Techno-economic Assessment of Industrial Co2 Storage in Depleted Shale Gas Reservoirs

Open Access
Tayari, Farid
Graduate Program:
Energy and Mineral Engineering
Doctor of Philosophy
Document Type:
Date of Defense:
July 18, 2014
Committee Members:
  • Seth Adam Blumsack, Dissertation Advisor
  • Seth Adam Blumsack, Committee Chair
  • Turgay Ertekin, Committee Member
  • Li Li, Committee Member
  • Rj Briggs, Special Member
  • Wind Power
  • Variability Cost
  • Water Heater
  • Load Management
  • Carbon Dioxide Sequestration
  • Injection
  • Storage
  • Cost
  • Shale
This research suggests two categories of carbon management methods to help control and reduce net CO2 emissions: increasing the efficiency of energy processes to reduce CO2 production and utilizing processes after CO2 production to reduce the amount of emission. Second chapter analyzes the use of remotely controllable household water heaters as a technique that can reduce the variability cost of wind power in the system. Produced wind power is variable and integrating large scale wind power with power system needs backup facility to keep the system reliable. Thus, variability of wind power imposes cost on the system which is called variability cost. Using a computational model, this research simulates a system of three elements: wind farm, household water heaters and grid (as power system) and suggests that using controllable water heaters as demand side management policy can help reducing variability cost of entire system. This chapter analyzes and compares three scenarios to show the effect of distributed thermal storage on variability of wind power. Third chapter develops a techno-economic model for assessment of industrial CO2 storage in Shale gas reservoirs. CO2 storage in underground deep formations can be a long-term efficient way for carbon management. In this method, CO2 needs to be captured from emitter (industrial plant), pressurized, transported with pipeline and then injected to the reservoir. CO2 sequestration for Enhanced Gas Recovery is technically feasible but its economic feasibility depends on many factors. This research has developed a techno-economic model, integrated with a reservoir simulation tool (SRM), to analyze costs associated with CO2 sequestration in Shale gas. Cost structure in techno-economic model has four parts (modules): Transportation, Injection, Production, and Post-Injection Site Care. Each module generates individual results and also contributes with other modules in producing overall results. Various scenarios defined and tested with the model to give a better understanding about sensitivity and importance of input parameters. Fourth chapter utilizes the upgraded version of techno-economic model to run stochastic, uncertainty, and sensitivity analysis. This chapter also studies the production and injection timing under uncertainty to find more efficient results. In addition to results in third chapter, subsurface and economic parameters have substantial impact on costs and revenue. Reservoir properties along with well characteristics determine CH4 production, CO2 injection, storage capacity, possible CO2 breakthrough in production and so on. Upgraded model has the capability of studying sensitivity of each single geologic property individually or any combination of them. Forth chapter will study the impact of influential variables to explore the sensitivity of outputs to major inputs.