This paper studies the technical and economic viability of this EOR technique in Eagle Ford shale reservoirs using natural gas injection, generally after some period of primary depletion, typically through long, hydraulically fractured horizontal-reach wells. The Eagle Ford formation has produced approximately 2 billion bbl of oil during the last 7 years, yet its potential may be even greater. Using improved oil-recovery (IOR) methods could result in billions of additional barrels of production. Shale EOR Works, But Will It Make a Difference? The promise of getting 30% more oil production from shale wells has set off a race by companies trying to see if they can replicate what EOG has done.
However, despite the fact that large resources of natural gas are present, several countries have to rely on imports for the domestic gas consumption. These countries have recently put forward ambitions to change this and become self-sufficient or even larger exporters of (Liquefied) Natural Gas. Regional countries have articulated to become self-sufficient in the future. This can be realised by at first lowering growth of domestic natural gas consumption by replacing electricity production by renewable and nuclear power. Other means to free up gas for consumption are increased energy efficiency (typically 2 to 5% of production) and finding alternatives for natural gas Injection for pressure maintenance (up to 30% of production).
This session addresses the challenges of staying above saturation pressure and/or maximizing recovery of the most valuable components for as long as possible, for the entire unit. Additionally, the strategy must include data acquisition and be executed within the confines of reasonable capital requirements, and without significant well intervention. Reservoir & well pressure management issues d. Mature unconventional production wells experience substantial production declines and were likely stimulated less optimally than newer wells. Rather than simply drilling more wells, this has led operators to look to restimulation of wells with reduced production rates and lesser stimulated reservoir volume.
Gas-based EOR in tight unconventionals is a growing application to tap the vast unproduced oil and condensate resources in liquid-rich shale basins. The Huff-n-Puff process now involves several hundred wells in the Eagle Ford, and pilots are planned or ongoing in all other liquid-rich basins (Bakken, Permian, and Montney). The course will discuss the Huff-n-Puff gas EOR process specifically, but will also address relevant fundamentals of displacement-based gas EOR methods (miscibility, vaporization, and displacement) in tight unconventionals. Introduction to Unconventional gas EOR Summary of gas EOR methods and recovery mechanisms What makes unconventional gas EOR different than conventional? To learn about and share experiences in gas EOR in tight unconventionals.
Flow assurance in the oil and gas industry refers to the systems put in place to guarantee uninterrupted profitable and sustainable flow of hydrocarbons from the reservoir to surface facilities and ultimately to refineries. Flow assurance challenges include: inorganic scale, asphaltene, wax, corrosion, hydrates, etc. Managing these challenges is becoming more complex because of development of fields under harsher conditions e.g. HPHT reservoirs, sour reservoirs, heavy oil; in addition to further implementation of EOR (gas injection, chemical, surfactant and polymer floods). Different engineering and chemical solutions can be put in place to manage these challenges. All cancellations must be received no later than 14 days prior to the course start date.
Southwest Research Institute is adding a new facility to its capabilities in testing and evaluating subsea equipment and systems. This review of papers illustrates some of the innovative solutions used in the region. This paper focuses on a numerical-modeling analysis of the acid-gas-injection (AGI) scenario in carbonate HP/HT reservoirs, and presents the way in which AGI impacts asphaltene-precipitation behavior. This paper demonstrates a design methodology that combines the API and American Society of Mechanical Engineers (ASME) Boiler and Pressure Vessels Code (BPVC) for designing an example subsea pressure containing component for HP/HT conditions greater than 15,000 psi and 250°F.
Content of PetroWiki is intended for personal use only and to supplement, not replace, engineering judgment. SPE disclaims any and all liability for your use of such content. Injection of a large volume of gas from an injection well where the gas is designed to lower the viscosity of the oil and help displace it towards the wellbore.