Diffusion-dominated proxy model for solvent injection in ultra-tight oil reservoirs

Research output: Contribution to conferencePaper

4 Citations (Scopus)

Abstract

Enhanced oil recovery (EOR) by solvent injection offers significant potential to increase recovery from shale oil reservoirs, which are typically between 3 and 7% OOIP. The rather sparse literature on this topic typically models these tight reservoirs based on conventional reservoir processes and mechanisms, such as by convective transport using Darcy's law, even though there is little physical justification for this treatment. The literature also downplays the importance of the soaking period in huff'n'puff In this paper we propose for the first time a more physically-realistic recovery mechanism based solely on diffusion-dominated transport. We develop a diffusion-dominated proxy model assuming first-contact miscibility (FCM) to provide rapid estimates of oil recovery for both primary production and the solvent huff'n'soak'n'puff (HSP) process in ultra-tight oil reservoirs. Simplified proxy models are developed to represent the major features of the fracture network. The key results show that diffusion-transport only can reproduce the primary production period within the Eagle Ford shale and model the HSP process well, without the need to use Darcy's law. The mechanism for recovery is based solely on density and concentration gradients. Primary production is a self-diffusion process, while the HSP process is based on counter-diffusion. Incremental recoveries by HSP are several times greater than primary production recoveries, showing significant promise in increasing oil recoveries. We calculate ultimate recoveries for both primary production and for the HSP process, and show that methane injection is preferred over carbon dioxide injection. We also show that the proxy model, to be accurate, must match the total matrix contact area and the ratio of effective to total contact area with time. These two parameters should be maximized for best recovery.

Original languageEnglish (US)
StatePublished - Jan 1 2018
EventSPE Improved Oil Recovery Conference 2018 - Tulsa, United States
Duration: Apr 14 2018Apr 18 2018

Other

OtherSPE Improved Oil Recovery Conference 2018
CountryUnited States
CityTulsa
Period4/14/184/18/18

Fingerprint

Recovery
oil
primary production
Darcy law
Oils
Shale oil
enhanced oil recovery
oil shale
fracture network
Shale
shale
carbon dioxide
methane
Carbon dioxide
Methane
Solubility
matrix

All Science Journal Classification (ASJC) codes

  • Energy Engineering and Power Technology
  • Geotechnical Engineering and Engineering Geology

Cite this

Cronin, M., Emami-Meybodi, H., & Johns, R. T. (2018). Diffusion-dominated proxy model for solvent injection in ultra-tight oil reservoirs. Paper presented at SPE Improved Oil Recovery Conference 2018, Tulsa, United States.
Cronin, M. ; Emami-Meybodi, H. ; Johns, R. T. / Diffusion-dominated proxy model for solvent injection in ultra-tight oil reservoirs. Paper presented at SPE Improved Oil Recovery Conference 2018, Tulsa, United States.
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Cronin, M, Emami-Meybodi, H & Johns, RT 2018, 'Diffusion-dominated proxy model for solvent injection in ultra-tight oil reservoirs', Paper presented at SPE Improved Oil Recovery Conference 2018, Tulsa, United States, 4/14/18 - 4/18/18.

Diffusion-dominated proxy model for solvent injection in ultra-tight oil reservoirs. / Cronin, M.; Emami-Meybodi, H.; Johns, R. T.

2018. Paper presented at SPE Improved Oil Recovery Conference 2018, Tulsa, United States.

Research output: Contribution to conferencePaper

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N2 - Enhanced oil recovery (EOR) by solvent injection offers significant potential to increase recovery from shale oil reservoirs, which are typically between 3 and 7% OOIP. The rather sparse literature on this topic typically models these tight reservoirs based on conventional reservoir processes and mechanisms, such as by convective transport using Darcy's law, even though there is little physical justification for this treatment. The literature also downplays the importance of the soaking period in huff'n'puff In this paper we propose for the first time a more physically-realistic recovery mechanism based solely on diffusion-dominated transport. We develop a diffusion-dominated proxy model assuming first-contact miscibility (FCM) to provide rapid estimates of oil recovery for both primary production and the solvent huff'n'soak'n'puff (HSP) process in ultra-tight oil reservoirs. Simplified proxy models are developed to represent the major features of the fracture network. The key results show that diffusion-transport only can reproduce the primary production period within the Eagle Ford shale and model the HSP process well, without the need to use Darcy's law. The mechanism for recovery is based solely on density and concentration gradients. Primary production is a self-diffusion process, while the HSP process is based on counter-diffusion. Incremental recoveries by HSP are several times greater than primary production recoveries, showing significant promise in increasing oil recoveries. We calculate ultimate recoveries for both primary production and for the HSP process, and show that methane injection is preferred over carbon dioxide injection. We also show that the proxy model, to be accurate, must match the total matrix contact area and the ratio of effective to total contact area with time. These two parameters should be maximized for best recovery.

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Cronin M, Emami-Meybodi H, Johns RT. Diffusion-dominated proxy model for solvent injection in ultra-tight oil reservoirs. 2018. Paper presented at SPE Improved Oil Recovery Conference 2018, Tulsa, United States.