In an exciting development in the renewable energy space, Shell is set to install a 100MW renewable hydrogen electrolyzer at its Energy and Chemicals Park Rheinland in Germany. This electrolyzer will generate up to 44,000 kilograms of green hydrogen daily using renewable energy. The project, designed to help reduce the site’s carbon footprint, is expected to start operations in 2027.
Unlocking Shell’s Massive Green Hydrogen Project: The REFHYNE II
The REFHYNE II project is the outcome of the successful execution of the original REFHYNE initiative. The new phase, funded by the European Climate, Infrastructure, and Environment Executive Agency (CINEA), aims to scale up Europe’s largest Proton-Exchange Membrane electrolyzer from 10 megawatts to a massive 100 megawatts. Notably, it aims to produce ~ 15,000 tons of green hydrogen annually.
As mentioned before, it will be installed at Shell’s Rheinland Energy and Chemicals Plant in Germany. The electrolyzer will produce green hydrogen and oxygen from a renewable energy source. This green hydrogen will then be integrated into the existing refinery systems to help reduce emissions from refinery operations.

source: REFHYNE
REFHYNE II: A Strategic Investment in Green Hydrogen
REFHYNE II benefits from supportive policies, such as the EU’s binding renewable hydrogen targets and Germany’s regulatory framework. Additionally, the project has received backing from the EU’s Horizon 2020 research and innovation program. This investment aligns with Shell’s goal to transform its Energy and Chemicals Parks into lower-carbon product sources.
Shell’s Downstream, Renewables and Energy Solutions Director Huibert Vigeveno noted,
“Today’s announcement marks an important milestone in delivering our strategy of more value with less emissions. Investing in REFHYNE II is a visible demonstration of our commitment to the hydrogen economy, which will play an important role in helping to decarbonise Shell’s operations and customer products.”
Noted in Shell’s press release, the company’s key partners in REFHYNE II include ITM Power (Trading) Ltd, ITM Power Germany GmbH, Linde GmbH, TECNALIA, ETM, SINTEF AS, and CONCAWE. Shell anticipates that the hydrogen produced will meet the EU’s renewable fuels of non-biological origin (RFNBO) standards. It has further elaborated that the REFHYNE II project will fit within Shell’s cash capital expenditure plans and surpass the internal rate of return (IRR) targets for its Renewables & Energy Solutions division. This was highlighted during last year’s Capital Markets Day organized by Shell.
Shell’s Bold Investments in Green Hydrogen
Greg Joiner, Executive Vice President of Shell Energy said,
“Shell’s commitment to renewable generation projects creates a path toward a sustainable future, where innovation and clean energy come together to power a brighter world. Across Europe through these renewable developments and further third-party offtake agreements, Shell Energy is supporting businesses to progress the energy transition by providing expertise and a range of renewable power solutions and bespoke offers.”
Shell Nederland and Shell Overseas Investments, subsidiaries of Shell plc, have decided to build Europe’s largest renewable hydrogen plant, Holland Hydrogen I. It will begin operations next year at the Rotterdam port. The 200 MW electrolyzer will produce up to 60,000 kilograms of renewable hydrogen daily. Additionally, the plant will use power from the offshore wind farm Hollandse Kust which is partially owned by Shell. The green hydrogen will decarbonize the Shell Energy and Chemicals Park Rotterdam, the key manufacturing hubs for petrol, diesel, and jet fuel.
Notably, Shell has always been a trendsetter in the green hydrogen space. In 2022, Shell and Kansai Electric Power collaborated on liquid hydrogen (LH2) supply chains to decarbonize their businesses Their partnership involved producing decarbonized hydrogen, deploying Shell’s liquefaction and storage technology, and using the hydrogen at Kansai, Japan’s thermal power plants.
Manufacturing green hydrogen is playing a pivotal role in Shell’s energy transition strategy supporting it to reach net-zero emissions by 2050. No wonder, this has marked a significant step toward a sustainable future.
Will the EU Meet its 2030 Hydrogen Goals?
