FGD and DeNOx
NEWSLETTER

 

March, 2021
No. 514

 

Table of Contents

 

COAL - US

COAL - WORLD

GAS TURBINE

RECIPROCATING ENGINES

BIOMASS

BUSINESS

 ______________________________________________________________________

 

COAL - U.S.

 

Titan America's Separation Technologies Introduces New Fly Ash Reclamation Process

 

Separation Technologies (ST) York Haven, PA, has commissioned the world's first industrial scale fly ash drying and electrostatic separation plant to reclaim fly ash from surrounding coal ash impoundment basins. Located at Talen Energy's Brunner Island Steam Electric Station, the pilot facility combines ST's new proprietary drying and screening system with ST's long proven electrostatic separation process for removing unburned carbon from fly ash for use in concrete construction. Removing the unburned carbon improves the performance of the fly ash in concrete and transforms it from an unusable waste product into a desired and marketable building material. The ST fly ash reclamation process yields two end products, branded as ProAsh® and EcoTherm®.

The combination of ST technologies at Brunner Island allows for ash harvested from the surrounding basins to be converted into ProAsh® and EcoTherm®, without relying on high temperature combustion of the residual carbon. This exclusive technology not only provides sustainable materials to the cement, ready-mix concrete, and power industries, but is also a desirable beneficiation solution for the cleanup and remediation of fly ash landfills and ponds and their surrounding communities.

 

"Fly ash pond and landfill reclamation represents the future of the supplementary cementitious materials industry," says Tom Cerullo, President of Separation Technologies. "ST is proud to announce this important milestone in our 25th year of history developing industry-leading solutions for the construction material and power generation sectors. This advancement now can be widely deployed as part of Titan Group's commitment to sustainable business practices, CO2 reduction, and the development of environmentally responsible products."

 

ST has enjoyed a collaboration with Talen Energy, beginning with the first commercial installation of a fly ash beneficiation facility at its Brandon Shores generation facility in 1999. The relationship expanded with the installation of a second beneficiation facility at Brunner Island in 2006. ST has processed and marketed five million tons of ProAsh® over 21 years onsite at Talen Energy facilities. ST's electrostatic processors have been employed at other North American utilities and across eight countries to produce a consistent, high quality fly ash with a lower CO2 footprint when used in concrete as compared to Portland cement. With the addition of the new drying and screening technology and by responsibly harvesting and processing the ash from basins, ST will continue its work to create greener, more environmentally friendly spaces for neighboring communities.

 

"This breakthrough achievement represents Titan America's commitment to the reduction of CO2 through innovation as we plan to deploy this technology across the power generation and construction material sectors," says Bill Zarkalis, President & Chief Executive Officer of Titan America, LLC. "By harnessing the power of this technology, ST is utilizing a revolutionary beneficiation process that is capable of converting reclaimed ash from ash basins in an efficient manner. The result is a high-grade, low carbon construction product and a fuel-rich product for power generation and cement manufacturing."

 

ProAsh® is an ASTM C 618 compliant product, and currently is being used by Titan America and external customers in ready-mix concrete, reducing its environmental footprint in the process. ProAsh® offers an important mechanism for carbon reduction, as each ton of fly ash utilized in ready-mix concrete offsets a comparable quantity of Portland cement and the carbon emissions associated with its manufacture. When used in concrete, the addition of fly ash has been proven to enhance performance by increasing the strength and durability of concrete and is viewed as an environmentally friendly solution for LEED (Leadership in Energy and Environmental Design) certified projects. 

 

EcoTherm® provides not only fuel value, but also chemistry to the raw mix needs in Portland cement manufacturing. Cement manufacturers are able to generate the same high-quality cement clinker, but with reduced carbon intensity and consumption of natural resources. ProAsh® and EcoTherm® allow for large quantities of fly ash to be beneficially reused while meeting the federal guidelines on encapsulation of CCR materials.

 

"Talen Energy is pleased to work with Separation Technologies on this pilot ash beneficiation process," says Scott Blair, Vice President – Major Projects. "There are substantial advantages in the beneficial use of ash in the concrete industry."

 

ST operates fly ash separation systems under the brand name, ProAsh®. ST is a subsidiary of Titan America LLC (http://www.titanamerica.com), a leading heavy building materials producer in the eastern United States. Titan America is headquartered in Norfolk, VA and its products include cement, aggregates, ready-mixed concrete, concrete products, and fly ash. Its parent company, Titan Cement International S.A. (www.titan-cement.com), headquartered in Brussels, Belgium, is a participant of the UN Global Compact, the world's largest corporate sustainability initiative, based on companies' commitments to implement universal sustainability principles and to support the UN goals.

 

Dominion to Close Three Coal-fired Power Plants by 2030

 

Dominion Energy South Carolina has released a revised 15-year plan in which it proposes to close its three coal-fired power plants in the state by 2030 and add up to 2,000 MW of solar and up to 900 MW of battery storage by 2048. Its original plan proposed keeping one coal unit operating until 2071. The original plan was challenged by the Sierra Club and rejected by the South Carolina Public Service Commission (PSC). The revised plan submitted to the PSC proposes closing the 660 MW Williams Station and the 772 MW Wateree Station by 2028 and the conversion of the 417 MW Cope Station to gas generation by 2030. All three plants are located in majority Black communities. The Sierra Club welcomed the commitment to close the polluting coal-fired power plants but described the proposed investment in a gas plant as short-sighted. The decision comes as the Mississippi Public Service Commission has ordered Mississippi Power to file a revised long-range plan to consider the potential closure of the two coal-fired units at the 1097 MW Victor J. Daniel Jr. Plant.

 

NIPSCO to Retire Two Units at R.M. Schahfer Plant This Year

 

Northern Indiana Public Service Company will retire two units with a combined capacity of 1,096 MW at the R.M. Schahfer plant by the end of 2021. The units were previously slated to close in 2023.

 

"As we continue to evaluate the economics of our generating fleet and the ongoing costs and investments required to keep the coal units operational, we determined that the right path forward for us is to initiate the retirement of two of the four coal units at Schahfer," NiSource Chief Strategy and Risk Officer Shawn Anderson said on the company's fourth-quarter 2020 earnings call. "Units 14 and 15 will retire by the end of 2021, which is the most economic decision for our customers." Units 14 and 15 provide about 903 MW of operating capacity, according to S&P Global Market Intelligence data.

 

In 2020, Schahfer was supplied coal by Peabody Energy Corp.'s Gateway Mine and North Antelope Rochelle Mine, and from Thunder Basin Coal Co.'s Black Thunder mine. NIPSCO will file its 2021 integrated resource plan with the Indiana Utility Regulatory Commission in the fourth quarter, which will provide a clearer picture of its long-term generation plans, company management said.

 

"With the current events that are going on across the industry right now, it just starkly demonstrates that reliability and capacity are essential and the integrated resource planning process itself is critically important," NiSource President and CEO Joseph Hamrock said on the earnings call. "So, that's why our approach really starts with reliability and balances all the other attributes against that fundamental requirement."

 

NiSource held its earnings call as an historic cold snap swept across the U.S., knocking about 45 GW of generation offline in the Electric Reliability Council of Texas Inc., which operates most of the state's power grid.

 

NIPSCO is focusing on a combination of wind, solar and storage capacity to replace its coal generation. About $1.8 billion to $2 billion in renewable energy investments will be added to NiSource's rate base by the end of 2023 as the company transitions its generation fleet.

The company also will pursue about $1 billion in tax equity partnerships through 2023 as it pursues a mix of joint ventures and power purchase agreements to replace retired capacity. NiSource's larger $10.5 billion capital plan through 2024 includes investments of $1.9 billion to $2.1 billion in 2021.

 

NiSource plans to finance its growth plans with a combination of annual equity and debt offerings, as well as a common equity block issuance of $500 million to $700 million in 2022 or 2023.

 

"I would just note that we continue to look at ways to optimize the financing of our growth strategy," NiSource Executive Vice President and CFO Donald Brown said on the call. "We are currently evaluating scenarios utilizing hybrids and/or convertibles that get 50% or more equity credit with the rating agencies and could minimize the need for [the] block equity offering in 2022 or 2023."

 

The company plans to execute a convertible or hybrid financing in 2021, which would help clarify the amount of equity still needed to be issued, the CFO said.

 

COAL – WORLD

 

Valmet to Supply Automation to Kapar Energy Ventures’ Power Plant in Malaysia

 

Valmet will deliver automation to Kapar Energy Ventures’ power plant in Malaysia. The order was placed by Valmet’s local partner Pestech Technology Sdn. Bhd. who will be responsible for the complete upgrade of the distributed control and turbine control systems at Kapar Energy’s Unit 3.

