volume: 1 issue: 4 june - july 2015 10/- magazine wrapper - june issue - … · power...

Volume: 1 Issue: 4 June - July 2015 ` 10/-Bimonthly, Chennai

A Bi-monthly Magazine of Indian Wind Turbine Manufacturers Association

Volume: 1 Issue: 4 June - July 2015

ContentsPage No.

Offshore Pre-feasibility Assessment 3

FOWIND consortium led by GWEC with partners CSTEP, DNV GL, GPCL and WISE

Grid Management in Indian Power System 5

V.K. Agrawal, Executive Director, N. Nallarasan, Deputy General Manager,

M. Pradeep Reddy, Senior Engineer, Power System Operation

Corporation Limited, New Delhi

New Challenges for Large Integration of Renewable in the Grid 9

Adrian Timbus, Segment Manager - Wind & Solar Automation, ABB Switzerland,

Inés Romero Navarro, Ph.D. Head of ABB Power Systems Consulting, Spain

Assigning Capacity Value for Large Scale Wind Farming - 22 A Case Study

M.P. Ramesh, Wind World (India) Limited, Bangalore

Green Energy Corridor - The Need of the Nation 32

O.P. Taneja, Associate Director, IWTMA, New Delhi

Know Your Wind Energy State - Rajasthan - A Snapshot 35

Compiled by Mr. Nitin Raikar, Suzlon Energy Limited, Mumbai

Photo Feature - Media Trip to Wind Farm Sites 38 Green Power Conference, Members Meeting and Knowledge Forum

Know Your Member - LM Wind Power 40

Indian Wind Turbine Manufacturers Association4th Floor, Samson Tower, 403 L, Pantheon Road, Egmore

Chennai - 600 008. Tel : 044 43015773 Fax : 044 4301 6132 Email : [email protected]

[email protected] Website : www.indianwindpower.com

(For Internal Circulation only)

Views expressed in the magazine are those of the authors and do not necessarily reflect those of the Association, Editor, Publisher or Author's Organization.

Chairman

Mr. Madhusudan Khemka Managing Director Regen Powertech Pvt. Ltd., Chennai

Vice Chairman

Mr. Chintan Shah President & Head, (SBD) Suzlon Energy Limited, Pune

Honorary Secretary

Mr. Devansh Jain Director, Inox Wind Limited, Noida

Executive Members

Mr. Ramesh Kymal Chairman & Managing Director Gamesa Wind Turbines Pvt. Ltd., Chennai

Mr. Sarvesh Kumar Deputy Managing Director RRB Energy Ltd., New Delhi

Mr. V.K. Krishnan Executive Director Leitner Shriram Mfg. Ltd., Chennai

Mr. Ajay Mehra Director, Wind World India Limited, Mumbai

Secretary General

Mr. D.V. Giri, IWTMA, Chennai

Associate Director and Editor

Dr. Rishi Muni Dwivedi, IWTMA, Chennai

2 Indian Wind Power June - July 2015

Dear Readers,

Warm Greetings from IWTMA!

Of all the forces of nature, I should think the WIND contains

the greatest amount of power-- said Abraham Lincoln. To

show this power of wind, IWTMA had arranged a wind

power familiarization trip by media persons to wind farm

sites near Coimbatore on 17th and 18th July 2015. The

media persons were taken to the wind farms, substations and wind-solar hybrid sites to give them a feel of the clean and

green wind energy generation and to understand as to how the wind mills are generating the power from the thin air.

India is slowly moving towards an energy system with higher penetrations of wind energy. Hence it is increasingly

important for grid operators to realize how they can reliably integrate large quantities of wind energy into system

operations. Grid is one of the major barrier in the wind power development programme. Hence this issue is devoted to

“Grid Management”, which is necessary keeping in view the increased penetration of wind in the grid. The wind season

is here and wind energy has substantial contribution to the grid.

IWTMA has taken an initiative and acting as a coordinating agency for compiling forecast data as received from various

developers and forwarding daily to SLDC, for about 1100 MW on day ahead basis in the state of Rajasthan. The forecasting

on a trial basis has also been initiated in Tamilnadu by IWPA and NIWE to help the State Load Dispatch Center to accept

higher penetration of wind.

During the first 3 months of the year, the wind power installations are 319.20 MW and we have to reach 4000 MW

during the year. This requires to work with fast pace in the next 8 months.

IWTMA has started Facebook page to spread awareness about the clean and non-polluting green wind power. This

message is to be spread further by all.

Please enjoy reading and send us your valuable feedback.

With regards,

Madhusudan Khemka

Chairman

From the Desk of the Chairman - IWTMA

3Indian Wind PowerJune - July 2015

Offshore Pre-feasibility AssessmentFOWIND consortium led by GWEC with partners CSTEP, DNV GL, GPCL and WISE

In the earlier month of this year we wrote about the FOWIND (Facilitating Offshore Wind In India) project activities and highlighted the launch of the Offshore Wind Policy and Market Assessment Report at the RE-INVEST 2015 Conference in New Delhi. The report was an important outcome towards realising an offshore wind policy framework in India.

As a next crucial step on 16 June, FOWIND published pre-feasibility reports for offshore wind power development focused on the states of Gujarat and Tamil Nadu under the FOWIND project. This is a first step in identifying sites for offshore wind development. DNV GL took the technical lead on these reports. After months of hard work identified key constraint data and meso-scale models were used to identify eight zones for each state where further detailed wind resource assessment should take place.

Globally, the offshore wind power industry is maturing and increasingly coastal countries are utilising this new, indigenous and carbon neutral source of energy. For a relatively young industry relying on considerable investment, R&D activity is spurring progress in leaps and bounds, leading to ever better economic prospects and improving the energy security of coastal states. India, with a vast coastline of over 7,600 km is beginning to explore offshore wind energy as a ‘strategic energy source’ to enable long term energy security.

Summary: Pre-feasibility Assessment for Offshore Wind Farm Development in Gujarat

This desktop study offers a preliminary overview of the potential for offshore wind development in the Indian state of Gujarat. Completed under Work Package one of the FOWIND (Facilitating Offshore Wind in India) project; technical, financial, social and environmental parameters were considered to identify eight potential zones for further study. Further high level technical, financial and social-environmental studies were conducted focusing on key offshore wind project components.

This pre-feasibility study relies on existing public domain data, documented international experience and proven characteristics of offshore wind energy technology to suggest plausible options for the Indian market. Key findings formulated during the course of this pre-feasibility study are summarised as follows:

² Wind Resource: To date no publically available on-site wind measurements have been recorded for the offshore sites in Gujarat

² Zone Selection: Eight zones have been identified with mean wind speeds in the range of 6.8m/s to 7.0m/s (at 120 m AGL) and water depths in the range of 15 to 43 m below LAT

² Turbine Selection: Predicted extreme typhoon wind conditions meant Class I or S wind turbines were taken forward for further investigation

² Energy Yield: For the eight zones and calculated wind speeds, Project Net Capacity Factors were estimated in the range of 18.5% and 29.7% (depending on the particular zone, MW capacity of the farm and the turbine MW capacity)

² Foundations: Mono pile, jacket and tripod foundations would be likely choices to take forward for the next stage of investigation

² Electrical: There is a healthy grid infrastructure present in the state of Gujarat with at least two high voltage substations


Snip

pet

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ind

Pow

er ² Installation: The preliminary screening study has

identified seven ports with some potential vessel availability in the region is high but presently not optimised for offshore wind. The consortium recommended that site-specific transportation and installation planning is conducted during the early project development stages

² Operations Maintenance: It is assumed that all the first offshore wind projects in India will use an O&M strategy based on work boat access

² Cost of Energy: Wind resource is the most significant factor affecting offshore wind’s Cost of Energy (COE)

² Environmental issues: Gujarat is home to sensitive marine eco systems, including; coral reefs, mangroves, various marine mammals/organisms and areas of archaeological significance

² Risks: The greatest risks highlighted are associated with the limited data available for the assessment. Where data were available, it is subject to high uncertainty. Specifically data relating to the following key areas : offshore wind resource, met ocean climate, geo technical conditions and grid connection

It is very important that the current high uncertainty with regards to zone level wind resource estimates, energy predictions, ground conditions, met ocean data and COE are reduced and mitigated before the true level of offshore wind feasibility can be identified for Gujarat.

Next Phase:

FOWIND has had a tremendous learning journey with this project so far. In the next phase, the FOWIND will deploy a LIDAR at a preferred site off the coast of Gujarat to kick-start an actual resource validation process.

To ensure effective collaboration, Global Wind Energy Council (GWEC) on behalf of the FOWIND consortium signed an MoU with the National Institute for Wind Energy (NIWE) on Global Wind Day (15 June) in Chennai, India. NIWE joined the FOWIND consortium as a knowledge partner.

A parallel study has been completed for the state of Tamil Nadu.

Courtesy: FOWIND www.fowind.in

We need your Feedback

www.indianwindpower.com

Renewable Energy seen Generating One Million JobsAs per the report released by IRENA, the renewable energy sector has generated 400,000 jobs till 2014. The sector could generate 10 lakhs jobs by 2022, if the government reaches its goal of 100 giga watts (GW) of solar photovoltaic (PV) energy and 60 GW of wind energy.

Source: Business Standard

APERC Dismissed DISCOMs Petition about RPO

APERC has issued order on OP No. 19 of 2014 dismissing the petition which was the filed by AP DISCOMs to sought waiver of shortfall in RPO for FY 2012-13 and to reduce the present RPO target. IWTMA had made written submission and oral presentation before APERC in this matter and the Hon’ble Commission has given due consideration to our submissions in its order (attached).

Central Package for DISCOMs Ruled OutThe government has ruled out the possibility of a central package for debt-ridden state run power distribution companies, and has insisted that it’s time they get their act together. The combined debt of all distribution companies was around Rs 2 lakh crore as on March last year, and despite most DISCOMs raising tariff, they haven’t really managed to cut losses significantly. They are, in fact, depending on loans for even taking care of operational expenses.

