IEA Bioenergy Task 41 publiceert internationaal rapport over waterstof in aardgasnetwerken

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IEA Bioenergy Task 41 publiceert internationaal rapport over waterstof in aardgasnetwerken

NB: Onderstaande samenvatting is in het Engels

The report summarizes the key findings from the Renewable Gases - H2 in the grid project with a particular focus on the specific role of hydrogen (H2) in gas grids, as H2 is the one renewable gas that:

  • has very high long-term potential due to fact that its production is limited only in terms of available renewable electricity, but
  • implies compatibility issues with the current gas infrastructure.

Renewable gases, including H2, will be a key component of the global energy system aiming at net zero greenhouse gas (GHG) emissions by 2050, compatible with the 1.5 °C goal of the 2015 Paris Agreement on mitigating climate change. IEA’s recent Net Zero Emissions scenario for 2050 shows that under a strict GHG mitigation logic, fossil gas supply will be peaking in the mid-2020s and shrinking up to 2050. In parallel, renewable gases (biomethane, H2, H2-based synthetic methane) will have to strongly increase.

The role of renewable gases in national policies for GHG emission reductions by 2030-2050 and respective estimates for the amounts needed by 2030-2050 was analyzed with a focus on H2 strategies and roadmaps. All of those (except Russia) indicate the need for H2 to decarbonize their economies in the 2030-2050 time horizons, with significant contributions of H2 to achieve country commitments under the Paris Agreement. Most country strategies and roadmaps see H2 as a means to overcome the limits of electrification and to help stabilize electricity grids against a growing share of variable renewable generation, especially solar and wind. Some H2 strategies address the potential role of longer-term energy storage needs to bridge seasonal variations in renewable electricity generation. Several countries indicate their ambition to export H2 in the 2030 timeframe and after, while others assume H2 imports. Besides trade, most strategies focus on domestic H2 application in hard-to-abate sectors, i.e., those where GHG emission reduction by renewable electrification is hindered, e.g., the chemical industry, steel-making, and transport (aviation, long-haul road, shipping). Nearly all country strategies and roadmaps address the role of existing gas infra[1]structure for future H2 transmission and distribution, and see H2 clusters as an important step towards H2 use, both in industry, and in regional H2 networks.

Several country strategies address the “color” of H2, i.e., its origin, and some focus on green H2 while others include a broader range, especially “blue” H2. 19 country strategies and roadmaps give ambitious quantitative H2 production targets for the year 2030. For 2050, just four countries out of the 21 countries included in the analysis provide targets, with one of them only addressing exports. All quantitative targets are subject to significant advances in cost-reduction for low-carbon and green H2 production: Target levels for 2030 are in the $2 – $5/kg H2 range, with prospects of a $1 – $2/kg H2 for 2050. The strategies and roadmaps commonly assume market introduction and support schemes for H2 as well as increased R&D over the next decade to deliver on the expected H2 production cost reduction. In that regard it is encouraging that many countries already committed significant financial resources to H2 development.

With regard to options and hurdles for H2 injection in gas grids, biomethane and synthetic methane (SM) can already be added to the existing gas infrastructure without problems. Co-processing biogas and H2 to SM could boost near-term grid[1]compatible production. Next to that, direct H2 injection in gas grids (HIGG) could provide a steppingstone for developing a H2 infrastructure with adding up to 20 vol% of H2 to the gas grid, i.e. about 7 % by energy content. For higher H2 shares in the gas grid without compromising downstream distribution and end-uses, the gas transmission system could be used for H2 transport only and H2 could be separated from transported natural gas before it is distributed to end[1]users. H2 separation would add $2 - $4 per kg of H2 in the longer-term. A potential alternative to HIGG (and later separation) is to convert H2 into renewable synthetic methane (SM) to make H2 fully compatible with existing natural gas infrastructure and end-use technologies. Methanation of H2 costs about 50% less than the longer-term additional cost of H2 separation and could help balancing the electricity system and longer-term storage of renewable electricity.

Converting existing natural gas transmission pipelines to H2 (“repurposing”) is possible in many cases. Cost of doing so would add approx. 0.05 $/kg H2, while cost for new dedicated H2 pipelines are twice as high. Costs to convert the gas distribution to be fully H2-compatible are about 20 % of repurposing transmission pipelines, and approx. 1/3 of new dedicated H2 pipelines, but strongly depend on the geographical distribution of end-users, and the topography of the area served. There is a clear transition logic from natural to renewable gas which also helps integration with the (decarbonized) electricity system.

Yet, there are many hurdles and obstacles in the regulatory system: As H2 in the grid is a rather new issue, the transformation of the gas system and “coupling” with other energy sectors is quite complex, and the international dimension of trade, especially when including climate policies, is challenging. Fundamental legal and administrative barriers which hinder H2 injection into gas grids concern legal complexity or absence of permitting rules, divergent regulation on H2 concentration levels in gas grids, contracts and billing arrangements based on calorific value or Wobbe Index, safety requirements for connection/injection of H2, and for all types of end-user equipment. Among the regulatory issues, the color and origin of H2 and respective GHG emission thresholds, the additionality requirements for green H2, access for H2 producers to the gas grid and respective grid development planning are, together with H2 safety issues, the most relevant topics which need to be addressed.

Open questions on “H2 in the grid” remain for which further research should be carried out:

  • Is H2 more favorable that direct electricity use in the (non-industrial) heat and road transport sectors?
  • What is the longer-term perspective of H2 vs. renewable synthetic methane, considering economic benefits for electricity system services and the economic value of existing gas infrastructure?