The disposition of gas–oil mixtures trapped under ice

1980 ◽  
Vol 58 (8) ◽  
pp. 1183-1190
Author(s):  
D. R. Topham
Keyword(s):  
Solid Surface ◽  
Oil And Gas ◽  
Sessile Drop ◽  
Stable Solution ◽  
Crude Oils ◽  
Drop Formation ◽  
Gas Bubble ◽  
Gas Oil ◽  
Oil Mixtures

A number of stable configurations which can be formed from mixtures of oil and gas trapped in water under a solid surface is examined. In particular, the problem of a lens of oil lying within a sessile bubble of gas is solved, and two forms of stable solution are found; a discrete lens of oil lying in the bottom of the gas bubble and a double sessile drop formation with the oil completely enclosing the gas. A comparison of the energies of the formation indicates the ranges of oil properties where each configuration is likely to be found. The results are applied to the specific case of crude oils trapped under ice and an appropriate existence diagram constructed.

Transportation fuels from co-processing of waste vegetable oil and gas oil mixtures

2013 ◽  
Vol 56 ◽  
pp. 43-52 ◽  
Author(s):  
Bharat S. Rana ◽  
Rohit Kumar ◽  
Rashmi Tiwari ◽  
Rakesh Kumar ◽  
Rakesh K. Joshi ◽  
...  
Keyword(s):  
Vegetable Oil ◽  
Oil And Gas ◽  
Gas Oil ◽  
Transportation Fuels ◽  
Waste Vegetable Oil ◽  
Oil Mixtures

The Use of Controlled Dissolution Glasses to Consolidate and Create Permeable or Impermeable Minerals in Formation

2021 ◽  
Author(s):  
Max Olsen ◽  
Ragni Hatlebakk ◽  
Chris Holcroft ◽  
Arne Stavland ◽  
Nils Harald Giske ◽  
...  
Keyword(s):  
Tensile Strength ◽  
Oil And Gas ◽  
Stable Solution ◽  
Oil And Gas Industry ◽  
Post Treatment ◽  
Strength Increase ◽  
Glass Technology ◽  
Nuclear Waste Storage ◽  
Wide Range ◽  
Glass Compositions

Abstract Scope Controlled dissolution glasses form a permanent consolidating mineral matrix inside formations with either permeable or impermeable properties. The unique solution has a low injection viscosity and can be easily injected into a wide range of formations. The application method is simple and does not require multiple fluids or pre- and post-flushing. This paper focuses on the benefits of controlled dissolution glasses and potential applications in the oil and gas industry. Methods, Procedures, Process Controlled dissolution glasses have been researched extensively by Glass Technology Services (GTS) since 1999 for the biomedical industry, nuclear waste storage industry, and defense and aerospace industries. GTS together with operators have been performing research and development for the oil industry over the last 10 years. The research investigated different glass compositions to determine their injectability and change in formation properties post-treatment. Sandstone, chalk, and shale formations were used in the testing. Flow testing using a Hoek cell and a core flood apparatus was used to determine the post-treatment permeability. For post-treatment strength measurement, Brazilian tensile strength tests and modified cone penetration tests were used to determine tensile strength and shear strength respectively. The testing evaluated different mixing fluids, such as water and different brines, compatibility, corrosion testing, and concentrations. Results, Observations, Conclusions The testing identified different glass compositions and concentrations that are suitable for different applications and formations. Certain glass compositions increase tensile strength significantly while also maintaining the permeability in the formation. Other glass compositions have similar tensile strength increase, but result in an impermeable seal. The liquid glass solutions react with the formation to form a mineral precipitation inside the formation. The reaction with the formation occurs quickly at downhole conditions, within hours of placement. The glass can be mixed with water and variety of brines to form a stable solution across a range of densities. The testing and results to date have laid the foundation for use in a variety of consolidation and P&A applications in oil and gas wells. Testing is ongoing for a chalk and sandstone consolidation solution and for a sealing solution. Novel/Additive Information These novel glass solutions can solve many of the production and instability challenges that plague weak formations. The glasses can be injected into very low permeability formation to either seal or consolidate.

