FGD and DeNOx
NEWSLETTER

January 2020
No. 501

 Table of Contents

REGULATORY

·         Trump Backs Trillion Tree Initiative

MARKETS

·         U.S. Coal-fired Power Generation will be Shrinking but Is Still Important

·         Coal-fired Power Generation Capacity will increase by Less than 1% Per Year

·         Coal-fired Power and FGD moving forward in the Philippines

INDUSTRY NEWS 

• Pace of Retirements of U.S. Coal Capacity Will Slow

• Dry Sorbent Injection with Hydrate Lime Can Make Coal Plants More Cost Effective in the U.S.

• Greek Court cancels Permit for proposed Coal Plant

• Enforcement action Launched Over One of Eskom’s Coal Plants

• Indian Ministry of Power Proposes Yet Another Pollution Deadline Extension

• B&W Subsidiary Awarded Retrofit Boiler Equipment Installation Contract for U.S. Power Plant

• Expert Microsystems receives Award from the US Department of Energy for Hybrid Analytics Solution to improve Coal-fueled Power Plant Operations

• FGD Program making progress in India

• MIT compares Chinese SO2 CEMS  to Satellite Sata

• Coal-fired Plants Around New Delhi Running Despite Missing Emissions Deadline

• Thermax Wins Rs. 431 Crore Order for Two Flue Gas Desulfurization (FGD) Systems

• Babcock & Wilcox Announces Renewal of Maintenance Contract for New Mexico Power Plant

• B&W Subsidiary to Supply Sootblowers for Power Plants in Asia

• MHI and Hitachi Dissolve MHPS Partnership

• Siemens to Equip Bajaj Energy Plant in India with Digitalization Solutions

• Indonesian Power Plant Will Operate with Advanced Air Pollution Controls meeting Chinese Standards

• EES Acquires Novinda’s Amended-Silicate Technology for Mercury Control from Utility & Industrial Power Plants

REGULATORY

Trump Backs Trillion Tree Initiative

 President Trump on January 21  announced the United States will join the One Trillion Trees Initiative. Trump made the announcement during an address to global business leaders gathered for the annual event in Davos, Switzerland. "We're committed to conserving he majesty of God’s creation and the natural beauty of our world," Trump said, adding that the U.S. "will continue to show strong leadership in restoring, growing and better managing our trees and our forests.”

 At the 4000-megawatt Drax plant in the UK biomass is being burned as a replacement for coal.  Furthermore, the utility is funding a sequestration program with the goal of permanently encapsulating CO₂ underground. 

 When you combine the trillion-tree initiative and biomass combustion and sequestration you have a program to actually reduce CO₂ not just avoid emitting more. This means that there is no tipping point beyond which there is no potential for carbon reduction. It is a good bet that our views on climate change will be considerably different 20 years from now than they are now.

 If it turns out that the impacts of elevated CO₂ levels are even worse than now anticipated the combination of planting, biomass combustion, and sequestration is even more important.  If it turns out as it did in the case of dioxins where the harm was vastly overestimated or ulcers where the true cause turned out to be a virus then there is a flexible program  which will respond appropriately. Here are the impacts on CO₂ levels of the various technologies. 

So, the flexible program incorporates additional tree planting until equilibrium is reached. Then dying trees are substituted for fossil fuels. If more reduction is needed, sequestration of the bIomass combustor emissions is undertaken

In 2006, the Billion Tree Campaign was launched, by the (UNEP) as a response to the challenges of global warming,

The Billion Tree Campaign was handed over to the Plant-for-the-Planet Foundation in December 2011, an organization that has been participating in the Billion Tree Campaign since 2007. In December 2017, following the discovery that there are more than three trillion trees on Earth, the planting target was revised to a trillion trees and the Billion Tree Campaign became the Trillion Tree Campaign.

One estimate found that this amount of trees would cancel out the last 10 years of CO₂ emissions and sequester 160 billion tons of carbon. However, ^the intergovernmental panel on climate change is even more positive. They estimate that one trillion trees  will store an estimated 205 billion tons of carbon, or about two-thirds of the carbon that humans have added to the atmosphere since the 1800s.

The problem with this approach is that 30 years from now in 2050 there will be lots of trees dying and emitting CO₂. However, at that time the biomass can be harvested and burned in power generators. If the 500,000 MW of new coal-fired capacity, which is built is designed to be biomass ready, it can be converted making each of the generators carbon neutral. If this CO₂ is then sequestered, these generators would be as the UK describes it “sucking the CO₂ out of the air.” They would be the only generator type which actually reduces CO₂.

What are the costs?  The continuation of the coal-fired power program would net a savings of $7.2 trillion over 30 years.  This saving would primarily be in a few Asian countries. The tree planting program would cost $700 billion resulting in a $6.5 trillion saving over the 30 years. For the period 2050-2080 the coal-fired power plants would be converted to burn biomass and if necessary, also sequester CO₂. Sequestration would raise costs of electricity generation and make this approach relatively more costly but only after 2050. Since biomass combustion and sequestration is the only CO₂ reduction option it can be employed if necessary. 

In 2050 these biomass ready coal-fired power plants would have already served their purpose as coal generators. Their conversion to biomass would ensure that the forestation approach is sustaining in terms of CO₂ minimization. However, if there are major improvements in the cost of wind and solar and no need to reduce CO₂ the plants could be retired. But since they would be the only alternative for dealing with dying trees, they will continue to be utilized.

Another option is to convert these plants to biomass combustion at an earlier date. There is optimism that the cost of sequestration can be greatly reduced through programs underway at Drax and other locations. If some of the most pessimistic forecasters are right and climate change becomes a crisis, then the biomass generation and sequestration becomes the only route to solve the problem since it reduces CO₂.

The present CO₂ level is 410 ppm. But a massive tree planting program could have the effect of reducing CO₂ by more than 1 ppm per year. The net effect would be a 390 ppm CO₂ level in 2050.  

After 2050 solar and wind will be more cost effective particularly if energy storage methods advance. The need for new coal-fired plants will cease but there will be other sources with the potential to add 20 ppm to the atmosphere in the 2050-2080 timeframe.

In 2050 there will be a very large quantity of fuel contained in elderly trees. They can be harvested and burned as fuel. The biomass would replace coal in existing boilers. They would  not emit CO₂ to the atmosphere if there is sequestration. New trees which replace the old trees will continue to remove CO₂.So, this initiative would more than offset man-made sources and the CO₂ level could drop to 380 ppm in 2080.

CO₂ sequestration has been commercially practiced for decades. One use has been enhanced oil recovery. CO is being piped long distances in many areas. Presently it is economic only if it has a use such as recovering oil. The UK believes that new carbon capture technologies will drive down the cost over the coming years. But whether it is inexpensive or expensive the situation is manageable in 2050 due to the ability to suck out the CO₂. This control provides flexibility. It will allow construction of coal fired plants in India, the Philippines, Indonesia, Bangladesh, and Vietnam and still achieve climate change goals.  

