All software that is designed to interpret production logs uses the same technique when it comes to dealing with flow across a perforation. This technique involves creating "stable" zones above and below the designated interval, and the flow calculations are done at these "stable" zones, and thus implying that the flow from the interval is equally distributed along its length. In some cases, it becomes of extreme importance to determine which parts of the perforated interval is actually producing, and producing what. This case arises when some perforating intervals are covering more than one type of rock, or different textures of the same formation. In this paper, we will show two methods that will define the location and type of flow from every foot of a perforated interval. A real case is introduced in this paper; the production logs involved are interpreted in the conventional manner, and also with the new techniques. The results show that with the new technique, a clear definition of the contribution of each foot of the perforated interval is shown, and an accurate assessment of the stimulation job performed in the well was achieved. Introduction The purpose of production logging is to provide the operator with the most detailed knowledge possible of the nature and behavior of the fluids in his well during production or injection. Such knowledge permits the most effective utilization of the well. Some of the potential benefits are1:Early detection of disturbances that are not clearly revealed by surface measurements; e.g. thief zones, channeled cement, plugged perforations, etc.Detailed information on fluid flow profiling. The results from a production log can define the success or failure of stimulation operations as well, and thus aiding in planning for future work on the well. To provide this information, a family of tools is used to measure the performance of producing and injection wells. This family includes:ThermometerGradiomanometerManometerSpinnerCaliperFloView*Ghost* The thermometer as its name suggests is used to define the temperature in the well. The gradiomanometer is used to define the density of the fluid around the tool in the well. The manometer is used to define the pressure in the well. The spinner defines the fluid velocity in the well. The caliper defines the diameter of the well in two directions. The FloView* is designed to differentiate between oil and water in the well through a resistivity probe that identifies oil as a non-conductive fluid. And finally the Ghost* is a tool designed to differentiate between gas and liquid in the well by means of optical sensors. Conventional Production Log Interpretation Conventional interpretation of production logs involves software that estimates the rate of each of the fluid phases in the well out of simulating the readings of the production logging tools. This software is a global solver that attempts to minimize the total mismatch error between the measured curves and the reconstructed (simulated) curves. The flow rate solving algorithm assumes the flow rates of oil, water and gas for each perforated zone, then simulates the measured data of the tools using the assumed rates, and the process repeats until a good match between the measured and reconstructed curves is achieved.

TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractEfficiently identifying and evaluating the producibility of fractures after drilling through potential reservoirs remains a challenge to both the oilfield operator and explorationist. Timely identification of features crossing the drilled borehole, indication of feature permeability, and testing of the well at the most promising depths with the drilling rig still on location are the keys to cost-effective development of tight and fractured reservoirs.The Kurrachine Dolomite formation in central Syria is of Middle Triassic age and has low primary porosity. Economical production from Kurrachine reservoirs is therefore highly dependent on the drilled wells encountering zones of permeable secondary porosity. This paper presents a field example demonstrating the success of wireline-conveyed services in evaluating the producibility of the Kurrachine Dolomite. The services involve the latest technology sensors for petrophysical formation evaluation, electrical imaging of the borehole to evaluate the depths of electrically conductive features crossing the hole, acoustic measurements to evaluate the relative permeability of the conductive features, and testing of the depths of interest by sampling, pressure measurement, and real-time formation fluid analysis. Analysis is presented to show which wireline measurements are particularly important to the operator in this environment. The paper presents techniques successfully implemented to overcome the challenges in formation pressure evaluation and fluid sampling of the Kurrachine formation.Because the formation is accurately evaluated in real time with the drilling rig on location, the combination of services permits efficient, cost-effective decision making for development of Kurrachine Dolomite reservoirs.

TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractEfficiently identifying and evaluating the producibility of fractures after drilling through potential reservoirs remains a challenge to both the oilfield operator and explorationist. Timely identification of features crossing the drilled borehole, indication of feature permeability, and testing of the well at the most promising depths with the drilling rig still on location are the keys to cost-effective development of tight and fractured reservoirs.The Kurrachine Dolomite formation in central Syria is of Middle Triassic age and has low primary porosity. Economical production from Kurrachine reservoirs is therefore highly dependent on the drilled wells encountering zones of permeable secondary porosity. This paper presents a field example demonstrating the success of wireline-conveyed services in evaluating the producibility of the Kurrachine Dolomite. The services involve the latest technology sensors for petrophysical formation evaluation, electrical imaging of the borehole to evaluate the depths of electrically conductive features crossing the hole, acoustic measurements to evaluate the relative permeability of the conductive features, and testing of the depths of interest by sampling, pressure measurement, and real-time formation fluid analysis. Analysis is presented to show which wireline measurements are particularly important to the operator in this environment. The paper presents techniques successfully implemented to overcome the challenges in formation pressure evaluation and fluid sampling of the Kurrachine formation.Because the formation is accurately evaluated in real time with the drilling rig on location, the combination of services permits efficient, cost-effective decision making for development of Kurrachine Dolomite reservoirs.