In the past, the central government had introduced ‘restructuring packages’ for DISCOMs — the most recent being 2013 — but it hadn’t been able to eliminate the problem. “There will be no package for DISCOMs. What they need to do is set efficiency right, eliminate corruption in the system, reduce losses, cut transmission and distribution losses. I need to handhold them and put on my investment banking to help them sort things out.” Minister of Power, Coal and Renewable Energy Piyush Goyal told ET.

Dear Reader,

It is our endeavour to make IWTMA magazine Indian Wind Power, “THE MAGAZINE” for the Indian wind Industry. Your feedback on the general impression of the magazine, quality of articles, topics to be covered in future, etc. will be of immense value to us. We are thankful to your response. Kindly address your mail to "[email protected]".

Thank You,

The Editor - “Indian Wind Power”

Indian Wind Turbine Manufacturers Association 4th Floor, Samson Tower, 403 L, Pantheon Road, Egmore, Chennai - 600 008. Tel : 044 43015773 Fax : 044 4301 6132 Email : [email protected]


1. Background – Formation of National Grid

The planning of Indian Power System started with the concept of regional self-sufficiency and the electricity requirements were met by local utilities that used to generate and distribute the power. Post-Independence, when the demand in the states started increasing and there was uneven disposition of energy resources, it became evident that for meeting the desired level of growth, the integration of the system is essential. Thus the concept of inter-state connection was brought in. Regional Electricity Boards were formed in 1964 to look into issues arising from these interconnections such as strengthening transmission systems.

By late eighties, five regional grids were developed viz. North, East, West, North-East and South with significant size. Initially, power exchanges at inter-regional level started in radial mode and in asynchronous mode through HVDC Back-to-Back links. Interconnection of regional grids was first done in October 1991 with the synchronization of North-Eastern Region (NER) with Eastern Region (ER) using 220kV Double-circuit line (220 kV Birpara – Salakati D/c). Later many lines were commissioned between different regions at different voltage levels, but their operation was restricted to radial mode only due to difficulty in maintaining the tie-line flows between the two regions. In March 2003, the Western Region was synchronized with the Eastern

Grid Management in Indian Power System

Power System Operation Corporation Limited, New Delhi

region using 400kV Double-circuit line (400 kV Raipur – Rourkela D/C) to form a central grid and in August 2006, the Northern region was synchronized with central grid to form N-E-W grid through 400 kV Gorakhpur – Muzaffarpur D/C. In December 2013, Southern Region was synchronized with N-E-W grid through 765kV Raichur-Sholapur S/C to form a synchronous National Grid of India.

2. Grid Management

Load Despatch is the function of paramount importance for power system and Load Despatch Centres (LDCs) at State/Regional/National level are playing a vital role in maintaining the Safe, Reliable, Economic and Secure operation of the power grid. Load Despatch is a process where primarily power flow in the grid is managed by balancing generation and demand through scheduling. The functions of load despatch have evolved due to integration of grids, increase in demand, changes in technology, and change in market mechanisms in power system, etc. Different entities viz. State Load Despatch Centres (SLDCs), Inter State Generating Stations (ISGS), Independent Power Producers (IPPs), Inter State Transmission System (ISTS) and Transmission Licensees are involved in managing the grid. Various functions have to be coordinated among these utilities for keeping the system parameters within the limits as per Indian Electricity Grid Code (IEGC) formulated by Central Regulatory Electricity Regulatory Commission (CERC) and ensuring the grid stability and security. The various functions to be discharged in grid management are as follows:

2.1. Frequency Control Management

Considering the huge inherent diversities across voluminous electrical network spreading across the length and breadth of the country, the only unifying factor is the Frequency. Since frequency is a function of the load-generation balance, it is subject to variation on a continuous basis due to variation of either of the two viz. generation or load. System operators at SLDCs, RLDCs and NLDC control rooms make all possible efforts to maintain the grid frequency within the normal IEGC band of 49.90 – 50.05 Hz by balancing demand & Figure 1: Evolution of Indian grid

V.K. Agrawal Executive Director

N. Nallarasan Deputy

General Manager

M. Pradeep Reddy

Senior Engineer


generation. Figure-2 below indicates the frequency of the grid for a typical day (14th June 2015):

Figure 2: 24 hours Frequency Profile for a typical day

2.2. Power Flow Management

System security is the primary goal of the operation of the interconnected network. In an interconnected system there exist numerous inter-dependencies of the networks forming part of the system. Each control area is responsible for maintaining the voltage, line loadings and angles within its control areas and its specified operating limits. N-1 criterion is used to constantly evaluate whether an emergency condition that may appear might lead to any criticality for the system as per the CEA planning criteria. In general, the power flow management is done by increasing/decreasing in generation, connection/disconnection of feeders, changing HVDC set points, generation rescheduling and switching on/off the lines or by curtailing Short Term Open Access (STOA), Power exchange (PX), Medium Term Open Access (MTOA) & Long Term Access (LTA) as per CERC regulations.

2.3. Scheduling of Power

SLDCs have the total responsibility for scheduling and despatch of their own generation (including generation of their captive licensees) and regulating their net drawal from the regional grid. RLDCs are responsible for scheduling of generation from Inter State Generating Stations (ISGS) & Regional entities, drawl schedules of States & Regional entities on day-ahead basis at ISTS level. LDCs take ramping up / ramping down rates and ratio between minimum and maximum generation levels while preparing the schedules. In case of forced outage of a unit(s) or in the event of a situation arising due to bottleneck in evacuation of power due to transmission constraint or in case of any grid disturbance, schedules are revised in real time by LDCs. The deviation between schedule and actual of regional entities get regulated in line with CERCs Deviation Settlement Mechanism (DSM) regulation. Similarly NLDC is responsible for inter-regional and cross border connection scheduling. Presently export of around 500 MW being scheduled to Bangladesh and export of 40 MW being scheduled to Nepal in addition to that around 150 MW being exported from Bihar and UP as bilateral agreement between the two countries. During high hydro season, around 1300 MW power is being imported from Bhutan by India.

2.4. Voltage Control and Reactive Power Management

Efficient management of any integrated power system envisages effective control of active and reactive power. While frequency indicates balance between active power generation and consumption, voltage reveals reactive power flows. System voltages must be controlled at all key nodes of the power network within acceptable limits. This is accomplished by the consumption or supply of proper amount of reactive power at these nodes. The voltages at different nodes are controlled by AVRs of Generators, VAR Exchange by constituents for Voltage and Reactive Control, VAR generation / absorption by generating units, Transformer Taps, Load Management for controlling the Voltage, Switching off the line reactors in case of low voltage, Switching off the lines in case of high voltage, Shunt Capacitor Bank Switching, Static VAR compensator operation, HVDC filter bank switching etc.

2.5. Deviation Control

Load forecasting & scheduling on a day-ahead basis is an important ex-ante function of grid management. This job requires constant participation by SLDCs and the RLDCs, involves prediction of demand for the next day keeping margin for any unforeseen events and revision of schedule for the same day based on system dynamics. The scheduling for a constituent involves division of 24 hours of a day into 96 time blocks, each block time duration of 15 minutes. "The deviations are calculated by comparing the net drawl schedule of the constituent with the actual drawl schedule which is measured in real time by SCADA by adding the respective drawl through Interstate banks at the constituent boundary."

2.6. Congestion Management

Congestion management in real time operation is tackled as per CERC Regulation dated 22nd December 2009 on “Measures to relieve congestion in real time operation”. Determination of TTC, TRM and ATC are carried out for reliable operation of the system and also to facilitate non-discriminatory open access in transmission. Whenever actual flow on inter/intra-regional link/corridor exceeds Available Transfer Capability (ATC) and security criteria as mentioned above are violated NLDC/RLDC issue a warning notice. If violation of Total Transfer Capability (TTC) limits persists for 2 time-blocks not counting the time-block in which warning notice was issued by RLDC and no affirmative action by the defaulting agency is taken, NLDC/ RLDC(s) shall issue a notice for application of congestion charge. The notices are communicated to all the concerned Regional entities telephonically or through fax message and through postings on website and making available the same at the common screen at NLDC/ RLDCs/ SLDCs. Figure-3 indicates the procedure followed for assessment of Transfer Capability. Also NLDC regularly give operational feedback on the congestions and the network constraints being based in the real system operation to planners and the policy makers.

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2.7. Contingencies in Real Time System Operation

In addition to above mentioned functions, various other contingencies are also handled by real time system operator such as High Frequency Conditions during Inclement weather / Low load days, Low frequency conditions, High/ low voltage conditions, Forecast of an inclement weather / Festival / Holidays, Complete blackout of a station / Island operation, Overloading of lines / ICTs, Tripping of major trunk lines, Oscillations etc. and also due to natural calamities such as cyclonic storms and earthquakes.

2.8. Shutdown and Outage Coordination

Planned outage for any element connected to the grid is mostly dealt by the offline reliability group. A standard procedure is followed wherein the shutdown is primarily cleared by the OCC of the region. In addition to planned outages, outage requests are received in real-time on urgent basis or emergency basis. Emergency outage requests that come up on real time basis are more critical since they are not backed up by any prior planned studies. Handling emergency shutdown in real time is challenge to system operator. In general, emergency outages are cleared with revision in TTC/ATC, generation rescheduling, load shedding, curtailment of open access transactions, switching on/off of transmission lines/ICTs/reactors by carrying out system studies.

2.9. Mock Black Start Exercises

In an integrated power system, disturbances can result in collapse of a part of the system or sometimes entire system. The affected system has to be restored the minimum possible time. The initial moments are particularly important and it requires the right decision to be taken at first instance for speedy restoration of the system. The right decisions have to be taken swiftly. All the operating personnel of Load Despatch Centres involved in grid operation should be thoroughly conversant

with the restoration procedure so as to minimise the time taken in restoration of the system after partial /total black out. Further during the Restoration process the system operators, Power station and Substation personnel must act in consonance to normalize the grid. Mock Black start exercises are carried out regularly by system operators in coordination with the various entities involved in the same.

