Modelling start-up injection of CO2 into highly-depleted gas fields

• Published in: Energy (Oxford) Vol. 191; p. 116530
• Main Authors: Sacconi, Andrea, Mahgerefteh, Haroun
• Format: Journal Article
• Language: English
• Published: Oxford Elsevier Ltd 15.01.2020; Elsevier BV
• Subjects: Boring tools; Carbon capture and storage; Carbon dioxide; CO2 injection; Computer simulation; Conservation equations; Depletion; Energy conservation; Flow rates; Gas expanders; Global warming; Gravitational effects; Gravitational fields; Gravity; Heat transfer; Ice formation; Injection; Mass flow rate; Mathematical models; Oil and gas fields; Optimization; Pressure; Relaxation time; Reservoir storage; Reservoirs; Storage reservoirs; Transient flow modelling; Two phase flow; Unsteady flow; Transient flow modelling; Global warming; Carbon capture and storage; CO2 injection
• ISSN: 0360-5442; 1873-6785
• DOI: 10.1016/j.energy.2019.116530

The development and verification of a homogeneous relaxation model for simulating the highly transient flow phenomena taking place during the start-up injection of CO2 into deep highly depleted gas fields is presented. The constituent mass, momentum, and energy conservation equations, incorporating a relaxation time to account for non-equilibrium effects, are solved numerically for single and two-phase flows along the steel lined injection well leading to the storage reservoir. Wall friction, gravitational field effects and heat transfer between the expanding fluid and the outer well layers are taken into account as source terms in the conservation equations. At the well inlet, the opening of the upstream flow regulator valve is modelled as an isenthalpic expansion process; whilst at the well outlet, a formation-specific pressure-mass flow rate correlation is adopted to characterise the storage site injectivity. The testing of the model is based on its application to CO2 injection into the depleted Golden Eye Reservoir in the North Sea for which the required design and operational data are publically available. Three injection scenarios involving a rapid, medium and slow linear ramping up of the injected CO2 flow rate to the peak nominal value of 33.5 kg/s are simulated. In each case, the predicted pressure and temperature transients at the top and bottom of the well are employed to ascertain the risks of well-bore thermal shocking, and interstitial ice or CO2 hydrate formation leading to its blockage due to the rapid expansion cooling of the CO2. The results demonstrate the efficacy of the proposed model as a tool for the development of optimal injection strategies and best-practice guidelines for the minimisation of the risks associated with the start-up injection of CO2 into depleted gas fields. •Transient fluid flow model or start-up injection of CO2 into depleted gas fields is presented.•Large drop in CO2 temperature at the well head observed hence risk of well blockage & fracture.•Surprisingly increasing the injection ramping up rate reduced the above risk.•Under all conditions tested well blockage due to hydrate formation found to be unlikely.•The model developed allows optimum injection strategies minimising the associated risks.