Field Case Studies of Downhole Electric Heating in Two Horizontal Alberta Heavy Oil Wells

Abstract

Downhole electric heating has historically been unreliable or limited to short, often vertical, well sections. Technology improvements over the past several years now allow for reliable, long length, relatively high powered, downhole electric heating suitable for extended-reach horizontal wells. The application of this downhole electric heating technology in two different horizontal cold-producing heavy oil wells in Alberta is presented. The first field case study discusses the application of electric heating in a mature, depleted field as a secondary recovery method while the second case study examines a virgin heavy oil reservoir, where cold production by artificial lift was economically challenged. The completion, installation, expected and actual results of both cases studies are compared and contrasted. Both field deployments demonstrate the benefits and efficacy of applying downhole electric heating. In the case of the mature depleted field, electric heating resulted in a 4X-5X increase in oil rate, sustained over a period of close to two years. The energy ratio of the heating value of the incremental produced oil to the injected heat was slightly over 7.0. In the virgin heavy oil field, electric heating reduced the viscosity of the oil in the wellbore from time zero, which allows for higher rates of oil production along the complete length of the long horizontal lateral at higher, if desired, bottomhole pressures than in a cold-producing well. This degree of freedom may ultimately allow for an operating policy that suppresses excessive production of dissolved gas, thereby helping conserve reservoir energy. Early production data in this field show 4X-6X higher oil rates form the heated well than from the cold-producing benchmark well in the same reservoir. Numerical simulation models, which include reactions that account for the foamy nature of the produced oil and the downhole injection of heat, have been developed and calibrated against field data. The models can be used to prescribe the range of optimal reservoir and fluid properties to select the most promising targets (fields, wells) for downhole electric heating as a production optimization method, which is crucially important in the current low oil price scenario. The same models can also be used during the execution of the project to explore optimal operating conditions and operating procedures. Downhole electric heating in long horizontal wells is now a commercially available technology that can be reliably applied as a production optimization recovery scheme in heavy oil reservoirs. Understanding the optimum reservoir conditions where the application of downhole electric heating maximizes economic benefits will assist in identifying areas of opportunity to meaningfully increase reserves and production in heavy oil reservoirs in Alberta as well as around the world.

Downhole electric heating of heavy-oil wells

“…A reservoir model, based on CMG-STARS [9], was used to historymatch the production rate and temperature of the heated well. The model has two differentiating features:…”

In Situ Thermal Remediation for Source Areas: Technology Advances and a Review of the Market From 1988–2020

“…Today, TCH has been successfully implemented at several crystalline bedrock sites, with unit costs of $175, $210, and $230 per cubic yard in three recent applications larger than 15,000 cubic yards (LaChance 2020). The deepest reported TCH project to date treated chlorinated impacts in fractured granite up to 150 ft below grade in Varberg, Sweden, though we believe there to be no practical depth limitation, as downhole electric heaters thousands of feet long have been used in the oil and gas industry (e.g., Penny et al 2019). ERH has also been effectively used for heating sedimentary bedrock at more than 10 sites (e.g., CDM Smith 2018), including applications in limestone epikarst (Beyke et al 2014) and sandstone up to 300 ft below grade (McGee 2013).…”

Effectiveness of electrokinetic-enhanced oil recovery (EK-EOR): a systematic review

“…The electrical current supports the hydrodynamic movement of fluid from the injection well into the production well. Successful deployment of this technique were recorded in heavy oil fields in the Santa Maria Basin, CA (USA), the Eastern Alberta (Canada) Plains, Little Tom Field Texas, Schoonebeek reservoir, Netherlands and also on the Rio Panon Field, Brazil [28,37,48,50]. During these field applications, EK-EOR was observed to have some inherent advantages over the conventional-enhanced oil recovery techniques.…”