Variable pumping rates increase stimulated reservoir volume by 17% compared to constant rates. This method enhances hydraulic fracturing and shale oil production effectiveness.

The study developed a model using Lee's correlation for gas viscosity, validated with Barnett Shale data. Results show intensified reservoir damage cuts productivity by 50%, while increased stimulation boosts it by 25%.

Nano variable-viscosity slick water improves oil recovery and sand-carrying in Chang 7 reservoir. The optimized fracturing parameters increased production in 13 wells by 10-15 times.

A non-metallic, pressure reservoir with variable volume is designed for closed-circuit hydraulic systems, offering advantages in lightweight and compact design. The study establishes mathematical models and verifies the reservoir's effectiveness in system operations through simulations and experiments.

Industry 5.0 integrates AI with domain expertise for sustainable industrial growth. The optimized model increases daily oil production by 13.84%, enhancing economic benefits.

The paper presents a method to estimate shale gas reservoir properties using deconvolution and productivity models without requiring shut-ins. The approach accurately predicts production trends and inverts parameters like permeability and porosity cost-effectively.

Mudstone's elastoplastic damage and permeability evolution in deep reservoirs were modeled and verified, enhancing engineering stability analysis. The research offered insights into damage stages and mechanical transitions under stress.

The core factors controlling productivity are stable water cut, shut-in time, fracturing-fluid volume, and oil saturation. XGBoost model achieved over 95% predictive accuracy.

The study assessed a waterflooding system, showing high sweep efficiency doubled the oil recovery factor. Reservoir heterogeneity and production conditions were also analyzed.

CO2 huff-n-puff experiments on shale oil optimize parameters like simmering time and injection volume. Economic benefits peak with an injection volume of 0.44 PVs, and recovery improvement lessens after three rounds.

MAGPSM-IDD optimizes well placement and fracturing more efficiently than HGA by maximizing NPV. It effectively handles numerous variables for enhanced oil recovery in tight reservoirs.

Integrated management showed similar cumulative oil production and energy demand to unintegrated management, but resulted in a 20% difference in carbon emissions due to gas compression. Short-term optimization increased oil anticipation by 10% but reduced the recovery factor.

The integrated SWAT-HEC-ResSim-GA framework enhances reservoir operation under climate change. It improves Kangsabati reservoir performance with time and volume reliability estimates.

AI models accurately predict Çamgazi Dam water levels with R² ≥ 0.96, despite limitations under extreme conditions. Nonlinear regression achieved R² = 0.849, offering insights into variable interactions.

The 2022-2023 winter in Southern California was unusually wet and cold, leading to record precipitation and alleviating drought conditions. The study highlights the impact of 11 Atmospheric Rivers on water management and snowpack dynamics.