Oil Well Stimulation Technique (Hydraulic Fracturing Method By PKN , KGD Models of Equation)

Abstract

Well stimulation has become an essential technique in petroleum engineering to enhance productivity and recovery, particularly in reservoirs characterized by low permeability. Among the commonly applied methods, hydraulic fracturing and acid fracturing are the two primary approaches used to improve hydrocarbon recovery. Hydraulic fracturing, in particular, has proven to be highly effective, as it increases the average permeability in the well’s drainage area by creating a conductive channel that allows hydrocarbons to flow more efficiently from the reservoir to the wellbore. This process involves injecting a fluid at a pressure greater than the fracture pressure of the formation, thereby initiating and propagating fractures that extend deeply into the surrounding rock. In this study, the design and evaluation of hydraulic fracturing in the X FIELD sandstone formation in Libya is presented, with a specific focus on applying well-established fracture geometry models—namely the Perkins–Kern–Nordgren (PKN) and the Khristianovic–Geertsma–de Klerk (KGD) models. The research encompasses a comprehensive assessment of reservoir characteristics, rock mechanical properties, and fluid treatment parameters that significantly influence fracture dimensions, including fracture length, width, and height. By integrating these models with field data and conducting a nodal analysis, the study aimed to evaluate the effectiveness of hydraulic fracturing in improving well performance. These outcomes highlight the importance of accurate modeling and proper treatment design in maximizing the benefits of hydraulic fracturing. Over all, the study confirms the critical role of hydraulic fracturing as a stimulation technology for unlocking the potential of tight sandstone reservoirs and recommends its further application across other low-productivity wells in the X FIELD to achieve optimal recovery and improved economic performance. The results obtained from the field application indicated a significant variation in well productivity as follows: For well X1, and before applying the hydraulic fracturing, the productivity index (PI) was calculated at 1.84 STB/day/psi with a baseline production rate (Qo) of 5100 STB/day, the well’s conditions improved to 6.8  STB/day/psi and 9000 STB/day after Fracturing, whereas in well X2 the PI increased from 0.34 to 1.4 STB/day/psi and recorded production rate development from 1100 to 2800 STB/day.

Finally, one of the further notes of the above findings is that, the a clearly disparity in reservoir productivity, between the two wells, is emphasizing the influence of reservoir variety characteristics and well conditions on production performance