CO2 Sequestration in Depleted Gas/Condensate Reservoirs

Shtepani, E.

doi:10.2118/102284-ms

Cited by 29 publications

(9 citation statements)

References 6 publications

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“…The adoption of EGR technique has not been generally well received. This is because of the excessive mixing of the injected carbon dioxide and in-situ natural gas during the flooding process (Al-abri et al, 2009;Honari et al, 2016Honari et al, , 2015Honari et al, , 2013Hughes et al, 2012;Khan et al, 2013;Oldenburg and Benson, 2002;Shtepani, 2006;Sidiq et al, 2011a;Sim et al, 2008;Zhang et al, 2014). This mixing contaminates the recovered natural gas and reduces its market value by reducing its calorific value and also, incurs additional cost in the sweetening processes (Oldenburg & Benson 2002;Sim et al 2008;).…”

Section: Introductionmentioning

confidence: 99%

Experimental investigation on the impact of connate water salinity on dispersion coefficient in consolidated rocks cores during Enhanced Gas Recovery by CO2 injection

Abba

Al-Othaibi

Abbas

et al. 2018

Journal of Natural Gas Science and Engineering

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Connate water salinity is a vital property of the reservoir and its influence on the displacement efficiency cannot be overemphasised. Despite the numerous analytical literatures on the dispersion behaviour of CO 2 in CH 4 at different parametric conditions, studies have so far been limited to systematic effects of the process while parameters such as connate water salinity of the reservoir has not been given much attention and this could redefine the CO 2 -CH 4 interactions in the reservoir. This study aims to experimentally determine the effect of connate water salinity on the dispersion coefficient in consolidated porous media under reservoir conditions. A laboratory core flooding experiment depicting the detailed process of the CO 2 -CH 4 displacement using Grey Berea sandstone core sample at a temperature of 50 o C and at a pressure of 1300 psig was carried out to determine the optimum injection rate, from 0.2-0.5 ml/min, for the experimentation based on dispersion coefficients and methane recovery in the horizontal orientation. This was established to be 0.3 ml/min. At the same conditions, the effects of connate water saturation of 10% and a salinity of 0 (distilled water), 5, and 10% wt. with a CO 2 injection rate of 0.3 ml/min on the dispersion coefficients was investigated. The results from the core flooding process indicated that the dispersion coefficient decreases with increasing salinity, hence the higher the density of the immobile phase (connate water) the lower the dispersion of CO 2 into CH 4 . This is a significant finding given that the inclusion of the connate water and its salinity have an effect on the mixing of the gases in the core sample and should be given importance and included during simulation studies for field scale applications of Enhanced Gas Recovery (EGR). This is the first experimental investigation into the relationship between the connate water salinity and the dispersion coefficient in consolidated porous media.

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Section: Introductionmentioning

confidence: 99%

Experimental investigation on the impact of connate water salinity on dispersion coefficient in consolidated rocks cores during Enhanced Gas Recovery by CO2 injection

Abba

Al-Othaibi

Abbas

et al. 2018

Journal of Natural Gas Science and Engineering

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“…Geological sequestration (Orr 2004) of CO 2 is one of the viable methods to stabilize the concentration of greenhouse gases in the atmosphere and to satisfy the Kyoto protocol. The main storage options are depleted oil and gas reservoirs (Shtepani 2006;Pawar et al 2004), deep (saline) aquifers (Kumar et al 2005;Pruess et al 2003;Pruess 2004), and unmineable coalbeds (Reeves 2001). Laboratory studies and recent pilot field tests (Mavor et al 2004;Pagnier et al 2005) demonstrate that CO 2 injection has the potential to enhance CH 4 production from coal seams.…”

Section: Introductionmentioning

confidence: 99%

Capillary Pressure and Wettability Behavior of CO2 Sequestration in Coal at Elevated Pressures

