Since the accidental discovery in the late 1800s of the benefits of injecting water into oil reservoirs to improve recovery, water has been the injection fluid preferred by the oil industry for use in recovery processes. Traditionally, waterflooding is considered an effective secondary recovery method for light and medium oil reservoirs. However, as production rates in these conventional reservoirs continue their decline, waterflooding is being considered, and used, more and more for the exploitation of more challenging heavy oil resources. Despite the unfavorable mobility ratio between injected water and more viscous heavy oils, many waterflood projects have been undertaken in heavy oil reservoirs around the world. However, the literature on heavy oil waterflooding is sparse. Those papers that have been published present a wide range of recovery factors for projects, and offer conflicting information on the theory and mechanisms involved in heavy oil waterfloods. The good news is that there is a long history in western Canada with waterfloods in heavy oil reservoirs, spanning more than 50 years. A vast amount of data and anecdotal information has been generated from these waterfloods. This could provide a key to raising the limits, in terms of reservoir conditions, under which waterflooding would be viable. In this paper we will discuss lessons learned after 50 years of waterflooding in heavy oil reservoirs, identify gaps in the application of the process, and speculate about what the future may hold as this technology evolves. Introduction Waterflooding is the most common IOR technology used to recover oil. Its contribution to oil production and reserves around the world is significant. Traditionally, waterflooding processes have been performed mainly in light and light-medium oil reservoirs. The advantages of waterflooding in these types of reservoirs include the availability of water, a favorable mobility ratio, good sweep efficiency, a high recovery factor, a long breakthrough time, and low costs associated with handling produced water. In spite of traditional wisdom, waterflooding is gaining popularity around the world as a potential technology for recovering heavy oil. This is driven in part by the decline in light oil reserves. There is a long history in western Canada with heavy oil waterfloods, spanning more than 50 years. Here, waterfloods have long been regarded as a viable successor/alternative to primary recovery in some heavy oil reservoirs. Vast amounts of data and anecdotal information have been generated from these waterfloods. Some of the results are as expected: mobility ratios tend to be highly unfavourable; breakthrough times tend to be quite short; sweep efficiency is poor; and, severe water channelling is endemic. It appears that breakthrough occurs more rapidly in reservoirs with a high initial water saturation. However, other observations have been quite surprising: extended periods of oil production at very high water cuts; more than half of cumulative oil production generated at water cuts higher than 90%; much higher recovery factors than could be predicted from conventional waterflood theory; and, reported recovery factors of up to 30% even for heavy oils with a viscosity of around 2,000 mPa?s. Experience has shown that the waterflooding process in heavy oil reservoirs may be improved by maximizing water injection and minimizing well spacing. Currently, the limit for heavy oil waterfloods in terms of oil viscosity is believed to be in the range of 1,000 - 2,000 mPa?s (dead oil viscosity at reservoir temperature). These results, observations and experiences suggest that the relative importance of some recovery mechanisms may be different in heavy oil waterfloods than in conventional waterfloods.