 

The order was included in Valmet’s orders received of the fourth quarter 2020. The value of the order will not be disclosed. The systems will be commissioned in spring 2022.

 

“The delivery marks a new milestone for Pestech Technology and Valmet for its Valmet DNA Automation System in Malaysia. This is a breakthrough for us as a local engineering company to undertake such a large coal-fired power plant (CFPP) project. It will be the first Valmet DNA Automation System to be installed in a CFPP’s complete plant-wide distributed control system and turbine governor control system in Malaysia. This opportunity will provide us with future growth potential in the country and region,” says Puvanesvaran, Sales Director, Pestech Technology Sdn. Bhd.

 

“Pestech Technology has established a strong presence in Malaysia as Valmet’s value-added reseller for automation systems. The company has delivered over ten distributed control system projects based on Valmet DNA technology to Malaysia. We see high potential in expanding our automation system business in the power generation and process industries in cooperation with Pestech Technology not only in Malaysia but also in other South East Asian countries,” says Kari S. Heikkilä, Director, Partner Business, Automation, Valmet.

 

Valmet’s total scope of delivery includes Valmet DNA Automation System hardware and licenses, a turbine control system, a turbine protection system, master fuel trip software & hardwired system, turbine supervisory instruments, operator training simulator hardware and a performance calculation application.

 

Kapar Energy Ventures Sdn. Bhd. is a subsidiary of Tenaga Nasional Berhad (60%) and Malakoff Corporation Berhad (40%). It is the second largest thermal power plant in Malaysia with a generating capacity of 2,200 megawatts.

 

Pestech Technology Sdn. Bhd. delivers power plant automation and electrification solutions and railway system work in close cooperation with international original equipment manufacturers.

 

Mitsubishi Withdraws from Vinh Tan Coal-Fired Power Project in Vietnam

 

Mitsubishi Corp. has decided to withdraw from the Vinh Tan 3 coal-fired power plant project in Vietnam amid growing international concern about climate change, Nikkei has learned.

The project is separate from the Vung Ang 2 coal-fired power plant, which the governments of Japan and Vietnam are pursuing together. Environmental activist Greta Thunberg has called for the cancellation of Vung Ang 2.

 

Vinh Tan 3, planned for Binh Thuan Province in southern Vietnam, is scheduled to come online in 2024. The 2-gigawatt plant is expected to feature cutting-edge ultra-supercritical technology.

OneEnergy, a joint venture of Mitsubishi and Hong Kong's CLP group, holds a 49% interest in the $2 billion project. State-owned Electricity of Vietnam owns another 29%. Chinese companies are handling materials procurement, construction, and equipment delivery.

 

The banking consortium behind Vinh Tan 3 includes Industrial and Commercial Bank of China. Standard Chartered and HSBC have pulled financing from the power plant.

Unlike Vung Ang 2, Vinh Tan 3 is not a national project, and the start date for construction has already been delayed, making it easier to bow out.

 

This marks Mitsubishi's first time withdrawing from a coal plant project. The trading house has said it will not build any new facilities of this type after Vung Ang 2. It plans to contribute to development on power projects that are less harmful to the environment, including liquefied natural gas and renewables such as solar.

 

First Phase of Telangana Super Thermal Power Project in India to be Commissioned in the 2021-2022 Financial Year

 

The first phase of the 2,400 MW Telangana Super Thermal Power Project (TSTPP) comprising two units of 800 MWs taken up by NTPC Ramagundam, is all set to be commissioned in the 2021-2022 financial year.

 

Disclosing this to the media at NTPC Ramagundam on Thursday, NTPC Chief General Manager Sunil Kumar said the project works were progressing in full swing after overcoming the hurdles caused by the outbreak of coronavirus and subsequent lockdown.

 

Stating that 85 percent of power generated at the TSTPP would be utilized by Telangana State, he said the company was confident of commissioning both the units during the 2021-2022 financial year.

 

With regard to the second phase of the TSTPP, he said the project was at discussion level, but was confident of executing it soon after completing all the formalities. The coal for the TSTPP would be supplied from the Mandakini coal block in Odisha and tapering linkage from Singareni for 6.85 million tonnes per annum. Sripada Yellampalli project would supply 2 tmc of water for the thermal power project, Sunil Kumar said.

 

Bangladesh Likely to Scrap Plans For Nine Coal Plants

 

A meeting chaired by Bangladesh’s Secretary of Power, Habibur Rahman, has reportedly agreed to scrap nine proposed coal plants with a combined capacity of 7,461 MW. The proposed 1,320 MW Moheskhali, 1,320 MW Ashuganj (Patuakhali) and 1,200 MW Uttarbanga plants are all likely to be excluded from the government’s revised power development plan. Two further coal plants, the 700 MW plant proposed by a Singapore–Bangladesh joint venture and the 1,200 MW Matarbari plant proposed by the Power Generation Company Bangladesh and Mitsui are also likely to be dropped from the plan. A further four private sector projects, which have not progressed despite being approved earlier, will also be scrapped. The decision has been driven by the poor viability of coal plants reliant on imported coal and growing public opposition to the health impacts of coal plant pollution.

 

Hamon Has Order For Two 1,000 MW Seawater Scrubbers

 

Hamon was selected for the design and delivery of one of the biggest seawater flue gas desulfurization systems worldwide for two 1,000 MW ultra-supercritical units of the Tanjung Jati B 5&6 power plant. The first unit of the entire plant has entered commissioning phase. 

Wet flue gas of the FGD system is 3,300,000 Nm3/h per unit. The unique design of seawater intake basin was confirmed by real model 1:10. 

 

Upon completion, Tanjung Jati B will become one of the biggest thermal power stations in Indonesia with a total installed capacity of 4,640 MW. 

 

Tanjung Jati B 5&6 expansion project includes two new high-efficient ultra-supercritical thermal power generator units in the area adjacent to Tanjung Jati B thermal Power Plant (units 1 to 4) in Central Java, Indonesia. 

 

Construction on the 2 GW re-expansion project started in March 2017. 

 

Construction Resumes at Indonesian Coal-fired Power Plant

 

Construction of a new 400 MW coal-fired power plant in Indonesia's Aceh regency has resumed after being halted early last year because of the Covid-19 pandemic.

 

The $600 million project is being developed by a consortium composed of China Datang Overseas Investment, Indonesian state-owned construction firm Pembangunan Perumahan's subsidiary PP Energy and power services company Sumberdaya Sewatama. It is scheduled to be completed in late 2023 and begin commercial operations in 2024. The power plant is expected to consume at least 1.2 million t/yr. of coal, 90-pc of which will be sourced from Kalimantan on Indonesian Borneo.

 

Construction was halted in March last year because of the pandemic, with PP Energy submitting a force majeure notification to state-owned transmission and generation firm PLN. The project was originally scheduled for completion in 2021 but has been delayed by land issues and other legal constraints.

 

Construction work is expected to accelerate over the next two years as Indonesia starts to recover from the Covid-19 pandemic, PP Energy said. The plant will operate as a baseload facility and help to alleviate electricity shortages in the Aceh Jaya, west Aceh, southwest Aceh and Nagan Raya areas.

 

The project is part of the Indonesian government's 35 GW power generation program. It will operate as an independent power producer with a 25-year supply contract starting from its commercial operation date under a power purchase agreement between PLN and the consortium partners.

 

Turkish Plant Cancelled

 

After a six-year campaign by a coalition of NGO groups, the Environmental Impact Assessment process for the proposed 1,200 MW Kahramanmaras Anadolu power station in Turkey’s Elbistan region has been cancelled by the Ministry of Environment. The original environmental assessment for the project was withdrawn by Anadolu Enerji in 2015, due to opposition from the local community. In late 2017 the company resubmitted a new assessment, but this too was found to be inadequate by the state water agency because of the plant’s impact on irrigated agriculture. The assessment process was restarted in June 2019, but the company has now abandoned the project.

 

Draft Chinese Policy Pitches Mandating Big Jump in Renewables Purchases

 

A draft National Energy Administration policy proposes that Chinese power companies should be required to increase purchases of clean energy generation from 28.2 percent in 2020 to 40 percent by 2030. The draft policy proposes that purchase of non-hydro renewables, largely wind and solar, would increase from 10.8 percent in 2020 to 25.9 percent by 2030 as part of a plan to realize President Xi Jinping’s pledge to make China “carbon neutral” by 2060. According to the latest Global Energy Monitor data, China built 38,400 megawatts (MW) of new coal-fired power capacity in 2020 and has up to 247,000 MW of new coal power projects in various stages of development.