MARKETS

U.S. Coal-fired Power Generation will be Shrinking but Is Still Important

The U.S. will continue to operate lower cost coal plants which can compete with natural gas. U.S. coal consumption is likely to decline sharply again in 2020, though the current list of planned and completed coal plant retirements suggests that there will be fewer retirements than in 2019.

At 13,703 MW, 2019 marks the highest level of annual coal capacity retirements in the U.S. since 2015, a new S&P Global Market Intelligence analysis of federal data shows. The amount of coal capacity planned for retirement in 2020 is expected to exceed the amount retired in each of 2014, 2016 and 2017. Another retirement has already been announced.

Tri-State Generation and Transmission Association Inc. said Jan. 9th that it was closing its 247-MW Escalante power plant in New Mexico by the end of 2020. Since 2014, U.S. power generators retired nearly 62,000 MW of coal-fired generation capacity, with another 26,947 MW of retirements teed up through 2025.

Morgan Stanley & Co. LLC forecast in a December 2019 report that about 70,000 MW to as much as 190,000 MW of coal-fired generation is "economically at risk" from the deployment of a "second wave of renewables" in the U.S. The research firm said these projections exclude about 24,000 MW of coal generation already set to shut down.

"We believe that carbon-heavy utilities that have not historically led the pack in clean energy deployment will accelerate their earnings growth by pursuing a 'virtuous cycle': shutting down expensive coal plants and investing in cheap renewables," the analysts wrote.

This statement has to be viewed in the context of timing. The U.S. coal fired plants are all 35 to 70 or more years old.  By 2050 they will be 75 to 100 years old. Who would deny that a 100-year-old plant is not going to be as economical as a new one whether it be gas, or coal?  Relative to comparison with solar and wind the assumption is that there will be improvements.  What about coal?  China says coal can be both cost effective and environmentally competitive.  They have a program to make coal plants as  green as gas plants with conversion to ultra-supercritical  combustion and zero liquid discharge.

There will continue to be capacity retirements but at a slower pace than in previous years. The retirements are throughout the country but less so in the Midwest than the two coasts.

Regional retirements have been compiled by S&P 

Cumulative retirements from 2014 through 2020  will be in excess of 60,000 MW or 10,000 MW per year. 

Earlier retirements were mostly small old plants without FGD and SCR. Plants to be retired in the next six years include larger plants with FGD and SCR as well as particulate  upgrades.  But for example, Sherburne County constructed one of the first FGD systems around 1970.  All of the plants are much older than the average plant in China or even Japan where replacement has taken place.

Coal-fired Power Generation Capacity will increase by Less than 1% Per Year

IEA issued a report on December 19^th predicting that global coal demand is expected to decline in 2019 but remain broadly stable over the next five years, supported by robust growth in major Asian markets, according to the International Energy Agency’s latest market analysis and forecasts.

The weakness in coal demand this year results mainly from coal-fired electricity generation, which is set to experience its largest ever decline – over 250 terawatt hours (TWh), or more than 2.5 percent. This drop is led by double-digit falls in the United States and Europe, according to Coal 2019, which contains forecasts through 2024.

It is too soon to say whether the expected global decrease in coal power generation this year will be the start of a lasting trend. The IEA forecasts that renewable sources will supply a major portion of the increase in global electricity demand over the next five years. Electricity generation from coal will rise only marginally over that period, at less than 1 percent per year — and its share will decline from 38 percent in 2018 to 35 percent in 2024. This means coal remains by far the single largest source of power supply worldwide.

Ultimately, global trends will depend largely on China, where half of the world’s coal is produced and consumed.

In Europe and the United States, coal power generation is sinking to levels not seen in decades. Growth in solar PV and wind, low natural gas prices and stagnating electricity demand have created a perfect storm for coal in both regions, where coal plants retirements continue to take place. These trends will continue through 2024, although the speed of the declines is expected to slow unless coal comes under additional pressure from stronger climate policies or lower-than-expected natural gas prices.

“Wind and solar PV are growing rapidly in many parts of the world. With investment in new plants drying up, coal power capacity outside Asia is clearly declining and will continue to do so in the coming years.

Demand continues to expand in Asia. The region’s share of global coal power generation has climbed from just over 20 percent in 1990 to almost 80 percent in 2019, meaning coal’s fate is increasingly tied to decisions made in Asian capitals.”

The report highlights that countries in South and Southeast Asia—such as India, Indonesia and Vietnam—are relying on coal to fuel their economic growth. Natural gas and oil have traditionally been the main sources of power generation in Pakistan, but the country has commissioned 5 gigawatts (GW) of coal power capacity since 2017, and another 5 GW is set to come online in the next few years. In Bangladesh, where natural gas has long generated the bulk of electricity supply, coal will gain share in the coming years, with 10 GW of capacity in the pipeline.

In 2019, global coal power generation will experience the biggest drop ever and coal power generation in India will probably decline for the first time in 45 years. The global picture, however, has not changed much. Coal is disappearing in many advanced economies, but it remains resilient and is even continuing to grow in developing Asia. The low coal power generation in India this year was due to unusually low growth in electricity demand and exceptionally high hydropower output. It is not at all clear that it will be repeated.

S.E Asia:  Coal demand in Southeast Asia is forecast to grow by more than 5 percent per year through 2024, led by Indonesia and Viet Nam. The region’s strong economic growth will drive electricity and industrial consumption, which will both be fueled in part by coal. South Asian countries are also in need of more electricity supply for the growing populations, and they are often turning to coal to provide it. Pakistan has recently commissioned over 4 GW of new coal power plants, with similar capacity under construction. Bangladesh is about to commission the first unit of the 10 GW it has in the pipeline.

China: This country is the world’s biggest coal producer and consumer. Consumption will plateau around 2022 according to IEA. Stronger-than-expected electricity consumption and infrastructure development have pushed coal use up in the last few years. In the  forecast, the decline of coal use in the residential and small industrial sectors continues because of air pollution concerns. Coal use in heavy industry also drops, driven by structural changes in the economy as well as macroeconomic conditions in the coming years. The  forecast sees coal power generation growing, although at a slowing rate. Its share of the power generation mix is expected to fall from 67 percent in 2018 to 59 percent in 2024. Overall, coal demand in China plateaus by 2022 and then starts to decline slowly. The trajectory outlined above remains subject to the policies and targets that will be included in the Chinese government’s 14th five-year plan (which will be released in 2020). Future coal demand will potentially be affected by the government’s economic growth objectives as well as its policies on nuclear power, wind and solar, and coal conversion projects. While reducing air pollution and CO₂ emissions will be policy priorities for China, coal is expected to continue play an important role in sustaining economic growth and guaranteeing energy security.

