Received: 24 May 2016 Revised: 8 December 2016 Accepted: 23 January 2017 DOI 10.1002/etep.2346 RESEARCH ARTICLE Analysis of transformer oil degradation due to thermal stress using optical spectroscopic techniques Hussain Kalathripi | Subrata Karmakar Department of Electrical Engineering, National Institute of Technology, Rourkela, India Correspondence Subrata Karmakar, Department of Electrical Engineering, National Institute of Technology, Rourkela‐769008, India. Email: karmakar.subrata@gmail.com Summary The power transformers are continuously under the impact of electrical and thermal stresses. These stresses are primarily responsible for the occurring incipient faults such as partial discharge, arcing, and pyrolysis. The incipient faults, if not taken care at the earliest, cause the insulating transformer oil to degrade and transformer failure over a period of time. Therefore, monitoring and diagnosing the power transformer have become an inevitable task for its effective functioning. In this proposed work, thermal analysis on different transformer oil samples has been performed by using optical methods such as ultraviolet‐visible spectroscopy, Fourier transform infrared spectroscopy and Nuclear magnetic resonance (NMR) spectroscopy. The obtained results with UV‐visible spectroscopy method exhibit proportional degradation of the oil samples with temperature rise. The Fourier transform infrared method identifies the dissolved gases (ie, CH4, C2H6) released during the decomposition of hydro carbon present in the transformer oil. Finally, NMR spectroscopy method also confirmed that it has the potential to monitor the decomposed oil by investigating the region under an NMR signal which is proportional to the number of absorbing protons. The employed photo‐spectroscopic methods can be best alternative next to so called dissolved gas analysis method. K EY WO R D S FTIR, NMR, power transformer, thermal stress, transformer oil, UV‐visible spectroscopy 1 | INTRODUCTION In power system network, various costly equipment are used for reliable power supply to the utility. Among all, the power transformers are the key apparatus in the network of power generation, transmission, and distribution. Any unattended fault in the transformer disturbs the entire power system network causing huge revenue loss along with supply interruption to the consumers.1 Though the transformer is occasionally affected by external faults, it is always prone to incipient faults inside the tank. The major incipient faults that arise usually are sparking, partial discharge, arcing, and pyrolysis.2 In fact, transformers are always subject to electrical stress, thermal stress, and mechanical stress.3,4 These Int Trans Electr Energ Syst. 2017;e2346. https://doi.org/10.1002/etep.2346 stresses cause the transformer oil to decompose which eventually leads to the formation of hydrogen (H2), methane (CH4), ethane (C2H6), ethylene (C2H4), acetylene (C2H2) gases and carbon monoxide (CO), and carbon dioxide (CO2), if cellulose insulation is also involve.5 These gases are indicative of the presence of incipient faults. The hydrogen (H2), ethane (CH6), and methane (CH4) are indicatives of low temperature effect in the transformer, whereas, H2 and C2H4 indicate high temperature that is more dangerous to the equipment functioning.6 Therefore, transformer has to be scrutinized constantly rather than periodically.7 Generally, gas analysis in the degraded transformer oil is done with so‐called dissolved gas analysis (DGA) method. It is a proven reliable diagnostic technique for detection of wileyonlinelibrary.com/journal/etep Copyright © 2017 John Wiley & Sons, Ltd. 1 of 11 2 of 11 incipient faults in the oil‐filled high‐voltage transformers.8 The DGA investigative methods like the established IEC and IEEE standard methods,2,9 are theoretically based on Halstead simplified thermodynamic and compositional representations for the thermal decomposition of transformer oil and on experimental data.10 Though DGA has been widely accepted method for the past few decades, it has certain drawbacks like it necessities carrier gas, regular calibration, and lack of expert personnel.11 To overcome these shortcomings with DGA, in