Cle lean Coal Technology (C (CCT CT) Training Program FY2019 - - PowerPoint PPT Presentation

Cle lean Coal Technology (C (CCT CT) Training Program FY2019 under CEA and JCOAL Cooperation

Annepu Suresh Director (Thermal Planning & Project Development) Central Electricity Authority Ministry of Power

Outline

• Generation and demand scenario in the country
• Imperative - Stable, reliable and sustainable electricity
• Policy and regulatory measures
• Technical issues which need to be addressed
• CCT Visit schedule
• Findings from the visit
• Way ahead

Capacity and Generation in 2018-19

All ll In India ia In Installe led Ca Capacity 2018 2018-19 19

Hydro, 45399, 12.75% Coal/Lignite, 200705, 56.36% Gas, 24937, 7.00% Diesel , 638, 0.18% Nuclear, 6780, 1.90% RES, 77642, 21.80%

3,56,100 MW

Gross

• ss Elect

Electricity Gener eneration in in In India ia 2018 2018-19 19

Hydro 134894 GWh 9.83% Coal 1022265 GWh 74.52% Gas 49834 GWh 3.63% Diesel 212 GWh 0.02% Nuclear 37813 GWh 2.76% R.E.S. 126800 GWh 9.24%

13,71,817 GWh

*

Demand supply position

12.2 11.2 11.7 12.3 13.8 16.6 11.9 12.7 9.8 10.6 9 4.5 4.7 3.2 1.6 2 0.8 0% 2% 4% 6% 8% 10% 12% 0% 2% 4% 6% 8% 10% 12% 14% 16% 18% PEAK DEFICIT / SURPLUS ENERGY DEFICIT/ SURPLUS

Peak met = 175,528 MW Energy availability =1,267,526 MU

Plant Load Factor (Coal and Lignite)

52.40 53.20 56.50 55.00 56.50 53.90 55.30 57.10 61.00 60.00 63.00 64.40 64.70 64.60 67.30 69.00 69.90 72.20 72.70 74.80 74.30 76.80 78.60 77.20 77.68 74.97 73.47 70.13 65.56 64.25 62.24 59.88 60.72 10 20 30 40 50 60 70 80 90 1985-86 1986-87 1987-88 1988-89 1989-90 1990-91 1991-92 1992-93 1993-94 1994-95 1995-96 1996-97 1997-98 1998-99 1999-00 2000-01 2001-02 2002-03 2003-04 2004-05 2005-06 2006-07 2007-08 2008-09 2009-10 2010-11 2011-12 2012-13 2013-14 2014-15 2015-16 2016-17 2017-18 PLF (%) Years

Sig Signif ific icance of PLF is is decre reasin ing

Energy mix in future

Hydro 2,68,859 12% Coal+Lignite 12,38,906 56% Gas+Diesel 86,182 4% Nuclear 1,10,696 5% RES 5,18,000 23%

Hydro Coal+Lignite Gas+Diesel Nuclear RES

Hydro 1,55,742.0 9.16% Coal+Lignite 10,71,801.0 63.05% Gas+Diesel 82,626.0 4.86% Nuclear 62,643.0 3.69% RES 3,27,000.0 19.24%

Hydro Coal+Lignite Gas+Diesel Nuclear RES

Mar arch, , 2022 2022 IC= IC=4,79,419 MW MW Gen=16,99,812 GWh Gen=22,22,643 GWh Mar arch, , 2027 2027 IC=6 IC=6,19,066 MW

Emerging scenario

Supply ly sid ide

• Share of installed capacity of RE in energy mix has increased from 9% in 2010 to 20% by 2018. It

will constitute 37% and 44% of generation mix in 2022 and 2027, respectively.

• Variability of RE and flexibilization of TPPs.

De Demand sid ide

• Growing adoption of distributed energy resources by end customers including roof top solar, RE

sources connected at distribution and sub-transmission voltage levels. These resources are largely ‘uncontrollable’ by system operators even at the state level.