Study Estimates Indian Coal Power Could Stall if Renewable Targets Met 

A new report by Ember, a climate think tank, estimates Indian coal power generation could stagnate or even fall from the current level between now and 2030. The group estimated that even if electricity demand is increasing at between four and five percent a year, coal generation could decline if the Indian Government achieves its wind and solar generation targets.

In 2020, India generated 118 terawatt hours (TWh) of electricity from wind and solar generation, well short of its 2021–22 target of 274 TWh from 175,000 MW of capacity. The official target for 2029–30 is for 793 TWh from 450 GW of renewables capacity. The report estimates it is possible India’s on-grid coal capacity could peak within five years assuming old coal-fired power plants slated for retirement close, and no new capacity is built beyond those plants already under construction.

BECCS Now an Integral Part of Climate Change Strategies

 

Bioenergy with carbon capture and storage—better known by the acronym “BECCS”—has come to be seen as one of the most viable and cost-effective negative emissions technologies.

Even though they have yet to be demonstrated at a commercial scale, negative emissions technologies — typically BECCS —are now included by climate scientists in the majority of modeled “pathways” showing how the world can avoid the internationally agreed limit of staying “well below” 2°C of global warming since the pre-industrial era.

 

Put simply, without deploying BECCS at a global scale from mid-century onwards, most modelers think we will likely breach this limit by the end of this century.

 

But where did the idea for this “savior” technology come from? Who came up with it? Who then developed and promoted the concept?

 

Continuing their week-long series of articles on negative emissions, Carbon Brief has looked back over the past two decades and pieced together the seminal moments – the conferences, the conversations, the papers – which saw BECCS develop into one of the key assumed options for avoiding dangerous climate change.

 

The interactive timeline above shows these moments in sequential order. But Carbon Brief has also spoken to the scientists who were instrumental to the concept first taking hold…

 

A history of BECCS is shown at https://www.carbonbrief.org/beccs-the-story-of-climate-changes-saviour-technology

 

Drax Looking at 'Coal-Free Future' as it Reveals £83m Pre-Tax Loss 

 

The operator of the UK’s largest power station has seen its share price slide after it posted a pre-tax loss of £83m in the first half of the year. The sliding share price came due to a loss in value of its coal assets after the government set a target to phase out use of the fossil fuel for power generation by 2025, alongside a £65m loss from currency hedging. However the company said it improved its earnings from renewables in the form of biomass power generation at its three converted former UK coal power units, reports BusinessGreen.

 

Around 68 percent of Drax’s UK power output now comes from biomass generation. Earnings from Drax’s biomass and coal power plant rose to £136.7m in the first half of this year, from £85.8m in the same period last year, The Times reports. Dorothy Thompson, Drax’s chief executive, revealed the company had submitted a planning application to convert one of its three remaining coal-fired units to gas. However, Carbon Pulse notes the firm has as it shelved testing on a fourth coal-to-biomass conversion until next summer. Drax also announced it has appointed David Nussbaum, former chief executive of the World Wide Fund for Nature in the UK, to its board, the Financial Times reports. The Telegraph also has the story.

 

This story appears on the Carbon Brief website.

 

Carbon Brief is a UK-based website covering the latest developments in climate science, climate policy and energy policy. The claim is We specialize in clear, data-driven articles and graphics to help improve the understanding of climate change, both in terms of the science and the policy response. We publish a wide range of content, including science explainers, interviews, analysis and factchecks, as well as daily and weekly email summaries of newspaper and online coverage.” https://www.carbonbrief.org/about-us

 

More Coal-fired Power Plants for Java

 

Two new coal-fired power plants, PLTU 9 and 10, are being constructed in northwestern Java to provide an additional 2,000 MW of installed electricity capacity in Indonesia. The new units are being constructed by Indonesia Power, a subsidiary of state-owned utility PLN. Jakarta-listed Barito Pacific Group and KEPCO, South Korea’s biggest utility, together retain a 49% stake in the project.

 

Seven coal-fired units already operate in Suralaya, with one other located in nearby Bojonegara village. The eight facilities, with a combined capacity of 4,025 MW, burn coal day in and day out to feed demand for power in the nearby capital, Jakarta, and its densely populated periphery.

Residents complain the cluster of eight existing coal-fired power plants in the area have already caused problems with public health, agriculture, and water pollution. Community anxiety over the construction goes beyond concern over additional air pollution and impact on landscape.

Jumani, a former ward chief in Suralaya, says he understands there are plans to dispose of coal waste near his own neighborhood. He says he asked Indonesia Power about the plan at a meeting between company representatives and the community in 2019. Jumani says the company told residents no decision had yet been made concerning waste disposal. “The electricity is fine here,” Jumani says. “So who else is it for? Where do they want to send it?”

 

Analysts question the logic of constructing new plants in the Java-Bali grid, where supply already exceeds demand, and in light of the state utility’s mounting debts.

 

In November 2020, the Indonesian Forum for the Environment (Walhi) initiated a lawsuit seeking the cancellation of the environmental permits issued for PLTU 9 and 10. The permits were issued in 2017, but Walhi says the construction should not have been approved because the specifications failed to meet the government’s own air pollution regulations.

 

Walhi cites an environment ministry regulation from 2019, which sets caps on emissions of sulfur dioxide, nitrous oxide, fine particulate matter, and mercury, all of which are byproducts of coal-fired energy generation.

 

The group adds the public had very limited access to the plants’ environmental permits, inhibiting open scrutiny of the impact on public health.

 

“Without disclosure people will lose their voice in the fight against PLTU 9 and 10,” says Ronald Siahaan, a lawyer with Walhi.

 

The government’s strategic plan to construct 35,000 MW of new capacity was predicated on an expected 8.3% annual increase in electricity demand. But the real growth has been closer to 6.9%, resulting in an excess of power capacity. The coronavirus pandemic has exacerbated this supply-demand problem.

 

Last year, reduced factory shifts and restrictions on movement resulted in a 46.6% oversupply on the Java-Bali grid in the year to end-November, according to PLN.

At the end of 2019, the total national installed generating capacity was 62,800 MW, 69% of which was on the Java-Bali network.

 

Coal will remain the dominant energy source powering Indonesia’s residential and commercial premises for the foreseeable future. The medium-term development plan from 2019-2028 expects coal to account for 62.7% of new electricity generation.

 

Government expectations that new technology will increasingly remedy the polluting effects of coal means PLN is under less pressure to phase out its use in the immediate term. “We have a lot of coal potential,” said Ikhsan Asaad, a director at PLN.

 

PLN considers some renewable projects to be unreliable, preferring cheaper coal plants that will pump out power without interruption.

 

Faced With a Public Backlash, Alberta Backtracks on Coal Policy

 

Faced with a rapidly growing backlash to opening protected lands at the foot of the Rockies to coal mining, the Alberta Government has reinstated the former 1976 coal policy while promising public consultation on a new policy. However, four projects approved under the previous policy and two approved after the 1976 policy was rescinded will be permitted to continue.

All six projects belong to Australian companies. In May last year the United Conservative Party’s Minister for Energy, Sonya Savage, revoked the 1976 policy without public consultation and announced the decision on the evening of a long weekend. The Alberta Wilderness Association said it was “pleasantly surprised” by the government’s move but noted new mines could still be approved. 

 

Controversial Cambodian Coal Ash Plant to Close

 

Cambodia’s Ministry of Environment has ordered a coal ash processing plant at Steung Hav in Sihanoukville Province to close by February 15. The ministry cited the health impacts on local communities, which have long complained about pollution from the plant. The plant processes coal ash from three nearby coal-fired power plants, one of which was a second-hand Chinese coal unit imported from Hunan province.

 

German Utility Sues Netherlands Over Forced Close of Coal Plants 

 

The German utility RWE has filed a €1.4 billion (US$1.7 billion) compensation claim before the International Centre for Settlement of Investment Disputes, the World Bank's arbitration court, over the Netherlands’ plan to close all coal-fired power plants by 2030. The Netherlands policy will require RWE to close its 600 MW Amer plant, which was commissioned in 1993, and its 1,560 MW Eemshaven plant, which was commissioned in 2015. RWE has launched the case on the basis of the Energy Charter Treaty, an investment charter agreed to by the European Union in 1994. ClientEarth, an environmental law NGO, argues that while RWE’s case is unlikely to succeed the treaty is a potential barrier to further climate action. The NGO has called on the European Union to withdraw from the treaty as Italy did in 2016.

 

Indian NGO Warns Against Further Delay in Emissions Standards

The Centre for Science and Environment (CSE), a Delhi-based think tank, has argued against a proposal by the Ministry of Power to further delay the introduction of new pollution standards applying to the country’s 448 coal units until 2024. CSE argues further delay would make “a complete mockery” of efforts over the last five years by the Supreme Court and regulators to control air pollution.