In 2022 green hydrogen got a whole new perspective with a wide range of uses. It was being used in steel production, mobility, natural gas blending, e-fuels, and heating. Thus, 41% of Europe’s clean hydrogen demand, amounting to 8.09 kt, came from these new hydrogen uses.
With Europe witnessing a rise in green hydrogen applications, the demand for it also grew. For instance, the Netherlands, the UK, and Austria rely on these applications for 100%, 90%, and 86% of their hydrogen consumption, respectively. In Estonia, it’s 100%, while in Switzerland, it’s 51%. Moreover, specific industries lead the demand in various countries. Germany’s refining sector accounts for 23%, Spain’s ammonia production makes up 80%, Iceland’s methanol production is at 90%, and Austria’s steel industry dominates at 83%. Check out the detailed report here: The EU hydrogen market landscape
source: EU
Furthermore, the European Roundtable on Climate Change and Sustainable Transition aka ERCST’s latest hydrogen report revealed that Europe has etched a significant mark in the low-carbon hydrogen market. It is fueled by ambitious targets and government incentives.
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The EU adopted a hydrogen strategy in 2020, aiming to install 6GW of electrolyzers by 2024 and 40GW by 2030.
The REPowerEU plan, introduced in 2022 to reduce reliance on Russian natural gas, set even higher goals. It targets 20 MTs of renewable hydrogen use by 2030, with 50% from domestic production. BloombergNEF estimates that meeting this domestic target requires 125GW of electrolyzer capacity, which is 3x of its 2030 target.
EU Member States have also set their electrolyzer targets separately. It totals to 54.3GW by 2030. These national goals align with the EU’s hydrogen strategy but fall short of the REPowerEU target. However, BloombergNEF forecasts that EU countries will deploy a maximum of 23GW by 2030, based on the ongoing projects and policies. On the downside, this study indicates that most countries may not meet their national electrolyzer goals.

Overall, with a solid investment backup, the REFHYNE 2 project will push innovation to its peak. Consequently, Shell’s experienced team will manage the major scale-up with precision, thereby advancing green hydrogen significantly to achieve the EU’s target.
The post Shell Powers Europe With A Mega 100MW Green Hydrogen Electrolyzer appeared first on Carbon Credits.
Carbon Footprint
Insetting vs Offsetting: Which Actually Counts Toward Your Scope 3 Targets
The accounting differences that decide whether your nature investment shows up in inventory, in BVCM, or nowhere at all.
The question reaches a procurement team about three weeks before the next sustainability committee meeting. Someone has read about insetting. Someone else has just signed off on an offset purchase. The CSO wants to know if the two are interchangeable. The answer is no, and the GHG Protocol Land Sector and Removals Standard is the reason why.
This article walks through what each term means at audit-grade specificity, what the standards actually say about how each gets counted, and how to decide which tool fits which target. The insetting vs offsetting question is one of the most-searched in corporate climate strategy, and one of the most poorly answered. By the end of this piece, you should be able to brief a committee on the difference without notes.
The two definitions, in plain English
Offsetting means buying carbon credits generated outside your value chain and retiring them against your residual emissions. The reduction happens somewhere else, financed by you, and the credit is the receipt.
Insetting means investing in emission reductions or removals inside your own value chain, typically with suppliers, where the reduction is directly linked to the products and services you buy. The reduction happens inside the boundary of your Scope 3 inventory, and the accounting treatment is fundamentally different.
The shorthand from the University of Oxford’s Nature-based Insetting Initiative is useful: insetting is what you do with the supply chain you have; offsetting is what you do with the supply chain you do not have.
What the GHG Protocol Land Sector Standard actually says
The GHG Protocol Land Sector and Removals Standard, finalised in 2024 after a multi-year pilot, sets the rules for how land-based emission reductions and removals enter corporate inventories. The Standard distinguishes between inventory accounting (Scope 1, 2, and 3) and project or intervention accounting (a separate methodology for crediting).
For insetting, the practical implication is that supplier-level interventions, when properly measured and attributed, can reduce your Scope 3 category 1 (purchased goods and services) emissions in your inventory. The reduction is not a credit retired against the inventory; it is a lower inventory number, period.
