Comparison of First and Multiple Contact Carbon Dioxide Induced Asphaltene Precipitation

Parra-Ramirez, M.; Peterson, B.; Deo, M.D.

doi:10.2523/65019-ms

Cited by 5 publications

(4 citation statements)

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“…A further complexity may arise when the addition of CO 2 leads to precipitation of asphaltenes from the oil, which is either reported as a VLLE or more commonly as a Vapor-Liquid-Solid Equilibrium (VLSE) system. A large number of publications deals with this topic (Novosad et al (1990), Monger et al (1991), Srivastava et al (1995), Parra-Ramirez et al (2001), and Broad et al (2007)). …”

Section: Introductionmentioning

confidence: 96%

Investigation of Miscibility Behavior of CO2 rich Hydrocarbon Systems – With Application for Gas Injection EOR

Lindeloff¹,

Mogensen²,

Oil³

et al. 2013

SPE Annual Technical Conference and Exhibition

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The phase behavior of two Middle East reservoir fluids mixed with CO 2 has been studied. The experimental work includes quantification of VLLE/LLE behavior studied in a visual high pressure PVT cell.To investigate the effect of dispersion on slim tube recoveries, experiments were performed using two different tube sizes. One of the reservoir fluids was found to be miscible with CO 2 at the reservoir temperature while a liquid-liquid split persisting at high pressure was observed for the other fluid. As the two liquid phases had approximately the same mobility, a high slimtube recovery was seen for the latter fluid despite the liquid-liquid split. EOS models have been developed matching the swelling and slimtube data and confirming the observed VLLE and LLE phase behavior.The work has led to an improved understanding of how swelling and MMP data for CO 2 -crude oil systems is to be interpreted. An important observation is that a miscible drive is not always attainable for a reservoir fluid undergoing CO 2 gas injection.

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Section: Introductionmentioning

confidence: 96%

Investigation of Miscibility Behavior of CO2 rich Hydrocarbon Systems – With Application for Gas Injection EOR

Lindeloff¹,

Mogensen²,

Oil³

et al. 2013

SPE Annual Technical Conference and Exhibition

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“…The volume of each phase is recorded over time to determine the phase properties. Alternatively, the pressure decay may be used to determine the CO 2 concentration and diffusivity in the oil, whereby the volume is kept constant in the PVT cell, and the pressure is monitored over time. , Asphaltene precipitation during CO 2 injection was also investigated using a PVT apparatus combined with a high-pressure core flooding system . The pendant drop method has also been used to measure the interfacial tension, oil swelling, and extraction pressure of CO 2 –oil mixtures. , The minimum miscibility pressure (MMP) of CO 2 –oil (i.e., the lowest pressure at which a gas becomes miscible with oil through a multiple contact process at a given temperature) is commonly measured separate from PVT testing, via the slim tube apparatus, rising bubble system, or vanishing interfacial tension method. − Moreover, a high-pressure cell combined with an X-ray source has been used to measure the oil swelling and minimum miscibility pressure for a CO 2 / n -decane system .…”

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confidence: 99%

“…32,36 Asphaltene precipitation during CO 2 injection was also investigated using a PVT apparatus combined with a high-pressure core flooding system. 37 The pendant drop method has also been used to measure the interfacial tension, oil swelling, and extraction pressure of CO 2 −oil mixtures. 33,38 The minimum miscibility pressure (MMP) of CO 2 −oil (i.e., the lowest pressure at which a gas becomes miscible with oil through a multiple contact process at a given temperature) is commonly measured separate from PVT testing, via the slim tube apparatus, rising bubble system, or vanishing interfacial tension method.…”

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confidence: 99%

Full Characterization of CO₂–Oil Properties On-Chip: Solubility, Diffusivity, Extraction Pressure, Miscibility, and Contact Angle

Sharbatian

Abedini

et al. 2018

Anal. Chem.

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Carbon capture, storage, and utilization technologies target a reduction in net CO emissions to mitigate greenhouse gas effects. The largest such projects worldwide involve storing CO through enhanced oil recovery-a technologically and economically feasible approach that combines both storage and oil recovery. Successful implementation relies on detailed measurements of CO-oil properties at relevant reservoir conditions (P = 2.0-13.0 MPa and T = 23 and 50 °C). In this paper, we demonstrate a microfluidic method to quantify the comprehensive suite of mutual properties of a CO and crude oil mixture including solubility, diffusivity, extraction pressure, minimum miscibility pressure (MMP), and contact angle. The time-lapse oil swelling/extraction in response to CO exposure under stepwise increasing pressure was quantified via fluorescence microscopy, using the inherent fluorescence property of the oil. The CO solubilities and diffusion coefficients were determined from the swelling process with measurements in strong agreement with previous results. The CO-oil MMP was determined from the subsequent oil extraction process with measurements within 5% of previous values. In addition, the oil-CO-silicon contact angle was measured throughout the process, with contact angle increasing with pressure. In contrast with conventional methods, which require days and ∼500 mL of fluid sample, the approach here provides a comprehensive suite of measurements, 100-fold faster with less than 1 μL of sample, and an opportunity to better inform large-scale CO projects.