this work, optical spectroscopy methods such as ultraviolet‐visible (UV‐Visible) spectrometer and Fourier transform infrared (FTIR) spectroscopy and Nuclear magnetic resonance (NMR) techniques have been proposed and implemented.12–14 The test has been conducted on different transformer oil samples, which have undergone thermal stress, using these methods. The UV‐visible spectroscopy results indicated the expected degradation level in every sample, whereas, with FTIR spectroscopy, various functional groups existed in the degraded oil are identified. In NMR method, the picture of the hydro‐carbon structure in the degraded oil samples is identified. Along with spectroscopy techniques, the refractive index measurement (RIM) and the breakdown voltage (BDV) tests have also been carried out so as to investigate the physical and the electrical properties of the given oil samples. The obtained results supported the spectroscopic method results as anticipated. This work discovered that there are so many advantages with spectroscopic methods. Mainly, the results obtained with these techniques are so quick without disturbing the sample. Furthermore, these methods are proved to have great optical throughput and effeciency. Therefore, this work concludes that optical methods can be best alternative besides the well‐known DGA method for diagnosing the health of the transformer. The novelties of the proposed work are as follows: • Ultraviolet‐visible spectroscopy has the potential to identify the age of the thermally affected‐degraded oil samples by measuring their concentrations in terms of peaks arose in the spectra at different wavelengths. • Fourier transform infrared spectroscopy is a capable technique to identify the different functional groups present in the degraded oil samples thereby detecting the dissolved gases developed due to the applied thermal stress. • Nuclear magnetic resonance spectroscopy provides the picture of the hydro‐carbon structure in degraded oil samples thus determining the physical and chemical information, as it concentrates at the nuclei and nuclear spins in the molecules. • Along with spectroscopy methods, the physical and the electrical properties of the oil samples have been inspected, ie, refractive index and the BDV tests which further shows the significant evidence of spectroscopic results. KALATHRIPI AND KARMAKAR The organisation of this paper is as follows: Section 2 describes the details of the transformer oil sample preparation, and Section 3 describes the different spectroscopy techniques used in this work along with the experimental setups. In Section 4, the obtained results from transformer oil samples are discussed and analysed. Finally, Section 5 concludes the proposed work. 2 | P R E PA R ATI O N O F OI L SA M P L E S The laboratory‐accelerated aging has been carried out on 3 different transformer oil samples, namely, fresh transformer oil (T‐1), transformer oil mixed with copper (T‐2), and transformer oil mixed with paper (T‐3). The first sample, T‐1, has been taken from a sealed drum full of fresh transformer oil that is uncontaminated and kept from oxidizing effect. The second sample, T‐2, has been prepared by mixing 30gm of copper pieces with the 250ml of fresh transformer oil in a conical flask made of glass and heated at 120°C temperature in different time durations. The small copper pieces are taken out from the copper bar using a sharp cutting tool. The purity of the copper material present in the copper bar is 99.5 %. The third sample, T‐3, has been prepared by mixing the fresh transformer oil with 2.5gm of insulating Kraft paper. The kraft paper pieces are dried to avoid moisture content and kept into the conical flask and genteelly added the 250 ml of fresh transformer oil into it. The conical flasks are thoroughly washed with clean water and finally dried in an oven to avoid the contamination due to traces of humidity. Before putting the sample in the heating chamber, the 3 samples are kept separately in 3 different conical flasks and sealed with aluminium leafs to keep them uncontaminated from air or duct particles. The main purpose of this work is to analyse the transformer oil degraded due to accelerated thermal stress