Abstract— Rapid Transport Electrification is imposing spatiotemporally heterogeneous loads on distribution networks. This study quantifies the impacts of residential Level 2 (L2) charging and public charging stations, including 50-kW DC fast chargers (DCFCs), on an 11-kV radial feeder using a 5-min time-series framework. Baseline demand is represented by measured-like diurnal profiles; station demand is synthesized via a finite-server, time-varying Poisson arrival process with stochastic service times. Network responses (bus voltages, branch flows, transformer loading, and I2R losses) are computed using a linearized DistFlow formulation. Three scheduling strategies are evaluated: (S1) uncontrolled plug-in, (S2) time-of-use (TOU) shifting to 22:00-06:00, and (S3) feeder-wide coordinated valley filling. Performance is assessed via peak feeder real power and timing, minimum voltage magnitude and violation count (<0.95 pu), transformer apparent-power utilization relative to nameplate, branch thermal margins, and daily energy losses. Uncontrolled charging coincides with the residential evening peak, amplifying maximum demand, losses, and voltage deviations. TOU shifting reduces coincidence with the native peak but can induce secondary off-peak surges. Coordinated charging most effectively flattens the net load, enhances voltage security, and mitigates thermal stress. Sensitivity analyses across EV penetration and L2/DCFC mix demonstrate robustness of the results and yield actionable implications for tariff design, public-station siting, and aggregator-mediated managed charging to increase distribution-level hosting capacity.