United States: The shale gas boom is coal’s undoing. The federal government and some coal-producing states still provide support for coal power plants, yet coal’s destiny in the United States continues to be determined by the shale gas revolution. Cheap and abundant natural gas combined with the climate policies of many states will continue to squeeze coal out of the electricity market. In the  forecast, US coal demand declines by almost 4 percent per year over the forecast period. Coal’s share in electricity supply, which had been as high as 50 percent in 2007, declines from 28 percent in 2018 to 21 percent in 2024. The decline in production is a bit lower because of the resilience of exports. But the collapse of the European market and the lack of export infrastructure on the West Coast limit future prospects.

South Africa:  The government’s Integrated Resource Plan has brought broad clarity for the future of the country’s energy sector, but other uncertainties are still hanging over the coal industry. These include the financial difficulties of electricity utility Eskom, changes in coal mine ownership, and the shift away from Mpumalanga, the country’s coal-mining heartland, to other areas. Overall, South Africa’s demand, production and exports are seen as remaining stable through 2024, but the factors mentioned above could change that trend.

Coal-fired Power and FGD moving forward in the Philippines

With the support of President Duarte, construction of coal-fired power is moving ahead in the Philippines. It is expected to provide 50 percent of the energy requirements by 2030. We have published an analysis in the Tracking System and displayed at

http://www.mcilvainecompany.com/utility/subscriber/Profiles/Philippines.pdf,  

We have also published 319 articles in the Utility E-Alert and have referenced some of them at the end of this article.

In addition to coal-fired boilers there may also be construction of waste-to-energy plants. Filipino infrastructure conglomerate Metro Pacific Investment Corporation’s proposal for a P22 billion (US$423 million) waste-to-energy plant is expected to be approved this month in Quezon City, the country’s most urbanized district. The project is expected to convert up to 3,000 metric tonnes of municipal solid waste into electricity each day in a power plant with 36 megawatts of installed capacity.

Relative to FGD, it appears that seawater scrubbing for the large coastal imported coal plants and dry scrubbers for the CFB boilers used for the smaller units will be the primary FGD types. Atimonan, with 2x 600 MW coal-fired boilers, will start up in 2021 with seawater scrubbing.

Here are the CFB units in the Visayas Grid. The TVUl started up in 2019 whereas the other plants have been in operation for some years.

The full display of  power plants for Visayas, Mindanao and Luzon are displayed at the following links.

http://www.mcilvainecompany.com/PDF/existing_power_plants_visayas_june_2019.pdf

http://www.mcilvainecompany.com/PDF/existing_power_plants_mindanao_june_2019.pdf

http://www.mcilvainecompany.com/PDF/existing_power_plants_luzon_june_2019_002.pdf

The San Buenaventura Power Plant will be the first supercritical generation plant in the Philippines. The plant is located in Mauban, Quezon, and will supply power to the Luzon grid. It is owned by San Buenaventura Power Ltd (SBPL), a partnership between Meralco PowerGen Corp. and New Growth BV. Meralco is the largest electric distribution company in the Philippines, while New Growth BV is a subsidiary of Thailand-based Electricity Generating Public Co. The San Buenaventura plant will have state-of-the-art emissions control technology, an electrostatic precipitator for fly-ash capture and removal, and a seawater FGD.

Threatened by looming energy insecurity and with industries dependent on fossil fuels, coal remains the prime power generation source for electrification in the Philippines. It’s the only country in Asia that gained a 1-gigawatt increase in power sourced from coal in 2019, which now accounts for 43 percent of the national energy mix. Given new investments, coal’s share of the pie will reach 50 percent in 2030.

The Philippines has a population of about 100.7 million, making it the 12th most populous country in the world. The World Bank estimated GDP growth at 5.9 percent in 2015 and 6.8 percent in 2016, ranking the Philippines as one of the strongest-performing Southeast Asian countries.

The government’s credit rating has remained stable. The Philippines would replace imported coal used in power generation with local output thanks to increased production from the Visayas and new mines in Mindanao.

The Philippines has 10,423 MW (US$20.8 billion) of largely imported coal expansion in its current pipeline. This runs on top of a total of 900 MW of existing coal-fired capacity. The Philippines imports 15 million tons of coal per year (80 percent of coal requirements), 95 percent of which comes from Indonesia, a source that has not always been reliable.

Of the 316 million tons of Philippine coal said to be economically recoverable, the majority is subbituminous coal and lignite. These types of coal have the least carbon content and thus a heating value that is lower than that of imported coal from Indonesia or Australia. Despite being a significant consumer of coal, the Philippines is a very minor producer, producing an average of 8 million tons in the last 6 years. Because the country produces only low-quality coal—which must be burned in larger amounts than higher-quality coal for the same energy output— and because most of its coal-fired power plants are built for imported coal, the country must continue to import from other countries for its coal needs.

Regarding reliable supply of FGD lime and limestone, it looks as if there will be little limestone used along with some lime. The seawater scrubbers will not need additional reagent. International lime suppliers are moving into the market.

Graymont is completing  the acquisition of the five Sibelco lime plants and a number of limestone quarries on the east coast of Australia, as well as lime plants in Malaysia and the Philippines. “With this transaction, Graymont is well positioned to further expand its reach in the Asia-Pacific,” stated President and Chief Executive Officer Stéphane Godin. “Mr. Godin noted that “wherever Graymont operates, we aim to be the preferred supplier, employer, and partner of choice—and Asia-Pacific is certainly no exception in that respect.”

The Rio Tuba plant is located in Palawan, Philippines and was built by Unichamp Group, It is a $24-million lime manufacturing plant in the Rio Tuba Economic Processing Zone in Bataraza, Palawan. It was completed  in 2015. It is  locked in a 15-year agreement with Coral Bay Nickel Corporation (CBNC) for the supply of lime milk used in metal processing. CBNC is a joint venture company of Rio Tuba Mining and three Japanese shareholders holders: Sumitomo Metal Mining Company Limited, Mitsui Company Limited, and Sojitz. The plant has the capacity to produce 400 metric tons of reconstituted lime milk per day.

Upward Agro Industrial Corporation is a manufacturer of high-quality lime (calcium carbonate), quicklime (calcium oxide) and hydrated lime (calcium hydroxide) for the local market of Negros, the Visayas and the rest of the Philippines. Lime and limestone products are a vital part of national industries in sugar milling, steel manufacturing, energy, environmental services, construction and mining, among others. Upward Agro lime products makes sugar purer. Air cleaner and water clearer. They make steel stronger. They make highways last longer. The company is also  targeting SO₂ capture in power plant scrubbing.

Lime production on Negros Island was almost entirely used for sugar milling in the 1960s. With the industrialization of the Philippine economy and the growth of new industries, lime became essential in the mining, steel, paper, water treatment and other sectors. From a small father-and-son enterprise in the mountains of Negros, Upward Agro Industrial Corporation has since grown to be one of the leading lime manufacturers in the Philippines. The enterprise became incorporated on July 30, 1986. The company today supplies quality lime products across the Philippines and employs over a hundred people.