High-Purity, CO2-Free Hydrogen Generation from Crude Oils in Crushed Rocks Using Microwave Heating

2021 ◽  
Author(s):  
Qingwang Yuan ◽  
Xiangyu Jie ◽  
Bo Ren
Keyword(s):  
Microwave Heating ◽  
Environmental Impacts ◽  
High Purity ◽  
Oil And Gas ◽  
Hydrogen Generation ◽  
Petroleum Industry ◽  
Petroleum Reservoirs ◽  
Crude Oils ◽  
Hydrogen Yield ◽  
Free Hydrogen

Abstract While the demand for hydrocarbon resources has been continuously increasing in the past 150 years, the industry is, however, criticized for carbon dioxide (CO2) emissions and concomitant global warming concerns. The oil and gas industry also face growing pressures in the ongoing energy transition. Generating and producing hydrogen (H2) directly from petroleum reservoirs has the potential to mitigate environmental impacts while revolutionizing the traditional petroleum industry and enabling it to become a clean hydrogen industry. This paper proposes a novel approach to generate high-purity, CO2-free hydrogen from the abundant oil and gas resources in petroleum reservoirs using microwave heating. In this work, laboratory experiments were conducted to validate this scientific proof-of-concept and examine the roles of crushed rocks, catalysts, and water/oil ratio in hydrogen generation from crude oils in a reactor. A maximum of 63% ultimate hydrogen content is obtained in the generated gas mixtures, while the original CO2content in all experiments is negligible (<1%). Catalysts can promote hydrogen generation by accelerating rate and locally enhancing microwave (MW) absorption to create ‘super-hot spots'. Water also participates in reactions, and additional hydrogen is generated through water-gas shift reactions. The water-oil ratio in porous rocks affects the ultimate hydrogen yield. Overall, this research demonstrates the great potential of using MW heating to generate high-purity, CO2-free hydrogen from in situ petroleum reservoirs. Further research and wide application of this technology would potentially transform petroleum reservoirs to hydrogen generators, thus mitigating the environmental impacts of traditional petroleum industry while meeting the increasing demand for clean hydrogen energy. This technology would also benefit the safe transition towards a decarbonized society.

Contact between a gas bubble and a solid surface and froth flotation

1970 ◽  
Vol 1 ◽  
pp. 112 ◽  
Author(s):  
A. Scheludko ◽  
Sl. Tschaljowska ◽  
A. Fabrikant
Keyword(s):  
Solid Surface ◽  
Froth Flotation ◽  
Gas Bubble

Basin-wide rock-physics analysis in Campeche Basin, Gulf of Mexico — Phase II: Reservoir rock and fluid properties

2021 ◽  
Vol 40 (10) ◽  
pp. 716-722
Author(s):  
Yangjun (Kevin) Liu ◽  
Michelle Ellis ◽  
Mohamed El-Toukhy ◽  
Jonathan Hernandez
Keyword(s):  
Oil And Gas ◽  
Rock Physics ◽  
Clay Content ◽  
American Petroleum Institute ◽  
P Wave ◽  
Reservoir Rock ◽  
Gas Oil ◽  
Amplitude Variation With Offset ◽  
Fluid Properties ◽  
The Impact

We present a basin-wide rock-physics analysis of reservoir rocks and fluid properties in Campeche Basin. Reservoir data from discovery wells are analyzed in terms of their relationship between P-wave velocity, density, porosity, clay content, Poisson's ratio (PR), and P-impedance (IP). The fluid properties are computed by using in-situ pressure, temperature, American Petroleum Institute gravity, gas-oil ratio, and volume of gas, oil, and water. Oil- and gas-saturated reservoir sands show strong PR anomalies compared to modeled water sand at equivalent depth. This suggests that PR anomalies can be used as a direct hydrocarbon indicator in the Tertiary sands in Campeche Basin. However, false PR anomalies due to residual gas or oil exist and compose about 30% of the total anomalies. The impact of fluid properties on IP and PR is calibrated using more than 30 discovery wells. These calibrated relationships between fluid properties and PR can be used to guide or constrain amplitude variation with offset inversion for better pore fluid discrimination.