3.0. Defence Mechanisms

The complexities of the Indian electric power system operation are increasing day by day and the size of the grid has expanded manifold at a high growth rate. Due to heavy flow of power through long corridors, outage of lines usually results in congestion in that part of the network which may result into disturbance in a large area of the grid resulting into loss of load and generation. To take care of sudden contingencies arising out of outage of generation stations or separation of inter-regional lines System Protection Schemes (SPS), Under-frequency and rate of change of frequency (UFR & df/dt) relays are designed. These settings are reviewed periodically by Regional power committees (RPCs) of regions.

Challenges in Grid Management

Introduction of Indian Electricity Grid Code, Availability Based Tariff, UI charges which has recently been modified as Deviation Settlement Mechanism (DSM), various regulations such as Open Access, computation of ATC and TTC Congestion Management etc., coupled with tightened frequency band have brought in a considerable discipline in Grid Management. Integration of large quantum of renewable generation into grid is expected to pose a number of challenges in power system operation. With the expansion grid and integration of large quantum renewables, various improvements mentioned below have to be brought in for further strengthening and establishing a reliable & secure grid.

² Availability of telemeter data for real time visualization at all control centres in the States

² Ancillary services ² Handling of reserves ² Wide Area Measurement Schemes (WAMS) ² Ensuring automated demand management schemes for

load shedding for grid security ² Islanding schemes for important load centres and

essential loads ² Technological improvements in the WTGs to take care of

faults /voltage dips ² Planning and strengthening of the State Transmission

Systems and Sub-Transmission Systems ² Keeping the defense mechanisms in healthy and

operating condition by the respective State Utilities ² Forecasting tools for renewables ² Capacity building ² Frequency and demand response ² Reliability and transmission standards

Figure 3: Transfer Capability Assessment


Evolution of Grid CodesThe increasing penetration of large amount of renewable energy in the last decades in transmission and distribution networks, especially the one associated to mega-plants, has increased the concerns at TSO levels to guarantee continuous, reliable and high quality power supply in the grid. Therefore transmission and distribution operators are constantly working on more demanding operational requirements for this new generation (grid code requirements).

New Challenges for Large Integration of Renewable in the Grid

Adrian Timbus Segment Manager

Wind & Solar Automation ABB Switzerland

Inés Romero Navarro, Ph.D. Head of ABB Power

Systems Consulting Spain

The traditional grid code requirements established by the transmission operators, have developed from only requesting static conditions such as reactive power control and/or power factor, or individual machine (turbines/inverters) capability to endure system faults and remain connected (low voltage ride through capability, LVRT) to more demanding conditions including full control to handle the dynamic reactive capability of the plant, voltage and frequency control at the point of connection (POC), limitation of harmonic and flickering distortion and so on.

The following table outlines the ongoing evolution of the grid code requirements from some of the main world electrical TSOs:

Requirements Traditional Requirements New Requirements

Active power & freq. control

Applicable

² Steady-state frequency control according to TSOs´ acceptable freq. ranges

² Protection settings

Applicable

² Requirements according to the size of the facilities

² Steady-state frequency control according to TSOs´ acceptable frequency ranges

² Protection settings

² Frequency control from individual equipment (inverter/wind turbines) expected at POC according to TSOs´ defined time response (“plant controller”)

Reactive power & V control

Applicable

² Power factor at the POC

² Dynamic capability to support faults

² Steady state voltage control according to TSOs´ acceptable voltage range

² Protection setting

Applicable

² Power factor and reactive power compensation at POC

² Steady state voltage control according to TSOs´ acceptable voltage range

² Protection setting

² Reactive capacity mapping at POC according to individual equipment

² Dynamic voltage/reactive power control at POC (“plant controller”)

Power quality Applicable

² Harmonic distortion and flickering levels

Applicable

² Requirements according to the size of the facilities

² Harmonic distortion and flickering levels

LVRT Applicable

² Capability to endure the fault with high demanding requirements in terms of reactive power injection to the grid

Applicable

² Capability to endure the fault with high demanding requirements in terms of reactive power injection to the grid


Modelling & Testing & Certification

Applicable

² Steady-state network model

² Dynamic black-box models if required to fulfil reactive power requirements during the fault

² Individual and/or aggregated generation model

² Applicable tests to demonstrate compliance with connection requirements for individual equipment (turbine/inverter)

² Certification required for new equipment

Applicable

² Steady-state network model

² Full dynamic network model to ensure reactive/voltage/frequency control at POC. Provide dynamic “plant controller” black-box model

² Individual and/or aggregated generation model

² Harmonic equivalent network model

² Applicable tests to demonstrate compliance with connection requirements for individual equipment (turbine/inverter)

² Certification required for new equipment

Operation & maintenance

Basic maintenance expected TSO and owner generator shall agree on the appropriate maintenance plan of production facilities in a timely and orderly fashion

Ancillary systems Not applicable Applicable

² Power oscillation damping control ² Virtual inertia ² Ancillary service (primary/secondary freq. control) ² Accurate forecast

Among other factors the governmental environmental concerns and political regulations are pushing more and more to replace large amounts of conventional generation by the new renewable sources, which nature is very different to conventional generation in terms of predictability and availability, inertia, and capability to provide both active and reactive control. In addition, the classic configuration of a renewable plant where the generation is distributed in a collecting system according to individual generation “machines”, differentiates the way the design, management and control of the electrical system is done when compared to conventional generation.

All the above mentioned key factors may impact the main obligations of the TSOs with the customers, if they are not managed correctly:

– Continuity of supply; the uncertainty related to the predictable capability of renewable may have an impact on the grid stability.

– Quality of supply; introducing new technology in the grid (power electronics) and the connection of distributed generation at lower voltage levels may impact the quality of supply resulting on higher harmonic emissions, voltage sags, resonances. In addition the reactive capability of the new resources is critical to guarantee constant and acceptable voltage levels.

– Reliable and secure supply; Disconnection of large amount of renewable resources may impact the overall stability of the grid. Available spinning reserve is needed to ensure a secure operation

Based on these obligations, and considering some of the demanding conditions described in the initial table, the importance of an optimized design both at the collecting but also at the sub-transmission/transmission level, and a proper control may be critical, i.e. an appropriate selection on the degree of redundancy and topology clearly will affect the reliability of the final design during normal but also contingency operation, an optimal selection for the voltage level for intermediate step-up transformers, and the distribution for the collecting grid will result on minimizing system losses and therefore maximizing the overall power capability of the plant.

Grid Code in IndiaChallenges in India, a country of continental size organized in different states, are managed by integrating them into all India grid, and allowing a flexible balancing of the variable renewable output.

The inter-state and inter regional transmission infrastructure is already being developed and all the five electrical regions of India are synchronously connected in 2014. However, new transmission corridors would be required for evacuating green energy from states such as Tamil Nadu, Gujarat, Rajasthan and J & K (Ladakh). It has now been recognized by the transmission planners that in view of the short gestation period of RE plants, the transmission has to lead generation and would require upfront investment. Such transmission corridors required in the next five year time span have already been firmed up through the established process of coordinated transmission planning and their implementation is being taken up progressively.


In view of this, Central Electricity Authority (CEA) released a note on the requirements of Grid Code in October 2013. Following are the grid requirements to connect RE Source to grid.

Requirements Traditional Requirements

Voltage /frequency ranges

² The voltage variation of up to ±5% of nominal

² The generating units shall be capable of operating in the frequency range of 47.5Hz to 52Hz and shall

be able to deliver rated output power in the frequency range of 49.5 Hz to 50.5 Hz.

Reactive power control

The generating station shall be capable of supplying dynamically varying reactive power support so as to

maintain power factor within limits of 0.95 lagging to 0.95 leading.

Power quality ² The generating station shall not introduce flicker beyond the limits specified in IEC 61000.

² The harmonic current injections from a generating station shall not exceed the limits specified in IEEE

519.

² The generating station shall not inject DC current greater than 0.5% of the full rated output at the

interconnection point.

² Measurement of harmonic content, DC injection and flicker shall be done at least once in a year in

presence of the parties concerned and the indicative date for the same shall be mentioned in the

connection agreement; Provided that in addition to annual measurement, if distribution licensee or

transmission licensee or the generating company, as the case may be, desires to measure harmonic

content or DC injection or flicker, it shall inform the other party in writing and the measurement shall be

carried out within 5 working days.

Active power control

RE generating station connected at voltage level of 66kV and above shall have facility to control active power

injection in accordance with a set point, which shall be capable of being revised based on the directions of

the appropriate Load Dispatch Centre (LDC). Provided that as far as possible, reduction in active power shall

be done without shutting down an operational generating unit and which reduction being shared by all the

operational generating units pro-rata to their capacity.

LVRT The RE generating stations connected at voltage level

of 66kV and above shall remain connected to the grid

when voltage at the interconnection point on any or

all phases dips up to the levels depicted by the thick

lines in the following curve:

² Where VT/Vn is the ratio of the actual volatge to

the nominal system voltage at the interconnection

point.

² Provided that during the voltage dip, the

individual RE generaing units in the station

shall generate active power in proportion to the

terminal voltage;

² Provided further that during the voltage dip,

the generating station shall maximise supply

of reactive current till the time voltage starts

recovering or for 300ms, whichever time is lower.


Connecting Wind Farms to Power GridDepending on the size of the wind farm/renewable facility three independent electrical systems can be distinguished. Different system demands should be analyzed for each one of them [1]. The following figure outlines them:

Figure 1: Wind Connection to Grid

3.

1.

Collecting system

Transmission power system

2 Sub-transmission power system

² The existing transmission or distribution system (system 1) is usually a high voltage network that might not be planned to support the new generation. Therefore the impact of this new generation must be evaluated to determine the need of additional network reinforcements.

