hubs, one of which is located across parts of northern SPP. Termed the Heartland Hydrogen Hub, the federal cost share may be up to $925 million with the hydrogen initially used for fertilizer production and co-firing in thermal power plants. Due to these favorable economics, until the expiration of the tax credits (project construction must start before 2033), hydrogen deployment is primarily constrained by supply-chains for electrolyzers, renewable siting, water availability, and other institutional constraints. The impact of these constraints is difÏcult to quantify, but the economic potential of subsidized hydrogen is robust. Achieving this level of deployment is not constrained by the type of hydrogen networks imagined in the long-term because many of the most attractive applications, such as the production of ammonia or other fuels, can potentially be co-located with electrolyzers to produce easily transportable products with deep international markets. A similar approach was taken as with data centers in this analysis, where an estimate of the scale of national load is made and then allocated into SPP. Unlike with data centers, a disproportionate amount of electrolysis load is allocated to SPP given the quality and abundance of renewable resources. Figure 13 shows the national electrolysis load estimates made for this study. The scale of hydrogen produced by 2035 in both the Moderate Electrification and Full Electrification Scenarios is similar in scale to the quantity of hydrogen consumed today in the U.S. Both Scenarios are at the same point in 2035 as both are assumed to be subject to the same non-economic constraints. Afterwards Full Electrification electrolysis load is assumed to continue to grow, but Moderate Electrification does not due to the expiration of the tax credits. FIGURE 13 National Electrolysis Load for the Three Load Scenarios 101 GW IN 2035 48 GW IN 2030 ZERO LOAD IN BASELINE SPP FUTURE LOAD SCENARIOS | EVOLVED ENERGY RESEARCH | 20