The standards for power plants were first announced in December 2015 to come into effect in December 2017 but have been repeatedly delayed in response to lobbying by private and public power utilities. CSE has proposed that the government prioritize power purchases from units that have met the standards and penalize those that have not installed pollution control equipment.

Laos to Build Coal-fired Power Plants in Order to Sell Electricity to Kingdom

 

Construction of two coal-fired power plants will begin at the end of 2021 in Xekong province in the southeast of Laos, according to a senior Lao government official.

 

The plants will become operational and begin transmitting electricity to Cambodia in 2025, based on an agreement signed between the developers and the Lao government.

 

Lao Deputy Minister of Energy and Mines, Dr. Daovong Phonekeo, announced that the first plant will be built by Phonesack Group Co Ltd in Kaleum district, with an installed capacity of 1,800 megawatts (MW).

 

It will be constructed at a cost between $3 billion to $4 billion and will include the construction of the power lines needed to transmit electricity to Cambodia.  Those transmission lines will be 200 kilometers in length.

 

The second plant will be built in Lamam district by a Chinese company, as yet unnamed, which plans to invest more than $1 billion in the project.  That plant will have an installed capacity of 700 MW.

 

The Chinese company will not build transmission lines but will partner with Electricite du Laos (EDL) in the export of power to Cambodia.

 

The two plants will sell electricity to Cambodia at a rate of 7.3 US cents per kWh, according to the deputy minister.

 

When queried, Dr. Daovong said there was a sufficient local supply of coal to power the plants over the concession period of 25 years. He added that surveys will be carried out to locate coal seams in other areas as optional sources of supply.

 

Governor of Xekong Province, Leklay Sivilay, told reporters last week that Xekong has a huge potential to produce energy for export, which will generate income for local people and drive economic growth in the province.

He said the government will take into account the need to balance power plant development and environmental protection and ensure that power plants benefit local communities and help to improve livelihoods in the area.

 

The government will use learning gained during the operation of the Hongsa coal-fired power plant, the largest energy-generating plant in Laos, when building the new coal-fired power plants in southern Laos.

 

Laos is looking to increase electricity exports to neighboring countries including Vietnam and Cambodia.

 

The 260 MW Don Sahong hydropower project in Khong district, Champassak province, is already transmitting electricity to Cambodia’s Stung Treng province.

 

Laos intends to increase the amount of electricity sold to Cambodia because the existing transmission line has the capacity to carry more energy.

 

GAS TURBINE

 

Tata Consulting Meets Steam Blowing Challenges at Indonesian GTCC Plant

Tata Consulting Engineers Ltd. (TCE) was retained as the engineering consultant for detailed design and engineering services of a combined cycle project in Indonesia. The plant was commissioned in December 2018 and is currently in commercial operation.

A steam blowing operation is one of the critical pre-commissioning activities carried out in new power projects where construction is completed, and the commissioning phase is ongoing. This activity is performed on the critical steam piping of the steam cycle circuit to ensure that any scales, oxides of metal, and slag left behind in the piping internals during the welding process are removed prior to initiating steam turbine operation.

The steam cycle circuit typically refers to all the piping that is connected between the heat recovery steam generator (HRSG) and the steam turbine. This is an important activity to be completed by the engineering, procurement, and construction (EPC) contractor as part of steam turbine original equipment manufacturer (OEM) start-up requirements. Otherwise, any leftover metal particles or scales formed within the pipes can travel along with the steam into the steam turbine and can cause pitting/damage on the turbine blades. In some cases, the damage can be catastrophic in nature. The criteria or guidelines for cleaning the steam piping are set by the steam turbine OEM and need to be fulfilled by the EPC contractor.

The experience gained by a project team during the steam blowing operation for a combined cycle power project is described in this article. The details of the steam blowing procedure (such as calculations, construction details, step-by-step sequence, and methodology to execute the steam blowing procedure) are not covered in this article. Rather, the focus is drawn more toward challenges faced during execution of the SBO at the site and solutions used to overcome the difficulties. To understand the necessity of this procedure in detail, readers should review literature available in the public domain. Another source to help
https://www.powermag.com/innovative-engineering-results-in-successful-steam-blowing-operation/

Mitsubishi SCR Will Be Key to the New Ammonia-fired Gas Turbine

 

Mitsubishi Power has commenced development of a 40-megawatt (MW) class gas turbine that is fueled by 100% ammonia (NH3). The project was started in response to the increasing global focus on decarbonization. As firing of ammonia produces no carbon dioxide (CO2), carbon-free power generation is achieved. Going forward, after combustion and other testing, Mitsubishi Power is targeting commercialization in or around 2025. When achieved, it will mark the world’s first commercialized gas turbine to make exclusive use of ammonia as fuel in a system of this scale, and will aid in the promotion of decarbonization of small to medium-scale power stations for industrial applications, on remote islands, etc.

 

Mitsubishi Power is working to reduce environmental impact through the development of high-efficiency power generation technologies. Until now, the company has pursued technological developments enabling a transition from natural gas fuel used in gas turbine combined cycle (GTCC) systems, which currently emit the lowest amount of CO2 among thermal power generation systems, to hydrogen, which emits no CO2. In tandem with pursuing active use of ammonia, the company has also been developing a system in which the waste heat from a gas turbine reconverts ammonia into hydrogen and nitrogen for use in hydrogen gas turbines. This development is carried out as part of a program by Japan’s New Energy and Industrial Technology Development Organization (NEDO) “Technology Development Project for Building a Hydrogen-based Society: JPNP14026.”

 

Developing a method for directly combusting ammonia will further expand Mitsubishi Power’s lineup of carbon-free power generation systems. A challenge needing to be addressed with direct combustion of ammonia is the production of nitrogen oxide (NOx) caused by oxidation resulting from the combustion of the nitrogen component of the fuel. Mitsubishi Power is aiming to resolve this issue through commercialization of a gas turbine system that combines selective catalytic reduction (SCR) with a newly developed combustor that reduces NOx emissions, for installation in the company’s H-25 Series gas turbines (output: 40-MW class), which has a rich operational track record spanning the globe.

 

Ammonia, which is a compound consisting of hydrogen and nitrogen, is a highly efficient hydrogen carrier, and it can also be directly combusted as fuel. In recent years, attention has begun to focus on ammonia from two perspectives: achieving carbon neutrality through transition to a hydrogen society, and minimizing environmental impact caused by existing energy modes. Expectations are held that early introduction of ammonia-based power generation equipment at power companies and independent power providers (IPPs) will promote ammonia’s future use as a carbon-free fuel.

 

Going forward, Mitsubishi Power will work to advance the energy transition as a member of MHI Group. By prioritizing its resources into expanding its gas turbine power generation and other efficient, environmentally friendly generation technologies, the company will contribute to the stable supply of power, indispensable to global economic development, and the protection of the environment through the promotion decarbonization.

 

Yara Not Only Makes SCR Reagents But Will Make The Ammonia Fuel

 

Yara International ASA (Oslo, Norway) has announced plans for 500,000 metric tons per year (m.t./yr) of green ammonia production in Norway, powering emission-free shipping fuels and decarbonized food solutions.

 

“Ammonia is the most promising hydrogen carrier and zero-carbon shipping fuel, and Yara is the global ammonia champion, a leader within production, logistics and trade. I am excited to announce that a full-scale green ammonia project is possible in Norway, where we can fully electrify our Porsgrunn ammonia plant,” says Svein Tore Holsether, President and Chief Executive Officer of Yara.

 

Ammonia’s chemical properties make it ideally suited for the hydrogen economy. It does not require cooling to extreme temperatures, and has a higher energy density than liquid hydrogen, making it more efficient to transport and store. Ammonia is therefore the most promising hydrogen carrier and zero-carbon shipping fuel.

 

Building on its long experience and leading position within global ammonia production, logistics and trade, Yara aims to capture opportunities within shipping, agriculture, and industrial appli-cations, in a market expected to grow by 60 percent over the next two decades. Against this backdrop, Yara announces plans to fully electrify its ammonia plant in Porsgrunn, Norway with the potential to cut 800,000m.t./yr. of CO2, equivalent to the emissions from 300,000 passenger cars.
https://www.chemengonline.com/yara-announces-world-scale-green-ammonia-project/

 

NewTeck Sensors For More Efficient Valve Operation

NewTek Sensor Solutions said its HAR Series of hermetically sealed linear position sensors provide critical position measurement in the monitoring and control of steam turbine valves in power plants.

Designed especially for power plant rehabilitation programs, these AC-operated LVDTs serve as OEM replacements for legacy applications, offering the same fit, function, and reliability as original units, the company said.