effect. All the samples are aged at 3 different time durations like 24 hrs, 48 hrs, and 96 hrs at 120°C in a heat chamber as shown in Figure 1. The reason for choosing 120°C is, at this stage effect of oil physicochemical property change is clearly evident as a transformer winding normal temperature is at 65°C. Table 1 shows the details about the transformer oil samples prepared for optical spectro photometric test. The photograph of the prepared transformer oil samples is shown in Figure 2 for further test. 3 | SPECTROMETRIC TECHNIQUES AND EXPERIMENTAL SETUP Nowadays, the spectro‐photometric techniques have become popular for diagnosis of transformer health condition monitoring. In the practice, the oil samples are collected from the service transformer and tested in the spectro‐photometric KALATHRIPI AND KARMAKAR FIGURE 1 3 of 11 Heat chamber used for the preparation of transformer oil samples TABLE 1 Details of the samples and their corresponding codes S. No. Sample name Details of sample Heating duration (h) Temperature ( °C) 1 T‐1 FTO 24, 48, 96 120 2 T‐2 FTO with Cu 24, 48, 96 120 3 T‐3 FTO with paper 24, 48, 96 120 Abbreviation: FTO, Fresh transformer oil. laboratory. To carry out the experiments, the transformer oil samples have been prepared with accelerated aging process in the laboratory to avoid the actual aging time and have been tested using UV‐visible, FTIR, and NMR spectrometers. The concept of each spectroscopic measurement technique and their individual experimental setup is explained as below. 3.1 | UV‐visible spectroscopy The UV‐visible spectrometer of Agilent Technologies (Model: CARY 100) has been used to carry out the experiment on the oil samples as shown in Figure 3A and in the inset in the same figure the photo of the UV‐visible spectrometer is given. The spectrometer has broad wavelength spectrum range of 190 to 900 nm consisting of a UV range 190 to 380 nm and a visible spectrum range of 280 to 900 nm. During the experiment, 2 quartz cuvette of 10 mm path length is used. The first one is used for filling up with sample oil and the second one is used for reference. All the 3 samples have been tested one after the other by filling 3 ml quantity of oil in the sample cuvette. The schematic diagram shown in Figure 3A clearly depicts the concept of UV‐spectrometer. The meter first measures the intensity of the light propagated through the sample cell (I) which is coming from UV source and then compares the same to the light before propagated through the sample cell (Io). The ratio, I/Io, is generally defined as transmittance. As per Beer‐Lambert law, the absorbance of light by the sample is deduced from the transmittance, as given in Equation 1, which is also proportional to the path length, concentration, and absorptivity of the given sample as follows:15,16 A ¼ ϵ×c×l ¼ − logðT Þ (1) where A refers to absorbance, T refers to transmittance, ϵ refers to molar absorptivity, c refers to the concentration of the sample, and l refers to the length of the light path, which is equal to the width of the cuvette. The same absorbance, A, is recorded on the detector after the transmitted light passed through the mirror and rotating disc comparing with the reference. 3.2 | FTIR spectroscopy Subsequently, same samples have been tested by using Fourier transform infrared (FTIR) spectrometer (Model: ALPHA, Germany, Bruker GmbH make) as shown in Figure 3B and in the inset in the same figure the photo of the FTIR spectrometer is given. It has wavenumber range of 4000 to 400 cm‐1, signal to noise ratio of the instrument is 50 000:1, and resolution of 4 cm‐1.17 An amount of 0.2 ml of oil sample has been used to obtain the FTIR spectrum which appears on the computer connected to the spectrometer. FIGURE 2 Different oil samples used for spectroscopy experimentation (A) Heated for 24 hrs. at 120 °C (B) Heated for 48 hrs. at 120 °C (C) Heated for 96 hrs at 120 °C KALATHRIPI AND KARMAKAR 4 of 11 FIGURE 3 (A) Ultraviolet‐visible spectrometer used for experimenting T‐1, T‐2, and T‐3 oil samples and its schematic diagram. (B) Fourier transform infrared spectrometer used for experimenting T‐1, T‐2, and T‐3 oil samples and its schematic diagram The FTIR spectroscopy