Early information about reservoir fluid complexity, dynamic behavior, and reservoir connectivity is crucial for development planning and production optimization of new plays. Such impact is manifested in three main areas: (1) reservoir presence and connectivity to understand the extent of the play (2) reservoir fluid variation to understand the charge history and devise production strategy (3) completion optimization in exploration wells to maximize early production.Petroleum Development of Oman pursued an ambitious exploration campaign firstly consisting of 8 wells targeting a shallow, thin, complex lithology formation to better understand a new play, especially from reservoir extension and connectivity viewpoints. In addition to advanced formation evaluation logging consisting of elemental spectroscopy and nuclear magnetic resonance, an advanced Downhole Fluid Analyzer (DFA) was deployed with Wireline Formation Testers (FT) aimed to obtain formation pressure and fluid samples. The fluid scanning using in-situ fluid analysis was also performed to obtain reservoir fluid information in real time and at reservoir condition. In addition, Interval Pressure Transient Tests (IPTT) was conducted to evaluate permeability of each well.This paper provides the workflow of using the DFA and laboratory data for full field development. This will include discussion of DFA data such as asphaltene, fluid composition, Gas-Oil-Ratio (GOR), density, viscosity, and fluorescence yield to help draw a full picture towards reservoir connectivity.Having detailed fluid properties data available in real time allows to optimize the completion decisions (pump selection as one example) in order to maximize early production while allowing longer term reservoir management planning. This paper also discusses the use of in-situ fluid viscosity and pressure transient data to estimate zone permeability during the FT operation, which will later be compared to actual well test data. Results show a good comparison and provide comfort to use FT pressure transient data to evaluate zone permeability at early stage of the operation.The DFA data from the first 4 wells suggested the presence of subtle but distinct fluid differences in terms of composition, oil color, and fluorescence yields. This DFA data was then supported by full PVT laboratory results. The differences in fluids will be examined in more details. This paper will present an effective workflow to integrate pressure, DFA, and PVT data to understand reservoir connectivity issue in this newly discovered formation. In addition, the DFA color gradient model was then used to help supporting other available information.