H.T. Mining Products Resources Corp. is one of the largest and leading lime products suppliers in the Philippines. Its manufacturing facility is situated in a readily accessible area in Barangay Tinandog, Atimon Quezon Province which adjoins the Maharlika Highway. The company produces high quality products such as: limestone, calcium carbonate, agricultural lime, quicklime, hydrated lime, and calcium hydroxide which all carry the brand name "Limpog." It currently operates four (4) kilns and three (3) high tech pulverizers with the total production capacity of 120 tons per day for the local markets as well as export markets catering mainly to steel  manufacturing, chemical manufacturing, construction, agricultural, water and waste treatment, paper industry, phosphate industry, asphalt production, feed and seed distributors, soil stabilization, sugar industry, tanning industry and others.

Here is a list of operating coal-fired power plants in the Philippines. 

The Utility Tracking system contains a database of 900 power generators with 98 percent of the world’s coal generation planned and operating capacity including industrial steam generators. Here is an excerpt from a sort by ranking of planned MW from 2400 down to 2,000 MW.  

The Utility E-Alert can be searched for 319 articles on the Philippines. Here are links to the first 10. 

Sort by relevance/Sorted by date ▼

(1.) UTILITY E-ALERT

...Rule (ACE): Compliance and Innovative Solutions First Supercritical Coal-fired Plant in the Philippines Case Study: How One Utility's Choice of a Control Platform Improved Plant Operation Economic...

Terms matched: - Score: 12 - 6 Dec 2019 -  URL: http://166.62.95.143/utilityalert/subscriber/UtilityE-Alert/2019/UTILITY E-ALERT 1449/utility_ealert_1449_.htm 

(2_ UTILITY E-ALERT

... Close Coal Ash recycling Rate declines amid shifting Production and Use Patterns COAL – WORLD Philippines' First Supercritical Power Plant expands Grid Capacity, ensures stable, cost-effective Power Supply ...

Terms matched: 1 - Score: 33 - 22 Nov 2019 - URL: http://166.62.95.143/utilityalert/subscriber/UtilityE-Alert/2019/UTILITY E-ALERT 1448/utility_ealert_1448.htm 

(3) Untitled 2

... to cut flooding Risk Endesa writes off US $1.6 billion on Spanish Coal Plants Philippines Energy Agency wants broader Tender Terms GAS TURBINES Siemens supplies HL-class Power Island to South ...

Terms matched: 1 -  Score: 21 - 9 Nov 2019 - URL: http://166.62.95.143/utilityalert/subscriber/UtilityE-Alert/2019/UTILITY E-ALERT 1446/utility_e-_alert_1446.htm  

(4.) UTILITY E-ALERT

 COAL – WORLD P56-billion PHL's First Supercritical Coal-fired Power Plant switches on in Quezon, Philippines Eskom ends corruption investigation into New Coal Plants Polish Government narrowly re-elected but loses Senate ... Terms matched: 1 - Score: 29 - 18 Oct 2019 - URL: http://166.62.95.143/utilityalert/subscriber/UtilityE-Alert/2019/UTILITY E-ALERT 1443/utility_ealert_1443.htm 

(5.)UTILITY E-ALERT

... . JGC is a designer of power plant systems with a recent order in the Philippines. It also offers a dry scrubber system which has been successfully employed in Japan ...

Terms matched: 1 - Score: 4 - 4 Oct 2019 - URL: http://166.62.95.143/utilityalert/subscriber/UtilityE-Alert/2019/UTILITY E-ALERT 1441/utility_ealert.1441.htm 

(6)  UTILITY E-ALERT

...about Coal export possibilities COAL – WORLD Royal Cargo delivers heaviest Piece of Cargo for Philippines Power Plant Project AfDB to scrap Coal-fired Power Stations across Africa Polish Coal Mining expansion ...

Terms matched: 1 -  Score: 21 - 27 Sep 2019 - URL: http://166.62.95.143/utilityalert/subscriber/UtilityE-Alert/2019/UTILITY E-ALERT 1440/utility_ealert_1440.htm 

(7) Untitled 2

... Boiler) - Successful Commissioning done of ESP for all the units. QUEZON, Philippines: 1x660 MW Power Plant – ESP – 1 No. of ESP - Successful...

Terms matched: 1 - Score: 5 - 13 Sep 2019 - URL: http://166.62.95.143/utilityalert/subscriber/UtilityE-Alert/2019/UTILITY E-ALERT 1438/utility_e_alert_1438.htm 

(8) UTILITY E-ALERT. its 105-megawatt (MW) coal-fired power plant in Talisayan, Zamboanga City, the Philippines. The SRPI plant's shortlisted EPC bidders are Northeast No.1 Electric Power Construction Co....

Terms matched: 1 - Score: 5 - 6 Sep 2019 - URL: http://166.62.95.143/utilityalert/subscriber/UtilityE-Alert/2019/UTILITY E-ALERT 1437/utility_ealert_1437.htm

(9  UTILITY E-ALERT

... at Iskenderun Power Plant Coal will account for 60 percent of the Power in the Philippines in 2028 GAS TURBINE GE celebrates 25th Anniversary of Its 6F Gas Turbine, secures...

Terms matched: 1 - Score: 33 - 23 Aug 2019 - URL: http://166.62.95.143/utilityalert/subscriber/UtilityE-Alert/2019/UTILITY E-ALERT 1435/utility_ealert_1435.htm 

(10.) UTILITY E-ALERT

... that this project will contribute to the growth expected in the ASEAN region. JGC Philippines Inc. was awarded a lump-sum turnkey basis contract for the Phase II construction work...

Terms matched: 1 - Score: 28 - 9 Aug 2019 -  URL: http://166.62.95.143/utilityalert/subscriber/UtilityE-Alert/2019/UTILITY E-ALERT 1433/utility_ealert_1433.htm

Result Pages: 1 2 3 4 5 6 7 8 9 10 11 Next >>

 INDUSTRY NEWS

Pace of Retirements of U.S. Coal Capacity Will Slow

Since peaking at nearly 318 gigawatts (GW) in 2011, U.S. coal-fired electric generating capacity declined to 257 GW in 2017 after several coal power plants retired. The U.S. Energy Information Administration (EIA) undertook a study with Sargent & Lundy to improve modeling for the Annual Energy Outlook (AEO). The results show the relationship between plant retirements and a plant’s operating and maintenance costs. According to the report, a larger share of plants with higher operating and maintenance costs retired by 2018 than those with relatively low operating and maintenance costs.

In its latest Short-Term Energy Outlook (STEO), released on January 14, the U.S. Energy Information Administration (EIA) forecasts that generation from natural gas-fired power plants in the electric power sector will grow by 1.3 percent in 2020. This growth rate would be the slowest growth rate in natural gas generation since 2017. EIA forecasts that generation from non-hydropower renewable energy sources, such as solar and wind, will grow by 15 percent in 2020 — the fastest rate in four years. Forecast generation from coal-fired power plants declines by 13 percent in 2020. 