converts raw data into the actual spectrum. It is a nondestructive, simple, and fast‐analyzing method18 used to acquire an infrared spectrum of absorption of a liquid, solid, and gas by collecting spectral data in a widespread spectral range. When IR radiation is disseminated through a collected sample, some of it is absorbed by the sample which means the energy of the light imposing on a molecule is equal to vibrational energy level difference within a molecule and the rest is transmitted, creating a molecular fingerprint of the sample.19 The vibrational energy difference in the molecule is defined as follows: one as shown in Figure 3B. As the mirror moves at a fixed rate, its position is determined by counting the interference fringes of a collocated He‐Ne gas laser. The interferometer actually divides a beam of IR radiation coming from IR source into 2 paths of different wavelengths using a beam splitter and afterwards recombines them. Finally, a detector detects the intensity of alterations of the exit beam as a function of the path difference. Δ Evib ¼ hcw Further, all the samples have been tested using NMR spectrometer shown in Figure 4 to know the quality of the oil that underwent thermal stress. In Figure 4 the schematic diagram and inset photograph of NMR (Model No: AV 400 Avance‐ III, 400 MHz, FT‐NMR Spectrometer Bruker biospin International, Switzerland) experimental setup is shown. The major key features used for diagnosis of transformer oil (2) where, Evib refers to vibrational energy, h is the plank's constant (Joule‐sec), c is the speed of light (cm/sec), and w is wavenumber in cm‐1. The heart of FTIR spectroscopy is an interferometer. It has 2 mirrors: one is a fixed one and the other is a movable FIGURE 4 3.3 | NMR spectroscopy Nuclear magnetic resonance spectrometer used for experimenting T‐1, T‐2, and T‐3 oil samples and its schematic diagram KALATHRIPI AND KARMAKAR associated with NMR are (1) 5 mm BBO and BBFO probe for multinuclear NMR (11B, 15 N, 19F, 29Si, 31P, 35Cl, 51 V etc.), (2) 5 mm multinuclear probe for solution studies, and (3) variable temperature facility from −80°C to 70°C with suitable solvent. The NMR test primarily concerns on the nuclear spin states within the molecule. The NMR experiments are performed to explore and analyse the chemical composition of the sample that helps to create relationship or correlation with sample aging for its characterization and quantification.20 The schematic diagram of NMR spectrometer as shown in Figure 4 has 2 major components, ie, a magnet and a radio frequency transmitter. This spectrometer is of classical continuous wave type because it uses technique similar to that of optical spectrometer. The instrument is described by the approximate resonance frequency of the nucleus to be analyzed, eg, 1H NMR. The functioning could be a slow scan of radio frequency at a constant magnetic field strength or magnetic field strength at fixed radio frequency over a purview corresponding to the resonance of the nuclei under study. In the process, absorption of energy by the sample generates as a signal which is detected, amplified, and recorded as an NMR spectrum. 4 | RESULTS A ND DISCUSSION All the aforesaid oil samples have been tested with a UV‐ Visible spectrometer, FTIR spectrometer, and NMR technique, and their results are presented. The transformer oil test sample (T‐1) has been aged with 24 hrs, 48 hrs, and 96 hrs at a constant temperature of 120°C and compared with new fresh transformer oil kept at normal temperature and pressure (NTP). The obtained results using UV‐visible spectroscopy of T‐1sample are plotted and discussed here which is shown in Figure 5. In Figure 5, the absorption peaks that have been correlated with the bonds present in the molecules are found in the UV‐visible range of 350 to 450 nm. It is observed that with the applied thermal stress, the nature of the oil sample and its PH values are affected leading to the formation of interfering substances. The peaks of the different aged transformer oil samples are observed with the aging time at elevated temperature as compared to fresh transformer oil, which does not have any absorption peaks. This clear change in absorbance level