² System 2, the sub-transmission network, usually a high voltage system, is associated to the wind power investment, and connects the wind farm to the transmission network. Defining this system implies to select the technical and economical optimal interconnection. Depending on the location and/or size of the wind farm this system may or may not be needed.

² System 3 or collecting system corresponds to the wind farm distribution network. It is normally powered in medium voltage (20 – 36 kV), however due to the advance in available technology higher voltage levels (72 kV) are also used. Defining the distribution system includes equipment sizing and specification to ensure the wind evacuation with high reliability at an optimized cost.

The following section describes the recommended methodology to analyze systems 1, 2 and 3.

Analysis of the existing High Voltage Network

Connecting a new wind farm to an existing transmission or distribution network may affect its behavior depending on two key variables; the capacity of installed wind power, and the strength of the network where the wind farm is planned to be connected (expressed in terms of Pcc/Pwind). Steady-state and dynamic analysis are recommended to assess the new connection.

a. Steady-state analysis: The impact of the new generation on an existing grid is focused on assessing the voltage profile and loading levels according to TSOs requirements during normal and contingency operation, and considering the new generation in service. This analysis allows to identify possible restrictions on the existing network.

Additionally, handling the reactive power capacity for the new wind farms is critical to identify compliance with TSO grid requirements (new wind technology) and / or possible voltage instability issues when working with old wind technology with limited reactive power control. P-V and QV curves are traditionally used to determine the maximum power that can be injected at a certain bus of the network and the margin to instability limits in terms of reactive power reserve.

In relation to the short-circuit contribution, and unlike to some other generation technologies, the wind power does not increase the short circuit level substantially. The main reason is the usage of induction or double-fed and full converter. Additionally, the electrical distance between the generation level and the transmission grid is damped by the equivalent impedance.

b. Transient Stability analysis, during transients, wind farm facilities might either aggravate existing voltage sags of the network (induction generators), tripped (technology with limited ride-through capability), and/or result in a large power/voltage deviation due to a sudden disconnection of a large amount of power. Dynamic simulations are recommended in this regard. Among others the following phenomena are investigated:

Our groundwork enables our

clean energy contribution

to touch the sky

Our groundwork is what earns us the wings:

§ Robust operations -

from concept to commissioning and lifetime care thereafter

§ Comprehensive in-house manufacturing facilities –

including complete turbines and towers

§ Turbine technology -

reliable and proven gearless technology

§ Holistic solutions –

to all wind energy related financial / regulatory / CDM aspects

§ Proven track record -

18 years of operation; capacities exceeding 4200MW

www.windworldindia.com

Wind World (India) Ltd.Wind World Towers, Plot No. A-9, Veera Industrial Estate, Veera Desai Rd., Andheri (W), Mumbai 400 053, India.Tel: +91 22 6692 4848 | Email: [email protected]

Our groundwork enables our

clean energy contribution

to touch the sky

Our groundwork is what earns us the wings:

§ Robust operations -

from concept to commissioning and lifetime care thereafter

§ Comprehensive in-house manufacturing facilities –

including complete turbines and towers

§ Turbine technology -

reliable and proven gearless technology

§ Holistic solutions –

to all wind energy related financial / regulatory / CDM aspects

§ Proven track record -

18 years of operation; capacities exceeding 4200MW

www.windworldindia.com

Wind World (India) Ltd.Wind World Towers, Plot No. A-9, Veera Industrial Estate, Veera Desai Rd., Andheri (W), Mumbai 400 053, India.Tel: +91 22 6692 4848 | Email: [email protected]


• Response of the regulation systems of the synchronous machines

• Dynamic behavior of the load as a function of the voltage

• Voltage and reactive power control

• Dynamic behavior of compensating equipment such us SVC

• Wind farm ride-through control system

• Protection system performance

In general, the results of many analysis performed by ABB have demonstrated that without considering additional power electronic solutions, guaranteeing a minimum SCR of 10 (SCC at the connecting point/ installed wind power) is needed to avoid system instability. Values between 5 and 10 can be accepted depending on the specific case (X/R ratio, electric demand in the area).

Analysis of the Sub-transmission Electrical System for Grid ConnectionThe sub-transmission system is utilized to connect several wind farms when they have a common interconnection point in the existing transmission network. The technical studies to define this system include among others, feasible analysis to select the optimal layout and voltage levels (usually high voltage levels), load flow studies to select the conductor (voltage profile, sizing, and losses), reliability studies, and economic studies.

The reliability studies consider both the reliability level required by the investor in the wind(s) farm(s) and the reliability level required by the TSO. The requirements from the investor are immediately translated into an additional cost, however the larger the level of automation is, the lower the reposition time will be after a system fault (measured in terms of SAIDI, for example) and the lower the customer outage frequency. Therefore this type of analysis assess the improvement of reliability indices depending of the level of automation, and the cost for the different options. The requirements coming from the TSO generally cover the N-1 and N-2 criteria for those voltage levels, even though the sub-transmission networks are frequently dedicated only to the new generation.

As a result of the analysis the following is set and verified; type of conductor depending on the voltage level and the power to transport, isolation level, cable sizing and equipment specification at substation, voltage regulation control if needed, losses per year per alternative, degree of redundancy, etc.

The technical analysis may provide more than one valid options, therefore, the final selection will fulfill the technical requirements considering the minimum cost.

Analysis of the Collecting System – Plant Design

Designing the collecting system includes among other analysis the basic system specification and optimization of equipment

such as transformers, MV switchgear, cables. Short circuit and load flow studies provide information about expected short-circuit contributions, system losses, loading levels and voltage profiles.

Defining the topology for the collecting grid is key to minimize system losses but also to increase system reliability and security. In this phase different set-ups are investigated from a reliability point of view (RAMS), playing with different variables, radial configuration, number of feeders, number of individual generating equipment per feeder, level of redundancy at substation level. An optimized plant design has a direct impact on distribution losses and reactive power requirements.

Earthing and grounding studies are also part of the design. According to the selected grounding system, the protection philosophy and settings are defined. Furthermore and especially for weakly earthed systems, the need of arresters during switching and lightning transients is verified.

In this phase, facilities owners are required to fulfil TSOs´ grid code requirements to access the grid. The specific requirements may vary depending on the country, nature of the renewable facility and size. In some occasions it may be sufficient to provide steady-state analysis, however more and more it is required to provide both steady-state and dynamic studies, network modelling and testing. Early described in this paper there is a summary of some of the ongoing changes for the main grid code requirements.

Designing and Validating the Plant ControllerTo increase the accuracy of the studies, the above analyses consider not only the electrical connections and interactions but also the wind plant behavior when connected to the power system. This behavior is in many cases represented by the plant controller, which coordinates all assets and turn the wind turbines into a single generation facility.

The plant controller monitors, in real time, data from the main operational variables (voltage, current, active and reactive power, number of individual machines in service), coordinates the different individual control strategies, and accounts for system losses. It controls and manages all this information by storing, analyzing, and taking smart actions to optimize the operation. To define the overall control strategy, at least the following information needs to be accounted:

• Set-points from the TSO or owner/operator in terms of active and reactive power, power factor or voltage at the POC

• General grid code requirements

• Limitation/capabilities of the installed wind/solar technology

• Status of the individual generation (machines in service)

• Control response from the different individual installed equipment such as reactive compensation, tap-changer operations, protection systems

• System topology (status of main couplers)


For each project, firstly, the control strategy is defined and implemented in a commercialized software simulation tool that allows to verify the compliance with the grid code requirements, and then the control is physically implemented in the control system typically located at the POC. The following Figure 2 shows an example of a control strategy for a wind farm where the individual wind generator production, status, as well as the tap changer control and the existing reactive power control is coordinated to satisfy the requirements at the POC.

To minimize the leveled cost of energy (LCOE) and optimize the asset utilization in a wind or solar plant, the controller should be capable of dispatching not only wind turbines or solar inverters but also additional sources of active and reactive power such as energy storage, flywheels, capacitor and inductor banks, STATCOMs or tap changers. Such a controller determines the optimal operating condition of the plant considering the constraints of the equipment, turning the plant into a flexible generation facility.

On load tap changer; tap

•Wind turbines

•No individual WTStatus ON/OFF

•Reactive power equipment:

•Status ON/OFFControl mode

• POC•

Wind farm measurements:

•Individual WTReactive power equipment

PLANTCONTROLLER

•Setpoint to individual WF:

P, Q, control mode

•Setpoint to Q equipment:

Q, I, control mode

•Onload tap changer:

Tap position

•Grid Code Requirements

•with droop Q; PF, Q control, V control

with droop P; P control, freq_control

Figure 2: Outline of Plant Controller Philosophy

In addition to grid code compliance, the latest tendency for large renewable facilities is the capability to participate in primary and/or secondary frequency regulation. Turbine inertia, energy storage solutions or flywheels may provide the necessary spinning reserve otherwise limited during production intermittency due to weather fluctuations. This extra spinning reserve ensures that a new renewable generation plant can fully emulate the control capabilities and power availability of a conventional generation

Figure 3: Schematic Diagram of the Wind Plant Control System


plant. To minimize business risks and dependency on weather conditions, another way of providing frequency support is through aggregation of many plants in virtual power plants.

The following section described the necessary systems and functions to enable the virtual power plants and to allow renewables become an integral part of power system operations and planning.

Virtual Power PlantsVirtual power plants are enabled by a flexible and scalable automation system capable to aggregate and integrate multiple plants, of different technologies, into a single monitoring & control system. Dedicated functionality for controlling and scheduling the power production of these plants enables the entire fleet of plants to behave as a single (virtual) power plant. The following paragraphs describe key functions of virtual power plants.

