Fracture characterization is a biggest challenge for the geoscientists insandstone and carbonate reservoirs. With the advancement of all technicalcapabilities in the acquisition of surface and subsurface Geological data, still it is extremely difficult to understand, characterize, and predict thedistribution of fractures in a field. Image logs can successfully be used tolocate and to provide directional trends of fractures near the wellbore.However, capturing all the fractures in one well and to predict their flowbehavior can still be a challenge. In this paper, a case study of a fracturedcarbonate reservoir will be presented. The field is currently producing about500 bbl of oil per day through fractures. Four wells have been drilled on thestructure to drain the oil reserves. Water flooding is being carried-out in thefield for the last 9 years for pressure maintenance and now 80% water is beingproduced. The reservoir has very low primary porosity and permeability, and theflow is through fractures only. On the basis of the three wells fracture data,a new well was drilled, located ideally at a structurally higher position, increstal area of the field. Image data showed abundance of fractures withdifferent orientation was seen in the well bore but the well didn't flow andthat led to its suspension. In this study, fracture data from image logs iscompared with outcrop analogs and seismic reflection and interpretation data.In this paper, limitation of the available information, importance ofunderstanding the stress regime, integration of G & G data and lessonlearned from the current evaluation of the fracture system and their impact ondevelopment of field in Potwar basin will be presented. Geological and Reservoir Overview Fimkaser oil field was undertaken as a case study for the understanding andcharacterization of the fracture. The field is located in the Himalayanforeland in North Pakistan and represents fault related anticline as shown inFigure-1. It was discovered in 1989 by Gulf Petroleum and later on handed overto the OGDCL. The producing formations are Chorgali and Sakessar limestone ofEocen age. These reservoirs are generally of low/none matrix porosity (1–3.5 %)and may be classified as type-1 of Nelson (1982), in which fractures provideessential porosity and permeability. In these types of carbonate reservoirs, secondary mouldic/vuggy and fracture porosity is important for storage ofhydrocarbons.