obeyed the Beer‐Lambert law. The absorbance of the light by the sample increases as the concentration of the oil increases with the applied temperature proportionally. To observe the thermal effects of transformer oil with copper winding placed inside the transformer tank, the 150ml of fresh transformer oil is mixed with 30gm of copper pieces and heated with different time durations. The second transformer oil samples (T‐2) are aged with different time durations of 24 hrs, 48 hrs, and 96 hrs along with the mixture 5 of 11 FIGURE 5 Ultraviolet‐visible spectroscopy results obtained for fresh transformer oil (T‐1) for 24, 48, and 96 hours at 120°C with copper pieces at 120°C constant temperature. The accelerated thermal aging process significantly changes the physical properties as the transformer oil is more sensitive to the temperature, which is shown in Figure 6. The colour of the transformer oil is much dark brown at the higher duration of temperature as compared to the other samples. The obtained results of T‐2 samples and the fresh transformer oil is compared, which is shown in Figure 6. The absorption peaks found because of thermally‐aged transformer oil with the comparison of fresh transformer oil kept at NTP is proportional to the increment in duration of temperature. The third transformer oil sample (T‐3) sample also has been examined with the UV‐visible spectrophotometer, and the obtained results are as shown in Figure 7. It is observed that absorbance has increased with increase of heating period FIGURE 6 Ultraviolet‐visible spectroscopy results obtained for transformer oil with Cu (T‐2) for 24, 48, and 96 hrs at 120°C KALATHRIPI AND KARMAKAR 6 of 11 FIGURE 7 Ultraviolet‐visible spectroscopy results obtained for transformer oil with paper (T‐3) for 24, 48, and 96 hours at 120°C which indicates that the degree of deterioration is raised up and curves obviously shifted upward with the aging time increased as compared to fresh transformer oil. The absorption spectra of transformer oil mixed with insulating paper used in transformer winding expose formation of impurities presence in the transformer oil at different time durations of heating. Finally, the T‐1, T‐2, and T‐3 oil samples have been compared on the basis of absorption peaks. The Table 2 shows the maximum absorption values of all the transformer oil samples T‐1, T‐2, and T‐3 with UV‐visible spectroscopy. It is found that in all the samples, there is clear peak difference from sample to sample. The transformer oil samples heated for 96 hours have higher absorbance peaks compared to 48 hours and 24 hours heated oil samples, respectively. The absorption peaks of 48 hours transformer oil samples lie in between 24 and 96 hours of aged oil samples. This way these results give the qualitative analysis of the oil samples. The colour of the transformer oil is changed from pale yellow to brownish in 3 different samples because of different temperature durations at 120°C as shown in Figure 2. The deformation of colour with respect to fresh transformer oil is basically due to the oxidization of the sample oils, which subsequently results in the formation of the acidic products, TABLE 2 The comparative results of T‐1, T‐2, and T‐3 oil samples with ultraviolet‐visible spectroscopy Absorption peak (max) Sample 24h 48h 96h T‐1 361 388 400 T‐2 365 383 391 T‐3 357 365 394 but the difference lies in the type of the sample and number of hours of heating. Though all the samples seem to be brownish, fresh transformer oil with Cu looks dark brown compared to fresh oil sample light brown. This is due to the increase in the decay products as a result of the thermal aging of the material inside the sample. The UV‐visible spectro‐ photometry characterizes the relative level of dissolved decay products such as aldehydes, peroxides, esters, ketones, and acids in transformer insulating oils.21 Overall, the clear absorbance difference is observed in all the samples and proved that UV‐visible spectrometry technique is an excellent tool to diagnose the health of the transformers such that the fault preventive measures can be taken thereafter. Moreover, the 3 samples (T‐1, T‐2 and T‐3) have been tested with FTIR spectroscopy