Remote Management CentresRemote management centers are used to aggregate all plants into a single automation system. Real time monitoring of relevant plant data is necessary to enable provision of services to the grid operators and to enable effective operations and control of the plants. These centers also help to establish a single point of contact between the plant operators and the grid and market operators. Power system and energy market management need to know production profiles of plants, and consolidated numbers provided by the remote management centers help keeping the complexity low.

Functionality to Help Integration

To facilitate integration of renewable plants, it is not enough to have consolidation of data alone, additional functionality is also required. In this paper we describe a few key features a

remote management center should have to allow for effective management and integration of distributed renewable plants into power systems operations and planning.

Integration in Energy MarketsGenerally, the market mechanism can be split in two main parts:

• Energy market or so called day ahead market, where the bulk energy necessary to cover the load for day ahead is traded.

• Ancillary service market or so called intraday market, where differences between planned production and actual load are traded. The ancillary service market is very important for a stable operation of the power grid and span across various time frames, as explained later in this paper.

In most areas, the renewable plants are typically paid a fixed revenue per kWh produced, favored by various supportive schemes such as feed in tariffs (FiT) or power purchase agreements (PPA). There are however countries, like Germany and Spain, where these supportive schemes have been reduced or even suspended, and therefore forcing the owners of the plants to participate to the energy market and sell their energy at the same price as the rest of plants. To minimize the market participation risk, key functionality such as portfolio or fleet power management as well as production forecasting is necessary.

Power ManagementIt is often misunderstood that the power production from renewable plants, particularly wind and solar plants, is uncontrollable and therefore integration into power system operations poses challenges. It is true that the power production of such plants depends on the availability and volatility of the input fuel source, such as wind or solar irradiance. But, as highlighted in the previous section of this paper, with modern automation solutions, these plants are fully controllable in the range between zero and maximum available power. Ramp rates, active and reactive power, power factor and voltage and frequency are controllable within the limit of the plant.

From the remote management center, it is important to be able to have control over the setpoints and control modes of the plants. In some countries, the transmission system operator (TSO) may request direct link and access to the plant control system to set the desired operating point of the plant while in other countries the TSO requests the generation operator to modify power production in certain nodes of the grid. In the latter case, a power dispatching functionality is necessary at the remote center level. This functionality can be a simple algorithm that dispatches the plants within their available limits or can be a more complex application which optimizes the setpoints considering also constraints and costs associated with the plants. The optimization approach is favored by the asset owners and operators as it considers asset condition, availability and plant operating costs when dispatching the

Figure 4: Remote management system and its crucial role as interface between the plants and the grid and market operators.


plants. It also allows for more optimal power production and flexible maintenance schedules.

Ancillary ServicesPlant capability to receive and track power setpoints is already a type of grid support functionality. However, the way how and how fast the plant reacts to the setpoints can be categorize in grid ancillary services is as follows [2]:

• Primary Balancing Power • Secondary Balancing Power

• Minute Reserve

Primary Balancing Power

The primary balancing power is utilized for immediate stabilization of the grid frequency in case of power imbalance or grid disturbances. The activation of primary balancing power is executed through an automated release call. The called technical units are obliged to provide the complete primary power within 30 seconds. This requires a fast and robust automation and dispatching system to ensure proper delivery of the service to the grid operator. Primary balancing power is offered jointly for negative and positive balance and the compensation is provided based only on the accepted price per kilowatt.

Secondary Balancing PowerIn case of a grid disturbance, secondary balancing power replaces the primary balancing power. Technical units that provide secondary reserve are activated automatically in 30 seconds after a disturbance by a release call and are obliged to provide the complete power within 5 minutes.

Specified by the virtual power plant operator, technical units provide either positive or negative secondary balancing power or both. The bids are accepted according to the price per kilowatt. In case of a release call, the bids are called according to the price per kilowatt per hour.

Minute Reserve

The minute reserve replaces the secondary balancing power after a grid disturbance. Moreover, minute reserve is utilized to balance power imbalances that are not manageable by secondary control on its own. The minute reserve is activated by an automated release call to the qualified technical units within 15 minutes of the disturbance, if the primary and secondary reserves have not been able to level the imbalance in the grid. The called technical units are obliged to provide the complete minute reserve within the next 15 minutes and hold available the offered amount of power for at least four hours.

Traditionally, conventional power plants were the only source for providing balancing energy. Ultimately, aggregation of distributed renewable and non-renewable plants into a virtual power plants can offer balancing power providing that

enough capacity is available to be accepted by the market operator [3]. Generally, the (virtual) power plant operators report the possible amount of balancing power and market agents place the bids at the energy market.

Power Forecasting

To allow renewable plants to offer the grid support services described above, a good understanding of the plant capabilities and operations is necessary. As the power production of wind and solar plants depends directly on the weather conditions, forecasting of weather and power production becomes critical. The forecasting horizon should cover very short time ahead (minutes to hours) but also a few days, to allow proper planning of operations and maintenance of the plants and the participation to the energy market.

Various technologies are used to create production forecasts for renewable plants, from persistence models (the power production in the future is as now) to more sophisticated artificial intelligence or physical modelling of atmosphere conditions at the plant location.

Application Examples

Large-scale Virtual Power Plant for Secondary and Minute Reserve

Figure 5 gives an overview of a large-scale virtual power plant and its integration with the balancing market. The shown Next pool consists of more than 1000 units summing up to 800 MW provided by wind, solar, biogas and hydro plants. The business model of Next is to provide ancillary services to the market, in particular to provide secondary and minute reserve to all four German transmission system operators. More information about system architecture and mathematical formulation of the optimization function can be found in [4].

The provision of these services is facilitated by a powerful optimization and dispatching application provided by ABB. OPTIMAX PowerFit uses real time and historical data along with power forecasting for all plants to optimize the production of the entire portfolio.

The intraday optimization example covers multiple power generation units, such as wind, solar, hydro, and combined heat and power plants. Available storage capacities include heat buffers and pump stores, besides electric cars.

Figure 6 shows the result of one optimization run. Dotted lines mark the original day-ahead plan of the plants. Caused by a surplus of wind production, the intraday optimization reduces the use of combined heat and power BHKW plants (green areas) until the heat buffers reach their lower limit (red areas). A battery located in a parking house is charged at times when there is too much power in the grid.


Figure 5: Forecasting Horizons and their relevance to Market and Plant Operations

References

1. Romero Navarro, I., Galván, I., Tomanovic, S. ‘Wind Farm Integration Power Analysis’. Power-Gen Asia 2007.

2. A. Timbus, L. Cicognani, S. Doga, M. Antoine, “Increase the Value of Renewable Plants with Remote Management Systems”, in proceedings of PowerGen Europe, 2014

3. S. Saliba, R. Franke, A. Frick, S. Hölemann: Optimale Steuerung von virtuellen Kraftwerken bei Abruf von Netzdienstleistungen. VDI Wissensforum, 2014.

4. R. Franke, S. Saliba and A. Frick, “Virtual Power Plants for Smart Markets”, in proceedings of PowerGen Europe, 2014

Figure 6: Generation mix. Optimization run

Snippets on Wind Power Wind Power Forecasting By NIWE/IWPA

On 27th May 2015 CE NCES, TANGEDCO had called for taskforce meeting. Discussion was mainly on forecasting by NIWE/IWPA. IWPA informed that has been delayed due to some technical issues in the meter specification. NIWE also demonstrated Vortex online portal, which will provide the forecast, where they showed the forecasted values. The scheme funding is being done by IWPA.

Big Jump in Renewable Energy Certificates Trading VolumesThere is a pick-up in the demand for renewable energy certificates that was seen in the trading session held on Wednesday, 27th May 2015. This sudden demand has been attributed to a recent judgment of the Supreme Court. As many as 256,579 non-solar and 83,189 solar RECs were sold on the two country’s energy exchanges—IEXL and PXIL.

Power Grid Corp to Tap Bond Market to raise ` 12,000 CroreMr. R N Nayak, Chairman of the state-run transmission utility Power Grid Corporation of India Ltd (PGCIL) has said that it

would be tapping the bond market to raise ` 12,000 crore in the current fiscal. Addressing a press conference, Nayak said in the current fiscal investments in power sector were coming up rapidly. Therefore, the proceeds from the bonds would be used for the ` 22,500- crore capital expenditure plan. PGCIL was gearing up for the new capacity additions

Source: Business Line

The theme of the next issue of "Indian Wind Power" is

“Forecasting and Scheduling”.We invite relevant articles to the theme.

We solicit your cooperation.Editor

Theme of Next Issue


Abstract

Procurement planning for electrical power with a sizeable contribution from RE technologies it is often stated that it is not possible to assign any capacity value to RE technology based generation except for hydro power. Therefore the planners would not take RE power while planning advance procurement of power. The variability of the RE power over time from weeks to hours to seconds makes it complicated to put forward an argument for large scale integration wind power given the fact that grid security can be given as a reason to limit or even deny access to grid. In this exercise an attempt has been made to look at the problem more holistically at a large area level where there is sufficient geological spread helping in getting advantage of averaging. In order to determine time dependent relations among turbines installed in different regions, concurrent wind data sets are needed over a considerable period. To this end MERRA data was employed in conjunction with an averaged normalized power curve that represents different technology turbines. Though the procedures used are not rigorous the results do give a high level understanding of collective behavior and its impact on integrated grid and local area grid is explored.

