Technologies for oil and gas production: Present and future

Economides, Michael J.; Nikolaou, Michael

doi:10.1002/aic.12714

Cited by 15 publications

(14 citation statements)

References 41 publications

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“…The results in Figure 2 show that a relative lower bitumen recovery of about 70% was observed for the microbial-treated ores with an incubation period of 7 days. Especially, the corresponding flotation rate constant is much lower and only about 0.09 min 21 . While for the ores with an incubation period of 14 and 20 days, the bitumen recovery could attain 93 and 98% with flotation rate constants of 0.18, and 0.19 min…”

Section: Processability Of the Microbial-treated Oil Sandsmentioning

confidence: 97%

“…Where R 1 (%) is the ultimate bitumen recovery and k is the flotation rate constant (min 21 ). By best fitting the experimental data in Figure 2 to above equation, the flotation rate k was obtained.…”

Section: Processability Of the Microbial-treated Oil Sandsmentioning

confidence: 99%

“…19 From that time on, numerous engineers and scientists have left their track on the progress of MEOR technique. Today, in addition to conventional technologies for crude oil production, 20,21 MEOR technique has been an alternative way used in classical or modern tertiary enhanced oil recovery. [22][23][24] The MEOR technique takes many advantages, such as cost efficiency and environmental friendliness.…”

Section: Introductionmentioning

confidence: 99%

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Application of microbial enhanced oil recovery technology in water‐based bitumen extraction from weathered oil sands

et al. 2014

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When using the water-based extraction processes (WBEPs) to recover bitumen from the weathered oil sands, very low bitumen recovery arisen from the poor liberation of bitumen from sand grains is always obtained. Application of microbial enhanced oil recovery (MEOR) technology in WBEPs to solve the poor processability of the weathered ore was proposed. It was found that processability of the microbial-treated weathered ore was greatly improved. The improved processability was attributed to the biosurfactants production in the culture solution, alteration of the solids wettability, degradation of the asphaltene component, and the decrease of the bitumen viscosity, which collectively contributed to the bitumen liberation from the surface of sand grains. Although it still has many issues to be solved for an industrial application of the MEOR technology in oil sands separation, it is believed that the findings in this work promote the solution to the poor processability of the weathered ore.

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Section: Processability Of the Microbial-treated Oil Sandsmentioning

confidence: 97%

Section: Processability Of the Microbial-treated Oil Sandsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Application of microbial enhanced oil recovery technology in water‐based bitumen extraction from weathered oil sands

et al. 2014

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“…There are two key technologies that have made production from unconventional resources practical-massive hydraulic fracturing and horizontal drilling (Economides and Nikolaou 2011;Yergin 2012). However, the economic development of unconventional gas resources entails substantial uncertainty and risk.…”

Section: Introductionmentioning

confidence: 99%

Analysis of Production History for Unconventional Gas Reservoirs With Statistical Methods

Bhattacharya

Nikolaou

2013

SPE Journal

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Unconventional gas resources have dramatically changed the future energy landscape. Developing these resources involves substantial risk. Such risk can be mitigated if information gathered at initial stages of the development of a field is used efficiently and effectively to guide future development. A variety of tools-such as decline-curve analysis (DCA), type-curve analysis, simulator history matching, and artificial intelligence (AI)-is used to that effect. These tools accomplish partially overlapping but different tasks. Additional tools that could not only facilitate the analysis of historical data but also guide future development would be of value. In this work, we propose an efficient methodology that can use historical production data from existing wells to answer questions such as the following: Which wells will behave similarly? Which wells will behave differently from each other or from standard expectations? Which factors will contribute to these differences? How can data from existing wells be used to anticipate the performance of new wells? The proposed methodology relies on standard principal-component analysis (PCA) and principal-component regression (PCR). The application of PCA to historical production data from twelve wells in the Holly Branch field quickly identified wells with distinct behavior. The subsequent investigation of pressure and the completion data for these wells revealed reasons for such distinct behavior. Finally, a simple linear model was built with PCR, with good ability to predict production from new wells, as assessed through cross-validation. The value of the efficiency offered by the proposed methodology would be much higher for larger data sets, for which manual analysis of production data is more cumbersome.

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“…In recent years, the energy technology has made remarkable progress on gas and oil productions as well as development of new concepts of energy generation and conversion (Utschig, Soltau, and Tiede 2015, Economides and Nikolaou 2011, Abutayeh et al 2014, Schmidt and Castellano 2014, Bowman et al 1992. However, to fulfill the current energy demand, fossil fuel is still the primary source of energy production.…”

Section: Introductionmentioning

confidence: 99%

The Effect of Pressure and TDS on Barite Scaling Kinetics

Bhandari

Kan

Zhang

et al. 2015

SPE International Symposium on Oilfield Chemistry

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Despite the significant progress made for the expansion of oil and gas productions from conventional to unconventional sources in the last several years, the steady growth of the hydrocarbon demand is driving the oil and gas industries to explore new or under-explored areas that are often challenging. Because of technological difficulties associated with extremely high temperature (Ͼ150°C), pressure (Ͼ10,000 psia), and TDS (Ͼ300,000 mg/L) at deep water production environments, prediction and control of mineral scaling pose significant challenges. Appropriate experimental data is needed for better understanding of scaling risk in those harsh environments, but current literature lacks the experimental findings that correlate the importance of pressure and temperature on the mineral scaling kinetics. This study attempts to bridge this knowledge gap by formulating the pressure dependence of barite formation kinetics at various temperatures (T) and saturation indices (SI).In order to study the effect of the pressure on the mineral scale formation kinetics, a high temperature high pressure (HTHP) flow loop apparatus was developed and experiments were carried out at various temperatures (70-175°C) and at a range of pressures (15-15,000 psia). Barite scale formation (precipitation) kinetics as a function of the pressure was investigated while maintaining constant pH, T, ionic strength, and SI. To determine the onset of scale formation (i.e. induction time), time dependent composition of reaction mixture containing Ba 2ϩ and SO 4 2 -species was analyzed using ICP-OES. In a separate but independent study, barite induction time at various ionic strengths at constant T, P, and SI was determined by laser light scattering method. This work will show that barite precipitation kinetic is a strong function of applied pressure at constant T, SI and TDS. Based on experimental results, the relationship between induction time for barite formation as a function of T, P and SI was established.

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Technologies for oil and gas production: Present and future

Cited by 15 publications

References 41 publications

Application of microbial enhanced oil recovery technology in water‐based bitumen extraction from weathered oil sands

Application of microbial enhanced oil recovery technology in water‐based bitumen extraction from weathered oil sands

Analysis of Production History for Unconventional Gas Reservoirs With Statistical Methods

The Effect of Pressure and TDS on Barite Scaling Kinetics

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