Using a new Intelligent Well Technology Completions Strategy to Increase Thermal EOR Recoveries–SAGD Field Trial

Abstract

Well segmentation and instrumentation have been used to improve steam injection and production conformance in a completions strategy for a thermal-enhanced oil recovery (EOR) project by using intelligent well technology and interval control valves (ICVs). The initial field trial is ongoing in the injector of a Northern Alberta steam-assisted gravity drainage (SAGD) well pair. The development of the completion technology suitable for thermal conditions, initial field trial results and the plans for further development are described in this paper. The application modeling shows that, depending on the level of heterogeneity present in the reservoir, a 45% reduction in the steam-oil ratio and an almost 70% increase in recovery can be achieved in a SAGD process when both improved injection conformance and producer differential steam-trap control can be applied in a segmented horizontal well pair. A cost-effective, intelligent-well completion solution to achieve this segmentation and control has the potential to add substantial value to field developments through improved steam conformance. This will result in increased energy efficiency and oil recovery. The method under development is also applicable to a wide range of other thermal EOR processes such as cyclic steam stimulation (CSS), steam drive, and variations, including, for example, those involving solvent additives. The initial field deployment in the injector well was initiated to prove the technology, to demonstrate the feasibility of modifying the steam distribution, and to obtain best practices for future developments. A successful installation and commissioning of the intelligent completion has validated the technology. Lessons learned are highlighted. Early injection test results and data show a significant increase in the understanding of the injection and production behavior in the well pair. A test program to optimize the distribution of the steam injection in the well is underway, and the results are discussed. The intelligent completion technology under trial and proposed further developments should enable more extensive use of downhole measurement and control in thermal EOR projects than has been possible to date.

Association of design and computational fluid dynamics simulation intent in flow control product optimization

“…By adding steam injection points between the heel and toe of the injection well, the OCD contributes to creating an even distribution, which alleviates the barbell-shaped steam chamber induced by the traditional two-injection tubing design. 24 Furthermore, the use of OCDs enables the conformance of the steam injection profile with the reservoir ''pay thickness'' (height of oil sands layer) along the well, which promotes steam chamber growth and reduces steam-oil ratio (SOR). 25 The performance of the OCDs is significant to the SAGD process efficiency.…”

Comprehensive Design and Manufacturing Solutions for Sand Control and Tooling towards Enhanced Oil Recovery

“…Steam breakthrough is said to occur when the steam finds a path of least resistance directly from the injector to the producer [36]. After steam breakthrough occurs, a fraction of the injected steam ends up in the reservoir, causing the steam cycling underground to be reduced substantially [37].…”

“…After steam breakthrough occurs, a fraction of the injected steam ends up in the reservoir, causing the steam cycling underground to be reduced substantially [37]. This increases the cost and environmental impact of creating steam and pumping it into the production well [36]. Meanwhile, steam carries with it sands and other fine particles at high speeds as it travels through the production string.…”

“…This damages the completion string and erodes the slotted liner and casing [7], [38]. Eventually, it will reduce production rates, damage artificial lift equipment, and jeopardize equipment downstream of the well [36]. Another issue caused by steam breakthrough is the higher vapor traffic both at the surface and in the vertical section of the producer, because it will affect the flow of mobile fluids between the wells and reduce the lifting capability of the well [7], [39].…”

“…The black model is best suited for non-volatile oils and assumes that the two components (oil and gas) are distributed in two hydrocarbon phases (liquid and vapor) [71]. The mechanistic model is a method of describing complex flow phenomena that combines macroscopic conservation principles with empirical closure relationships [36]. There are two types of mechanistic models which are well established.…”