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North sets Ferrexpo on a course for ‘carbon neutrality’

Ferrexpo is used to setting trends. It was the first company to launch a new open-pit iron ore mine in the CIS since Ukraine gained its independence in 1991 and has recently become the first miner in Ukraine to adopt autonomous open-pit drilling and haulage technology.

It plans to keep up this innovative streak if a conversation with Acting CEO Jim North is anything to go by.

North, former Chief Operating Officer of London Mining and Ferrexpo, has seen the technology shift in mining first-hand. A holder of a variety of senior operational management roles in multiple commodities with Rio Tinto and BHP, he witnessed the take-off of autonomous haulage systems (AHS) in the Pilbara, as well as the productivity and operating cost benefits that came with removing operators from blasthole drills.

He says the rationale for adopting autonomous technology at Ferrexpo’s Yeristovo mine is slightly different to the traditional Pilbara investment case.

“This move was not based on reduction in salaries; it was all based on utilisation of capital,” North told IM. While miners receive comparatively good salaries in Ukraine, they cannot compete with the wages of those Pilbara haul truck drivers.

Ferrexpo Acting CEO, Jim North

North provided a bit of background here: “The focus for the last six years since I came into the company was about driving mining efficiencies and getting benchmark performance out of our mining fleet. This is not rocket science; it is all about carrying out good planning and executing to that plan.”

The company used the same philosophy in its process plant – a philosophy that is likely to see it produce close to 12 Mt of high grade (65% Fe) iron ore pellets and concentrate next year.

Using his industry knowledge, North pitted Ferrexpo’s fleet performance against others on the global stage.

“Mining is a highly capital-intensive business and that equipment you buy has got be moving – either loaded or empty – throughout the day,” North said. “24 hours-a-day operation is impossible as you must put fuel in vehicles and you need to change operators, so, in the beginning, we focused on increasing the utilised hours. After a couple of years, I noticed we were getting very close to the benchmark performance globally set by the majors.

“If you are looking at pushing your utilisation further, it inevitably leads you to automation.”

Ferrexpo was up for pushing it further and, four years ago, started the process of going autonomous, with its Yeristovo iron ore mine, opened in 2011, the first candidate for an operational shakeup.

“Yeristovo is a far simpler configuration from a mining point of view,” North explained. “It is basically just a large box cut. Poltava, on the other hand (its other iron ore producing mine currently), has been around for 50 years; it is a very deep and complex operation.

“We thought the place to dip our toe into the water and get good at autonomy was Yeristovo.”

This started off in 2017 with deployment of teleremote operation on its Epiroc Pit Viper 275 blasthole drill rigs. The company has gradually increased the level of autonomy, progressing to remotely operating these rigs from a central control room. In 2021-2022, these rigs will move to fully-autonomous mode, North says.

Ferrexpo has also been leveraging remotely-operated technology for mine site surveying, employing drones to speed up and improve the accuracy of the process. The miner has invested in three of these drones to carry out not only site surveys, but stockpile mapping and – perhaps next year – engineering inspections.

“The productivity benefits from these drones are huge,” North said. “In just two days of drone operation, you can carry out the same amount of work it would take three or four surveyors to do in one or two weeks!”

OEM-agnostic solution

It is the haul truck segment of the mine automation project at Yeristovo that has caught the most industry attention, with Ferrexpo one of the first to choose an OEM-agnostic solution from a company outside of the big four open-pit mining haul truck manufacturers.

The company settled on a solution from ASI Mining, owned 34% by Epiroc, after the completion of a trial of the Mobius® Haulage A.I. system on a Cat 793D last year.

The first phase of the commercial project is already kicking off, with the first of six Cat 793s converted to autonomous mode now up and running at Yeristovo. On completion of this first phase of six trucks, consideration will be given to timing of further deployment for the remainder of the Yeristovo truck fleet.

This trial and rollout may appear fairly routine, but behind the scenes was an 18-month process to settle on ASI’s solution.

“For us, as a business, we have about 86 trucks deployed on site,” North said. “We simply couldn’t take the same route BHP or Rio took three or four years ago in acquiring an entirely new autonomous fleet. At that point, Cat and Komatsu were the only major OEMs offering these solutions and they were offering limited numbers of trucks models with no fleet integration possibilities.

“If you had a mixed fleet – which we do – then you were looking at a multi-hundred-million-dollar decision to change out your mining fleet. That is prohibitive for a business like ours.”

Ferrexpo personnel visited ASI Mining’s facility in Utah, USA, several times, hearing all about the parent company’s work with NASA on robotics. “We knew they had the technical capability to work in tough environments,” North remarked.