Gas turbines use various valves (control, gate, transfer, bleed) for different operations. Using position feedback on valves from the HAR LVDT Position Sensors, operators can ensure they are opened and closed according to control schemes for more efficient plant operations. Just a 2% increase in efficiency can translate into millions of dollars in savings annually, the company said.

Well-established for measuring the position of steam turbine valves, the HAR Series of Displacement Sensors are reliable and resilient in harsh environments, offering highly accurate feedback with long life. Hermetically-sealed to IP-68, these LVDT Position Sensors can withstand high shock and vibration while operating over a wide operating temperature range of -65°F to 400°F. A right-angle configuration stops debris from accumulating inside the sensor body. Units are available in measurement ranges from ± 0.05 to ± 10 in.
https://www.dieselgasturbine.com/news/NewTek-position-sensors-for-steam-turbine-valves/8010538.article

Malaysia Becomes First Country To Fire Up GE 9HA.02 Turbine

Malaysia is targeting a 45% reduction in CO2 emissions by 2030. The country of 33 million consists of several large, hilly islands and a peninsula where open land suitable for building large wind or solar farms is scarce. 

That conundrum has led Southern Power Generation (SPC), a large Malaysian utility, to turn to GE Gas Power and its advanced turbines capable of efficiently turning natural gas and other fuels, including liquid fuel distillate as a backup into large amounts of lower-carbon electricity. In fact, SPG will become the first power producer in the world to use a pair of 9HA.02 turbines to generate electricity.

The turbines come from a new generation of GE machines that had already set a world power plant efficiency record. They are also equipped with a combustion system that allows them to burn up to 50% by volume of hydrogen when blended with natural gas, allowing SPG to have the option to utilize hydrogen or other lower or no-carbon fuels at some point in the future.

Advanced Class Gas Turbine SCR and CO Catalyst System Operating Challenges

One of the tradeoffs for the higher efficiency of new advanced class gas turbines (namely the G-, H-, and J-class machines) is increased thermal NOx make, which is caused by higher firing temperatures in the gas turbine combustors. The result is GT exit NOx concentrations in the 25 – 35 ppmvdc range for the advanced class turbines, which is significantly higher than the 9 – 20 ppmvdc range for their F-class predecessors.

Since regulators tend to view all gas turbines as being the same, they assume that the same stack emissions levels can be met regardless of the turbine technology. Because of this, the advanced class turbines are expected to achieve the same stack emissions levels as F-class machines without giving consideration to the differences in combustion dynamics between the different classes of turbines.

Modern day F-class machines are expected to achieve stack limits of 2.0 – 2.5 ppmvdc NOx and 2.0 – 5.0 ppmvdc ammonia slip through the use of selective catalytic reduction (SCR) systems, which use ammonia as the reducing agent to convert NOx across a catalyst. These systems provide 72 – 90% NOx reduction while being allowed to slip 22 – 25% excess ammonia (2 ppm NH3 slip/9 ppm inlet NOx to 5 ppm NH3 slip/20 ppm inlet NOx). By contrast, the advanced class machines must provide 90 – 94% NOx conversion while only being allowed to slip 7 – 8% excess ammonia to achieve the same stack emissions levels.

This increase in required NOx reduction accompanied by the decrease in allowable excess ammonia results in increased SCR system performance requirements that are by no means trivial. As NOx conversion requirements increase to 90% and above, the systems have much less tolerance for non-ideal performance, particularly with such low levels of allowable excess ammonia. As a result, SCR systems for advanced class turbines require higher SCR catalyst volumes, near-perfect ammonia-to-NOx distribution, and air-tight seals around the SCR catalyst perimeter and all catalyst modules. In order to reliably meet stack emissions requirements, these sites will need pro-active SCR management plans that include proper ammonia injection grid design and tuning, a catalyst testing program that takes into account all plant operating modes, thorough catalyst system maintenance, and proper design and selection of replacement catalyst that adapts to changing SCR system needs.

Additional challenges for advanced class turbine SCR and CO catalyst systems are the requirements for low turndown operation, fast start-ups, and frequent cycling. Historically, gas turbines have only been required to operate down to 50% of baseload. Many of the new, advanced class sites are being asked to operate at loads as low as 20%, start up and achieve emissions compliance within shorter timeframes, and to cycle frequently between low loads and baseload. These requirements put additional stress on catalyst systems, primarily attributed to sub-optimal operating temperatures and elevated gas turbine NOx and CO emissions under these operating conditions.

Cydsa Incorporates Wet Scrubber Prior to Gas Turbine Inlet Filter in Order to Provide Greater Gas Density

 

Cydsa wanted to provide the most dense and clean combustion air for its gas turbine power plant in Mexico. It purchased a package from Nederman. The air first is scrubbed in a packed tower, which removes larger particles and humidifies the gas. A vane section eliminates remaining droplets. The final filtration is achieved with HEPA filters.
https://www.nedermanmikropul.com/en-us/knowledge-center/case-study-cydsa

 

Coal-to-Gas Transition in China: Junliangcheng Power Plant Adds over 650 Megawatts with GE’s Advanced 9HA Technology

 GE announced the start of commercial operation for Junliangcheng Power Plant in Tianjin City, mainland China. GE provided the power generation equipment for the new combined heat and power (CHP) gas power plant that replaced the existing coal-fired power plant. Today, the plant provides up to 661 megawatts (MW) of electricity, the equivalent output needed to heat and power approximately 100,000 homes in China living in an area of 7 million square meters. Following the coal-to-gas transition, Junliangcheng plant is expected to reduce sulfur dioxide (SO2) and NOx emissions by approximately 1,194 and 7,775 tons per year, respectively.

The new plant, owned by China Huadian Tianjin Junliangcheng Power Generation Co., Ltd., part of China Huadian Corporation (CHD), features the first commercially operating GE 9HA.01 technology in China. In addition to the 9HA.01 gas turbine, GE supplied the Mark* VIe Distributed Control Solution, for full combined cycle plant control and operation, while GE's local partner on this project— Harbin Electric — provided the steam turbine, generator, and balance-of-plant equipment for Juliangcheng.

 

GE’s Gas Power Technology Chosen by Colorado Springs Utilities to Take One Step Closer to Retiring the Martin Drake Coal Power Plant by 2023

GE announced an order from community-owned Colorado Springs Utilities for six of its advanced LM2500XPRESS aeroderivative gas turbine packages to help Springs Utilities bridge the gap and power the downtown area until a new transmission line is completed in 2025.

In alignment with Colorado’s goals to reduce statewide greenhouse gas emissions from transportation, electricity generation, and other sectors, Colorado Springs Utilities’ Board committed to retiring the coal-fired Martin Drake Power Plant by Dec. 31, 2022—12 years earlier than previously planned.

GE’s recently debuted LM2500XPRESS* power plant technology will help Springs Utilities acquire the flexibility they need to bring more renewables onto their system and move forward with the retirement of Martin Drake. Consistent with their Energy Vision, they are now on the path to reduce carbon emissions from their electricity service by at least 80% by 2030, from 2005 levels.

The 34-megawatt (MW) LM2500XPRESS* units are the first of their kind to be installed in North America and expected to start commercial operation by the summer of 2022. Using the highly mobile nature of the units—which can be moved on trailers—the LM2500XPRESS* units will eventually be relocated to other sites in the Colorado Springs area.

GE’s LM2500XPRESS* power generators are 95% factory assembled into simplified modules and provide a “plug and play” concept that can be installed in less than three weeks. This makes the units ideal to bring fast power to the grid when needed. Each power block comprises a GE LM2500* aeroderivative gas turbine modular package, gas compressor and emissions control system. In addition, there is a black start diesel generator included to provide start-up capability in case of grid events. 

The LM2500XPRESS* is engineered to be faster to install, save cost on coal-to-gas transition, and respond to intermittent renewable resources quickly and easily. The units provide dual-fuel capability, primarily burning natural gas, and can use liquid fuels to help meet periods of low natural gas availability. An advanced emissions control system uses a dry low emission (“DLE”) combustion system that cuts down on water use, and an oxidation catalyst to reduce emissions from these units.

MHI Invests in C-Zero, a U.S. Hard Tech Startup, to Accelerate Efforts to Produce Clean Hydrogen from Natural Gas

Mitsubishi Heavy Industries, Ltd. (MHI) announced that it has invested in C-Zero, a hard tech startup located in Santa Barbara, California, to accelerate the first commercial-scale deployment of C-Zero's drop-in decarbonization technology, which will allow industrial natural gas consumers to avoid producing CO2 in applications like electrical generation, process heating and the production of commodity chemicals like hydrogen and ammonia. The investment has been executed through Mitsubishi Heavy Industries America, Inc.

