The production of green hydrogen from renewable energy and water by electrolysis is considered an important technology for decarbonation of many industries. To improve the competitiveness of this burgeoning industry, many jurisdictions are introducing incentive programs, including Europe, the US, and Australia. Eligibility for these incentives is linked to electricity sourcing rules to promote the use of renewable and low-carbon sources. However, definitions of green and lowcarbon hydrogen vary between jurisdictions. One key difference is the measurement of temporal correlation between renewable sources and electrolyser consumption, with hourly, monthly, and yearly time-matching proposed. Furthermore, certain regions with cleaner grid mixes may have the option to produce low-carbon hydrogen without adherence to these rules. This paper studies the impact of these differing green and lowcarbon classification rules on sourcing strategy, equipment sizing, final cost, and grid emissions exposure of the produced hydrogen. A market-focused 2-stage stochastic model of a green hydrogen producer supplying a hydrogen demand is used, with uncertainty in renewable production and electricity spot market prices. Strict hourly time-matching is observed to increase demand for diversified power purchase agreement (PPA) portfolios, and require greater electrolyser and hydrogen storage capacities. For carbon-intensive grids, less strict time matching rules can lead to the produced hydrogen being classified as 100% green whilst exceeding intended maximum emissions intensities.