“We also saw work they had been doing with Ford and Toyota for a number of years on their unmanned vehicles, and we witnessed the object detect and collision avoidance solutions in action on a test track.”

Convinced by these demonstrations and with an eye to the future of its operations, Ferrexpo committed to an OEM-agnostic autonomous future.

“If we want to get to a fully autonomous fleet at some stage in the future, we will need to pick a provider that could turn any unit into an autonomous vehicle,” North said. It found that in ASI Mining’s Mobius platform.

Such due diligence is representative not only of the team’s thorough approach to this project, it also reflects the realities of deploying such a solution in Ukraine.

“It is all about building capability,” North said. “This is new technology in Ukraine – it’s not like you can go down the road and find somebody that has worked on this type of technology before. As a result, it’s all about training and building up the capacity in our workforce.”

After this expertise has been established, the automation rollout will inevitably accelerate.

“Once we have Yeristovo fully autonomous, we intend to move the autonomy program to Belanovo, which we started excavating a couple of years ago,” North said. “The last pit we would automate would be Poltava, purely due to complexity.”

Belanovo, which has a JORC Mineral Resource of 1,700 Mt, is currently mining overburden with 30-40 t ADTs shifting this material. While ASI Mining said it would be able to automate such machines, North decided the automation program will only begin when large fleet is deployed.

“When we deploy large fleet at Belanovo and start to move significant volumes, we intend for it to become a fully-autonomous operation,” he said.

Poltava, which is a single pit covering a 7 km long by 2 km wide area (pictured below), has a five-decade-long history and a more diverse mining fleet than Yeristovo. In this respect, it was always going to be harder to automate from a loading and haulage point of view.

“If you think about the fleet numbers deployed when Belanovo is running, we will probably have 50% of our fleet running autonomously,” North said. “The level of capability to run that level of technology would be high, so it makes sense to take on the more complex operation at Poltava at that point in time.”

Consolidation and decarbonisation

This autonomy transition has also given North and his team the chance to re-evaluate its fleet needs for now and in the future.

This is not as simple as it may sound to those thinking of a typical Pilbara AHS fleet deployment, with the Yeristovo and Poltava mines containing different ore types that require blending at the processing plant in order to sustain a cost-effective operation able to produce circa-12 Mt/y of high-grade (65%-plus Fe) iron ore pellets and concentrate.

“That limits our ability in terms of fleet size for ore mining because we want to match the capacity of the fleet to the different ore streams we feed into the plant,” North said.

This has seen the company standardise on circa-220 t trucks for ore movement and 300-320 t trucks for waste haulage.

On the latter, North explained: “That is about shovel utilisation, not necessarily about trucks. If you go much larger than that 320-t truck, you are talking about the need to use large rope shovels and we don’t have enough consistent stripping requirements for that. We think the 800 t-class electric hydraulic excavator is a suitable match for the circa-320 t truck.”

This standardisation process at Poltava has seen BELAZ 40 t trucks previously working in the pit re-assigned for auxiliary work, with the smallest in-pit Cat 777 trucks acting as fuel, water and lubrication service vehicles at Poltava.

“The Cat 785s are the smallest operating primary fleet we have at Poltava,” North said. “We also have the Hitachi EH3500s and Cat 789s and Cat 793s, tending to keep the bigger fleet towards Yeristovo and the smaller fleet at Poltava.”

In carrying out this evaluation, the company has also plotted its next electrification steps.

“Given we have got to the point where we know we want 220 t for ore and 300-320 t nominally for waste at Yeristovo, we have a very clear understanding of where we are going in our efforts to support our climate action,” North said.

Electrification of the company’s entire operation – both the power generation and pelletising segment, and the mobile fleet – forms a significant part of its carbon reduction plans.

A 5 MW solar farm is being built to trial the efficacy of photovoltaic generation in the region, while, in the pelletiser, the company is blending sunflower husks with natural gas to power the process. Fine tuning over the past few years has seen the company settle on a 30:70 sunflower husk:natural gas energy ratio, allowing the company to make the most of a waste product in plentiful supply in Ukraine.

On top of this, the company is recuperating heat from the pelletisation process where possible and reusing it for other processes.

With a significant amount of ‘blue’ (nuclear) or ‘green’ (renewable) power available through the grid and plans to incorporate renewables on site, Ferrexpo looks to have the input part of the decarbonisation equation covered.

In the pellet lines, North says green hydrogen is believed to be the partial or full displacement solution for gas firing, with the company keenly watching developments such as the HYBRIT project in Sweden.

