Carbonated Waterflood Results--Texas and Oklahoma

Christensen, Rod

doi:10.2523/66-ms

Cited by 7 publications

(6 citation statements)

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“…Injection of CO2-enriched water for enhanced oil recovery and CO2 storage has received substantial attentions amongst oil industry and CCS stakeholders [ (Blackford, 1987) (Christensen, 1961) (Oelkers, et al, 2008) (Alizadeh, et al, 2014) (Mosavat & Torabi, 2014)].…”

Section: Introductionmentioning

confidence: 99%

An integrated evaluation of enhanced oil recovery and geochemical processes for carbonated water injection in carbonate rocks

Mahzari

Jones

Oelkers

2019

Journal of Petroleum Science and Engineering

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During carbonated water injection and CO2-WAG scenarios for enhanced oil recovery, the transfer of CO2 from the aqueous phase into resident oil can cause local spatially pH changes, which can provoke mineral dissolution and precipitation reactions. The transfer of CO2 from carbonated water into the oil phase can also liberate its light components creating a gas phase in-situ. In this investigation, a novel method was developed to numerically simulate these complex processes using an integrated approach. Calculations took account of the results of coreflood experiments performed on a carbonate rock at 3100 psi and 100 o C to optimise reaction parameters. Using the optimised parameters in a radial sector model, a series of simulations was performed to analyse change in rock porosity and enhanced oil recovery for large scale for carbonated water injections. Results demonstrate that mineral dissolution takes place mostly in vicinity of the injection wellbore. However, the simulation results demonstrate that injection of short cycle of carbonated water followed by plain water would alleviate the dissolution issue, while significant additional oil recovery is achieved.

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Section: Introductionmentioning

confidence: 99%

An integrated evaluation of enhanced oil recovery and geochemical processes for carbonated water injection in carbonate rocks

Mahzari

Jones

Oelkers

2019

Journal of Petroleum Science and Engineering

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“…Because the optimal WAG ratio and slug sizes are constantly changing between cycles, site-optimization procedures require extensive efforts and monitoring . Others have proposed carbonated water injection (CWI), i.e., injecting water with dissolved CO 2 , to eliminate the mobility control issue associated with injecting gaseous CO 2 and have demonstrated these in both field-scale − and laboratory-scale − tests. Regarding the field practice, CWI requires no surface facilities beyond the basic water flooding system, except the pressurized mixing tank for the CO 2 dissolution step.…”

Section: Introductionmentioning

confidence: 99%

In Situ CO₂ Enhanced Oil Recovery: Parameters Affecting Reaction Kinetics and Recovery Performance

Wang¹,

Chen²,

Li³

et al. 2019

Energy Fuels

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In situ CO2 enhanced oil recovery (ICE) shows great potential for increasing oil field tertiary recovery. Instead of injecting liquid CO2 directly into the oil reservoir, a solution of a CO2-generating agent is injected to deliver CO2 to the targeted zone. Urea is an attractive gas-generating agent for ICE because it has both low price and exceptional stability in brine with elevated divalent cation concentrations. Besides CO2, urea thermal hydrolysis releases NH3(aq). Both molecules have positive impacts on the tertiary recovery, such as oil swelling, oil viscosity reduction, brine alkalinity increase, and sand surface wettability reversal. Thermal hydrolysis of urea is rapid at 120 °C, but the reaction rate decreases exponentially at lower temperatures. This work compares tertiary recovery from urea hydrolysis at 120 and 80 °C with and without a homogeneous catalyst (NaOH) for the purpose of examining the feasibility of urea-ICE for low-temperature reservoirs. The tertiary recovery was studied and optimized with data from 11 one-dimensional sand pack tests at varying conditions. Since urea hydrolysis produces a reaction intermediate, ammonium carbamate, which is known to precipitate in the presence of divalent cations, brines with elevated calcium concentrations were studied to examine the divalent cation stability of the proposed system. The optimization work included tests with urea concentrations varying from 1 to 35 wt % and different injection strategies and flow rates (0.03–0.3 mL/min). Tertiary oil recovery results of this study show that there are two different optimal concentrations of urea, one that maximizes the volume of tertiary oil produced and another that minimizes the cost per barrel of tertiary oil produced. The urea consumption of the proposed ICE can be as low as 34 kg/barrel with 2.5 wt % chemical slug, and the tertiary recovery can be as high as 48.3% with 10 wt % chemical injection. The optimal injection strategy was strongly dependent on chemical residence time because the tertiary recovery mechanisms vary with the injected concentrations. The aqueous effluent showed increasing solution pH, approaching pH 10. Based on an high-performance liquid chromatography analysis of the aqueous effluent, the mass balance of different tests was calculated. No adverse effect on tertiary recovery was observed in simulated seawater brines, with up to 1 wt % dissolved divalent salts. At higher levels of divalent ions (Ca2+ 7000 ppm) in a so-called API brine, lower tertiary recovery was observed but there was no evidence of formation damage and tubing blockage. In this work, the proposed ICE system showed superior tertiary recovery performance (48.3%) compared to the most recent efforts by our group (29.5%) as well as similar ICE systems (2.4–18.8%) proposed by others. Results illustrate the economic feasibility and the divalent cation tolerance of the urea-ICE process.

