Assessment of reservoir stress state and its implications for Paleozoic tight oil reservoir development in the Oued Mya Basin, northeastern Algerian Sahara

Abstract

• In-situ stress regime and pore pressure of the tight Paleozoic reservoirs. • A mean NW-SE S HMax orientation inferred from the B-D quality wellbore breakouts. • Multiple linear regression models to predict the S hmin and S HMax magnitudes. • Estimated pore pressure and in-situ stress behavior agree with observed data. • Optimum drilling and stimulation strategies are inferred. The Cambrian and Ordovician clastic reservoirs of the Oued Mya Basin exhibit significant vertical thickness and extensive lateral continuity, despite being tight. These reservoir intervals have not been properly understood yet in terms of in-situ stress distribution and pore pressure behaviour. The main objectives were to infer the reservoir stress state and draw implications for the tight oil reservoir development based on the geomechanical analyses. We interpreted breakouts from a cumulative 1485 m of acoustic image logs and interpreted a NW-SE S HMax orientation (N125°E-N147°E) in the Oued Mya Basin. The inferred breakouts were of B-D quality as per the World Stress Map ranking criteria. Both the reservoirs have a pore pressure gradient of 13.58-13.77 MPa/km, while the minifrac data infers a reservoir S hmin gradient of 17.3-19.2 MPa/km. Based on the breakout widths, we estimated the S HMax gradient as 23.8-26.5 MPa/km. Following the univariate regression analyses to identify various influencing parameters on horizontal stress magnitudes, we proposed multiple linear regression (MLR) models to predict the S hmin and S HMax based on pore pressure, S v , Poisson's ratio, and Young's modulus. Results indicate that S v influences the horizontal stress estimates significantly more as compared to the other influencing variables. The predicted S hmin and S HMax values are in good agreement (goodness of fit as R 2 = 0.976 and 0.994) with the measured data. The newly proposed MLR equations can be utilized in absence of subsurface validation data. A strike-slip faulting reservoir stress state is concluded from stress polygon analysis. An optimum drilling strategy is discussed based on the observed wellbore failures. We recommended the drilling fluid pressure to be increased by 8 MPa and 14 MPa to avoid breakouts against the Ordovician and Cambrian reservoirs respectively, however, that may incur tensile fractures which do not have a considerable effect on wellbore stability while drilling. Based on this work, horizontal well trajectory along NE-SW (i.e., parallel to S hmin ), together with oriented perforations aligned parallel to inferred S HMax direction is recommended. The potential fracture reactivation risks during reservoir pressurization are evaluated and discussed.