Date of Graduation


Document Type


Degree Type



Statler College of Engineering and Mineral Resources


Petroleum and Natural Gas Engineering

Committee Chair

Khashayar Aminian.


Coalbed methane (CBM) production has become increasingly profitable in recent years. Production prediction and analysis is challenging in these reservoirs due to two-phase flow conditions. A CBM reservoir is classified as an unconventional gas reservoir due to its unique flow and storage characteristics. Software simulators are by far the best way to predict production performance in CBM reservoirs.;This study investigated the impact of relative permeability on production type curves of horizontal wells in CBM reservoirs. Both relative permeability to gas and water were analyzed using numerical models. The simulation model used for this study is Eclipse Office due to its capability of incorporating the unique flow and storage characteristics of CBM reservoirs. A set of production type curves were developed throughout the study to compare all results. After the type curves were analyzed, a correlation between the relative permeability exponents and the peak production rate was generated and verified. A range of parameters was chosen to use for each simulation model based on previous work in the area.;The water relative permeability exponent had significant impact on gas production up until the peak gas rate was reached. The gas relative permeability exponent only had minor impact on the gas production type curve up until the peak production rate was reached. The shape of the water production type curve seemed to only be affected when the gas relative permeability exponent became large. The well penetration (L/Xe) also had a significant impact on the gas production type curve.