On the diesel side of things, Ferrexpo is also charting its decarbonisation course. This will start with a move to electric drive haul trucks in the next few years.

Power infrastructure is already available in the pits energising most of its electric-hydraulic shovels and backhoes, and the intention is for these new electric drive trucks to go on trolley line infrastructure to eradicate some of the operation’s diesel use.

“Initially we would still need to rely on diesel engines at the end of ramps and the bottom of pits, but our intention is to utilise some alternative powerpack on these trucks as the technology becomes available,” North said.

He expects that alternative powerpack to be battery-based, but he and the company are keeping their options open during conversations with OEMs about the fleet replacement plans.

“We know we are going to have to buy a fleet in the next couple of years, but the problem is when you make that sort of purchase, you are committing to using those machines for the next 20 years,” North said. “During all our conversations with OEMs we are recognising that we will need to buy a fleet before they have probably finalised their ‘decarbonised’ solutions, so all the contracts are based on the OEM providing that fully carbon-free solution when it becomes available.”

With around 15% of the company’s carbon footprint tied to diesel use, this could have a big impact on Ferrexpo’s ‘green’ credentials, yet the transition to trolley assist makes sense even without this sustainability benefit.

“The advantages in terms of mining productivity are huge,” North said. “You go from 15 km/h on ramp to just under 30 km/h on ramp.”

This is not all North offered up on the company’s carbon reduction plans.

At both of Ferrexpo’s operations, the company moves a lot of ore internally with shuttle trains, some of which are powered by diesel engines. A more environmentally friendly alternative is being sought for these locomotives.

“We are working with rail consultants that are delivering solutions for others to ‘fast follow’ that sector,” North said referencing the project already underway with Vale at its operations in Brazil. “We are investigating at the moment how we could design and deploy the solution at our operations for a lithium-ion battery loco.”

Not all the company’s decarbonisation and energy-efficiency initiatives started as recently as the last few years.

When examining a plan to reach 12 Mt/y of iron ore pellet production, North and his team looked at the whole ‘mine to mill’ approach.

“The cheapest place to optimise your comminution of rock is within the mine itself,” North said. “If you can optimise your blasting and get better fragmentation in the pit, you are saving energy, wear on materials, etc and you are doing some of the job of the concentrator and comminution process in the mine.”

A transition to a full emulsion blasting product came out of this study, and a move from NONEL detonators to electronic detonators could follow in the forthcoming years.

“That also led us into thinking about the future crusher – where we want to put it, what materials to feed into the expanded plant in the future, and what blending ratio we want to have from the pits,” North said. “The problem with pit development in a business that is moving 150-200 Mt of material a year is the crusher location needs to change as the mining horizons change.”

It ended up becoming a tradeoff between placing a new crusher in the pit on an assigned bench or putting it on top of the bench and hauling ore to that location.

The favoured location looks like being within the pit, according to North.

“It will be a substantial distance away from where our existing facility at Poltava is and we will convey the material into the plant,” he said. “We did the tradeoff study between hauling with trains/trucks, or conveying and, particularly for Belanovo, we need to take that ore to the crusher from the train network we already have in place.”

These internal ‘green’ initiatives are representative of the products Ferrexpo is supplying the steel industry.

Having shifted away from lower grade pellets to a higher-grade product in the past five years and started to introduce direct reduced iron pellet products to the market with trial shipments, Ferrexpo is looking to be a major player in the ‘green steel’ value chain.

North says as much.

“We are getting very close to understanding our path forward and our journey to carbon neutrality.”

Primero banks new work with Fortescue, Rio Tinto and Hazer Group

Primero Group says it has recently booked new business totalling some A$55 million ($39 million) with Fortescue Metals Group, Rio Tinto and the Hazer Group as it continues to build out its 2021 financial year contracted order book.

First, it has been awarded the engineering, procurement and construction contract for the Non-Process Infrastructure (NPI) at Fortescue’s Eliwana mine and rail project, in the Pilbara.

Works commenced in late July based on a limited notice to proceed, with the full contract now awarded to Primero following a successful Early Contractor Involvement (ECI) process. The contract includes the complete engineering design, procurement and construction of heavy vehicle workshops and washdown and refuelling infrastructure required for the new Eliwana mine, with works expected to be completed in the 2021 financial year.

Once completed, the $1.275 billion Eliwana project, which includes the building of a 30 Mt/y iron ore processing facility, will maintain Fortescue’s overall production rate of a minimum 170 Mt/y over 20 years.