• Novel uses of electricity (e.g., for electric vehicles, battery charging), can also increase demand

uncertainty.

Policy and regulatory measures

Thrust areas Intended Nationally Determined Contribution @ COP21

• India intends to reduce the emissions intensity of its GDP by 33 to 35 % by 2030 from 2005

level.

• To achieve about 40 percent cumulative electric power installed capacity from non-fossil fuel

based

• Introducing new, more efficient and cleaner technologies in thermal power

generation - Future planned projects based on super, ultra supercritical or advanced ultra supercritical technology

• To reduce emissions from Thermal Power Stations new environmental norms in

December 2015 regarding Suspended Particulate matter (SPM), SOx, NOx, Mercury introduced

• Norms for specific water consumption by Thermal Power Stations have also been

notified to conserve water.

Policy and regulatory measures

Thrust areas

• Retirement of old and inefficient units (8,670 MW retired in last 3

years and 10,159 MW identified for retirement by 2022).

• Programme for replacement of old and inefficient units.
• Policy for blending of Biomass (`5%).
• Mandatory usage of treated waste water in TPPs located within

50kms of STP.

• ACQ per MW entitlements for all thermal power plants, irrespective
• f their age or technical parameters, shall be calculated based on

Normative Station Heat Rate with upper ceiling of 2600 kcal/kwh.

Policy and regulatory measures

Other areas

• Flexibility in Generation and Scheduling of Thermal Power Stations to

reduce emissions.

• Flexibility in utilization of domestic coal for reducing the cost of generation
• Security Constraint Economic Dispatch –under implementation.
• Real Time Market for power dispatch –under consideration of regulator.
• Reserve Regulation Ancillary Services, DSM, DAM, etc.
• All such power plants including private generators which do not have PPAs,

shall be allowed Coal linkage for a period of minimum 3 months up to a maximum of 1 year.

Technical issues

• Share of Non-fossil fuel installed capacity to increase to 47% by 2022 which will

contribute around 20% of the Total Energy Requirement.

• Coal power plants need to have enhanced ramping capability
• Minimum technical limit for Coal power plants may have to be revised downward.
• Limited availability of Hydro, Pumped Storage & availability of Gas for Gas based

Station.

• Total coal requirement may be around 730-800 MT in 2021-22.
• Coal quality issues
• FGD retrofit is difficult in many of the older stations due to space constraint and
• ngoing R&M
• Sustained supply of Coal for daily generation
• Waste handling - Ash and gypsum disposal

Expectations from coal fired plants

Higher ramping rates during loading/unloading Faster Startup Lower stable minimum load Frequent & increased load cycling Fast load ramp up and ramp down Low load operation Two shift operation Frequent and increased number

• f unit startup &

shutdown cycles Reduced effect on life of Equipment Minimal impact on environment

CCT Visit Schedule

• Kick off meeting with JCOAL on 14.10.19 at 1015 hrs at Tokyo
• A presentation on Isogo Thermal Power Station of J-Power on 14.10.19 at 1400 hrs at

Tokyo

• Visit to Toshiba Head Office on 16.10.19 from 0830 hrs to 1030 hrs at Kawasaki
• Visit to NEDO on 16.10.19 from 1045 hrs to 1215 hrs at Kawasaki
• Visit to Hibikinada Biomass Co-fired TPS on 17.10.19 from 0930 hrs to 1200 hrs at

Kitakyushu

• Visit to Reihoku Coal fired TPS of Kyushu EPCO on 18.10.19 from 1300 hrs to 1600 hrs at

Kumamoto

• Visit to MHPS Head Office on 21.10.19 from 0900 hrs to 1045 hrs at Yokohama
• Visit to Data Analysis Centre of JERA on 21.10.19 from 0900 hrs to 1045 hrs at Yokohama
• Wrap-Up Meeting on 21.10.2019 at 1500 hrs at TKP Shimbashi Conference Center, Tokyo.