C-Zero's technology uses innovative thermocatalysis to split methane — the primary molecule in natural gas — into hydrogen and solid carbon in a process known as methane pyrolysis. The hydrogen can be used to help decarbonize a wide array of existing applications, including hydrogen production for fuel cell vehicles, while the carbon can be permanently sequestered. When renewable natural gas is used as the feedstock, C-Zero's technology can even be carbon negative, effectively extracting carbon dioxide from the atmosphere and permanently storing it in the form of high-density solid carbon.

 

With the investment, MHI continues to strengthen and diversify the hydrogen value chain, advancing both strategic initiatives for its energy transition business and its commitment to making continued progress toward global carbon neutrality goals. MHI joins a consortium of investors, including Breakthrough Energy Ventures, Eni Next and AP Ventures.

 

The investment signals cooperation around accelerating the use of "turquoise hydrogen," which could further strengthen the hydrogen value chain. Hydrogen produced via methane pyrolysis processes like C-Zero's is increasingly being referred to as "turquoise hydrogen," as it combines the benefits of both "blue hydrogen," (SMR with CO2 sequestration) and "green hydrogen" (produced by splitting water via electrolysis) by being low cost and low emissions, respectively.

As part of the investment, MHI will examine the potential of using the company's technology for the production and supply of hydrogen that could then be utilized for power generation systems and the decarbonization of industry.

 

Mitsubishi Power Achieves #1 Market Share for Heavy-Duty Gas Turbines in the Americas in 2020 by Offering Industry-Leading Decarbonization Solutions to the Power Sector

 

Mitsubishi Power Americas, Inc. (Mitsubishi Power) secured the highest market share for heavy-duty gas turbine orders in the Americas in 2020, according to McCoy Power Reports data. Orders in the Americas totaled 3,288 megawatts, representing 54 percent of total orders.

Orders for Mitsubishi Power’s solutions spanned a variety of applications, with decarbonization and hydrogen capability emerging as key competitive advantages. More than half of Mitsubishi Power’s 2020 orders include a hydrogen performance guarantee or have a joint development agreement for hydrogen in progress.

Mitsubishi Power’s orders include the first combined-cycle gas turbines specifically ordered to operate on 30 percent green hydrogen by their commercial operation date. These gas turbines will have the lowest carbon dioxide emissions intensity — by at least 11 percent — of all heavy-duty gas turbines ordered in 2020. Carbon dioxide emissions intensity is measured in pounds of carbon dioxide emissions per megawatt hour of electricity produced.

Mitsubishi Power now ships all of its heavy-duty gas turbines with hydrogen capability for deeper decarbonization. As-delivered, the gas turbines are capable of operating on a mixture of up to 30 percent hydrogen and 70 percent natural gas, which can be increased to 100 percent hydrogen in the future. As hydrogen content increases, carbon intensity is reduced. When a unit reaches 100 percent green hydrogen, carbon intensity will drop to zero.

Southern Company Takes Foundational Leadership Role in Hydrogen R&D Effort to Achieve Net-Zero Goals

Southern Company and its Southern Company Gas subsidiary have helped to start a new research and development (R&D) initiative, known as HyBlend, to address the technical barriers to blending hydrogen in natural gas infrastructure and study life-cycle emissions of hydrogen blends. As the leading energy industry sponsor, Southern Company Gas will spearhead the initiative. The HyBlend project will utilize expertise in Southern Company's industry-leading R&D organization, along with industry partners, research consortia, academia, and national laboratories, and encompass more than $15 million in hydrogen research.

"Natural gas is a critical partner in the growth of renewables as we foresee numerous opportunities to leverage our existing infrastructure to support clean energy, such as hydrogen," said Dr. Mark S. Berry, vice president of R&D at Southern Company. "Emerging technologies such as hydrogen will be key as we work to achieve our enterprise-wide goal of net-zero carbon emissions by 2050."


Introducing hydrogen into existing natural gas infrastructure has national and regional benefits for energy storage, resiliency, and emissions reductions. Hydrogen can be produced by splitting water molecules with renewable, nuclear, or other sources of energy. This hydrogen could be injected into natural gas infrastructure, and the blend of hydrogen and natural gas can then be transported to end users of the fuel.

 

This two-year project was selected by the U.S. Department of Energy's (DOE) Hydrogen and Fuel Cell Technologies Office in the Office of Energy Efficiency and Renewable Energy through the H2@Scale 2020 CRADA Call.

 

The HyBlend team is comprised of six DOE national laboratories ― National Renewable Energy Laboratory, Sandia National Laboratories (SNL), Pacific Northwest National Laboratory (PNNL), Oak Ridge National Laboratory, Argonne National Laboratory, and the National Energy Technology Laboratory ― and more than 20 participants from industry and academia.

"We're working with industry to answer their high-priority research questions," said Michael Peters, HyBlend project engineer at National Renewable Energy Laboratory. "First, are pipelines compatible with hydrogen? Second, what are the costs and environmental impacts? And finally, how will hydrogen blends affect appliances and other equipment in buildings?"

 

The areas of research include studying life-cycle emissions of hydrogen blends and techno-economic analysis of the costs and opportunities of hydrogen production. The project will leverage DOE's Hydrogen and Fuel Cell Technologies Office's Hydrogen Materials Compatibility Consortium, led by SNL and PNNL, which is an internationally recognized framework for the study of hydrogen–materials compatibility.

Siemens Energy Signs Agreement to Build First-of-its-Kind Waste Heat-to-Power Facility in Canada

 

Siemens Energy has signed an agreement with Canada-based TC Energy Corporation (TC Energy) to commission a novel waste heat-to-power pilot installation in Alberta. The facility will capture waste heat from a gas-fired turbine operating at a pipeline compression station and convert it into emissions-free power. The electricity produced will be put back into the grid– resulting in estimated greenhouse gas reductions of 44,000 tons per year, equivalent to taking more than 9,000 vehicles off the road.

 

As part of the agreement with TC Energy, Siemens Energy will build, own, and operate the facility, with the option for ownership to be transferred back to TC Energy at a later date.

At the heart of the facility will be an innovative heat recovery process designed by Siemens Energy. The patented technology, licensed under.

 

Echogen® Intellectual Property, is based on an advanced Rankine Cycle and uses supercritical carbon dioxide (sCO2) as the working fluid to convert waste heat into power. Because of its properties, sCO2 can interact more directly with the heat source than water/steam, eliminating the need for a secondary thermal loop, typically required in traditional waste heat recovery systems.

By deploying sCO2-based waste heat recovery solutions, midstream operators can realize greater value than traditional alternatives based on Organic Rankine or steam cycles. Benefits include a 25 – 40 percent smaller footprint than steam-based systems, a 10 percent increase in compressor station efficiency, and the capability to produce clean, emissions-free electricity. Moreover, because the working fluid is contained within a closed-loop system, no boiler operator is required, making the system suitable for remote operation.

 

The pilot project is supported by $8 million in funding from Emissions Reduction Alberta’s (ERA) Industrial Efficiency Challenge. For more than 10 years, ERA has been investing the revenues from the carbon price paid by large final emitters to accelerate the development and adoption of innovative clean technology solutions. Since ERA was established in 2009, they have committed $616 million toward 186 projects worth $4.55 billion that are helping to reduce GHGs, create competitive industries, and are leading to new business opportunities in Alberta. These projects are estimated to deliver cumulative reductions of 35 million tonnes of CO₂e by 2030.

 

The new facility is expected to be commissioned toward the end of 2022 and could generate enough electricity to power more than 10,000 homes.

 

TC Energy is currently evaluating other compressor station sites to deploy the technology, with the potential to generate 300 megawatts of emissions-free power.

 

 

RECIPROCATING ENGINES

 

Wärtsilä Supplying Engines and Gas Valves for Artic LNG 2 Project

Wärtsilä will supply the dual-fuel engines for six new 172 500 cbm LNG carrier vessels being built to serve the Arctic LNG 2 project in Russia’s Arctic waters. The order, which is valued at more than €100 million, was placed by Daewoo Shipbuilding and Marine Engineering. There is an option for a further four ships.

Each vessel will be fitted with six Wärtsilä 46DF dual-fuel engines, plus gas valve units and auxiliaries. Deliveries of the equipment will commence in August 2021.

“This is a major newbuild project, and we were able to propose a technical solution that ensures clear benefits and cost savings for the customer. Our experience with LNG applications is unmatched, and this order represents an acknowledgement of that fact,” says Östen Lindell, sales director, East Asia & China, Wärtsilä Marine Power.