Hydrocracking of vacuum gas oil-vegetable oil mixtures for biofuels production

2009 ◽  
Vol 100 (12) ◽  
pp. 3036-3042 ◽  
Author(s):  
Stella Bezergianni ◽  
Aggeliki Kalogianni ◽  
Iacovos A. Vasalos
Keyword(s):  
Vegetable Oil ◽  
Vacuum Gas Oil ◽  
Gas Oil ◽  
Oil Mixtures

The Development of an Oil Reservoir with Condensate Gas Cap

2012 ◽  
Vol 524-527 ◽  
pp. 1615-1619
Author(s):  
Heng Song ◽  
Lun Zhao ◽  
Jian Xin Li ◽  
Kou Shi
Keyword(s):  
Numerical Simulation ◽  
Oil And Gas ◽  
Oil Reservoir ◽  
Gas Oil ◽  
Gas Reservoir ◽  
Oil Rim ◽  
High Level

The development of gas-oil reservoir with condensate gas is more difficult than pure gas reservoir or oil reservoir. This article gives the example of G oil reservoir the development of gas cap and oil rim. According to the characteristic of the oil developing and the results of numerical simulation, the rules for oil and gas developing and developing time have been defined, by which the recoveries of gas, oil, and condensate oil will reach a significantly high level.

Variations of Gas/Condensate Relative Permeability With Production Rate at Near-Wellbore Conditions: A General Correlation

2006 ◽  
Vol 9 (06) ◽  
pp. 688-697 ◽  
Author(s):  
Mahmoud Jamiolahmady ◽  
Ali Danesh ◽  
D.H. Tehrani ◽  
Mehran Sohrabi
Keyword(s):  
Relative Permeability ◽  
Oil And Gas ◽  
Coupling Effect ◽  
Flow Behavior ◽  
Accurate Determination ◽  
Gas Condensate ◽  
Gas Oil ◽  
Fractional Flow ◽  
General Correlation ◽  
Fluid Saturation

Summary It has been demonstrated, first by this laboratory and subsequently by other researchers, that the gas and condensate relative permeability can increase significantly by increasing rate, contrary to the common understanding. There are now a number of correlations in the literature and commercial reservoir simulators accounting for the positive effect of coupling and the negative effect of inertia at near-wellbore conditions. The available functional forms estimate the two effects separately and include a number of parameters, which should be determined with measurements at high-velocity conditions. Measurements of gas/condensate relative permeability at simulated near-wellbore conditions are very demanding and expensive. Recent experimental findings in this laboratory indicate that measured gas/condensate relative permeability values on cores with different characteristics become more similar if expressed in terms of fractional flow instead of the commonly used saturation. This would lower the number of rock curves required in reservoir studies. Hence, we have used a large data bank of gas/condensate relative permeability measurements to develop a general correlation accounting for the combined effect of coupling and inertia as a function of fractional flow. The parameters of the new correlation are either universal, applicable to all types of rocks, or can be determined from commonly measured petrophysical data. The developed correlation has been evaluated by comparing its prediction with the gas/condensate relative permeability values measured at near-wellbore conditions on reservoir rocks not used in its development. The results are quite satisfactory, confirming that the correlation can provide reliable information on variations of relative permeability at near-wellbore conditions with no requirement for expensive measurements. Introduction The process of condensation around the wellbore in a gas/condensate reservoir, when the pressure falls below the dewpoint, creates a region in which both gas and condensate phases flow. The flow behavior in this region is controlled by the viscous, capillary, and inertial forces. This, along with the presence of condensate in all the pores, dictates a flow mechanism that is different from that of gas/oil and gas/condensate in the bulk of the reservoir (Danesh et al. 1989). Accurate determination of gas/condensate relative permeability (kr) values, which is very important in well-deliverability estimates, is a major challenge and requires an approach different from that for conventional gas/oil systems. It has been widely accepted that relative permeability (kr) values at low values of interfacial tension (IFT) are strong functions of IFT as well as fluid saturation (Bardon and Longeron 1980; Asar and Handy 1988; Haniff and Ali 1990; Munkerud 1995). Danesh et al. (1994) were first to report the improvement of the relative permeability of condensing systems owing to an increase in velocity as well as that caused by a reduction in IFT. This flow behavior, referred to as the positive coupling effect, was subsequently confirmed experimentally by other investigators (Henderson et al. 1995, 1996; Ali et al. 1997; Blom et al. 1997). Jamiolahmady et al. (2000) were first to study the positive coupling effect mechanistically capturing the competition of viscous and capillary forces at the pore level, where there is simultaneous flow of the two phases with intermittent opening and closure of the gas passage by condensate. Jamiolahmady et al. (2003) developed a steady-dynamic network model capturing this flow behavior and predicted some kr values, which were quantitatively comparable with the experimentally measured values.

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