• Double-porosity and fracture-network modeling became the central framework for fractured reservoirs, integrating fracture skin, inter-porosity transfer, and block size effects to explain type-curve behavior and production responses in fissured systems [1], [13], [2], [6].

• Interference tests and pressure transient analyses matured as primary diagnostics for fractured and double-porosity reservoirs, enabling estimation of transmissivity, storativity, anisotropy, and fracture connectivity through scheme-level curves [3], [13], [11], [7].

• Tracer-based and related diagnostics provided direct evidence of flow paths, fracture volumes, and sweep efficiency in fractured geothermal and granitic reservoirs, complementing porosity-flow models [6], [12].

• Time-domain buildup, mass-curve analysis, and flow-duration effects emerged as a pattern for inferring storage and permeability from transient responses, often within a systems-analytic framing [8], [18], [7].

• Hydraulic-property estimation in tight/low-permeability formations relied on nonsteady-state and slug-test–like type curves to extract permeability, skin, and related parameters [16], [10].