With Rio Tinto, Primero has been awarded two multi-year Master Service Agreements for NPI and Structural, Mechanical, Piping services across the miner’s Pilbara operational and project locations. The two contracts have an initial term of three years, with an option for a two-year extension. They cover sustaining capital and maintenance projects required over that period across all Rio Tinto Iron Ore Pilbara sites, it said.

The services cover design, procurement and construction activities for engagement under negotiated commercial terms in a “panel style agreement”, according to Primero.

Primero has also been awarded an EPC contract for Hazer Group’s hydrogen/graphene commercial demonstration plant in Western Australia at the Woodman Point Water Treatment Facility.

Hazer is undertaking the commercialisation of the Hazer Process, a low-emission hydrogen and graphite production process. This process enables the effective conversion of natural gas and similar methane feedstocks, into hydrogen and high-quality graphite, using iron ore as a process catalyst, according to the company.

“The full project award has followed a successful ECI process that has extended over the past 12 months,” Primero said. “This process was targeted at developing the technology engineering to the point where a commercial contract could be executed to deliver the project. The project is the first of its kind in the new global renewables energy market and is patented groundbreaking technology in the hydrogen space.”

Alongside this, Primero said it had been awarded the detailed design contract for a 130 km water delivery pipeline and associated pumping stations for the Covalent Lithium Mt Holland project feasibility study in Western Australia.

Primero said its committed order book for the 2021 financial year now stands at around A$285 million.

SSAB, LKAB and Vattenfall start up world’s first pilot plant for fossil-free steel

SSAB, LKAB and Vattenfall have celebrated the start-up of their HYBRIT pilot plant as part of a project to produce fossil-free sponge iron.

Sweden Prime Minister, Stefan Löfven, started up the plant together with Isabella Lövin, Minister for Environment and Climate and Deputy Prime Minister in Sweden, Martin Lindqvist, President and CEO of SSAB, Jan Moström, President and CEO of LKAB, and Magnus Hall, President and CEO of Vattenfall, today.

The achievement comes just over two years since ground was broken to mark the start of the pilot plant build for fossil-free sponge iron (direct reduced iron/hot briquetted iron) with financial support from the Swedish Energy Agency.

At the plant, HYBRIT will perform tests in several stages in the use of hydrogen in the direct reduction of iron ore. The hydrogen will be produced at the pilot plant by electrolysing water with fossil-free electricity. Tests will be carried out between 2020 and 2024, first using natural gas and then hydrogen to be able to compare production results.

The framework for HYBRIT also includes a full-scale effort to replace fossil oil with bio oil in one of LKAB’s existing pellet plants in Malmberget, Sweden, in a test period extending until 2021. Preparations are also under way to build a test hydrogen storage facility on LKAB’s land in Svartöberget in Luleå, near the pilot plant.

The HYBRIT initiative has the potential to reduce carbon dioxide emissions by 10% in Sweden and 7% in Finland, as well as contributing to cutting steel industry emissions in Europe and globally. Today, the steel industry generates 7% of total global carbon-dioxide emissions, according to the companies.

“With HYBRIT, SSAB, LKAB and Vattenfall aim to create a completely fossil-free value chain from the mine to finished steel and to introduce a completely new technology using fossil-free hydrogen instead of coal and coke to reduce the oxygen in iron ore,” they said. “This means the process will emit ordinary water instead of carbon dioxide.”

Chevron to supply gas to BHP Nickel West operations

Chevron has announced the signing of a domestic gas sale agreement with BHP’s Nickel West division that will see a total of 22 Pj of equity domestic gas delivered to the operations in Western Australia over a 3.5-year period.

Chevron will supply the natural gas from its Wheatstone domestic gas facility from July.

Chevron Australia Managing Director, Al Williams, said the agreement highlighted the important role of natural gas in powering critical industries, such as mining, across the state.

“As a reliable and cost-effective way to generate electricity, natural gas is a vital energy source for current and future energy needs of Western Australian industry,” he said.

At full capacity, the Chevron-operated Gorgon and Wheatstone natural gas facilities will produce 500 tj/d of domestic gas for the Western Australia market – enough to generate electricity for 4.3 million households, according to the company.

Nickel West is a fully integrated mine-to-market nickel business with over 3,500 employees and contractors, BHP says. All nickel operations (open pit and underground mines, concentrators, a smelter and refinery) are located in Western Australia. The integrated business adds value throughout the company’s nickel supply chain, with the majority of Nickel West’s current production sold as powder and briquettes, the company added.