Nuclear. Two nuclear plants totaling 1.6 GW are currently scheduled to retire in 2020. Indian Point Unit 2, located in New York, is scheduled to retire in April. Iowa’s only nuclear power plant, Duane Arnold Energy Center, is scheduled to retire in December.

EIA expects 42 gigawatts (GW) of new capacity additions to start commercial operation in 2020. Solar and wind represent almost 32 GW, or 76 percent, of these additions. Wind accounts for the largest share of these additions at 44 percent, followed by solar and natural gas at 32 percent and 22 percent, respectively. The remaining 2 percent comes from hydroelectric generators and battery storage.

 Source: U.S. Energy Information Administration, Preliminary Monthly Electric Generator Inventory

Dry Sorbent Injection with Hydrate Lime Can Make Coal Plants More Cost Effective in the U.S.

Injecting DSI ahead of the SCR and the air heater can lower the SO₃ concentrations enough to avoid maintenance and turn down issues. Injecting enough sorbent further upstream in the flue gas means utilities can lower load and capture waste heat that would typically escape from the stack. This also gives utilities flexibility to run the coal-fired units at a lower load, typically at night, and be more efficient.”

Buckeye Cardinal Unit 2 in Brilliant Ohio initiated this change in 2017. Construction of Cardinal started in November 1963. The project was a joint venture of Ohio Power (a forerunner of AEP) and Buckeye Power. Units 1 and 2 began commercial generation in 1967 at a cost of $131 million. Unit 3 began generation in 1977 after six years of construction at a cost of $220 million. In 2017, AEP and Buckeye Power reached an agreement for Buckeye Power to operate all three units at Cardinal. To  further reduce nitrogen oxide (NO_x) emissions, AEP and Buckeye Power announced in 2001 they would install selective catalytic reduction (SCR) systems to complement their LO-NOx burners at Cardinal. The SCRs would decrease NO_x emissions at the plant from 30 percent to 90 percent. Between 2005 and 2010, flue-gas desulfurization (FGD) systems were installed to all three units at Cardinal with Units 1 and 2 costing $300 million to construct. The FGD equipment reduces sulfur dioxide (SO₂) emissions by 98 percent. A year after it was installed, inspectors found severe corrosion in its tank vessel. AEP negotiated a settlement with Black & Veatch, the contractor who installed the FGD equipment, to address the corrosion. Instead of constructing a new chimney for Unit 3's FGD system, AEP retrofitted a cooling tower to release waste heat into the atmosphere. AEP announced in 2015 that its Cardinal unit will be converted into a natural gas power plant by 2030 in order to comply with EPA standards.

This 590-MW coal unit spent $3 million to modify the system to allow DSI upstream of the SCR. In this case, Buckeye will save more than $1.1 million every year. About a third of that savings is from lowering the unit load by lowering the SCR minimum operating temperature, about half of the savings is from reducing the air heater outlet temperature and improving heat rate, and the rest is money saved on maintenance.

Both sodium and calcium can achieve the reduction to 5 ppm SO₃, but the hydrated lime has proved the most cost effective according to Don Wolf of Burns & McDonnell.

There will be a continuing need for coal-fired power to supplement solar and wind. Also, the low-cost coal plants will continue to operate for a number of years due to economics. Finding ways to lower operating costs such as the hydrate injection ahead of the SCR will extend the life of these plants and ensure that they will not be replaced by gas turbine plants.

Greek Court cancels Permit for proposed Coal Plant

Greece’s Supreme Administrative Court, the Greek Council of State, has cancelled the environmental permits for the Public Power Corporation’s (PPC) proposed 450 megawatt (MW) Meliti II unit and the existing 330 MW Meliti plant. The environmental permits for the lignite-fired plants were challenged by ClientEarth, WWF Greece and Greenpeace Greece which argued that the 2018 decision to issue a ten-year permit for the units without undertaking an environment impact assessment was in breach of both Greek and European Union law. The ruling has been welcomed by environmental groups, but the written judgement is not expected to be issued for several weeks. The ruling means that Meliti II will not proceed while the existing unit will require a fresh permit to continue operating. In December, PPC announced that existing lignite units would be phased out by 2023.

Enforcement action Launched Over One of Eskom’s Coal Plants

In late December 2019 the South African Dept. of Environmental Affairs’ Environmental Management Inspectorate, also referred to as the Green Scorpions, issued a compliance notice to Eskom requiring it to submit a maintenance plan by January 12 to “improve its compliance with the minimum air quality standards” for its 4116 MW Kendal coal plant. In July 2019 Eskom acknowledged that poor maintenance at its plants during 2018 had resulted in increased pollution and that bag filters had failed on four units at the plant. While the department said the timing of the compliance plan rests with Eskom, the government-owned utility is under pressure to close its two most polluting units, with a combined capacity of 1200 MW, and detail what it will do about the other four polluting units. In June 2019 the Centre for Environmental Rights, representing Ground Work and the Vukani Justice Movement in Action, launched legal action against the South African Government over pollution in Mpumalanga region from Eskom’s 12 coal plants, including Kendal, and Sasol’s Secunda coal-to-liquids plant.

Indian Ministry of Power Proposes Yet Another Pollution Deadline Extension

India’s Ministry of Power has proposed extending the December 2019 deadline for compliance with new pollution standards for coal plants in the region around New Delhi. Only one of 11 utilities has met the December 2019 deadline for the installation of flue gas desulfurization units. No enforcement action has been taken against the non-compliant plants, despite extreme pollution levels in the region. The Ministry of Power has proposed that the non-compliant plants should be required to meet the new pollution standards between July 2020 and December 2021.

B&W Subsidiary Awarded Retrofit Boiler Equipment Installation Contract for U.S. Power Plant

Babcock & Wilcox Construction Co., LLC (BWCC), a subsidiary of Babcock & Wilcox Enterprises, Inc. (B&W), has been awarded a contract for more than $5 million to install retrofit boiler equipment at a U.S. coal-fired power plant.

BWCC’s project scope includes the removal and installation of various boiler components, which will allow the plant to continue operating efficiently and reliably for the customer.

BWCC Vice President and General Manager Mike Hidas said, “BWCC operates regional construction offices strategically located across North America that provide valuable assistance for fast turnaround requests. This, combined with our deep project and construction management experience, helps differentiate us from the competition.”

Expert Microsystems receives Award from the US Department of Energy for Hybrid Analytics Solution to improve Coal-fueled Power Plant Operations

The United States Department of Energy, Office of Fossil Energy (DOE) awarded funding to Expert Microsystems, Inc. as part of its funding opportunity DE‐FOA‐0001989 entitled “Improving Efficiency, Reliability, and Flexibility of Existing Coal-Based Power Plants.” The DOE seeks innovative solutions that integrate data analytics and machine learning techniques with physics-based models to improve coal-fueled power plant operations.