techniques, and the obtained results are shown in Figure 8, Figure 9 and Figure 10. Figure 8A shows the FTIR results for fresh transformer oil heated for 24 hrs at a constant temperature of 120°C. The absorption peaks are found at 728, 1374, 1456, 2363, 2854, 2918, and 3742 wavenumbers. The characteristic absorptivity between the wavenumbers1470 cm‐1and 1350 cm‐1, 2 peaks are observed ie, 1456 and 1374, which indicate the functional group of alkane C─H bond stretch of CH3 bond. The peaks found between 860 and 680 are aromatic C─H bending functional groups. It is also observed that between 1500 and 400 cm‐1 wavenumbers, elucidation of peaks in the finger print region is little intricate as number of different vibrations befall here including a wide variety of bending vibrations. To show the clear variation of absorption peaks in the sample after heating, a portion of the plot having wavenumbers from 2200 to 2500 cm‐1 is shown in Figure 8B. Figure 9A shows the results obtained for T‐1, T‐2, and T‐ 3 samples, which are heated at a constant temperature of 120°C for 48 hours. In this case, the peaks are also observed at 728, 1374, 1456, 2363, 2854, 2918, and 3742 wavenumbers. There is a clear peak popping up at 3740 wavenumber where water molecules are observed which is the result of applied thermal stress. The same functional groups like CH, CH2, and CH3 that are found at different wavenumbers led to the formation of gases ie, CH4, C2H6, and C2H2 which are indicative of low temperature effect in the transformer oil. Figure 9Bclearly shows the more significant degradation of the transformer oil samples as the more temperature is applied in this case. Figure 10A shows the results for T‐3 oil sample with FTIR spectroscopy, which has the major peaks at 728, 1374, 1456, 2363, 2854, 2918, and 3742 wavenumbers. It is observed that though characteristic peaks for T‐1, T‐2, and T‐3 seem to be same, there is transmittance difference among them and T‐3 highlights with some intense peaks which are the result of high thermal stress due to increased duration of heating. In fact, all the FTIR plots are exhibiting same functional groups because peaks observed in this case KALATHRIPI AND KARMAKAR 7 of 11 FIGURE 8 Fourier transform infrared (FTIR) spectra for 24 hours. (A) FTIR comparative results obtained for transformer oil samples T‐1, T‐2, and T‐3 at 120°C, 24 hrs. (B) part of FTIR spectrum showing clear indication of sample disruption with temperature FIGURE 9 Fourier transform infrared (FTIR) spectra for 48 hrs. (A) FTIR comparative results obtained for transformer oil samples T‐1, T‐2 and T‐3 at 120°C, 48 hrs. (B) Part of FTIR spectrum showing clear indication of sample disruption with temperature FIGURE 10 Fourier transform infrared (FTIR) spectra for 96 hrs. (A) FTIR comparative obtained for transformer oil samples T‐1, T‐2, and T‐3 at 120°C, 96 hrs. (B) Part of FTIR spectrum showing clear indication of sample disruption with temperature are almost at the same wavenumbers. With the data acknowledged from Figure 10A, it is known that various gases and moisture particles are dissolved and identified such as CH4, C2H6, C2H4, and H2O, which are the result of thermal stress in the transformer.22 Figure 10B shows the clear variation in the property change of the sample oil with the increment of temperature which informs more degradation has taken place. Therefore, FTIR spectroscopy is a good analyzer of the transformer oils samples to know the health of the transformer from time to time. This diagnosis technique is more useful especially for the high voltage transformers which are continuously under the thermal stress from the time of their installation. Table 3 depicts all the transmittance peaks observed in the FTIR spectra of all the oil samples (T‐1, T‐2, and T‐3) KALATHRIPI AND KARMAKAR 8 of 11 TABLE 3 Transmittance peaks of Fourier transform infrared spectra of the different oil samples Transmittance peaks of oil samples Wavenumber (cm ) Heating period (h) at 120°C T‐1 T‐2 T‐3 728 24 48 96 0.95452 0.95313 0.95662 0.95409 0.95425 0.95611 0.95504 0.95436 0.95492 1374 24 48 96 0.91388 0.91312 0.91188 0.91542 0.91447 0.91257 0.91621 0.91323 0.91106 1456 24 48 96 0.80521 0.80322 0.80178 