For offsetting, the credit is retired separately. It can be reported as a contribution toward a net-zero claim under the SBTi Beyond Value Chain Mitigation framework or as part of a VCMI Carbon Integrity claim, but it does not lower the inventory number.
A practical consequence: if your Science Based Target requires a 50% absolute reduction in Scope 3 emissions by 2030, insetting moves you toward the target. Offsetting does not. This single point of difference reshapes the procurement decision.
When insetting counts toward Scope 3 (and when it does not)
Insetting counts toward Scope 3 only when several conditions are met:
- The intervention must occur with an entity in your value chain.
- The emissions reduction or removal must be measured against a defensible baseline.
- The reduction must be attributed to your share of that supplier’s output, not double-counted with other buyers.
- It must follow the inventory accounting rules in the GHG Protocol Land Sector Standard, not the project accounting rules used to generate credits.
The most common failure mode is double counting. If your supplier sells the same reduction as a credit on the voluntary market and also reports it to you as a Scope 3 reduction, the math breaks. The Standard requires you to address this risk, typically by purchasing and retiring the supplier-issued credit as part of your inventory or by contractual provisions that prevent the supplier from selling the reduction twice.
When insetting does not count toward Scope 3: when the intervention sits with a supplier you do not buy from, when the baseline is not defensible, when the attribution is unclear, or when the documentation does not survive audit. Those cases default to Beyond Value Chain Mitigation, which is still useful but operates on a different ledger.
The procurement and supplier engagement question
Insetting is harder than offsetting. That is the unfashionable truth most buyers eventually confront. Offsetting is a transaction; insetting is a relationship.
To run an insetting program, you need supplier mapping precise enough to know which farms or facilities sit at which Scope 3 boundary. You need an engagement model that gets suppliers to participate, which usually requires multi-year commitments and shared economics. You need an MRV architecture that measures the right things and produces audit-ready documentation. And you need a contractual structure that prevents double counting and protects both sides.
The trade-off you receive in return is significant. Reductions count against your inventory rather than your residual. Supplier relationships deepen, which protects sourcing continuity. Yield and quality improvements often follow regenerative interventions, which reduces your input cost over time. And the regulatory file, under CSRD, CSDDD, EUDR, and the SBTi FLAG Guidance, is materially stronger.
Choosing the right tool for the right target
A practical decision rule. If your target is a science-based Scope 3 reduction and you operate in a FLAG sector or source FLAG commodities, insetting is the structurally correct tool. If your target is a net-zero claim that includes neutralising hard-to-abate residual emissions outside your value chain, BVCM via high-integrity offsets is the structurally correct tool. Most companies with material Scope 3 exposure need both, in different proportions, sequenced over time.
The sequencing matters. Insetting takes longer to stand up but produces a permanent reduction in the inventory. Offsetting can be transacted faster but does not change the inventory and now sits under tighter claim restrictions. Treat them as complementary tools with different jobs, not as substitutes. The Accountability Framework Initiative and the IUCN Global Standard for Nature-based Solutions both provide useful guardrails for the insetting side, with biodiversity, human rights, and benefit-sharing requirements that go beyond carbon math.
If you are mapping a Scope 3 reduction roadmap and need to scope which interventions count toward your inventory versus which sit in Beyond Value Chain Mitigation, the carbon and sustainability experts at Carbon Credit Capital can help you structure a nature-based supply chain investment program that fits your FLAG exposure, your target architecture, and your audit horizon. Schedule a consultation.
Carbon Footprint
Net zero needs nature: a carbon credit guide
Net zero is often described as a balancing act: cut what you can, account for the rest, and reach zero on the ledger. That framing is useful, but it leaves something out. It treats every tonne of carbon as interchangeable and every route to zero as equally sound, while the science tells a more specific story.
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Carbon Footprint
Deforestation in Malawi: causes and solutions
Malawi has lost a striking share of its forests over the past three decades. Woodlands that once covered well over a third of the country now cover less than a quarter, and the pressure on what remains is increasing. Behind those figures sit two practical questions: what is driving the loss, and what reverses it?
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