The division is currently in the middle of construction of a nickel sulphate plant at the Kwinana nickel refinery. Stage 1 is expected to produce up to 100,000 t/y of nickel sulphate.

Cat continues to see LNG interest for large mining trucks

Caterpillar’s focus on minimising the environmental impact its large mining trucks have on operations has seen it pursue many new and old technologies of late, one of which is the use of alternative fuels.

In a recent Viewpoint post, David Rea, General Manager for Cat Large Mining Trucks, said the company is looking throughout its supply chain to reduce the emissions associated with using and building its vehicles.

“We’re meeting the most stringent emissions regulations,” he said. “We’re offering trucks that can run on alternative fuels, and others that can be electrified using our trolley conversion kit. We’re also making sure we get the most out of parts and components so we’re reducing waste and energy usage.”

On top of this, the company is pursuing Project Verde, a project “focused on energy and emissions reduction, and helping customers decrease their carbon footprints through machinery and power solutions that contribute to lower greenhouse gas”, Brian Weller, Chief Engineer, Surface Mining & Technology, Caterpillar Inc, told IM earlier this year.

In the meantime, Cat said it continued to see interest around the world for alternative fuels and was researching various solutions both in the lab and field in response to this.

One solution, liquefied natural gas (LNG), is a clean-burning fuel that can be sourced locally and is produced more naturally than diesel. It has been discussed as a diesel fuel alternative in the industry for more than a decade, but it is yet to find widespread industry appeal.

Nic Tegtmeyer, Senior Product Specialist at Cat, says the company’s Dynamic Gas Blending (DGB) conversion kits for mining trucks are a dual-fuel technology that enables miners to substitute diesel fuel with LNG.

“Not only has LNG been proven to reduce emissions by up to 30%, it also costs about 30% less than diesel,” he said. “Physical ability remains over 90% and DGB has no impact on unplanned downtime.”

DGB vaporises liquid fuel into natural gas, then replaces diesel fuel with LNG when possible. On average, DGB replaces about 60-65% of diesel with LNG, according to Cat.

One place where this technology is being utilised is Fresnillo’s Penmont division in Mexico, where Cat and its Mexico-based dealer, Matco Cat, has converted the entire fleet of large mining trucks at the La Herradura open-pit mine, in Sonora.

Tegtmeyer says DGB is relatively new in mining, but it has over 10 million operating hours of proven data to its name.

“Testing and customer trials have resulted in zero recordings of unplanned downtime related to DGB,” he added.

DGB kits are currently available for Cat 785C and 793D trucks, but this offering could expand beyond that, according to Tegtmeyer.

“We’re listening to our customers and gauging interest in offering the kits for additional truck models,” he said. “Not every mine is an ideal candidate for this solution, but if a natural gas supply is nearby, it can provide significant savings.”

This article is an edited version of this story here.

Newcrest and Chevron Australia sign natural gas agreement

Newcrest Mining has signed a domestic gas sale agreement with Chevron Australia that will see the energy company deliver domestic gas from its portfolio across the Wheatstone (pictured), Gorgon and North West Shelf facilities, in Australia.

Some 16 PJ of equity domestic gas will be delivered over the 3.5-year agreement, which will begin soon and end in July 2023, according to Chevron.

Chevron Australia Managing Director, Al Williams, said: “Chevron is a leading and growing domestic gas supplier to Australia and we’re proud to deliver new natural gas supply to Western Australian industries, businesses and households.”

He added: “As a reliable and cost-effective way to generate electricity, natural gas is a vital energy source for current and future energy needs, powering local jobs, industry and communities.”

At full capacity, the Chevron-operated Gorgon and Wheatstone natural gas facilities will produce 500 TJ/d of domestic gas for the Western Australia market – enough to generate electricity for 4.3 million households, according to the company.

As a key and growing participant in the evolving Western Australian market, Chevron is actively marketing domestic gas under long and shorter-term arrangements.

Suncor to cut GHG emissions by 25% with natural gas project

Suncor has made the decision to replace its coke-fired boilers with two cogeneration units at its Oil Sands Base Plant, in Alberta, Canada, as it looks to lower its carbon footprint within the province.

The cogeneration units will provide reliable steam generation required for Suncor’s extraction and upgrading operations and generate 800 MW of power, the company said.

The power will be transmitted to Alberta’s grid, providing reliable, baseload, low-carbon power, equivalent to around 8% of Alberta’s current electricity demand. This project will increase demand for clean natural gas from Western Canada, Suncor said.

Mark Little, President and CEO, said: “This is a great example of how Suncor deploys capital in projects that are economically robust, sustainability minded and technologically progressive.