As the lead investigator, Expert Microsystem, Inc. will develop, demonstrate, and commercialize a novel approach to improve coal-fired power plants’ ability to follow loads and handle transient behavior by integrating two proven real-time monitoring techniques. The hybrid analytics approach provides a single solution that integrates an established, advanced data-driven analytics solution that includes artificial intelligence, advanced pattern recognition, and machine-learning techniques provided by Expert Microsystems with a well-proven, first-principle thermal heat balance model solution provided by MapEx Software Inc.

Randy Bickford President & CTO of Expert Microsystems notes that, “The future role of coal plants will depend on the ability to cycle power output and follow loads to meet marginal power demands, accommodate renewables and support the grid. Essential to success in this new role is a plant’s ability to maintain high reliability, efficiency and flexibility. However, these changing operational demands put significant stresses on power plant components that directly impact the ability to perform these new requirements. Our innovative Hybrid Analytics solution enhances real-time fault detection, provides automated diagnostics and remaining time to act forecasts, and provides critical, enhanced and accurate real-time information to coal plant operators. As a result, coal plants can improve efficiency, reliability, and flexibility and can cost-effectively maintain their key role in the power delivery system.”

Also supporting Expert Microsystems in the execution of the project is XMPLR Energy LLC.

FGD Program making progress in India

India is falling behind its target dates but is moving forward with as much wet limestone FGD as was installed in the U.S. over several decades. It is also installing more than any other country except China. The total has been expanded this year to 167 GW and 441 units with the target date still 2022 for all units.

The number of FGD systems that have been commissioned is tiny, but the bid and award process is comprehensive.

Bids have been awarded only for 8,000 MW of the 57,000 MW of units 500 MW or larger.

FGD is being accompanied by ESP upgrades and some form of DeNOx as shown for the Delhi area. 

MIT compares Chinese SO₂ CEMS  to Satellite Sata

The Chinese government accelerated implementation of tougher air pollution standards for power plants, with limits to take effect in July 2014. One key standard limited emissions of sulfur dioxide (SO₂), which contributes to the formation of airborne particulate pollution and can cause serious lung and heart problems. The limits were introduced nationwide but varied by location. Restrictions were especially stringent in certain “key” regions, defined as highly polluted and populous areas in Greater Beijing, the Pearl River Delta, and the Yangtze River Delta.

Valerie J. Karplus, an assistant professor of global economics and management at the MIT Sloan School of Management said “ there have been few attempts to look systematically at plants’ compliance with environmental regulation. We wanted to understand whether policy actually changes behavior.”

For China, focusing environmental policies on power plants makes sense. Fully 60 percent of the country’s primary energy use is coal, and about half of it is used to generate electricity. With that use comes a range of pollutant emissions.

To begin their study, the researchers examined changes in the CEMS data around July 2014, when the new regulations went into effect. Their study sample included 256 power plants in four provinces, among them 43 that they deemed “large,” with a generating capacity greater than 1,000 megawatts (MW). They examined the average monthly SO₂ concentrations reported by each plant starting in November 2013, eight months before the July 2014 policy deadline.

Emissions levels from the 256 plants varied considerably. The researchers were interested in relative changes within individual facilities before and after the policy, so they determined changes relative to each plant’s average emissions — a calculation known as demeaning. For each plant, they calculated the average emissions level over the whole time period being considered. They then calculated how much that plant’s reading for each month was above or below that baseline. By taking the averages of those changes-from-baseline numbers at all plants in each month, they could see how much emissions from the group of plants changed over time.

In January 2014 plants were well above their baseline, and by July 2016 they were well below it. So average plant-level SO₂ concentrations were declining slightly before the July 2014 compliance deadline, but they dropped far more dramatically after it.

Based on the CEMS data from all the plants, the researchers calculated that total SO₂ emissions fell by 13.9 percent in response to the imposition of the policy in 2014. “That’s a substantial reduction,” notes Karplus. “But are those reported CEMS readings accurate?”

To find out, the researchers compared the measured CEMS concentrations with SO₂ concentrations detected in the atmosphere by NASA’s Ozone Monitoring Instrument. “We believed that the satellite data could provide a kind of independent check on the policy response as captured by the CEMS measurements,” Karplus  says.

For the comparison, they limited the analysis to their 43 1,000-MW power plants — large plants that should generate the strongest signal in the satellite observations. Patterns in the two measures are similar, with substantial declines in the months just before and after July 2014. That general agreement suggests that the CEMS measurements can serve as a good proxy for atmospheric concentrations of SO₂.

To double-check that outcome, the researchers selected 35 relatively isolated power plants whose capacity makes up at least half of the total capacity of all plants within a 35-kilometer radius. Using that restricted sample, they again compared the CEMS measurements and the satellite data. They found that the new emissions standards reduced both SO₂ measures. However, the SO₂ concentrations in the CEMS data fell by 36.8 percent after the policy, while concentrations in the satellite data fell by only 18.3 percent. So, the CEMS measurements showed twice as great a reduction as the satellite data did. Further restricting the sample to isolated power plants with capacity larger than 1,000 MW produced similar results.

Key versus non-key regions

One possible explanation for the mismatch between the two datasets is that some firms overstated the reductions in their CEMS measurements. The researchers hypothesized that the difficulty of meeting targets would be higher in key regions, which faced the biggest cuts. In non-key regions, the limit fell from 400 to 200 milligrams per cubic meter (mg/m³). But in key regions, the limit went from 400 to 50 mg/m³. Firms may have been unable to make such a dramatic reduction in so short a time, so the incentive to manipulate their CEMS readings may have increased. For example, they may have put monitors on only a few of all their exhaust stacks or turned monitors off during periods of high emissions.

At large, isolated plants in non-key regions, the CEMS measurements show a 29.3 percent reduction in SO₂ and the satellite data a 22.7 percent reduction. The ratio of the estimated post-policy declines is 77 percent — not too far out of line.

But a comparable analysis of large, isolated plants in key regions produced very different results. The CEMS measurements showed a 53.6 percent reduction in SO₂, while the satellite data showed no statistically significant change at all.

One possible explanation is that power plants actually did decrease their SO₂ emissions after 2014, but at the same time nearby industrial facilities or other sources increased theirs, with the net effect being that the satellite data showed little or no change. However, the researchers examined emissions from neighboring high-emitting facilities during the same time period and found no contemporaneous jump in their SO₂ emissions. With that possibility dismissed, they concluded that manipulation of the CEMS data in regions facing the toughest emissions standards was “plausible,” says Karplus.

Compliance with the new standards

Another interesting question was how often the reported CEMS emissions levels were within the regulated limits. The researchers calculated the compliance rate at individual plants — that is, the fraction of time their emissions were at or below their limits — in non-key and key regions, based on their reported CEMS measurements. In non-key regions, the compliance rate at all plants was about 90 percent in early 2014. It dropped a little in July 2014, when plants had to meet their (somewhat) stricter limits, and then went back up to almost 100 percent. In contrast, the compliance rate in key regions was almost 100 percent in early 2014 and then plummeted to about 50 percent at and after July 2014.