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“…On the other hands, the lower reservoir has not encountered any remarkable asphaltene related problems so far. The increase of asphaltene risks by gas injection has been worldwidely recognized as general rule 3,14,[16][17][18][19][20][21][22][23][24] , and a preparatory evaluation of asphaltene behavior under gas mixing condition is important to minimize its risks and to optimize gas injection project. Among available various remedies in each technology which have been widely applied in the world 1-7 , the most conventional ways have been applied in our target field.…”

Section: Introductionmentioning

confidence: 99%

Ready for Gas Injection: Asphaltene Risk Evaluation by Mathematical Modeling of Asphaltene Precipitation Envelope (APE) With Integration of all Laboratory Deliverables

Yonebayashi

Masuzawa²,

Dabbouk³

et al. 2009

All Days

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An offshore carbonate oil field in the Arabian Gulf is exhibiting asphaltene deposition problem mainly inside tubing of production wells completed in one of two main producible limestone reservoirs. This problem significantly reduces well profitability due to production loss and frequent asphaltene removal job (solvent soaking). Furthermore, future full-field EOR development, namely gas injection, is now planned and might have a risk to enhance the asphaltene problem. Therefore, comprehensive study has been carried out not only to establish less frequent and more effective remedy than the current action but also to evaluate a future risk of gas injection.The study was initiated with careful review of the fundamental measurements, collected during the 20 years production history, of asphaltene properties, i.e. SARA (saturates, aromatics, resins and asphaltenes) analysis, asphaltene contents, AOP (asphaltene onset pressure) measurement, etc. Subsequently, the mathematical modeling analysis using those properties was incorporated into the study in order to develop APE (asphaltene precipitation envelope) for better understanding/predicting of asphaltene precipitation behavior. Therefore, this paper describes the integration/optimization of the APE modeling based on all available laboratory data, and consequently suggests representative APE. The APE model validity was evaluated by comparison with actual observation data in the problematic reservoir.Based on the mathematical models once established, several sensitivities, namely mixing with injection gas and blending oils produced from two main producible reservoirs, were investigated in order to assess impacts of the future EOR on asphaltene risk from sub-surface and surface point of views. Several types of injection gas were examined, and their risks were compared and identified. Consequently, the surface facility design was adequately modified and optimized in order to minimize asphaltene risk assisted by gas injection.

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Comparison of First and Multiple Contact Carbon Dioxide Induced Asphaltene Precipitation

Cited by 5 publications

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Investigation of Miscibility Behavior of CO2 rich Hydrocarbon Systems – With Application for Gas Injection EOR

Investigation of Miscibility Behavior of CO2 rich Hydrocarbon Systems – With Application for Gas Injection EOR

Full Characterization of CO₂–Oil Properties On-Chip: Solubility, Diffusivity, Extraction Pressure, Miscibility, and Contact Angle

Ready for Gas Injection: Asphaltene Risk Evaluation by Mathematical Modeling of Asphaltene Precipitation Envelope (APE) With Integration of all Laboratory Deliverables

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Comparison of First and Multiple Contact Carbon Dioxide Induced Asphaltene Precipitation

Cited by 5 publications

References 0 publications

Investigation of Miscibility Behavior of CO2 rich Hydrocarbon Systems – With Application for Gas Injection EOR

Investigation of Miscibility Behavior of CO2 rich Hydrocarbon Systems – With Application for Gas Injection EOR

Full Characterization of CO2–Oil Properties On-Chip: Solubility, Diffusivity, Extraction Pressure, Miscibility, and Contact Angle

Ready for Gas Injection: Asphaltene Risk Evaluation by Mathematical Modeling of Asphaltene Precipitation Envelope (APE) With Integration of all Laboratory Deliverables

Contact Info

Product

Resources

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Full Characterization of CO₂–Oil Properties On-Chip: Solubility, Diffusivity, Extraction Pressure, Miscibility, and Contact Angle