Wärtsilä has earlier supplied the engines for 15 ships serving the Yamal LNG project, as well as numerous dual-fuel engines for other LNG carriers built at the Daewoo yard.
 https://www.dieselgasturbine.com/news/wrtsil-supplying-arctic-lng-vessels/8010011.article

ANDRITZ Supplies the Scrubbers and Dust Collectors for Ship Engine Exhaust

ANDRITZ supplies complete solutions for emission control to the maritime industry. Its exhaust gas cleaning systems (EGCS) include scrubbers and filtration solutions and all the ancillary equipment as well as installation supervision, commissioning, and after-sales service. ANDRITZ is the only company that supplies two completely flexible system solutions for cleaning exhaust gas on board maritime vessels — SeaSOx Scrubber (the common and well-known wet scrubbing system) and SeaSOx Dual/Multi Filtration. Due to the demand for exhaust gas cleaning solutions for use at anchor or during a stay in port, SeaSOx Barge is an additional option for vessels without a scrubber or filtration solution installed. Tailor-made solutions cover all possible options and combinations to develop the perfect solution for each vessel and customer. The EGCSs from ANDRITZ can be installed on all types of new-build vessels or retrofitted to ships already in service.

The different technologies are characterized as follows: 

  1. SeaSOx Scrubber, using seawater for exhaust gas cleaning, suitable for merchant vessels worldwide. The I-type or U-type scrubbers in round or rectangular shape are provided for all possible applications (open loop, closed loop, hybrid ready, hybrid). 
  2. SeaSOx Dual/Multi Filtration, without wash water, for merchant vessels operating in coastal waters and inland waterways, ferries, feeders, RoRo, RoPax, cruise ships, and so on. There is no discharge of wastewater into the sea and no dry dock is required for installation.
  1. SeaSOx Barge, an all-in-one solution to remove SOx, NOx, and PM from exhaust gas during stays in port – suitable for connecting to any type and size of vessel.

ANDRITZ provides a unique and complete dual/multi filtration EGCS solution for the maritime industry. The scope of supply includes filter bags, silos, automation, integration engineering, emission monitoring, residue transport system, sealing air fans, exhaust gas dampers, valves, piping, engineering supervision, commissioning, and after-sales service. ANDRITZ’s SeaSOx filtration has been certified by DNV GL with a MED-G certificate, the first of its kind worldwide.

Based on a proven technology that has been used for decades in land-based projects, this dry exhaust gas cleaning system has now been adapted for maritime applications. The technology uses sodium bicarbonate as absorbent for the removal of SO2 and SO3. In addition to SOx, all kinds of particles like dust, soot (black carbon), ultrafine, and respirable particulates are removed to the highest extent possible (more than 99.9%). The next step in ANDRITZ’s ongoing technology developments includes the removal of NOx, making the system future-proof when it comes to more stringent emission requirements for shipping.

 

Wärtsilä Combined Heat and Power Plant Helps Germany to Reach Its Green Energy Goals

 The recently completed combined heat and power (CHP) plant supplied by technology group Wärtsilä to Kraftwerke Mainz-Wiesbaden (KMW) in Germany has been officially handed over for commencement of commercial operations. The handover took place on December 23 allowing municipal energy provider KMW to reliably provide 100 MW of electrical power. The CHP plant feeds the excess heat generated during power generation into the Mainz district heating network. From this, Mainz customers are supplied with sufficient heat to supply around 40,000 modern single-family homes.

The state-of-the-art plant operates with ten gas-fueled Wärtsilä 34SG engines. The operational flexibility of the plant enables KMW to start and stop the engines without limitations as fast as in 2.5 minutes. This provides essential grid balancing support as the power system incorporates ever increasing renewable sources, namely wind and solar. It also allows KMW to operate in the short-term balancing markets, since power output can be quickly adjusted to respond to fluctuations in the power demand, as signaled by the electricity price.

Wärtsilä supplied and built the plant on a full engineering, procurement, and construction (EPC) contract. The scope also includes a comprehensive 15-year maintenance agreement that guarantees the plant’s availability and reliability. The services provided include on-site support.

 

Andritz Installs Large Hybrid Scrubber on Two Ships

 

Andritz said it has supplied a multi-inlet hybrid scrubber that is the largest ever installed at China’s Chengxi shipyard. The scrubber, with an outer diameter of 4.1 m and an overall footprint of around 7.1 x 4.1 m, was installed on board the MV Dole Maya.

 

Additionally, Andritz AG was responsible for environmental compliance certification under the supervision of the DNV GL classification society. After the successful sea trial, the necessary IAPP certificate was issued. The Andritz AG SeaSOx system will treat the exhaust gas from one main engine and four auxiliary engines to fulfill the MARPOL requirements.

 

Andritz will also supply a hybrid scrubber for the Dole Maya’s sister vessel, Dole Aztec, which will be completed and delivered to the Dole Food Company in April 2021.

 

The Dole Maya scrubber project was the result of international collaboration within the Andritz Group, as the equipment was engineered and designed in Austria and manufactured at the company’s own production facility in China. Project management was handled by an experienced Croatian colleague from the maritime industry.

 

With this installation, Andritz said it is the only company globally to offer, deliver, install, and successfully commission the complete portfolio of exhaust gas cleaning systems for maritime vessels. The portfolio includes open-loop and hybrid scrubbers as inline (I-type) and bypass (U-type) models for wet scrubbers as well as the dry, dual filtration system without any wash water. In addition, Andritz now also has experience with various major classification societies, such as DNV GL, ABS and RINA.

 

To extend its portfolio, Andritz is now developing a barge solution – SeaSOx Barge – for vessels on stay in port that will reduce the level of SOx, NOx, and ultrafine particulates in the exhaust gas regardless of the size of the vessel or its engines.

 

BIOMASS

 

Bioenergy with Carbon Capture and Storage Can Help Decarbonize UK

 

Prime Minister Boris Johnson recently announced ambitions to reduce carbon emissions by 68 percent by the end of 2030, placing a greater emphasis on renewable energy resources. However, renewables’ weather-dependency can make securing consistent power difficult. Simone Bruckner, managing director of power resistor manufacturer for renewables Cressall, explores how biomass can ensure a reliable electricity supply on a renewable grid.

 

The Committee on Climate Change’s (CCC) Sixth Carbon Budget report explains that, to achieve net zero emissions, the UK must eliminate all fossil fuel generated power by 2035 and increase variable renewable energy production by 80 percent by 2050. In addition to executing this shift, the electrification of other areas of industry, such as the automotive sector, will see a rise in electricity demand from the current 300 to 610 terawatt hours (TWh) by 2050.

Meeting this increased demand solely from renewable sources cannot be guaranteed, since renewables such as wind power are heavily weather dependent. The amount of electricity generated by renewables varies since it is determined by a natural uncontrolled source, such as wind speed. Therefore, an additional energy source will be required for periods when renewables cannot meet demand.

 

In line with the target to fully decarbonize electricity generation by 2035, this alternative, dispatchable source must be low-carbon, or carbon neutral. The CCC estimates that, as part of the renewable grid, this source will be responsible for generating 50 TWh of electricity. But which source meets all these criteria?

 

Bioenergy with carbon capture and storage (BECCS): a two-step, carbon neutral energy generation method.

The first step of BECCS involves burning biomass, which is any plant or animal matter, to generate energy. This organic waste produces electricity in the same way as fossil fuels — combustion of biomass produces heat, which in turn produces steam to turn a turbine to power a generator and produce electricity.

 

The crucial difference between biomass combustion and fossil fuel combustion is the carbon emissions. Biomass absorbs carbon dioxide (CO2) as it grows and re-releases the same amount when burned, making biomass combustion carbon neutral.

 

The CO2 produced when burning biomass is captured directly from the air using carbon capture and storage (CCS) technology. The simplest CCS technology is oxyfuel combustion. In oxyfuel combustion, the CO2 produced by burning biomass is purified and compressed to form a liquid, which can be transported to an underground storage space.

 

Combining carbon neutral biomass combustion with CCS technology results in a carbon negative electricity generation that is available when required to fill any gap between energy production from variable renewables and demand.

 

BECCS is vital to ensure a reliable, renewable energy supply in a decarbonized UK, acting as an on-demand energy source in periods of low renewable energy production. However, for biomass plants to turn fuel into a reliable form of power, these facilities must make use of suitable power protection equipment to prevent electrical faults that may impact delivery. 

 

To ensure a reliable supply, the plants must be protected against the impact of power problems like fault currents and transient over-voltages. Cressall produces medium voltage neutral earthing resistors (NERs), which mitigate the impact of these faults. In the event of a fault, NERs limit the current that can flow through the neutral point of a transformer or generator and dissipate the excess energy as heat, preventing damage to network equipment.