Plug¹,

Mazumder

Bruining

2008

SPE Journal

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Enhanced coalbed-methane (ECBM) recovery combines recovery of methane (CH 4) from coal seams with storage of carbon dioxide (CO 2). The efficiency of ECBM recovery depends on the CO 2 transfer rate between the macrocleats, via the microcleats to the coal matrix. Diffusive transport of CO 2 in the small cleats is enhanced when the coal is CO 2-wet. Indeed, for water-wet conditions, the small fracture system is filled with water and the rate of CO 2 sorption and CH 4 desorption is affected by slow diffusion of CO 2. This work investigates the wetting behavior of coal using capillary pressures between CO 2 and water, measured continuously as a function of water saturation at in-situ conditions. To facilitate the interpretation of the coal measurements, we also obtain capillary pressure curves for unconsolidated-sand samples. For medium-and high-rank coal, the primary drainage capillary pressure curves show a water-wet behavior. Secondary forcedimbibition experiments show that the medium-rank coal becomes CO 2-wet as the CO 2 pressure increases. High-rank coal is CO 2-wet during primary imbibition. The imbibition behavior is in agreement with contact-angle measurements. Hence, we conclude that imbibition tests provide the practically relevant data to evaluate the wetting properties of coal.

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“…Additionally, these costs are often lumped. A common rule of thumb is that 80% of the cost is associated with capture and compression, while 20% is associated with transport and injection (2)(3)(4)(5)(6)(7) .…”

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confidence: 99%

Analysis of the Storage Capacity for CO2 Sequestration of a Depleted Gas Condensate Reservoir and a Saline Aquifer

Barrufet

Bacquet

Falcone

2010

Journal of Canadian Petroleum Technology

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Summary Among the three types of geological CO2 sequestration (mature oil and gas fields, unminable coalbeds and deep saline formations), depleted gas condensate reservoirs are particularly interesting. First, because of the high-compressibility of gas, these reservoirs have larger storage capacity than oil reservoirs or aquifers. Second, the condensate that has dropped out from the gas phase during natural depletion will re-vaporize because of re-pressurization of the reservoir and by miscibility with the injected CO2. This condensate can be recovered from producing wells and leaves more pore volume for available storage of CO2. The objective of this study is to investigate the CO2 storage capacity in different formation types, for different levels of CO2 purity and different injection schedules. To this aim, we analyzed the injection of a CO2-based stream into a depleted gas condensate reservoir and into a saline aquifer using a compositional reservoir simulation model. The dynamics of the reservoir impose a minimum period of injection that is required in order for the storage scheme to benefit from 100% of the reservoir storage capacity. Hence, over and above a certain CO2 injection rate, it becomes meaningless to invest in bigger compressors to increase this rate to reduce the time of injection. When the CO2 stream contains impurities, such as N2 or methane, the storage capacity of the reservoir decreases proportionally to the impure stream's compressibility factor and its concentration of impurities. This finding suggests that an economic optimum between the costs of separation, compression and injection can be determined. Finally, the mass of CO2 sequestrated per pore volume in the equivalent aquifer model is approximately 13 times lower that of the depleted gas condensate reservoir model. This confirms that, because of their low overall compressibility, aquifers offer a far lower ratio of CO2 stored per pore volume than depleted gas condensate reservoirs. However, aquifers tend to have a far larger extent, which often compensates somewhat for this lower ratio and therefore provides storage for significant volumes of CO2.

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CO2 Sequestration in Depleted Gas/Condensate Reservoirs

Cited by 29 publications

References 6 publications

Experimental investigation on the impact of connate water salinity on dispersion coefficient in consolidated rocks cores during Enhanced Gas Recovery by CO2 injection

Experimental investigation on the impact of connate water salinity on dispersion coefficient in consolidated rocks cores during Enhanced Gas Recovery by CO2 injection

Capillary Pressure and Wettability Behavior of CO2 Sequestration in Coal at Elevated Pressures

Analysis of the Storage Capacity for CO2 Sequestration of a Depleted Gas Condensate Reservoir and a Saline Aquifer

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