The researchers interpret that result as an indication of the toughness of complying with the stringent new standards. “If you think about it from the plant’s perspective, complying with tighter standards is a lot harder than complying with more lenient standards, especially if plants have recently made investments to comply with prior standards, but those changes are no longer adequate,” she says. “So, in these key regions, many plants fell out of compliance.”

She makes another interesting observation. Their analyses had already produced evidence that firms in key areas may have falsified their reported CEMS measurements. “So that means they could be both manipulating their data and complying less,” she says.

Coal-fired Plants Around New Delhi Running Despite Missing Emissions Deadline

Coal-fired utilities around New Delhi were still operating despite threats from the Indian authorities to close them down if they had not installed equipment to cut emissions of sulfur oxides by the end of the year.

Three senior executives at companies operating power plants around New Delhi and facing an end-2019 deadline said they had not received direction on whether they could continue to run the plants having not installed the kit.

Only one out of the 11 utilities in the national capital region had installed the equipment.

India had already extended its December 2017 deadline for its utilities to meet the emissions standards—posing a further challenge to the authorities grappling with the pollution that can cause lung disease and blights air quality.

Officials from India’s Central Pollution Control Board (CPCB), who had threatened a shut down for non-compliance, did not respond to repeated calls and text messages seeking comment.

Reuters reported last month that more than half of India’s coal-fired power plants and 94% of the coal-fired units ordered to retrofit equipment to curb air pollution would likely miss the phased deadlines.

The air quality index for the Indian capital, the worst affected major city, indicated “severe” conditions last week—like most days this winter—a potential risk for even healthy people.

Real-time government data showed both power plants in the country’s largest state of Uttar Pradesh which had a December 31 deadline were operating. In Punjab, Vedanta-owned TSPL units were producing power, as were state-run plants at Ropar and Bhatinda.

Mohammed Shayin, Managing Director at northern Haryana state-run power generator HPGCL said all units other than ones under scheduled maintenance were operational, adding that the utility was “pleading” with federal authorities to extend the emissions deadline.

Private producers such as Vedanta and Larsen & Toubro Ltd argued for yet another extension to the deadline.

L&T-owned Nabha Power Ltd said it was “constrained to shut down both its units due to a delay in extension of timelines by the CPCB.”

Vedanta said it was “confident” that authorities “would take a considerate stand.”

“We shall shut the plant in case we get the directions from the CPCB or the environment ministry,” the company said.

Thermax Wins Rs. 431 Crore Order for Two Flue Gas Desulfurization (FGD) Systems

Thermax Limited has concluded an order of Rs. 431 crore from a public-private joint venture power company to set up two flue gas desulfurization (FGD) systems at their thermal power plant in the state of Jharkhand, India.

The customer will install two units of FGD systems of 525 MW capacity each at their plant, to limit SO_x emissions as per the revised regulations from the Ministry of Environment, Forest and Climate Change.

“The Environment business has had a good run in terms of order intake, and I am happy that we have concluded the year on a high note with this inclusion. It also shows that the implementation of industrial pollution norms has gained momentum in the country, considering that we bagged two large FGD orders within a short span of six months,” said M.S. Unnikrishnan, MD & CEO, Thermax Limited.

The scope of supply includes design, engineering, manufacturing, civil work, construction and commissioning of the FGD systems. The commissioning of the project is scheduled over 30 months.

Babcock & Wilcox Announces Renewal of Maintenance Contract for New Mexico Power Plant

Babcock & Wilcox Enterprises, Inc. announced that its subsidiary, Babcock & Wilcox Construction Co., LLC (BWCC), has received a contract renewal valued at more than $4 million to provide maintenance services for Public Service Company of New Mexico’s (PNM) San Juan Generating Station in 2020.

BWCC will continue to provide a variety of services at the power plant next year, including general plant maintenance, coal pulverizer equipment maintenance and outage support, as it did in 2019.

“We very much appreciate our long-term relationship with PNM and this opportunity to continue to support them,” said Jimmy B. Morgan, Senior Vice President, The Babcock & Wilcox Company. “We’re pleased that our customer has renewed our contract and shown confidence in our services and ability to keep this critical plant operating at peak performance.”

Omni Warner, Director, San Juan Generating Station Plant Manager, said “We’re pleased with the commitment to safety, high level of service and support BWCC has provided us in 2019 and look forward to working closely with them in 2020. BWCC provides a cost-effective approach as PNM continues to transition to a plant closure in 2022.”

BWCC Vice President and General Manager Mike Hidas also expressed his appreciation to PNM for continuing its relationship with BWCC.

“B&W supplied one of San Juan Generating Station’s current boilers, as well as other key equipment,” Hidas said. “We have unmatched expertise and depth of experience to service and maintain our own and competitors’ equipment anywhere in the world. I thank PNM for the opportunity to continue providing our services for its facilities.”

BWCC provides outage services, installation, refurbishment, mechanical repair and maintenance services for a variety of industries, equipment and plant installations, regardless of the original manufacturer.

B&W Subsidiary to Supply Sootblowers for Power Plants in Asia

Babcock & Wilcox Enterprises, Inc.’s Scotland-based subsidiary, Diamond Power Specialty Limited (DPSL), has been awarded two contracts to supply sootblowers and furnace cleaning systems for two coal-fired power plants under construction in Asia. The combined value of these contracts is more than $4 million.

DPSL will design and supply HydroJet^® intelligent furnace cleaning systems and sootblower systems for four boilers. The equipment is scheduled for delivery to the facilities in 2021 and 2022.

“Diamond Power^® boiler cleaning systems are known worldwide as the most advanced and dependable technologies in the industry,” said B&W Chief Executive Officer Kenny Young. “Whether for new-build coal plants like these important projects in Asia, or as replacements and upgrades to existing plants, our Diamond Power subsidiary can supply cost-effective and high-performing boiler cleaning and ash-handling technologies.”

Diamond Power boiler cleaning systems are available in steam/air, high pressure water, and dual-media air heater cleaning configurations. The company’s specialized designs and configurations meet customer needs for precision, reliability and efficiency.

MHI and Hitachi Dissolve MHPS Partnership

Hitachi and Mitsubishi Heavy Industries, Ltd have reached a settlement relating to a transfer of the boiler construction projects in the Republic of South Africa conducted by Mitsubishi Hitachi Power Systems, Ltd, the joint venture company that integrated the respective thermal power generation system businesses of MHI and Hitachi, in conclusion of their discussion.

Hitachi will transfer all of its shares of MHPS (share-holding ratio of 35 percent) to MHI. In addition, Hitachi will recognize settlement money of 200.0 billion yen as a debt for MHI, offset the amount by transferring its credit for a subsidiary of MHPS to MHI at 70.0 billion yen and make a payment of 130.0 billion yen to MHI in March 2020.

