© 2018 JETIR November 2018, Volume 5, Issue 11 www.jetir.org (ISSN-2349-5162) JETIRDR06073 Journal of Emerging Technologies and Innovative Research (JETIR) www.jetir.org 448 Interpretation of Hydraulic Fracture in Low Permeability Hydrocarbon Reservoirs system Vishesh Bhadariya*, Fenil Khatri*, Shindlay Nath*, Musa Saleem* Abstract A new approach to make decision on fly while monitoring hydraulic fracturing pressure with the help of improvement in Nolte smith plot. Simplification and validation - Use of FRACPRO software to completely design fracturing treatment for PKN type fracture and use the same parameters to calculate design properties using MS – excel. Hydraulic Fracturing Process Steps include is to formulate the geologic model of the reservoir that should include the estimated pressure in each of the geologic layers encountered in the zones of interest. This data used to determine the needed Fracture Conductivity “FCD” and associated fracture stimulator treatment “FOI” for various proppant and fracture lengths. During this treatment modelling process fracturing fluid loss is then estimated. During the study, A fracture geometry model is designed from various rock stresses, modulus pressure, net pressure and fluid loss. This model is then calibrated, and treatment schedule is constructed using the Nolte process. Keywords: Hydraulic Fracturing, FRACPRO, Reservoir Simulation, Fracturing Model. Introduction The objective of reservoir engineering is to optimize and balance the optimal benefits from a prospect area. The team must identify and define all individual reservoirs and their physical properties, deducing the performance of each reservoir, preventing the drilling of unnecessary wells, initiating operational control at the appropriate time and all- important economic factors should be considered. Early and accurate identification and definition of the reservoir system are essential for well-reasoned engineering. Traditional geologic techniques rarely provide sufficient data to identify and define individual reservoir; Geological studies should be complemented with engineering data and tests to provide the necessary information to the engineer. Reservoir management requires an in-depth knowledge of the reservoir that can only be achieved through its characterization by the process of acquiring, processing, and integrating many basic data. [1] In this paper, A low-permeability reservoir is one that has very low tendency of fluid to flow through porous medium Permeability of reservoir is less than 0.1 md. In many formations due to chemical and/or physical processes changes the pore distribution including the pore size and geometry that will alter the pore openings and reduce the ability to flow of a fluid through the porous medium. To improve the Low permeable reservoir required the reservoir stimulation with the process of acid stimulation, Acid Fracturing and Hydraulic fracturing. There might be other reason for permeability reduction near by the wellbore region during the drilling and production operation where formation damage can lead to the reduction in permeability. Damage occurs as completion and drilling fluids leak off into the reservoir near wellbore area which leads to change the wellbore environment in terms of reservoir rock properties. Due to this plugging of the pores this may lead to reduction in permeability and reduction changes in flow rate. Formation Damage can be very problematic for the fractured reservoirs and for desired solution this further stimulation required as a artificially fracture while injection high pressure injection rate fracturing fluid inside the formation which leads to permeability enhancement near by the well bore area. If this type of cases like damaged reservoir, low permeable formation and layered horizontal wells would be uneconomical unless proper action should not be taken such as hydraulic fracturing treatment. The stimulation engineer would be taken care of economic success of the project while using optimal fracture treatment design and implemented this process successfully. Methodology Material Balance Once the fracture forms, the growth is dominated by material balance Fracture volume = volume pumped − volume lost to fluid loss. These three volumes can be idealized as Fracture volume = H × L × w (where H and w are the average values of height/width). Volume pumped = Qtp (Q is the constant pump rate and tp is the total pump time). Volume lost = 4 CHP L√tp (C is the “fluid loss coefficient” discussed in the succeeding text, HP is the permeable or leak-off height, and L is the tip-to-tip length). and these combine to give providing the very first fracture “model” Lovely Professional University,, Phagwara Punjab-144411