 

NTPC set to Implement Waste-to-Energy Technology in Power Plants

 

In what could make a major difference to the management of urban solid waste, National Thermal Power Corporation (NTPC) is all set to implement a waste-to-energy technology that it has co-developed with a Chennai-based orthopedic surgeon. The “torrefied coal”, made out of carbonized waste, will be used by NTPC in its power plants in Varanasi, Bhopal, Indore and Hubli for power generation, officials said.

 

“The idea is to carbonize solid waste in low oxygen conditions and convert the material into coal. Because there is no oxygen involved in the process, and the carbonization is taking place with external heat, the conversion process is not toxic and the carbonized output is of usable quality for power plants,” said Amit Kulsreshtha, NTPC’s general manager-new initiatives. Also the product is cost-competitive and at times cheaper than coal.

 

 

BUSINESS    

 

CECO Reports Slightly Lower 4th Quarter Revenue

 

·        Revenue of $82.9 million, compared with $89.4 million

·        Gross profit of $26.2 million (31.6% margin), compared with $30.0 million (33.6% margin)

·        Operating income of $3.7 million, compared with $7.0 million

·        Non-GAAP operating income of $8.8 million, compared with $9.6 million

·        Net income of $1.8 million, compared with $8.4 million

·        Non-GAAP net income of $5.6 million, compared with $9.6 million

·        Adjusted EBITDA of $9.9 million, compared with $10.1 million

·        Earnings per diluted share was $0.05, compared with $0.24

·        Non-GAAP earnings per diluted share of $0.16, compared with $0.27

·        Bookings of $77.2 million, compared with $67.7 million

·        Backlog of $183.1 million, compared with $189.1 million as of September 30, 2020

·        Cash and Cash equivalents of $36.0 million, compared with $35.6 million

·        Bank Debt of $74.0 million, compared with $67.3 million
CECO Environmental Corp. Reports Fourth Quarter and Full Year 2020 Results (prnewswire.com)

 

Mixed Reality Installation of Ecolab Chlorine Dioxide Generators

 

Ecolab used mixed reality to guide the installation of PURATE chlorine dioxide generators at multiple facilities for one of the largest independent midstream energy infrastructure companies in the U.S. These installations mark Ecolab’s first use of mixed reality to install, test and deliver a chlorine dioxide generator solution for cooling tower operations at an energy plant.

 

Mixed reality combines elements of virtual reality and augmented reality to create a blend of the physical and digital world that users experience through mixed reality headsets. Ecolab leveraged the technology to install three PURATE generators, which generate ClO2 and can be more effective than bleach or bromide solutions in controlling the fouling and microbial problems that can reduce the efficiency of heat exchangers in cooling towers (EPA Reg. No. 1706-242).

 

“Due to the travel, social distancing and plant access restrictions in effect for COVID-19, a typical installation process that involves several on-site engineers was not possible for this company,” said Steve Kramarczyk, a corporate account manager for the Global Heavy division of Ecolab. “Still, the company wanted to realize the cost and logistics savings PURATE offers, so we were able to use mixed reality to safely oversee its installation.”

 

By wearing a mixed reality headset, a single Ecolab field representative was able to transmit on-site visuals and critical data to a team of Ecolab engineers working remotely. Similar to a guided space mission, the engineers, whose combined experience totaled more than 50 years, were then able to guide the representative through a variety of operations at the plant that included:

The installations took approximately 1.5 days each and the results were near instantaneous. The PURATE ClO2 solution is more effective than competitive products, which results in fewer shipments of chemicals to the company’s plants. This means there is less time spent onboarding supplies, reducing logistics and labor needs, as well as the time spent handling chemicals, which contributes to the customer’s health and safety goals. Fewer chemicals on site enables the company to better optimize its available plant space. PURATE also operates in a wider pH balance than bleach or bromide, which will offer the midstream company more flexibility in its treatment options in the future.

“Digital technologies like mixed reality will have a transformative effect in the energy sector,” Kramarczyk said. “Not only will companies that embrace them be able to perform major equipment installations, but they will also be able to better assess risk, monitor their operations and improve their efficiency. Ecolab has spent decades building relationships with our customers and learning about the innerworkings of their operations. It’s this intimate knowledge that enables us to leverage our digital solutions effectively for our customers.”

 

Thermax Registers 34% Higher Operating Profit Before Tax and Exceptional Items

 

For the third quarter of FY2020-21, Thermax Group posted an operating revenue of Rs. 1,411 crore at the consolidated level, same as in the corresponding quarter last year. Profit after tax and exceptional items for the quarter was Rs. 83 crore, down 2% compared to Rs. 85 crore in the corresponding quarter of FY2019-20. Exceptional items impacted the results on account of impairment of goodwill in Thermax Netherlands B.V. and reversal of part of the provision created earlier for claims arising from closure of a German subsidiary, net Rs. 28 crores. Resumption of normalcy in the company’s operations, improved performance of all business segments and cost control measures have improved the Profit Before Tax and Exceptional Items from Rs. 105 crore to Rs. 141 crore, 34% higher.

 

As on December 31, 2020, Thermax Group had an order balance of Rs. 5,208 crore (Rs. 5,439 crore), down 4%. Order booking for the quarter was 2.6% lower at Rs. 1,565 crore (Rs. 1,606 crore). This includes a major EPC order from a biorefinery in Assam for setting up a captive Combined Heat and Power plant. Thermax’s order book witnessed broad based recovery with momentum in sectors ranging from food & beverage to cement and steel.

 

On a standalone basis, Thermax posted an operating revenue of Rs. 903 crore during the quarter, 6% higher as compared to Rs. 850 crore in the previous year. The company registered a loss of Rs. 3 crore, lower than last year’s profit of Rs. 58 crore. Exceptional items impacted the results on account of impairment of goodwill in Thermax Netherlands B.V., impairment of our investment in Indonesia via Thermax Engineering Singapore Pte Ltd. and reversal of the provision for closure of a German subsidiary, totaling Rs. 90 crore. Excluding exceptional items, the PBT improved from Rs. 77 crores to Rs. 105 crore, up 38%. Order balance on December 31, 2020, stood at Rs. 3,627 crore (Rs. 3,682 crore), down 1.5%. Order booking for the quarter, Rs. 1,020 crore (Rs. 1,316 crore) was 22.5% lower.

 

Mitsubishi Power to Restructure the Domestic Locations for its Boiler Business

 

Mitsubishi Power, a subsidiary of Mitsubishi Heavy Industries (MHI) Group, has decided to restructure the domestic locations for its boiler business.

 

Since the predecessor of Mitsubishi Power, MHPS, was established in 2014, the boiler business has continued to operate two plants in Japan, Nagasaki Works, and Kure Works. The industry has experienced sweeping changes in the market demand for coal-fired power generation that has led to a sharp contraction in new plant construction.

 

Addressing the market situation, Mitsubishi Power will consolidate the boiler manufacturing function of new construction and after-sales service, as well as the new facility design and the construction function, at the Nagasaki Works. At the Kure Works, management resources will be shifted to the boiler design and engineering services business and Air Quality Control System (AQCS) business, with the objective of strengthening competitiveness in both businesses. The restructuring is scheduled for completion at the end of fiscal 2022.

 

The business environment for coal-fired power generation is changing radically amid efforts to achieve carbon neutrality by 2050, and a sharp contraction in demand for new coal-fired power plants is projected globally and in Japan. At the same time, there is a greater need to improve the environmental performance and generating efficiency of existing coal-fired power plants, while addressing the need for decarbonization using technologies such as biomass and ammonia co-firing. Mitsubishi Power is responding with selection and concentration of management resources and has adopted the current restructuring plan to pivot to expanding services and environmental solutions, enabling us to achieve carbon neutrality while supporting stable power supplies.

 

Kure Works was established in 1959 as a boiler manufacturing plant, supplying countries around the world with products and services for energy and environmental conservation solutions. This included thermal power generation boilers and AQCS (flue gas desulfurization systems and selective catalyst reduction systems). The plant will continue to actively pursue development of new technologies, such as integrated coal gasification combined cycle (IGCC), low-grade coal combustion, and CO2 capture technologies. Going forward, Kure Works will aim to expand its service business while positively impacting the environment by contributing to decarbonization of existing boilers, and promoting the AQCS business, which is expected to see rising demand amid tightening of environmental regulations worldwide, will provide products that help lower environmental loads and achieve carbon neutrality, and strengthen the solutions business.

 

Mitsubishi Power will continue to work in close cooperation with the areas in which its plants are located, as well as all stakeholders, to build a production structure in keeping with the business environment and customer needs, and as a member of MHI Group, work to advance the energy transition and realize a sustainable society.

 

  

 

FGD and DeNOx Newsletter No. 514