Introduction

Capacity Credit (CC) assigned to a renewable power plant is the fraction of its installed capacity by which the conventional power generation capacity can be reduced without affecting the benchmark quality of supply.[G. Giebel “Wind energy has a capacity credit – a catalogue of 50+supporting studies”, WindEng eJournal 2004]

A number of attempts have been made to assign a capacity credit to wind power plants in a balanced grid situation. For RE technologies the capacity credit that can be assigned depends on a number of factors:

² Penetration levels

² Amount of Spinning Reserve

² Wind parameters

² Base case reliability

² Voltage levels at which the units are connected

² Proximity to the load centers

² Size of the power system

² Variability of the generator

² Order of correlation of the interconnected wind projects

With more and more wind turbines getting added to the grid, system operators who are used to the traditional way of dealing with grid management find it complicated to respond to frequent changes in the output from wind farms. With tight financial control on frequency of operation and absence of fast acting balancing power at their command the grid managers tend to treat the uncertainty in power from Wind and other RE technologies as an undesirable element notwithstanding the environmental friendly tag. Attempts to draw parallels with what happens elsewhere where the grid integration and fewer bottlenecks in transmission systems and a better developed electricity market ends up in a faceoff between grid managers and the small suppliers. Biggest difference is the UI charge regime that is being used as a solution for any and all ills of the grid management. Though some limited realization that it really is no lasting solution for all problems of a deficit energy supply system with no real spinning reserves and severely constrained inter-regional corridors has found expression among grid planners, alternate solutions may take a while to emerge. In the meanwhile with grid managers with a limited agenda of balancing the loads and supplies tend to continue to rely on the so called firm sources of power rather than wind or other RE technologies. The justification to do so is always grid security. With much short fall (that too with restricted demand) it appears that contracts with Independent Power Producers using conventional generation is an attractive and easy option to take, notwithstanding the fact that they have to be paid even when they do not produce. With such agreements in place there will be less incentive to accept wind power on grid and pay for it and also pay the conventional IPP for the time when they do not produce power. Naturally, this dries up any space for variable sources in the name of grid security. There has been a concerted effort to improve grid frequency over the years and it has yielded positive results. Figure 1 shows block wise grid frequencies of a particular week (September 24-30) in two years (2012 & 2013) and the 2013 shows higher frequencies as compared to 2012.

Assigning Capacity Value for Large Scale Wind Farming - A Case Study

M.P. Ramesh, Wind World (India) Limited, Bangalore


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Figure 1: Fifteen minute block frequencies over a typical week (24-30/September)

Figure 2: Monthly average grid frequencies over four years

Taken on a monthly basis again there is a marked improvement in the grid frequency (figure 2)

While this is good, it cannot be taken as a sign of good grid control because it was in the year 2012 (July 30th and 31st) there were major grid disturbances. In terms of demand met, the trends have remained more or less the same in terms of energy supplied against (deemed) demand.

Table 1

Peak Demand in Tamil Nadu during 2012

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Demand 12499 11967 12296 12269 12004 12606 12538 11755 12323 12038 11803 12736 12736

Available 9841 10182 11053 10877 10566 10348 10269 8306 9409 9698 10021 10556 11053

Surplus/Deficit -2658 -1785 -1243 -1392 -1438 -2258 -2269 -3449 -2914 -2340 -1782 -2180 -1683

% -21.3 -14.9 -10.1 -11.3 -12 -17.9 -18.1 -29.3 -23.6 -19.4 -15.1 -17.1 -13.2

Actual power supply position in terms of energy requirement vis-à-vis energy availability (MU) of various States/ Systems during the year 2012.


Table 2

Demand 7583 6796 7868 8043 7840 7990 8233 7110 7450 7859 7288 8242 92302

Supply 5817 5840 6834 7333 6763 6606 6574 5254 5831 6668 5998 6643 76161

Deficit -1766 -956 -1034 -710 -1077 -1384 -1659 -1856 -1619 -1191 -1290 -1599 -16141

Deficit % -23.3 -14.1 -13.1 -8.8 -13.7 -17.3 -20.2 -26.1 -21.7 -15.2 -17.7 -19.4 -17.5

Load Generation Balance Report for Tamil Nadu 2013-2014.

Table 3

MU Requirement for April - September 2013

Requirement Availability Deficit % deficit Requirement Availability Deficit % deficit

April 8,199 6,769 -1,430 -17.4 MU

May 8,717 7,832 -885 -10.2 16,916 14,601 -2,315 -13.7

June 7,858 7,568 -290 -3.7 24,774 22,169 -2,605 -10.5

July 8,004 7,796 -208 -2.6 32,778 29,965 -2,813 -8.6

August 7,681 7,446 -235 -3.1 40,459 37,411 -3,048 -7.5

September 7,266 7,159 -107 -1.5 47,725 44,570 -3,155 -6.6

http://www.cea.nic.in/monthly_power_sup.html

SRLDC monthly reports provide an excellent insight into the grid management in Tamil Nadu. Figure 3 shows the energy

mix from various sources on a monthly basis from April 2012 to September 2013 covering two windy seasons.

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Figure 3: Energy mix in TN grid for the period April 2012 to September 2013


The following important factors are emerged from a study:

1. Utilization of wind energy during the windy months is in the range of 1400 to 1600 MU during the months May - September 2012 while it has fallen drastically in corresponding period during 2013.

2. There is a strong input of about 800/900 MU from cogeneration during 2013.

3. There is a sudden increase of dependence on central pool demand and drawl.

4. There is also a marked increase of power contribution from IPPs.

5. The energy from hydro also shows a significant increase compared to 2012.

It can be seen that TN has managed to bridge the gap between availability and requirement progressively by increasingly relying on firm sources of power both from private power suppliers and state and centrally owned entities. In the same period the EB has practically kept out energy from wind installations citing grid security as the reason. A point to note is that in the wind farming history in Tamil Nadu there are practically no instances of grid security being compromised by wind power. On several instances when wind penetration was very high the grid managers were able to deal with the situations comfortably and have several times gone on record that wind power has supported grid in critical situations.

InputsIn order to make a reasonable estimate of wind power available on a short time the following steps are needed at the minimum:

² Time series of wind speeds at hub height

² Power curve (Power Vs Wind Speed curve)

² Geographical locations where wind turbines are established in large numbers.

Wind DataTamil Nadu being at the forefront of wind power development for over two decades has considerable information on wind speeds and directions from a variety of sources including the data from national wind monitoring program and other sources. However these data sets are not suitable for the present exercise. These data sets are from different time periods and therefore cannot be used to determine simultaneous availability of wind power from different locations. The synthesized data sets are created using a variety of climatologically averaged information at a grid spacing of ½° latitude by ° longitude. At a high level, the model outputs try to keep spatial and temporal consistency across the grid points and refined with measured data. In this analysis the MERRA data has been used from 36 data points (figure 4) over the state of Tamil Nadu and Kerala.

Figure 4: MERRA data points across Tamil Nadu

Wind farming in Tamil Nadu has taken place in four specific areas given in Table 4.

Table 4

Pass Relevant MERRA pointsNo of MW installed

Palakkad 1,2,5,6,15,16,24 & 25 2832

Khambam 7,14 0534

Senkottah 8,9,12,13,27 2032

Aralvoimozi 10,11 1810

All of TN 7208

Power Curve

Tamil Nadu is the most wind farmed state in the country with an installed capacity of 7208 MW as of March 2013. Few operational turbines are from as far back as mid eighties. Wind turbines have their certification classifications which relate to the extreme winds that the turbine can withstand without damage. The classification also drives the design for fatigue of all components of the wind turbine. Turbines designed prior to 2005 were designed to five classes and presently it is 4 classes. With a mix of so many turbines it is decided to take different power curves available in public domain, normalize them with the rated power given by:

nPv =Pv / Prated

Where nP6 = normalized power at wind speed v

Pv = power at wind speed v

Prated = Rated power

The derived power curve is presented in Figure 5.


Figure 5: Normalized Power Curve from different Turbines

Estimation of Hour by Hour Wind Power Availability

1. MERRA data for the period 2000 to 2012 was extrapolated to a hub height of 75 m agl with a Power Law Index of 0.2 as this is the average measured in plains of Tamil Nadu.

2. The wind data from the relevant locations as per Table 4 were used to individually estimate power on an hourly basis.

3. Power curve used in conjunction with the extrapolated hub height wind speed to obtain hourly generation for an average wind turbine (normalized).

4. The power thus obtained scaled up to the number of MW from each area.

5. Statistical analysis carried out based on the resultant generation data.

Assumptions

² The grid and turbine availability are at 100%

² The applicable MERRA data (extrapolated to a hub height of 75 m) from the data points at ½" latitude x " longitude hold good over the wind farm areas.

Analysis

The idea is to first look possible generation levels from different regions at a gross level from monthly average perspective. With wind speeds showing certain amount of inter annual variability it was necessary to look sufficiently long time periods. Figure 6 shows a plot of attainable generation levels on monthly basis for 13 years (2000 to 2012). It is clearly seen that the seasonality of wind power availability grossly sticks to fairly established patterns.

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Figure 6: Wind Power Availability across the four Wind Farming Areas (MW)

January and February show some activity while March

and April go considerably low. There could be some days

and weeks of not much wind power being available.

End of April and May winds pick up and we already

see considerable generation levels reached during these

months. June, July and August the wind turbines achieve

impressive plant load factors in the range of 45 to 50%.

September starts seeing the wind power falling slightly.

October and November progressively loose wind power

only to pick up moderately during December.

This pattern is seen over the last 13 years though with a

certain amount of meandering in a temporal and sense of

capacity. This is to be expected of any natural processes.

Figure 7: Month on Month Wind Power Availability from four Windy Passes based on current installations

(7208 MW)


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Figure 8: Contributions from different Passes

Figure 9: Variations of Wind Power Availability over years

Figure 10: Diurnal Pattern of Wind Energy Availability during January

Figure 11: Diurnal Pattern of Wind Energy Availability during February

Figure 12: Diurnal Pattern of Wind Energy Availability during March

Figure 13: Diurnal Pattern of Wind Energy Availability during April

Figure 14: Diurnal Pattern of wind energy availability during May

Figure 15: Diurnal Pattern of Wind Energy Availability during June


The month-wise plots have been presented to bring out the wind energy availability from different passes and give a fair idea of how much to expect from each of these passes. This will go a long way if the wind power has to be included at planning stage (Load Generation Balancing Report).

