. However, very few references define the proper method for calculating the source impedance to use in the ratio. The transmission system is a complex network with many sources and branches, and the topology of the network can have a major effect on the results, depending on the method used. This paper analyzes several methods in common usage and presents a simple method that provides a better result. The effect of the SIR on line relay settings and examples of various transmission network topologies are discussed.

/pdf/a-tutorial-on-calculating-source-impedance-ratios-for-48rismipnq.pdf

A tutorial on calculating source impedance ratios for determining line length

While series compensation of transmission lines is not new technology, it is becoming more prevalent due to significant changes in the way grids are being operated. Compensating lines makes better use of transmission line investments and available right of way. However, series capacitors create many challenges for protection engineers. These challenges are mitigated using modern protective relays, robust telecommunications channels, and advanced transient simulation tools to validate protection systems. The Lower Colorado River Authority (LCRA) in the United States is protecting a series-compensated line on their transmission grid for the first time as part of the Competitive Renewable Energy Zone (CREZ). This paper discusses experiences in designing, setting, and validating the new protection system.

/pdf/series-compensated-line-protection-challenges-in-the-crez-4bby5zpeq2.pdf

Series-compensated line protection challenges in the CREZ region

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A tutorial on calculating source impedance ratios for determining line length

Series-compensated line protection challenges in the CREZ region