0.80644 0.80415 0.80239 0.80794 0.80395 0.80173 2363 24 48 96 0.99284 0.99042 0.97708 0.99344 0.98937 0.97844 0.99546 0.98625 0.98069 2854 24 48 96 0.674 0.67393 0.67735 0.674 0.6739 0.67608 0.67424 0.67368 0.67689 2918 24 48 96 0.53882 0.539 0.54288 0.53888 0.53895 0.54119 0.5392 0.53851 0.54248 3742 24 48 96 0.99185 0.98728 0.98025 0.99387 0.98882 0.98165 0.9972 0.99012 0.9827 ‐1 at different wavenumbers. The careful investigation into all the peak values of spectrum reveals that there is a transmittance difference between the samples. This is because all the samples T‐1, T‐2, and T‐3 are different in nature by the way they are prepared. Because of the addition of copper and paper in T‐2 and T‐3, they tend to release the more decay products and make the sample highly concentrated. Because all the samples have undergone temperature effect, the properties of the transformer oil samples change in terms of generating the free radicals of the chemical bonds and their recombination to form gases. For this reason, in Table 3, the variation in transmittance levels is observed at different wavenumbers. The change in the transmittance peak means the change of the by‐products (gas, moisture etc.) in the sample oils as indicated in Figures 8A, 9A, and 10A. The glimpse of transmittance difference is shown in figures 8B, 9B, and 10B at 2363 wavenumber. Nuclear magnetic resonance spectroscopy also has been carried out on all the oil samples (T‐1, T‐2, and T‐3). The CDCl3 has been used as the solvent in the sample transformer oils. For every 20 to 22 gm of oil sample, 0.4 ml of CDCl3 is used. The prepared oil samples have been processed through NMR spectrometer for 1H spectra which gave the replica of what exactly the samples have gone through after applied thermal stress. The spectra clearly exhibit variation in the property change in the oil samples as shown in the Figure 11. The figure consists T‐1, T‐2, and T‐3 sample oils heated for 48 hours at constant temperature of 120°C. The NMR for the 48 hrs heating period at 120°C is chosen to show how NMR can be a useful technique to investigate the deteriorated oil samples. Indeed, the results show that the vitality of this method for degraded oil analysis.23 The graph of all the samples T‐1, T‐2, and T‐3 for 48 hours heating period which is put on 0.5 ppm to 2.0 ppm as shown in Figure 11, represent free radicals CH2 and CH3 molecular groups which eventually recombine and lead to the formation of gases like C2H4 and C2H6, which are basically results of overheating of oil. These are found on the up field side. Between 0.5 to 1.9 ppm, more strong lines are acknowledged and between 1.9 and 3 ppm, signals which authorize the formation of alkoxyl groups are identified owing to transformer oil aging due to heat treatment given to the samples. Finally, between 6.5 and 7.5 ppm, the lines confirm the aromatic groups, which are generally indicative of the result of the process of the degradation of the oil.23 Though all the graphs seem to be same, there is significant variation based on the type of the sample oil. The careful investigation reveals that there is more degradation in the oil sample mixed with copper, ie, T‐3 followed by T‐2 and T‐1. The reason is there are more decay products in T‐3, which is degraded because of the applied thermal stress. KALATHRIPI AND KARMAKAR FIGURE 11 9 of 11 Nuclear magnetic resonance spectra of different oil samples for 48 hrs at 120°C (A) T‐1 sample, (B) T‐2 sample, and (C) T‐3 sample Further, all the transformer oil samples underwent RIM techniques for verifying its physical properties due to the effect of the different thermal aging process. The refractive index (RI) is generally determined as follows: η ¼ C=V; (3) where c refers to the speed of light through vacuum and V refers to phase velocity through the medium considered. The dielectric value of the transformer oil sample is also defined by its relative permittivity. Square of RI actually denotes relative permittivity of a medium. This information gives the knowledge about the turbidity of the liquid KALATHRIPI AND KARMAKAR 10 of 11 medium.24,25 Table 4 shows the RI of the samples considered in this work. It is observed that all the RI value is