“This project generates economic value for Suncor shareholders and provides baseload, low-carbon power equivalent to displacing 550,000 cars from the road, approximately 15% of vehicles currently in the province of Alberta.”

The project cost is estimated to be C$1.4 billion ($1.06 billion), delivering a high teens return and projected to be in-service in the second half of 2023.

“This project will substantially contribute to the company’s goal of an increased C$2 billion in free funds flow by 2023,” the company said. “This will be achieved through oil sands operating cost and sustaining capital reductions along with margin improvements. It will also contribute materially to Suncor’s publicly announced greenhouse gas (GHG) goal.”

Replacing the coke-fired boilers with cogeneration will reduce GHG emissions associated with steam production at Base Plant by some 25%. It is also expected to reduce sulphur dioxide and nitrogen oxide emissions by approximately 45% and 15%, respectively, the company says.

The cogeneration units will eliminate the need for a flue gas desulphurisation (FGD) unit, which is currently used to reduce sulphur emissions associated with coke fuel. Decommissioning the FGD unit will reduce the volume of water the company withdraws from the Athabasca River by around 20%.

“By producing both industrial steam and electricity through a single natural gas-fuelled process, cogeneration is the most energy-efficient form of hydrocarbon-based power generation. Suncor believes this project will contribute to both Alberta and Canada’s climate ambitions.”

Cummins powers up solutions drive in face of mining energy evolution

Craig Wilkins, Director of Prime Power & Global Sales Support at Cummins, sees the company’s new HSK78G natural gas generator as a mainstay in the mine power sector, able to offer companies fuel flexibility, reliable power generation and comparatively low emissions.

With the industry currently undergoing an evolution in power inputs – the focus having shifted towards renewable and clean options that can offer both a reduced carbon footprint and energy diversity – the HSK78G can be used alongside the likes of diesel, solar and wind energy to ensure mining companies have a reliable power solution in place.

Cummins debuted the 1.6-2 MW generator series at the 2019 Middle East Electricity show back in March and Wilkins told IM at the AIMEX 2019 show in Sydney, Australia, last week (Cummins stand pictured above) that the reception from the mining sector has been positive.

The HSK78G (pictured, left) has been running at Blackham Resources’ Matilda-Wiluna gold mine, in Western Australia, for a few years, in addition to units being deployed at mine sites in China. The company also has plans to test the generator’s efficiency at altitude with a mining customer trial lined up next year in Latin America.

Cummins says the HSK78G is a prime power solution for heavy industry installations in the most extreme environments. Its engineering is designed to push the boundaries of performance and challenge the perceived limitations of natural gas generators for mining operations, according to the company, with the generator designed to operate at the highest altitudes in the most remote locations, all far from the closest grid. This sees the unit offer full power capability without derating at 50°C (122°F) and 500 m (1,640 ft) above sea level (asl), and up to 4,000 m asl with some derating.

It also offers “barrier-breaking fuel flexibility” and the ability to burn pipeline natural gas, flare gas down to 40 methane number (MN), biogas and ultra-low fuels down to 273 BTU/scf without derating. At the same time, it can handle contaminant levels on very aggressive fuels, Cummins says.

This sees the generator deliver high electrical efficiency of up to 44.2% (50 Hz) and 43.5% (60 Hz) on a range of pipeline natural gas down to 70 MN, with as low as 250 mg/NM³ nitrous oxide emitted without aftertreatment – bringing it in compliance with the relevant EU and US standards.

The most obvious markets for the generator are those regions with plentiful natural gas supplies – Australia being one – according to Wilkins. Yet, as all operators are looking to cut their fuel and electricity consumption and diversify their energy mix, the 78 L generator set could end up reaching a far wider audience.

Battery backup is being discussed across the mine power sector currently, with installations such as the wind power solution at Glencore’s Raglan nickel mine in Nunavik, Canada, held up as an example of how effective renewable energy can be even when the wind is not blowing.

Despite this, not all renewable power solutions using batteries offer an economic business case for mines. In some applications, a battery’s weight and size can also inhibit operations.

This leaves a void for other energy inputs to fill. Wilkins is confident natural gas and the generators Cummins is now producing can fill that void in many markets looking for a cleaner power supply than the alternative diesel equivalent, and one that can be relied on regardless of weather.

Cummins has invested heavily in the HSK78G, which it is hoping will become a platform it can build a natural gas generator portfolio on.

“It can deal with all different gas types,” Wilkins told IM, explaining that the generator has been fitted with a variety of sensors that assess the energy input and react accordingly. This allows customers to use a variety of natural gas in the generator from different industrial sectors, while benefitting from the same performance.

