Completion and Production Strategies for Liquids-Rich Wells in Ultra-low-permeability Reservoirs

Abstract

Producing from liquids-rich, ultra-low-permeability reservoirs requires long, horizontal wells with multiple fractures—a situation that demands a better understanding of well-completion practices in relation to reservoir dynamics to maximize benefit. This paper attempts to augment that understanding through a stochastic reservoir modeling approach. A reservoir simulation model for a typical condensate well in the Eagle Ford liquids-rich area was used in a decision-under-uncertainty framework to identify optimal completion and production strategies. The important factors considered are for fractures (length, conductivity, conductivity endurance, and spacing), reservoir (matrix permeability), fluid (saturation pressure and condensate-gas ratio), and well constraints (bottomhole pressure and rates). The effect of these factors, grouped into decision and uncertainty variables, on well productivity were examined to identify the optimal combination of values for each decision variable, considering the impact of uncertainty variables represented by a statistical metric. Completion techniques and proppant selection that maximize well productivity in conventional or even tight formations by maximizing fracture conductivity are not necessarily optimal for ultra-low-permeability reservoirs. The marginal benefit of higher fracture conductivity diminishes rapidly in such reservoirs, and lower-grade proppants can be used. The optimal completion strategy consists of balancing the effects of decision variables based on a clear objective of maximizing reserves or accelerating production or a specific combination thereof. This is because the variables interact; for example, longer fractures both accelerate production and add reserves (bigger drainage volumes), whereas if drainage volumes interfere, closer fracture spacing can accelerate production without increasing reserves. The rapid falloff in production rates for wells in ultra-low-permeability reservoirs encourages operators to establish high initial rates. In liquids-rich wells, such a strategy can leave a large quantity of unproduced liquids in the fractures that also impedes production rates. At a very low drawdown, however, the well may not even produce. Hence, an optimal production strategy maximizing the liquid yield at the surface should be planned and employed. During the fracture-treatment design process, large uncertainties that affect fracture geometry and properties are often ignored, leading to designs that are suboptimal for well productivity in the field. This study considers decision and uncertainty variables related to both completion and production. Insights developed with respect to the interaction of various factors from the study allow for a fuller understanding and provide practical guidelines for completion and production practices. The dynamic behavior of condensate banks in the presence of hydraulic fractures as it relates to production practices is also examined—this has not been discussed in detail in the literature.

Effects of Well Placement Timing and Conductivity Loss on Hydrocarbon Production in Multiple Hydraulically Fractured Horizontal Wells in a Liquids-Rich Shale Play

“…For the cases studied, a one-year delay did not result in a significant loss of five-year cumulative oil or gas production, except for the cases in which the created fractures for the well placed later had shorter half-lengths than the original wells. • Placing the well at the location with highest CGR and highest matrix permeability always resulted in higher production, and this does not contradict the single-well sensitivity observations by Kumar et al (2013) and Dahl et al (2014). • This study also showed that much higher cumulative production of oil and gas can be obtained by increasing the vertical height of the fractures.…”

“…Kumar et al (2013) and Dahl et al (2014) show that hydraulic fracturing and reservoir simulation tools can be used with sensitivity analysis to provide significant insight into expected reservoir responses with different completion technologies and reservoir characteristics.…”

Oil production technology for unconventional reservoirs

“…• eff ective fracture length, • fracture conductivity, • eff ective drainage volume, • optimum fracture spacing, -very low eff ective reservoir permeability; -complex, multi component reservoir systems; -severe vertical heterogeneity; -signifi cant lateral heterogeneity [6].…”

Modeling Production Decline in Liquid Rich Shale (LRS) Gas Condensate Reservoirs

“…The range of parameters was selected by choosing representative values from the literature (Orangi, 2011;Gong, 2013;Elamin, 2013;Nagarajan, 2013;Kumar, 2013). To confirm with the history match and to maintain simplicity, the reservoir fluid with an initial CGR of 150 STB/MMScf was used for each case.…”