The expected plant load factors for wind energy can be estimated in terms of total installed capacity for the state and it is possible to even have regional plfs on a month on month basis (Table 5).

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Figure 16: Diurnal Pattern of Wind Energy Availability during July

Figure 17: Diurnal Pattern of Wind Energy Availability during August

Figure 18: Diurnal Pattern of Wind Energy Availability during September

Figure 19: Diurnal Pattern of Wind Energy Availability during October

Figure 20: Diurnal Pattern of Wind Energy Availability during November

Figure 21: Diurnal Pattern of Wind Energy Availability during December

Table 5 Possible P50 PLFs in TN

Aralvoimozi Senkotta Khambam Palakkad All TN

Jan 25% 14% 15% 14% 19%

Feb 18% 10% 11% 11% 14%

Mar 12% 7% 7% 8% 10%

Apr 11% 5% 5% 6% 8%

May 34% 18% 23% 21% 27%

Jun 47% 26% 36% 37% 41%

Jul 46% 25% 36% 38% 41%


Aug 40% 22% 30% 32% 35%

Sep 33% 18% 23% 21% 26%

Oct 21% 10% 12% 11% 15%

Nov 16% 9% 11% 12% 14%

Dec 26% 14% 17% 17% 21%

Conclusions

It is seen that the wind power output when one considers average values across the state of Tamil Nadu follows a predictable pattern. There can be large seasonal fluctuations certainly predictable and sensible amounts of power can be expected from wind power plants. There are of course some sharp changes that may occur over a day but these effects can be captured by a well established collective forecasting and scheduling system. The idea is depending on the monthly demand and monthly wind energy availability can be factored into the energy mix.

One of the basic refrain in allowing unconditional grid access to Wind power is the intra-day variations which are allegedly difficult to handle. For example, the variations

during windy seasons could be about 4000 MW to 800 MW over a period of seven to eight hours. If we consider a mid value of say 3000 MW the variations will be in the range of ±1000 MW. It does not appear to be very large. However, invariably this drop is quoted as a variation of 3200 MW. If a deemed capacity of 3000 MW is assigned to wind power for that month, variations are considered about that value, half the problem is already solved.

If collective forecasts are made and scheduled first to check out the science behind presently practiced forecasting techniques without attaching difficult to manage financial implications, it is perfectly possible to make scheduling wind power meaningful for all stakeholders including wind power producers.

The methods established in this study can be repeated for other windy states so that we will have a much better understanding of the magnitude of the issues pertaining to wind power absorption on the grid. At this time the knee jerk reactions to an overrated problem situation is not permitting determination of logical or effective solutions that are acceptable to all stakeholders.

RERC: Wind Tariff Order for FY 2015-16Generic Tariff for Wind Power Plants getting commissioned during FY 2015-16

S. No.

Particulars

Tariff ('kWh) if

AD benefit is not

availed

Tariff ('kWh) if AD

benefit is

availed 1 Wind Power

Plants located in Jaisalmer, Jodhpur & Barmer districts

5.74 5.14

2 Wind Power Plants located in districts other than Jaisalmer, Jodhpur & Barmer districts.

6.02 5.39

Creation of National GridA nationwide synchronous power grid, interconnecting all the five regional grids, has been established with the commissioning of 765kV S/c Raichur – Sholapur line on December 31, 2013. POWERGRID is strengthening its

Sn

ipp

ets

on

Win

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ow

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transmission network to establish inter-state and inter-regional links for enhancing the capacity of National Grid in a time bound manner to ensure optimal utilization of uneven distribution of energy resources. As on December 31, 2014, National Grid with inter-regional power transfer capacity of about 46,450 MW has been established. The inter-regional power transfer capacity is envisaged to be augmented to about 72,250 MW by the end of the XII Plan (2016-17).

Source: Ministry of Power, Govt. of India

MPERC: RPO Regulation AmendmentMPERC has proposed draft amendments to its Cogeneration and Generation of Electricity from Renewable Sources of Energy Regulations 2010. Below are the proposed targets.

Financial Year

Cogeneration and other Renewable Sources of Energy

Solar (%) Non Solar (%) Total (%)

2015-16 1.00 6.00 7.00

2016-17 1.25 6.50 7.75

2017-18 1.50 7.00 8.50

2018-19 1.75 7.50 9.25


Green Energy Corridor - The Need of the Nation

O.P. Taneja Associate Director, IWTMA, New Delhi

India has been on the gradual increasing path of power generation from renewable resources. Major thrust had been on wind and hydro Power generation. With the launch of National Solar Mission in 2010, solar generation has also taken a lead. Various policies, regulatory and fiscal incentives have accelerated development of renewable energy (RE) generation. Due to such initiatives, large capacity addition though renewable generation is envisaged. Boost is expected much faster as the government, has extra focus of generation through renewable sources.

Some of the states have abundant renewable energy resources, while others do not have. In case of large scale renewable generation, it is not possible to absorb the energy within the state, particularly during other than peak hour conditions.

Transmission system is required to be planned for integrating renewable generation with the state grid as well as with the inter-state grid. Integrated planning approach would ensure that renewable generation does not have to be backed down during scenario other than peak demand period and local load centers are provided with uninterrupted supply even when renewable generation is not available.

The transmission systems for Renewable Energy Sources (RES) are not stand alone and require to be integrated with state grid and/or regional/national grid depending upon quantum of power to be transmitted. The conventional grids face difficulty in absorbing renewable electricity because of its varying voltage and supply. The planned transmission system would be made dynamic to handle the variations leading to an integrated grid across the nation.

Key Challenges in absorbing RE Power in the System

² Intermittency & variability impacting Grid stability

² Implementation of transmission network matching with the RE generation

² Technical issues like Reactive Power management, Real Time Grid operation, etc.

² Economic viability of the transmission system due to low Capacity Utilization Factor (20-30%)

Mitigating Measures

² Strong grid interconnections to enlarge balancing areas

² Forecasting of renewable generation on different time scale

² Energy Storage: Large scale (like pumped hydro) for balance of power, fast acting storage for stability

² Load Management & Demand Response

² Dynamic Reactive Compensation (SVC/STATCOM) at strategic locations

² Wide Area Monitoring System (WAMS) establishing Smart Grid

² Establishment of Renewable Energy Management Centers (REMC) integrated with SCADA/control centers

After many deliberations MNRE and Forum of Regulators/CERC have entrusted POWERGRID the job of comprehensive study including identification of transmission infrastructure capacity additions of RE based power mainly from wind, solar and mini hydro.

Studies included identification of transmission infrastructure for renewable.

Capacity addition of RE in 8 states: Tamil Nadu, Karnataka, Andhra Pradesh, Maharashtra, Gujarat, Himachal Pradesh, Jammu & Kashmir and Rajasthan including the estimation of capex requirement, strategy framework for funding and speedy renewable power development.

The project popularly known as the Green Energy Corridor Project is an upcoming project which aims at synchronizing electricity produced from renewable sources, such as solar and wind, with conventional power stations in the grid.

The whole project has been divided into two parts:

1. Inter State: To be developed by state utilities

2. Intra State: To be developed by Power Grid Corporation of India (PGCIL)

In addition to above, the substantial work needs to be undertaken on other related infrastructure like dynamic reactive compensation, energy storage, smart grid applications, forecasting of renewable generation, real time monitoring, establishment of renewable energy management centre, electric vehicles, investment etc.

It also covers perspective plan for integration of renewables by 2030.


The Map below shows “Prospective transmission plan for RE by 2030”.

Power grid presented the outcome of the studies in the report entitled “Green Energy Corridors” covering all the aspects as mentioned above. The report has been finalized after discussion with MNRE/Planning Commission, Ministry of Power, CEA, CERC, State entities and other concerned departments. This report is the first of its kind in our country which will provide a momentum to large scale integration of renewable paving the way for clean energy development.

“Green Energy Corridor” report is one of the most appreciable efforts as the renewable energy sector is coming into increasing focus in the context of climate change vis-à-vis concern on energy security.

Germany, who has expertise in making smart grids that integrate renewable energy into national grid, will be assisting India in this project.

With an intention to encourage the increased use of renewable energy in India through technical as well as financial cooperation, the Government of Germany and the Government of India (GoI) expressed their intention to support the evacuation of renewable energy by strengthening the power transmission infrastructure in India.

Both governments signed a Joint Declaration of Intent on the occasion of the second Indo-German Government Consultations in Berlin, Germany, on 11th April 2013.

Estimated investment requirement for development of above infrastructure would be about Rs. 43,000 Crore.

Cost Estimation

Entire transmission system strengthening has been categorized into following:

1. Intra State Transmission strengthening including last mile connectivity of RE farms to nearest Point of Common Coupling (PCC) in STU network.

2. Inter State Transmission strengthening including last mile connectivity of RE farms (=>50 MW) to nearest Point of Common Coupling (PCC) in ISTS Network

3. Provision of Dynamic Reactive Compensation (STATCOM etc.) to provide dynamic voltage support

4. To facilitate real time monitoring of the state of grid, installation of synchrophasor technology i.e. PMU/PDC and fibre optic communication links between PCC and control centres have been proposed.

5. Provision of Energy Storage technology to provide instantaneous power balance

6. To facilitate forecasting of wind and solar generation, coordination with RE generator control centres, SLDC/RLDC/NLDC, control of RE generation etc., to begin with setting up of Renewable Energy Management Centre(REMC) at the Renewable (Wind/solar) rich States.

Estimated cost of above proposed scheme and the same is as below:

• Intra State transmission system strengthening: Rs. 20,466 Cr (for all States) incl. last mile connectivity

• Inter State transmission system strengthening: Rs. 18,848 Cr including last mile connectivity to ISTS

• Dynamic Reactive Compensation: Rs 568 Cr

• Real Time Monitoring System (PMU/PDC) including Fiber Optic Communication links): Rs. 451 Cr.

• Energy Storage: Rs. 2000 Cr.