increased with the increased duration of the thermal aging process. For example, when T‐1 is heated for 24 hours at 120°C, its RI is 1.7885 and when it is heated for 96 hours at 120°C its RI is 1.8149 and same is the case with T‐2 and T‐3. This shows that there is difference in the physical property change in the oil from 24 hrs to 96 hrs heat treatment. Close observation of the results also indicates that RI of the T‐3 is higher for all the heating periods indicating less propagation of light through it which implies that it is more degraded because of thermal stress and moisture as they directly affect the dielectric property of the transformer oil. In addition to spectroscopy techniques and RIM, BDV test has also been performed to know the electrical properties of the prepared oil samples. The BDV test is the one of the most important transformer oil diagnostic tests performed to know how much electrical stress it can withstand.26,27 All the samples used in this work have been passed through BDV test. The BDV test kit has a gap of 2.5 mm between its sphere‐ shaped electrodes of 25 mm diameter as per IEC standard 60156. During the test, the voltage has been increased gradually at the rate of 2 kV/s. The Table 5 depicts the BDV results of T‐1, T‐2, and T‐3 oil samples. For each measurement of BDV, averages of 3 sample BDV results are recorded. The T‐1 oil sample has recorded higher BDV of 36 kV because it is fresh transformer oil without any added material to it. As the period of temperature is increased to 48 and 96 hours at a constant temperature of 120°C, the BDV decreased to 32 and 30, respectively, which again assures the effect of constant thermal stress on transformer oil sample. The results of T‐2 and T‐3 also reveal that as the oil temperature is increased their BDV is reduced which is according to the previous results. Overall, the RI and BDV test results of the all TABLE 4 Refractive index of different oil samples at different heating periods Sample name RI‐24h at 120°C RI‐48h at 120°C RI‐96h at 120°C 1 T‐1 1.7885 1.8018 1.8149 2 T‐2 1.7851 1.7867 1.8067 3 T‐3 1.7930 1.8063 1.8248 Sl. No TABLE 5 Breakdown voltage of different oil samples at different heating periods Sl. No Sample Avg. BDV‐24h Avg. BDV‐48h Avg. BDV‐96h name at 120°C at 120°C at 120°C 1 T‐1 36.00 32.00 30.00 2 T‐2 33.16 30.12 27.62 3 T‐3 42.50 36.16 35.75 the samples considered in this work to support the spectroscopic results obtained by using UV, FTIR, and NMR techniques. 5 | C O NCLUS IO N S Though DGA technique has been most used method to diagnose the health of the transformer for decades, it has certain drawbacks such as the need of carrier gas and regular calibration of the instrument. To overcome these drawbacks, the work has been focused on the alternate techniques like UV‐visible, FTIR and NMR spectroscopy. All the aforementioned 3 samples, namely, fresh transformer oil, transformer oil with Cu, and transformer oil with insulating paper measured with these methods gave vital results to identify the presence of the thermal fault. The obtained results clearly established that as the heating period is increased, the degradation of the oil is also increased. The UV‐visible spectroscopy provided the qualitative information about the degraded oil samples. The FTIR technique has given the information of different functional groups exists in the sample molecules and also the gases released during the process of thermal aging. Further, NMR spectroscopic technique results also helped to know the quality of the sample oils considered in this work. In addition to spectroscopy techniques, RIM and BDV test results also provided the condition of the sample transformer oils which supported all the spectroscopic results in this study. Therefore, as these proposed spectroscopy techniques have great optical throughput and do not cause any harm to the measuring samples, they can be best alternative next to well‐ known DGA method. Further, in future, the on‐line condition monitoring with these proposed techniques of different oil filled high voltage power equipment is planned to improve the faster testing process and with better test results. 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