Some captivating pictures from Japan

Reihoku: Entrance Reihoku: Turbine Floor

Some captivating pictures from Japan

Reihoku: Coal yard Hibikinada: BTG

Findings from the visit

• Government policy in Japan for necessary installation of FGD and SCR

in all thermal power plants for emission control and reduction.

• Notification of area-wise norms of SOx and NOx emissions in

consultation with local bodies and limits under the overall ambit of national policy.

• Efforts are being put in further reduction of other emissions (CCS).
• Use of biomass to the extent possible in coal fired plants.
• Insights into coal, ash and gypsum handling – salability and

disposability.

Findings from the visit

• Project execution at Isogo TPS serves as a model example for

replacement and upgradation projects.

• Novelty in operations – receipt of crushed coal, imported biomass,

and erection of coal silos. (Hibiki-nada co-gen plant)

• High standards of quality followed in construction of plants.
• The good practices of O&M were visible in man, material and plant

management.

• Stations like Reihoku are able to achieve flexibility in operations by

ramping down to 15% of rated capacity on an intraday basis. The station showed ramp rates of 4%.

Findings from the visit

• Project execution at Isogo TPS serves as a model example for

replacement and upgradation projects.

• Novelty in operations – receipt of crushed coal, imported biomass,

and erection of coal silos. (Hibiki-nada co-gen plant)

• High standards of quality followed in construction of plants.
• The good practices of O&M were visible in man, material and plant

management.

• Stations like Reihoku are able to achieve flexibility in operations by

ramping down to 15% of rated capacity on an intraday basis. The station showed ramp rates of 4%.

Findings from the visit

• Manufacturers like MHPS provide solutions for entire gamut of efficient

emission control technologies along with remote monitoring services.

• Digital transformation solutions in the energy field provided by Toshiba

help in coal management, optimized load distribution, maintenance planning, fuel optimization, abnormality detection, equipment diagnosis, plant modernization etc.

• Digital transformation solutions are also available in areas as Smart use of

renewable energy, virtual power plant, plant maintenance using digital twin and efficient sophisticated maintenance.

• Currently companies in Japan are working on technologies for Energy

storage and Hydrogen energy.

Other observations

• Japan has nuclear and thermal plants for base load and Gas plants for peak
• load. The intermittent RE issue is addressed with ample gas stations and

flexible operation.

• Adequate supply of good quality coal and gas.
• High quality plant equipment leading to smooth and comfortable
• peration.
• Quality wise class of boiler insulation, valve condition, overall house keeping, CHP

conveyor system, coal mill condition is excellent.

• Inventory and supply chain
• Inventory of coal: 50% of yard capacity i.e. 0.2MT for 2x700 MW.
• Capacity of OEMs to supply quickly.
• Minimum no. of spares kept.

Other observations

• Unit overhaul of BTG is for a period of 100 days at intervals of 3 years.
• Plant maintenance is once in two years.
• Plant safety aspect

– Non dependence on SAP/MAXIMA and usage of manual systems. – OSHA and ANSI compliant safety aspects like gratings, zebra painting, fire system followed.

Resourceful CCT interventions

• Coal Resources Exploration and Development
• Exploration, mining, safety and preparation
• Coal handling and processing
• Crushing, transportation and storage
• Coal Gasification and Liquefaction, De-ashing and Reforming Technologies
• Coal utilization
• Coal fired power generation technologies
• Combustion Technologies
• Gasification Technologies
• Co-production Systems
• Environment countermeasures
• Flue Gas Treatment and Gas Cleaning Technologies
• Technologies to Effectively Use Coal Ash
• CO2 Recovery Technologies

Way ahead

• Planning for flexibilisation issue at boiler design stage.
• Revisiting and revamping existing O&M practices.
• Integration and differentiation – ownership, responsibility, supply,
• peration and maintenance, disposal.
• Address realization gap from concept to creation.

Thank you