Hydrogen Could Be A Game-Changer For Midstream Oil & Gas
This is the final article in a series that examines Environmental, Social, and Corporate Governance (ESG) programs in the oil industry, with an emphasis on how some companies are using hydrogen to improve their metrics. Previous articles were:
- The Cost Of Ignoring ESG
- How Blue Hydrogen Can Help Decarbonize The Economy
- Addressing Blue Hydrogen Feedback
Today I want to talk about specific examples of how various companies are incorporating hydrogen into their businesses.
Alerian on Midstream ESG
The genesis of this series came from a recent research piece from independent energy infrastructure and master limited partnership (MLP) market intelligence data provider Alerian: Midstream/MLPs: The Unsung ESG Push.
The research piece covered a number of different initiatives, but I was particularly interested in learning what these companies are doing in the area of hydrogen. I inquired, and heard back from Mauricio Samaniego, Senior Research Analyst, Alerian and S-Network Global Indexes, who said:
“As you may be aware, the recurring hydrogen theme for midstream has revolved around natural gas pipelines and storage facilities being used for the transportation and storage of blue or green hydrogen over the next decade.
Today, hydrogen initiatives are in very early stages and are mostly focused on blending hydrogen into existing natural gas pipelines, which has been set forth, explored, and/or discussed by Enbridge (ENB), TC Energy (TRP), Kinder Morgan (KMI), and The Williams Company (WMB). Additionally, TRP and Enterprise Product Partners (EPD) have also discussed—and are evaluating—leveraging existing nuclear and petrochemical plants for hydrogen production.”
He included a number of bullet points delineating these hydrogen-related initiatives, some of which I have used in the commentary below.
Hydrogen in Midstream
There are three readily accessible uses for hydrogen produced near a natural gas field. The first is compression. Midstream operators rely on compression to move natural gas from the field to the customer.
The National Energy Technology Laboratory (NETL), a branch of the Department of Energy, estimates that there are 1,700 midstream natural gas pipeline compressor stations with a total of 5,000-7,000 compressors, approximately 13,000-15,000 smaller compressors in upstream, and 2,000-3,000 compressors (all sizes) in downstream oil & gas and liquefied natural gas (LNG) applications. The DOE estimates that 2-3% of U.S. natural gas production is utilized by these compressors. (Source).
Among other companies, GE has developed hydrogen-fueled compressors. They currently have more than 100 units in the field operating on up to 100% hydrogen. So, a midstream operator could utilize hydrogen locally produced from underutilized products like ethane to improve ESG metrics.
Industrial gas turbines are currently the prime mover of choice for most mainline applications. Each of these turbines emits carbon dioxide, and they are high-profile targets for ESG improvements. Within the next 15 years, an estimated 5 million horsepower of compression must be replaced. (Source).
Operators of gas-fired power plants are also in the crosshairs, with regulators and investors setting ambitious CO2 reduction targets. Power plant turbines can be operated using a blend of methane and up to 20% hydrogen to reduce CO2 emissions. Mitsubishi Power has announced development of turbines capable of operating on 100% hydrogen.
To get that hydrogen to the power plants, many midstream operators are testing the blending of hydrogen into natural gas pipelines. In its Q4 2020 earnings call, Kinder Morgan mentioned having the technology in place to blend hydrogen with natural gas and move it via its pipelines.
Enbridge currently has two ongoing hydrogen projects, including a $5.2M hydrogen blending pilot project in Markham, Ontario and a $90 million, 20 MW hydrogen production and blending project in Gatineau in western Quebec.
At a recent energy conference, Energy Products Partners mentioned evaluating hydrogen applications for transportation and storage—citing ongoing discussions with a petrochemical company regarding hydrogen pipeline and storage projects.
Related: China Oil Consumption Seen Peaking In 5 Years
TC Energy (formerly TransCanada) is evaluating blending hydrogen into its existing pipeline, as well as adding dedicated hydrogen assets. On their Q1 2021 conference call, management mentioned that they see their pipelines as being big assets when it comes to thinking about the future of how hydrogen is going to move.
Finally, the Canadian Government has incorporated a hydrogen strategy that intends to position Canada as a world-leading producer of clean hydrogen. This explains why Canadian midstream corporations are leading the hydrogen movement (e.g., Enbridge, TC Energy).
For American midstream operators, U.S. policy support has started to take shape the last few months, with both the Biden Administration and Congress proposing new and expanded hydrogen tax credits, along with other incentives for hydrogen investment. Along with the proposed policies, more supportive legislation could presumably accelerate the adoption of hydrogen and lead to further hydrogen-related developments across the midstream space.
By Robert Rapier
How mining waste can be used for hydrogen fuel production
MINING.COM Staff Writer | September 15, 2021
Powdered feldspar.
Researchers at the Queensland University of Technology have discovered a way to use mining waste as part of a potential cheaper catalyst for hydrogen fuel production.
The team led by Ziqi Sun and Hong Peng published these findings in the journal Advanced Energy & Sustainability Research. In their article, they explain that, normally, water splitting reactions that produce hydrogen are triggered using platinum, which costs about $1,450/ounce, iridium at $1,370/ounce and ruthenium at $367/ounce. Cheaper but less active metals such as cobalt, whose price is about $70,000/tonne, nickel at $26,000/tonne and iron at $641/tonne, are also used.
But they propose the idea of a new catalyst that requires only a small amount of these reactive metals and is combined with feldspars, aluminosilicate rock minerals found in mining waste that some companies pay about $30/tonne to dispose of. Feldspars make up about 60% of the Earth’s crust.
FELDSPARS ARE ALUMINOSILICATE ROCK MINERALS FOUND IN MINING WASTE. SOME COMPANIES PAY ABOUT $30/TONNE TO DISPOSE OF IT
In a series of experiments, the scientists triggered a water-splitting reaction using heated-activated feldspars nano-coated with only 1–2% of the cheaper reactive metals.
“Water splitting involves two chemical reactions—one with the hydrogen atom and one with the oxygen atom—to cause them to separate,” Sun said. “This new nano-coated material triggered the oxygen evolution reaction, which controls the overall efficiency of the whole water splitting process.”
According to Sun, cobalt-coated feldspar was very efficient and optimizing the new catalysts could see them outperform raw metals or even match the superior efficiency of platinum metals. He also said the aluminosilicates were chemically inert, but heat caused defects that were useful for chemical reactions and electron transport.
In his view, the new catalyst could potentially lower the cost of lithium-ion batteries and other sustainable energy solutions that rely on electrochemical conversions. This is why his group is now looking to test the catalysts at a pilot scale.
“Australia’s abundance of aluminosilicate and the simplicity of this modification process should make industrial-scale production of this new catalyst easy to achieve,” Sun said.
“Companies like Tesla could potentially use this technology for energy production, advanced energy storage solutions like new battery technologies, and renewable fuel.”
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