Miscible Gas Injection and Asphaltene Flow Assurance Fluid Characterization: A Laboratory Case Study for Black Oil Reservoir

2012 ◽  
Author(s):  
Afzal I. Memon ◽  
Bashar Qassim ◽  
Moudi Fahad Al-ajmi ◽  
Asok Kumar Tharanivasan ◽  
Jinglin Gao ◽  
...  
Keyword(s):  
Gas Injection ◽  
Flow Assurance ◽  
Oil Reservoir ◽  
Black Oil ◽  
Miscible Gas Injection ◽  
Fluid Characterization

Minimum Miscibility Pressure of CO2/Hydrocarbon Systems Within Nanopores

2021 ◽  
Author(s):  
Gang Yang ◽  
Xiaoli Li
Keyword(s):  
Oil Recovery ◽  
Gas Injection ◽  
Unconventional Reservoirs ◽  
Minimum Miscibility Pressure ◽  
Theoretical Approaches ◽  
Fluid Systems ◽  
Confined Fluid ◽  
Miscible Gas Injection ◽  
Fluid Characterization ◽  
The Impact

Abstract Minimum miscibility pressure (MMP), as a key parameter for the miscible gas injection enhanced oil recovery (EOR) in unconventional reservoirs, is affected by the dominance of nanoscale pores. The objective of this work is to investigate the impact of nanoscale confinement on MMP of CO2/hydrocarbon systems and to compare the accuracy of different theoretical approaches in calculating MMP of confined fluid systems. A modified PR EOS applicable for confined fluid characterization is applied to perform the EOS simulation of the vanishing interfacial tension (VIT) experiments. The MMP of multiple CO2/hydrocarbon systems at different pore sizes are obtained via the VIT simulations. Meanwhile, the multiple mixing cell (MMC) algorithm coupled with the same modified PR EOS is applied to compute the MMP for the same fluid systems. Comparison of these results to the experimental values recognize that the MMC approach has higher accuracy in determining the MMP of confined fluid systems. Moreover, nanoscale confinement results in the drastic suppression of MMP and the suppression rate increases with decreasing pore size. The drastic suppression of MMP is highly favorable for the miscible gas injection EOR in unconventional reservoirs.

AUTOMATED WORKFLOW TO INDICATE RESERVOIR CONNECTIVITY THROUGH ASPHALTENE EQUILIBRIUM

2021 ◽  
Author(s):  
Melanie Jensen ◽  
◽  
Lalitha Venkataramanan ◽  
Li Chen ◽  
Sandip Bose ◽  
...  
Keyword(s):  
Optical Density ◽  
Development Planning ◽  
Oil Reservoir ◽  
Quasi Equilibrium ◽  
Primary Concern ◽  
Domain Experts ◽  
First Case ◽  
Black Oil ◽  
Reservoir Connectivity

The evaluation of downhole fluid analysis (DFA) measurements of asphaltene gradients provides the ability to determine the extent of asphaltene equilibrium and the operative reservoir fluid geodynamics (RFG) processes. Typically, equilibrium of reservoir fluids indicates reservoir connectivity, a primary concern in field development planning. Currently, the modeling of asphaltene gradients is done through the manual evaluation of the DFA optical density gradients. The optical density measurements are fit to an equation of state (EOS), such as the Flory-Huggins-Zuo EOS, and evidence for asphaltene equilibrium is concluded if the inferred asphaltene diameter corresponds to that of the Yen-Mullins model for asphaltene composition. In this work, we present an automated Bayesian algorithm that proposes multiple hypotheses for the state of asphaltene equilibrium. The proposed hypotheses honor DFA measurements; physical models for asphaltenes in equilibrium, such as the Yen-Mullins model; and prior domain knowledge of the reservoir, such as geological layers, faults, and flow units. The leading hypotheses are reported, and evidence for or against asphaltene equilibrium is concluded from inferred quantities. Our proposed method provides a faster way for domain experts to explore different reservoir realizations that honor the theory of asphaltenes gradients and previous knowledge about the reservoir. We verify our novel method on three case studies that are undergoing different RFG processes through comparison of the interpretation done by domain experts. While there are many reservoir complexities associated with each case study, we focus on whether the underlying RFG process corresponds to the asphaltenes in equilibrium. The first case study is a light oil reservoir in the Norwegian North Sea that is mostly in fluid equilibrium with exceptions at the flanks. The second case study is a black oil reservoir that has undergone a fault block migration after the reservoir fluids had a chance to achieve equilibrium. The last case study is a black oil reservoir in quasi-equilibrium due to biodegradation in the lower portion of the well.

Maximize the Ultimate Recovery by Designing & Optimizing a CO2 Miscible Gas Injection Pilot in Giant Carbonate Oil Reservoir, Abu Dhabi

2012 ◽  
Author(s):  
Ali Rawahi ◽  
Hafez H. Hafez ◽  
Arafat Al-yafei ◽  
Saleem G. Ghori ◽  
Kevin Putney ◽  
...  
Keyword(s):  
Gas Injection ◽  
Abu Dhabi ◽  
Oil Reservoir ◽  
Miscible Gas Injection

Minimum Miscibility Pressure of Gas Injection in Unconventional Reservoirs

2021 ◽  
Author(s):  
Gang Yang
Keyword(s):  
Phase Behavior ◽  
Gas Injection ◽  
Fluid Phase ◽  
Unconventional Reservoirs ◽  
Unconventional Reservoir ◽  
Minimum Miscibility Pressure ◽  
Confined Fluid ◽  
Miscible Gas Injection ◽  
Fluid Characterization ◽  
The Impact

Abstract Unconvnetional reservoirs are predominantly consisted of nanoscale pores. The strong confinement effect within nanopores imposes significant deviations to the confined fluid phase behavior. Minimum miscibility pressure (MMP) in unconventional reservoirs, as a parameter highly related to the phase behavior of confined fluids, is inevitably affected by the nanoscale confinement. The objective of this work is to investigate the impact of nanoscale confinement on MMP of unconventional reservoir fluids and to recognize a reliable theoretical approach to determine the MMP values in unconventional reservoirs. A modified Peng-Robinson equation of state (PR EOS) applicable for confined fluid characterization is applied to perform the EOS simulation of the vanishing interfacial tension (VIT) experiments. The MMP of a binary mixture at bulk and 50 nm are obtained via the VIT simulation. Meanwhile, the multiple mixing cell (MMC) algorithm coupled with the modified PR EOS is applied to compute the MMP for the same binary system. Comparison of the calculated results to the experimental values recognize that the MMC approach has higher accuracy in determining the MMP of confined fluid systems. Moreover, this approach is then applied to predict the MMP values of both Bakken and Eagle Ford oil at different pore sizes with various injected gases. Results demonstrate that the nanoscale confinement causes drastic suppression to the MMP of unconventional reservoir fluids and the suppression rate increases with decreasing pore size. The drastic suppression of MMP is highly favorable for the miscible gas injection EOR in unconventional reservoirs.

Successful Foam EOR Pilot in a Mature Volatile Oil Reservoir Under Miscible Gas Injection

2013 ◽  
Author(s):  
A. Ocampo ◽  
A. Restrepo ◽  
H. Cifuentes ◽  
J. Hester ◽  
N. Orozco ◽  
...  
Keyword(s):  
Gas Injection ◽  
Volatile Oil ◽  
Oil Reservoir ◽  
Miscible Gas Injection
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