The limited availability of natural gas (NG) and its associated emissions raise concerns about meeting residential energy demand.This work investigates the feasibility of hydrogen blending (HB) in a specified urban NG network from energy, economic, and environmental perspectives.First, the impact of 1-20 % volumetric hydrogen blending on gas composition and thermophys. properties is analyzed.The TOPSIS decision-making method then determines the optimal HB percentage for cold and hot months.Finally, dynamic network parameters-including volumetric flow, energy contribution, hydrogen production power requirements, efficiencies, CO2 emissions, and costs-are evaluated based on the optimal HB percentages.Results illustrated that optimal HB levels of 12 % in winter and 13 % in summer (totaling 23024 m3 of hydrogen annually) could save 7044 m3 of NG.This integration required 93.4 MWh of PEM electrolyzer power to supply 70 MWh of hydrogen energy to end users annually (4.34 % of the total natural gas demand), while reducing CO2 emissions by 13 tons.However, economic anal. showed that annual expenses were four times higher than revenues, with grid electricity purchasing costs being the most significant expense.Finally, to deliver the blended natural gas with hydrogen to end users with the same energy content as pure NG, an addnl. 27.2 % annual cost was incurred, resulting in a levelized cost of energy (LCOE) of 54.7 $/MWh.