Different sensors on the machine can constantly monitor the generator’s performance, providing the baseline predictive maintenance solution every mining customer operating in a remote region is currently after.

Realising this 12 cylinder generator is likely to be used as part of a wider power solution – not necessarily being in constant operation – the HSK78G is also fitted with a load variation system that is able to manage fluctuations in power supply.

As the ‘platform’ comment would indicate, the HSK78G is not the start and end of Cummins’ venture into the gas generator field.

Wilkins said the company is already working on the launch of a 500 kW gas generator that could be used in remote communities (such as those around mine sites). This is expected to be launched later this year.

He also said Cummins’ engineers envisaged both 16-cylinder and 20-cylinder generators being added to the range.

The company is not setting its sights solely on natural gas as far as mining energy diversity goes.

Wilkins said. “We have got to be across a number of different solutions.”

To this end, Cummins has made investments in natural gas, diesel and batteries. It is also awaiting approval for its acquisition of fuel cell manufacturer Hydrogenics.

This corporate activity is a clear indicator of the changing power characteristics of not only the mine power segment, but the wider industrial energy sector.

“Customers are demanding more of a ‘solution’ than a product now,” Wilkins said. “There are a lot of companies out there that can provide the individual components, but we want to provide these solutions.”

Cummins HSK78G gas generator gets a runout at Blackham’s Matilda-Wiluna gold mine

Blackham Resources has enlisted the help of Cummins and its new HSK78G gas generator to power up production at the Matilda-Wiluna gold operations in Western Australia, according to the engine manufacturer.

Blackham’s power supplier, Perth-based Contract Power Group, selected the newly launched Cummins HSK78G generator to supply prime power for the next stage of expansion at the mine. The new gas-powered generator will provide up to 20% of the mine’s power as the company strives to increase its production.

Located 500 m above sea level, Matilda-Wiluna is subject to extreme temperatures, ranging from -2° C to 50° C throughout the year. Considering these conditions, the HSK78G’s capability to deliver power in remote areas and extreme climates – generating up to 1,800 kWe in ambient temperatures of 55°C – was a crucial requirement behind the choice to select the generator, Cummins said.

With a power density of 2 MW from the new Cummins 78-litre, V12 gas engine, the HSK78G provides high electrical efficiency up to 44.2% on a wide range of pipeline natural gas down to 70 methane number (MN) without impacting power and efficiency output, according to the company.

Craig Wilkins, Director of Cummins Prime Power Segment and Global Sales Support, said: “It’s an exciting time in the power solutions sector and we’re delighted to deliver the latest innovations in gas generator technology to Blackham Resources. The company operates on a massive scale and required a sizeable dependable power generation solution to operate in difficult conditions. Cummins’ HSK78G offered the required performance levels as well as one of the industry’s longest major overhaul service cycles of 80,000 hours.”

Marc Grosser, General Manager of Contract Power Group, said: “We are happy with the performance of the unit so far and the associability of maintenance items. It’s a compact unit and very well designed. Cummins have ensured there is fast service and support when called upon, despite our extremely remote location.”

Blackham expects to produce 70,000-80,000 oz of gold in its 2020 financial year and aims to progress its Sulphide Expansion project to unlock the large sulphide reserves and resources it has delineated at Wiluna.

Cummins powers up for the future of mining

Mining operations are embracing the opportunities created by new technology, from automation and electric vehicles to renewable energy, but what can traditional fossil fuel power generation contribute to this technology-led evolution of mining? Craig Wilkins, Director Prime Power at Cummins, explains how natural gas power is key to meeting the industry’s power needs in the coming decades.

Many mining operations take place in remote parts of the world where access to large electric utility feeds is either unavailable or requires significant investments in electrical transmission and distribution. These same sites may also have little or no access to pipeline gas, or experience a variation of natural gas supply. In addition, they are operating in the most extreme climates imaginable, faced with blistering heat, the wettest humidity and high altitudes.

Therefore, the need to secure a reliable prime and peaking power supply to keep production up and running 24/7 is paramount.

Cummins has responded to this challenge with a significant investment into the natural gas arena with the launch of its HSK78G gas-powered generator, a flexible prime power solution for heavy-industry installations in the most extreme environments. Its extreme engineering is designed to push the boundaries of performance and challenge the perceived limitations of natural gas generators for mining operations. It has barrier-breaking fuel flexibility, able to burn pipeline natural gas, flare gas and biogas, even the lowest BTU methane down to 40MN, and free fuel sources, with high efficiency and low emissions.