• Establishment of Renewable Energy Management Centre: Rs. 224 Cr.

Total Cost: Rs. 42,557 Cr. Say Rs. 43,000 CR.

Government of Germany has come forward for financial cooperation to support Green Energy Corridor project under Indo German bilateral development cooperation with total commitment of Euro 750 million. This soft & cheap loan will be given to Powergrid and to the participating states as per agreement signed by the stakeholders on Dec. 17, 2014.

(Inputs from Powergrid Reports, presentations and other sources)


Know Your Wind Energy State - Rajasthan - A Snapshot

Compiled by Mr. Nitin Raikar, Suzlon Energy Limited, Mumbai([email protected])

Topography & ClimateState brief:

Rajasthan is a north westerly state of India and covers an area of 132,150 sq mi or 342,239 km². It lies between 26.45°N Latitude & 73.30° E Longitude. It is bound on the west and northwest by Pakistan, on the north and northeast by the states of Punjab, Haryana and Uttar Pradesh, on the east and southeast by the states of Uttar Pradesh and Madhya Pradesh, and on the southwest by the state of Gujarat. The main geographic features of Rajasthan are the Thar Desert and the Aravalli Range, which runs through the state from southwest to northeast, for more than 850 km. About three-fifths of Rajasthan lies northwest of the Aravallis, leaving two-fifths on the east and south. The northwestern portion of Rajasthan is generally sandy and dry and most of the region is covered by the Thar Desert, The climate of Rajasthan can be divided into four seasons: summer, monsoon, post-monsoon and winter. Summer extends from April to June, and is the hottest season, with temperatures ranging from 32°C to 45°C.

Overall Power Scenario(as of 31 Mar 2015 & figures in MW)

Total installed capacity (all energy sources) 16228.69

Thermal (Coal+Gas+Diesel) 9625.75

Nuclear 573.00

Hydro 1643.69

RE Capacity (Grid connected) 4386.25

Peak Demand (April 2014 - March 2015) 10642.00

Peak Met (April 2014 - March 2015) 10642.00

Deficit (April 2014 - March 2015) 0%

Wind Resource(as on 31st Mar 2015)

Installable Potential as per CWET Wind Atlas

5005 MW at 50m Hub Height/5050 MW at 80m Hub Height

Total Nos of established Wind Monitoring stations and data recorded by CWET

48

Number of operational wind stations

13

Stations with WPD > 200 W/sq m Extrapol./ Measured at 50 m

8

Windy Districts Jaisalmer, Barmer, Jodhpur, Pratapgarh, Sikar

Wind Statistics(as of 31 Mar 2015)

Cumulative installed capacity (MW) 3307.20

Govt Demonstration Projects (MW) 6.35

Private & PSU Sector Projects (MW) 3300.85


State Ranking # 4th

% of Wind Installations w.r.t. all energy sources

20.38%

% of Wind Installations w.r.t. RE sources 75.40%

Green Statistics(Data as of 31 Mar 2015)

Million tones of CO2 emissions offset by Wind power projects in the state (p.a)

~7.1 million tonnes

Million tones of Coal savings by Wind power projects in the state (p.a)

~5.20 million tonnes

No. of Households tentatively powered ~2.0 million homes

Wind Policy - Salient features

Feed in Tariff (Sale to EB)

Case 1: If Higher dep availed then, Rs 5.14 per unit flat (WEGs commissioned for the year 2015-16) - Jaisalmer, Barmer & Jodhpur Districts & Rs 5.74 per unit for other districts.

Case 2: If Higher dep not availed then, Rs 5.39 per unit flat (WEGs commissioned for the year 2015-16) - Jaisalmer, Barmer & Jodhpur Districts & Rs 6.02 per unit for other districts.

HT Industrial Tariff (for captive)

Net set off Tariff will be Rs 5.50

HT Commercial Tariff (for captive)

Net set off Tariff will be Rs 7.45

PPA/WBA Tenure 25 years

Transmission & Distribution charges (for captive)

4.2% : For the supply using distribution network of distribution licensee 132 kV or above

8% (3.8%+4.2%) : For the supply using distribution network of distribution licensee for 33KV

16.8.%(4.2%+12.6%) : For the supply using both EHV transmission & distribution system for 11KV

Banking Charges 2% (But banking is permissible on monthly basis only) upto 10% max

Fixed Charges (for captive)

Rs 148.91/KW/Month for the year 2014-15 as per the rated capacity of WTG. Variable as per RERC tariff orders annually

Wheeling Charges (for captive)

Rs 0.01 per unit (applicable for 132kV and above level consumers)

Rs 0.11 per unit (applicable for 33kV level consumers)

Rs 0.32 per unit (applicable for 11kV level consumers)

Reactive Power Charges

5.75 paisa /kVArh on net KVArh drawl from Grid (Per annum escalation will be 0.25 paisa)

Renewable Purchase Obligation

8.2% (Non Solar)for FY 15-16

APPC rate for REC trading (prevailing)

JVVNL (Rs 3.086 per unit), AVVNL (Rs 3.134 per unit), JdVVNL (Rs 3.0780 per unit),

Regulatory Agencies & State Utilities

Govt. Nodal Agencies Rajasthan Electricity Regulatory Commission (RERC) Rajasthan Renewable Energy Corporation Limited (RRECL)

State Utilities Rajasthan Rajya Vidyut Utpadan Nigam Limited (RVUN) Rajasthan Rajya Vidyut Prasaran Nigam Limited (RVPN) Ajmer Vidyut Vitran Nigam Limited (AVVNL) Jaipur Vidyut Vitran Nigam Limited (JVVNL) Jodhpur Vidyut Vitran Nigam Limited (JDVVNL)

Miscellaneous Factoids

Project Commencement Year

The first wind power project was a demonstration project set up by the Govt. of Rajasthan in Jaisalmer in Apr 2000. The Project had a cumulative installed capacity of 2.0 MW and comprised of 8 X 250kW turbines of BHEL-NORDEX make.

Key References : CERC, CEA, MNRE, RERC & Internal Records

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Photo FeatureMedia Familiarizing Trip to Wind Farm Sites

To familiarize the media persons about the wind energy, IWTMA has taken 15 media persons from various publications to site visit to wind farms and the sub-stations near Coimbatore on 17th and 18th July 2015. The reviews and reports that appeared highlighted the wind energy sector and introduction of wind-solar hybrid.

Media at Suzlon 1.25 MW wind millMs. Asha Bajpai, AGM, Corporate Communications, Suzlon making presentation about wind energy to media at Suzlon, Bogampatti Site Office

Sri Madhusudan Khemka, Chairman, IWTMA and Sri D. V. Giri, Secretary General, IWTMA interacting with media persons

Media at Gamesa Pethappampatti-110/33KV Sub-Station Visit to Regen Wind – Solar Hybrid Farm

2.8 MW Regen Wind TurbineGamesa 2.00 MW Wind Turbine Looking Inside the Tower of a Wind Turbine


14th Green Power Conference and Exposition on Renewable Energy Technologies 2015CII-Godrej GBC had organized 14th edition of “Green Power Conference and Exposition on Renewable Energy Technologies” on 2 & 3 July 2015, at Hotel ITC Grand Chola, Chennai. Indian Wind Turbine Manufactures Association took active part in the Conference and Exhibition. The event deliberated on important issues connected with the renewable energy sector. The Association members were the part of the panels in various sessions.

Panel members in discussion at the Session on Central & State Policies & Regulation on 3rd July 2015

IWTMA Members Meeting 24th July 2015 held at New Delhi

Delegetes at the Knowledge ForumMr. Jorn Gerlach and Mr. Phubade from DEWI OCC, Dr. S. Gomathinayagam, DG, NIWE and Mr. D.V. Giri, Secretary General,

IWTMA at the Inaugural of the Knowledge Forum

Sri Madhusudan Khemka, Chairman, IWTMA speaking at Regional Interactive Meeting organized by MNRE at Chennai on 31st July 2015

Panel members in discussion at the Session on Opportunities and Challenges in Policy and

Regulation of Wind Energy sector on 3rd July 2015

Knowledge Forum on “Recent Trends in Wind Turbine Testing, Validation and Certification”IWTMA in partnership with UL-DEWI, DEWI – OCC and NIWE (CWET) had organized Knowledge Forum on the captioned subject on 29th July 2015 at NIWE auditorium, Chennai.


Know Your Member

Printed by R.R. Bharath and published by Dr. Rishi Muni Dwivedi on behalf of Indian Wind Turbine Manufacturers Association and printed at Ace Data Prinexcel Private Limited, 3/304 F, (SF No. 676/4B), Kulathur Road, Off NH 47 Bye Pass Road, Neelambur, Coimbatore 641062 and published at Indian Wind Turbine Manufacturers Association, Fourth Floor, Samson Towers, No. 403 L, Pantheon Road, Egmore, Chennai 600 008.

Editor: Dr. Rishi Muni Dwivedi

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LM Wind Power India started production of 13.5 meter blades in 1995 at a plant in Hosakote. Today, the company operates from Dobaspet near Bangalore and makes 48 meter blades suitable for 2 MW turbines. During 20 years, LM Wind Power has made important contributions to develop the Indian wind industry, reducing cost of energy and make wind energy mainstream.

Hemkant Limaye is Commercial Director of LM Wind Power India and is responsible for sales, marketing and business development activities. Hemkant has been with the company for the past eight years and in between worked in the Americas region to develop LM Wind Power’s local customer base.

He has over 19 years of working experience with reputed multinational companies handling various roles in Key Account Management, Business Development and Product Management.

Hemkant holds an MBA in Marketing and a Bachelors degree in Mechanical Engineering.

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Registered with REGISTRAR OF NEWSPAPERS for India, New DelhiVide No. TNENG/2015/60605 Date of Publishing : 31.07.2015

June - July 2015

volume: 1 issue: 4 june - july 2015 10/- magazine wrapper - june issue - … · power...

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