Abstract: Objective and Methods The dynamic partitioning mechanism of the production efficiency of adsorbed gas and free gas is a critical scientific issue that urgently needs to be addressed in the exploration and development of deep coalbed methane (CBM). Based on core testing and laboratory data from exploration wells, this study systematically analyzed the theoretical mobility of deep CBM resources. By integrating the construction of mathematical/numerical models, monitoring methane carbon isotopes, and analysis of drainage curves, the research revealed the co-evolutionary process of pressure drop expansion, adsorbed gas desorption, and free gas seepage induced by drainage. Furthermore, a collaborative gas supply mechanism and theoretical production model for multi-state methane in deep coal reservoirs was proposed. Results and Conclusions (1) During the production process of deep CBM wells, free gas and adsorbed gas exhibit a "continuous-synergistic" gas supply characteristic and a "competitive production" allocation relationship. At any given moment, the produced gas is a mixture of both, where the dynamic partitioning ratio of methane in different occurrence states depends on the superposition of free gas mass transfer efficiency and adsorbed gas desorption efficiency within the pressure propagation domain at different production stages. (2) Deep coal reservoirs undergo the entire desorption process, requiring substantial pressure drawdown to reach critical desorption nodes. The inherent conflict between early-stage high reservoir pressure with low desorption efficiency and late-stage high desorption efficiency with limited pressure drop space remains challenging to reconcile. Within the pressure drawdown funnel, the average desorption rate of adsorbed gas remains low, with gas supply units predominantly concentrated in high-permeability stimulation zones. Under single-well drainage conditions where pressure drawdown does not reach reservoir boundaries, the free gas supply radius continues to expand and consistently maintains a dominant production share. However, inter-well interference in clustered well groups may lead to a decline in free gas contribution during mid-to-late production stages, shifting productivity dominance to adsorbed gas. (3) Free gas and adsorbed gas demonstrate distinct production characteristics: "sharp increase followed by gradual decline" or "sudden increase-sharp decline-gradual decline" for free gas, and "gradual increase-stabilization-gentle decline" for adsorbed gas. Overall production capacity progresses through three primary phases: rapid buildup, relatively stable output, and slow decline. Production curve morphology is governed by free gas volume, in-situ permeability, reservoir stimulation effectiveness, and pressure drawdown management strategy. Some wells exhibit two substages: an initial sharp decline followed by stabilization during the relatively stable production phase. (4) Enhancing stimulation volume, extending horizontal well sections, and targeting free gas-rich zones with high porosity-permeability constitute core strategies for production enhancement. The development of technologies to improve adsorbed gas desorption efficiency and achieve comprehensive pressure drawdown magnitude emerges as the key to advancing exploration depths. (5) Guided by the principle of geology-engineering integration, determining reasonable productivity targets and required well control areas in different deep geological units, while synergistically optimizing completion methods, well spacing density, fracturing parameters, production allocation rates, and operational cycles, constitutes the paramount priority for cost-effective development of deep CBM.