The investment on the HSK78G comes as the power market across the globe is changing. Technological advances in renewable energy and its application with batteries as part of modular power networks, tend to dominate the future of power generation. The concept is flexible, scalable and able to power entire cities as well as remote off-grid installations – such as mines. So why invest in traditional natural gas power?

Gas vs diesel

Miners continuously look for ways to lower their cost of production.  One of the major sources of cost for an open-pit mine site is fuel.  Some mines have access to an un-interruptible supply of natural gas that offers them a lower total cost when compared to diesel. 

Although technological advancements in natural gas storage and filling have yet to yield an economical replacement to diesel engines in mobile mining equipment, prime power generator sets are quickly moving towards lean burn, natural gas technologies. Lean burn gas powered generator sets use twice as much air in the fuel/air mix than required for total burn, which lowers burn temperature and NOx output, ensuring compliance with emission regulations.

Due to increasing emissions limits being adopted for generator sets, diesel generators sometimes are limited in their use. Lean burn, natural gas generator sets typically have ten times lower NOx than diesel equivalents (250-500 mg/Nm3 for natural gas compared to 2,500-3,000 mg/Nm3 for diesel.) Also, lean burn particulate levels are almost zero, so meeting location specific emissions regulations can be far easier across a global perspective.

Power generation fuel flexibility

Technological advances in design, running in tandem with market change, will result in gensets that can use fuel efficiently in varying qualities. This innovation is demonstrated by our new HSK78G, which delivers high electrical efficiency of up to 44.2% (50 Hz) and 43.5% (60 Hz) on a range of pipeline natural gas down to 70 methane number (MN) without impacting power output and efficiency.

Ultimately this fuel flexibility empowers operators to derive clean power from what would otherwise be regarded as waste products, at worst emissions. The technology for smarter and cleaner power solutions is speeding up and adoption will continue to grow as more mines embrace its capital expenditure (capex) and operational expenditure (opex) advantages.

Engineered to extremes

A further challenge for the mining operation is the environment in which the generator set operates. As engines operate, they produce heat and tend to be more sensitive to the ambient temperature levels. A generator’s ambient capability is defined as the maximum temperature at which it can operate without experiencing a loss of efficiency and it is an essential factor for customers operating in such extreme environments.

Without an engine capable of meeting high ambient temperatures, customers risk having to derate their engine, which can lead to reduced power efficiency and shorter operational life from the generator or having to stop it altogether. The HSK78G has been designed to operate at the highest ambient temperatures in the most remote locations, all far from the closest grid, offering full power capability without derating at 50°C (122°F) and 500 m (1,640 ft).

Gas vs renewables

The focus of many customers is to achieve the optimum levelised cost of electricity (LCOE) given the availability of different technologies which are suitable for their application. This can range from 100% gas generation through to a balanced mix of renewable sources such as wind or solar, and complementary storage technologies that leverages the reliability of gas generation to ride through periods where renewables are limited by their cyclical nature. The technology mix utilised will drive the different capex and opex cost scenarios that will ultimately affect the LCOE.

Improvements in gas engine technology, such as in the new HSK78G engine from Cummins, have pushed maintenance and overhaul limits well beyond the traditional envelope, thereby lowering opex costs over time. Jointly, we will continue to see cost reductions in storage and battery technology as volumes increase. For the near future, however, miners will continue to look for mixed technology to balance their capex and opex trying to achieve the lowest LCOE for its sites.

Preparation for electrification

As much as 40% of an underground mine’s energy outlay is spent on powering ventilation systems to remove pollutants from tunnels. Reducing the use of fossil fuels underground could have significant cost benefits for underground mines. In addition, The International Council on Mining and Metals have set their vision to provide solutions for minimizing the impact of underground diesel exhaust by 2025. As more underground mining vehicles and equipment contemplate the potential benefits of electrification, Cummins will continuously invest in power systems that will be ready to support such power need and respond to any changes in the mining industry

The right technology choice

In the future most power systems will require a mix of technologies that are specifically suited to their environment, emissions zone and location.  Natural gas power offers mining operators an efficient and proven and prime power solution. From Cummins perspective, a lot of investments are made in new gas engineering technology, which are demonstrated with the HSK78G gas series. Additional product investments are being made within the 500-1 MW space, which will be released later this year, offering a comprehensive gas product portfolio to meet all market requirements. Progressively stringent global emissions standards are also driving Cummins investment into a variety of technologies – natural gas, diesel, batteries and fuel cells, to ensure that customers have the right power for the right application.