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“…CWI is not a new topic in the petroleum industry. Its development stems from the study of CO 2 , while searching for a new raw material that is suitable as a reservoir surfactant, yet cheap enough to use in quantity . Hickok et al .…”

Section: Introductionmentioning

confidence: 99%

“…Its development stems from the study of CO 2 , while searching for a new raw material that is suitable as a reservoir surfactant, yet cheap enough to use in quantity. 20 Hickok et al 21 reported the first commercial application of CWI at the K&S project in Texas and Oklahoma. The performance of CWI was encouraging; additional oil recovery and enhanced injectivity were obtained.…”

Section: Introductionmentioning

confidence: 99%

Integrated PVT and Coreflooding Studies of Carbonated Water Injection in Tight Oil Reservoirs: A Case Study

Zou

Chen

et al. 2019

Energy Fuels

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Carbonated water injection (CWI) is a modified CO2 flooding technique for enhanced oil recovery, which takes advantage of both CO2 flooding and water injection and has attracted much attention recently. However, the dedicated research so far has focused heavily on conventional reservoirs. The objective of this research is to investigate the performance of CWI in a tight oil reservoir. First, a set of well-designed multiple contact tests were conducted to simulate the dynamic mass transfer process of fresh carbonated water (CW) to live crude oil. In each test, CW was brought into contact with live crude oil in a high-temperature and high-pressure PVT cell. Pressure changes during the test were observed and recorded. After equilibrium, all the transferred CW was taken out of the cell and the swelled oil proceeded to the next contact. The volumes of water and liberated gas were measured. Then, the oil swelling factor could be calculated, which would verify the existence of the moving interface between CW and live crude oil. It was observed that the system pressure built up immediately after CW was mixed with live crude oil in the PVT cell. For the first contact, the equilibrium pressure increased by 6.46 MPa, and the equilibrium pressure increased by 2.16 MPa at the last contact. This result indicates a strong interaction between CW and live crude oil, which is beneficial to maintain reservoir pressure. Because a large amount of CO2 from CW was transferred to the live crude oil, the swelling factor of 1.26 was obtained at the end of the tests. The diffusion of CO2 into the live crude oil also leads to subsequent oil viscosity reduction. In addition, a series of coreflood experiments under real reservoir conditions were carried out to evaluate the performance of CWI for improving oil recovery in core samples from a tight sandstone reservoir. Coreflood results showed that both secondary and tertiary CWI recovered additional oil compared to water flooding. Finally, a significant amount of CO2 was stored in the cores. Our experimental results clearly indicate the potential of CWI for improving oil recovery and CO2 storage capacity in tight oil reservoirs.

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Carbonated Waterflood Results--Texas and Oklahoma

Cited by 7 publications

References 0 publications

An integrated evaluation of enhanced oil recovery and geochemical processes for carbonated water injection in carbonate rocks

An integrated evaluation of enhanced oil recovery and geochemical processes for carbonated water injection in carbonate rocks

In Situ CO₂ Enhanced Oil Recovery: Parameters Affecting Reaction Kinetics and Recovery Performance

Integrated PVT and Coreflooding Studies of Carbonated Water Injection in Tight Oil Reservoirs: A Case Study

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Carbonated Waterflood Results--Texas and Oklahoma

Cited by 7 publications

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An integrated evaluation of enhanced oil recovery and geochemical processes for carbonated water injection in carbonate rocks

An integrated evaluation of enhanced oil recovery and geochemical processes for carbonated water injection in carbonate rocks

In Situ CO2 Enhanced Oil Recovery: Parameters Affecting Reaction Kinetics and Recovery Performance

Integrated PVT and Coreflooding Studies of Carbonated Water Injection in Tight Oil Reservoirs: A Case Study

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In Situ CO₂ Enhanced Oil Recovery: Parameters Affecting Reaction Kinetics and Recovery Performance