Potential of waterflooding in shale formations

Samiha Morsy, J. J. Sheng, Roland O. Ezewu

Research output: Chapter in Book/Report/Conference proceedingConference contributionpeer-review

18 Scopus citations

Abstract

Waterflooding is the cheapest and most profitable secondary recovery method that has been used for more than seventy years for conventional oil reservoirs. However, few studies have been done on its viability on unconventional tight formations especially shales. The objective of this study is to investigate the potential of water imbibition in different shale formations. In this study, fresh water, water with different salinities, and high pH alkaline solutions were examined to recover oil from different shale formations. Reservoir core samples from Eagle Ford and outcrop samples from Mancos, Barnett, and Marcellus shales were used in this study. The samples were 2.54 to 3.81 cm in diameter and 0.762 to 5.08 cm in length. First, we studied the porosity of samples using helium porosimeter, weight difference, and CT Scanning. The average porosity was 3.4% for Mancos, 2% for Eagle Ford, 2.6% for Marcellus, and 7.7% for Barnett shale samples. Second, we studied the rock stability and spontaneous imbibtion of the different used samples in fresh water, different saline solutions (5-15 eq wt% of NaCl and KCl), and high pH alkaline solutions (0.1-2 wt% NaOH). During the spontaneous imbibition, the maximum oil recovery was 59% for Mancos using fresh water, 44% for Eagle Ford using 2 wt% NaOH and fresh water, 24% for Barnett using fresh water, and 4% for Marcellus using 2 wt% NaOH and 2 eq wt% of KCl. The Mancos shale samples were very sensitive to low water salinity (0-15 eq wt %) compared with the other shales. The higher oil recoveries of Mancos samples were positively correlated with clay swelling in fresh water and low saline solutions. Eagle Ford recovered more oil when exposed to NaOH solutions due to favorable mineral dissolution without affecting the cores' stability. On the other hand, Barnett was partially damaged when exposed to higher alkaline solutions (2 wt% NaOH) and Marcellus was very tight to allow any fluid imbibition. Collectively, our study showed a great potential of waterflooding in unconventional shale reservoirs.

Original languageEnglish
Title of host publicationSociety of Petroleum Engineers - 37th Nigeria Annual Int. Conf. and Exhibition, NAICE 2013 - To Grow Africa's Oil and Gas Production
Subtitle of host publicationRequired Policy, Funding, Technol., Techniques and Capabilities
PublisherSociety of Petroleum Engineers
Pages114-122
Number of pages9
ISBN (Print)9781627489683
DOIs
StatePublished - 2013
Event37th Nigeria Annual International Conference and Exhibition - To Grow Africa's Oil and Gas Production: Required Policy, Funding, Technology, Techniques and Capabilities, NAICE 2013 - Victoria Island, Lagos, Nigeria
Duration: Jul 30 2013Aug 1 2013

Publication series

NameSociety of Petroleum Engineers - 37th Nigeria Annual Int. Conf. and Exhibition, NAICE 2013 - To Grow Africa's Oil and Gas Production: Required Policy, Funding, Technol., Techniques and Capabilities
Volume1

Conference

Conference37th Nigeria Annual International Conference and Exhibition - To Grow Africa's Oil and Gas Production: Required Policy, Funding, Technology, Techniques and Capabilities, NAICE 2013
CountryNigeria
CityVictoria Island, Lagos
Period07/30/1308/1/13

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