Hitachi and MHI will promptly request JCAA (Japan Commercial Arbitration Association) to stop the progress of the arbitration. MHI will withdraw the request for arbitration in JCAA after the completion of the payment and the transfer of shares mentioned above.

MHPS will become a 100 percent subsidiary of MHI and Hitachi will withdraw from management of MHPS. Hitachi will continue to work with MHI on maintenance services of existing thermal power generation plants. Hitachi will acquire ABB’s world-class power grid business in the first half of 2020, and by combining it with Hitachi’s digital technology, Hitachi will provide high-value-added energy solutions globally. In addition, Hitachi will contribute to stabilization of energy supply and realization of decarbonized society by accelerating expansion of energy solutions such as renewable energy, nuclear energy, and distributed power supply.

Siemens to Equip Bajaj Energy Plant in India with Digitalization Solutions

Siemens will equip Lalitpur Power Generation Company Limited (LPGCL), a Bajaj Group company, with advanced digital solutions for its power plant located in Lalitpur, Uttar Pradesh, India.

Siemens will provide a complete thermal twin for the LPGCL coal-fired power plant, enabling improvements in the plant’s performance. Siemens experts, in close collaboration with plant operations team, will provide remote performance monitoring and diagnostics from the recently launched Siemens MindSphere Application Center in Gurgaon. The thermal twin, powered by thermodynamic analysis and machine learning, allows power plant operators to diagnose performance gaps for every asset in the cycle in real time and provides recommendations for improving efficiency. This co-creation approach will assist the plant team in identifying and rectifying performance gaps in a timely manner.

R. S. Sharma, Managing Director, Bajaj Power Ventures, said, “We are delighted to partner with Siemens in our digitalization journey. The digital solutions are aimed at improving power plant performance and optimizing operations. The solutions, once executed, will result in sustainable and efficient power generation.”

“With our advanced digital products and solutions, we are providing customers in India and around the world with the tools to navigate changing market requirements and meet their operational goals,” said Laura Anderson, head of Siemens Gas & Power Services, Controls and Digitalization. “Close collaboration from inside our MindSphere Application Centers enables us to work together with our customers to fully realize the value behind their data.”

Over 90 percent of the coal-fired plants directed to comply with new pollution standards by a December 31 deadline will not have installed the required flue gas desulfurization (FGD) units. The plants have a combined capacity of 14,000 MW. The new standards were first announced in December 2015 with the initial deadline for compliance in December 2017 extended to December 2019 following lobbying from power utilities. The bulk of the plants set to breach the standards are located in the states of Haryana, Punjab and Uttar Pradesh. A further 26,330 MW of coal units have been directed to meet the emission standards by December 2020 and over 64,000 MW in each of 2021 and 2022. To date contracts for FGD units have only been awarded for 35,200 MW of the total capacity.

Indonesian Power Plant Will Operate with Advanced Air Pollution Controls meeting Chinese Standards

Bengkulu will soon complete a long-awaited 2×100 MW coal-fired power plant. A reliable electricity supply will accelerate the province’s economic development and attract investors.

The plant at Sepang Bay, which took three years to build, will go into full operation in February of next year. The total 200 megawatts (MW) capacity will not only power Sumatra’s western province but also nearby isolated regions.

With approximately two million residents, Bengkulu province suffered an acute lack of electricity. The new power plant will guarantee not only a reliable household electricity supply but will also enable investors to start new businesses in the area and accelerate economic growth.

The US$360 million (Rp 5 trillion) power plant project is operated by privately-owned power producer PT Tenaga Listrik Bengkulu (TLB) — a joint venture between PowerChina Resources (PCR), which is a backbone subsidiary controlled by PowerChina, and local heavy equipment distributor PT Intraco Penta (INTA). PCR is the majority shareholder.

The first unit of the plant has already been completed and began to generate electricity in October. The second unit is expected to be fully functional by the end of December. The final COD (commercial operation date) is February 2020. At that time, TLB will supply electricity to state-owned utility firm PLN for the next 25 years.

“We hope all stakeholders will join forces to run and maintain these power plants responsibly so that the people of Bengkulu can benefit from the project,” INTA president director Petrus Halim said during a ceremony at the project site on November 15. He added that the coal plant construction project is part of the Indonesian government’s strategic plans to add another 35.000 MW of power capacity. Bengkulu, a priority region for investment funds, has added Baai Island as a special economic zone.

TLB assures that the project meets official waste-management standards. The company uses advanced technology to control the levels of emission from coal combustion and to prevent toxic coal ash from contaminating the soil and water. The coal for powering the plants is transported by sea instead of by land. This measure is taken to minimize coal ash pollution during transport.

The plant uses a cooling technology that circulates water to absorb heat. This enables more efficient electricity production. The water is taken from the ocean and flushed back into the sea after use because it is not polluted during the process. Contaminated water will be treated and reused in the power plant site, mostly to wash the coal and settle dust.

“The contaminated water never goes out of the site. That means local residents will still have safe groundwater,” said Zul Helmi, one of the power plant’s engineers.

“The first unit of the plant has begun operation at 80 percent capacity, and the pollution from the chimney stack is hardly visible,” said Sun Shuhua, the assistant of the general manager of PCR.

China, which uses coal power extensively, applies stricter air pollution standards and more advanced technology in building power plants than Indonesia does. The two new coal-fired power plants in Bengkulu are being built according to China’s standard, Sun says.

PCR has worked on projects in the Chinese "One Belt, One Road" initiative, which develops infrastructure overseas. From the outset, the Chinese government has fully supported the Bengkulu project.

EES Acquires Novinda’s Amended-Silicate Technology for Mercury Control from Utility & Industrial Power Plants

Environmental Energy Services, Inc. (EES), a privately held clean energy company utilizing innovative chemistry for energy efficiency, air pollution control, and water treatment for utility and industrial power plants announced that it has acquired the exclusive intellectual property rights and all associated assets for Amended-Silicate Technology from Novinda Holdings, Inc.

The acquisition of the Amended-Silicate Technology expands EES’ current line of KLeeNscrub^® mercury mitigation products for wet flue gas desulfurization (FGD) to include plants with dry FGD and circulating dry scrubber technologies. Wet and Dry FGD technologies are used for SO₂ emission control.

Making the announcement, Rick Nowak, President & CEO of EES said, “This acquisition strengthens our existing business by increasing the applicability of our current AQCS products to the power industry as well as expanding our offerings to the waste-incineration, cement, and other industrial power markets.”

Mark Keffer, EVP added “EES is currently discussing projects with several energy facilities interested in safer, environmentally friendly, corrosion-free solutions to mercury control, acid gases, organics and other pollutants from the combustion processes. The newly acquired Amended Silicates technology not only delivers a high level of mercury emissions capture but also preserves the beneficial use of fly ash, demonstrating exceptional SO₃ tolerance besides being less corrosive on the balance of plant equipment.”

FGD and DeNOx Newsletter No. 501