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Results
Abstract In-situ gelling acids are used in carbonate reservoir stimulation to reduce the leakoff rate of the acid and to divert acid to low-permeability zones. Understanding the mechanism of flow diversion and the impact of fluid rheological properties on diversion is critical to developing good matrix stimulation designs. A literature review shows that few studies present models for stimulation with in-situ gelling acids. Specifically, there are no theoretical or empirical rheological models for gelling acids that describe the effects of pH on viscosity and hence flow diversion. The objective of this work is to develop, analyze, and validate a model to represent carbonate acidizing with gelling acids. In this work, a semi-empirical rheological model based on experimental data for gelling acids that accounts for viscosity as a function of temperature, shear rate, and pH is presented. A two-scale continuum model is developed for non-Newtonian fluids, such as gelling acids. Using the model, the effect of rheological parameters on flow diversion is analyzed and the conditions for maximum diversion are identified. The predicted results are compared with the available experimental data and field observations. A scaling analysis is also presented that leads to a criterion for the optimum injection rate for attaining maximum stimulation for a fixed amount of acid (or a minimum in pore volumes to breakthrough (PVBT)). It is shown that the optimum injection rate for gelling acids depends strongly on rheological parameters of the acid. It is found that the presence of gel leads to more branching of wormholes and more uniform stimulation compared to Newtonian acids.
- Asia > Middle East (0.46)
- North America > United States > Texas (0.28)
Abstract Production has two components – the subsurface potential and the actual production to feed the export line. In North Kuwait, sub surface potential had never been an issue for any speculation. The most difficult part is to integrate all resources, synchronize with each other and create "wonderful symphony" leading to actual production delivery. Several processes have been developed and matured now to gear up the asset to meet the challenging production target for 2010–11 which indicates a jump in production by about 23% in a single year. In this effort, major processes to play a key role are: Development Well Subsurface Selection Process to optimize the best wells in terms of potential; New Development Well Assurance Process with Key Opportunities for Improving integration with key service providers to NK Asset such as Drilling Group (rig schedule, materials); Production Operations (Flow line/header connections, process capacity); Water Handling (Flow line/header connections, Water injection Supply capacity); Artificial Lift to synchronize ESP equipment availability in line with the well/ rig availability, Project Management (Flow line installation & rationalization), Learning's from Post Appraisal of Wells drilled in last few years; Surveillance Plan - data acquisition, how new information helps to minimize reservoir uncertainties; Drilling & Completion Programs - appropriate technology choices to meet well and reservoir objectives such as multi-zone needs, rigless access for surveillance or interventions, NCWs and artificial lift requirements.
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (0.37)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Sabriyah Field > Marrat Formation > Upper Marrat Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Sabriyah Field > Marrat Formation > Sargelu Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Sabriyah Field > Marrat Formation > Sabiriyah Mauddud (SAMA) Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Sabriyah Field > Marrat Formation > SAMA Formation (0.99)