Inhibition effects of thermally degraded MEG on hydrate formation for gas systems

AlHarooni, Khalifa; Barifcani, Ahmed; Pack, David J.; Gubner, Rolf; Ghodkay, Varun

doi:10.1016/j.petrol.2015.10.001

Cited by 60 publications

(83 citation statements)

References 40 publications

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“…Based on the analysis of the repeatability of the generated experimental data, we estimate that the maximum experimental error is 1.92%, with a standard deviation (S) of S ϭ 0.54 (AlHarooni et al 2015). Based on the analysis of the repeatability of the generated experimental data, we estimate that the maximum experimental error is 1.92%, with a standard deviation (S) of S ϭ 0.54 (AlHarooni et al 2015).…”

Section: Resultsmentioning

confidence: 99%

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Evaluation of Different Hydrate Prediction Software and Impact of Different MEG Products on Gas Hydrate Formation and Inhibition

AlHarooni

Barifcani

Pack

et al. 2016

Day 3 Thu, March 24, 2016

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New hydrate profile correlations for methane gas hydrates were obtained computationally (using three different hydrate prediction software packages) and experimentally (with three different MEG products from different suppliers). Methane gas with pure distilled water was the benchmark case used for the software comparison at pressures of 50 to 300 bar. In order to compare the hydrate inhibition performance of the MEG products, aqueous 10 wt% MEG solutions were tested using the isobaric method at a pressure range of 50 to 200 bar.Furthermore, the kinetics of MEG hydrate inhibition were studied experimentally for methane gas using a stirred cryogenic sapphire cell. Hydrate formation start, hydrate dissociation initiation and hydrate dissociation end points were identified and analysed. The results were correlated with the hydrate formation start points predicted by three well known selected hydrate prediction software packages (which all use the Peng-Robinson equation of state). Moreover, the hydrate inhibition performance of the three MEG products was evaluated to determine the superior MEG product that provides the best hydrate inhibition performance.Our analysis shows that the hydrate formation points predicted computationally are not identical to the hydrate formation start points measured in this work. Software ЉAЉ and software ЉBЉ predicted results matching with the average curve of the experimental hydrate formation start and hydrate dissociation start points, and with a deviation value of 0.06°C for software ЉAЉ and a deviation value of 0.03°C for software ЉBЉ. However, software ЉCЉ predicted results almost identical with the experimental dissociation start points, and with an average deviation value of 0.54°C.The methane gas hydrate profiles for the three different MEG products (X-MEG, Y-MEG and Z-MEG) indicated that X-MEG was the most efficient inhibitor as it shifted the hydrate curve most to the left; X-MEG shifted the hydrate formation curve by an average temperature of 2.07°C when compared to the benchmark curve (100% water); while Z-MEG shifted the curve by an average temperature of 1.81°C and Y-MEG shifted the curve by an average temperature of 1.71°C.We conclude that not all software packages predict the same results although they are all based on the same equation of state. Furthermore not all MEG products supplied have the same hydrate inhibition efficiency. Importantly, choosing the best MEG supplier will reduce the OPEX by reducing the amount of MEG used, and it will accommodate more relaxed operating conditions of lower temperatures and higher pressures.

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Section: Resultsmentioning

confidence: 99%

“…The gas hydrate formation start point was measured based on visual observations, Fig. All procedures were previously described in detail by AlHarooni et al (2015). 2 (b).…”

Section: Otc-26768-msmentioning

confidence: 99%

Evaluation of Different Hydrate Prediction Software and Impact of Different MEG Products on Gas Hydrate Formation and Inhibition

AlHarooni

Barifcani

Pack

et al. 2016

Day 3 Thu, March 24, 2016

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“…In order to perform the optimization study, PIPESIM software was used. This software is capable of determing optimum prodcution scenarios during artifi cail lift activities (Sedarat et al 2014, Silva et al 2015, AlHarooni et al 2015. The required data such as production rate data, average reservoir pressure, bottom hole fl owing pressure, and well profi le data were used as input data.…”

Section: Simulation Studymentioning

confidence: 99%

A case study on simulation and optimization of artifi cial lift methods in one of the Iranian oil fi elds

Azdarpour¹,

Karaei²,

Dabiri³

2017

Biosci. Biotech. Res. Comm

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Oil production from reservoirs usually occurs by natural fl ow of the fl uid out of the formation. This oil recovery is called primary recovery, where the production is solely controlled by the natural energy of the formation. However, after some times of production reservoir pressure declines, which causes a decline in oil production rate. Thus, regaining the reservoir pressure to enhance oil production is of great importance. Gas lift as one of the best methods of oil recovery when reservoir pressure declines has been implemented for decades. The reservoir pressure of one of the oil fi elds in Iran has been dropped to a level where no natural fl uid fl ow occurs form the reservoir. Gas lift has been proposed to compensate the natural pressure of the reservoir and ease the petroleum production from the reservoir. PIPESIM software was used to study the effectiveness of the gas lift system. Different parameters including tubing diameter, injected gas rates, and injection depth and their effect on infl ow performance relationship (IPR) were investigated. The simulation results showed that natural energy of the reservoir is not suffi cient for producing oil. Thus, gas lift as of the best methods of increasing the production rate in this fi eld could be implemented successfully.

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“…MEG is one of the most favoured thermodynamic hydrate inhibitors used in hydrocarbon transportation pipelines and processing facilities due to its low volatility, low toxicity, low flammability, favourable thermodynamic behaviour, simple and proven technology requirements and high availability (Bikkina et al 2012, Haque 2012). Furthermore, the preference for using MEG over other traditional thermodynamic hydrate inhibitors such as methanol stems from several operational, environmental and safety issues imposed by the use of methanol and MEG's ability to be effectively recovered, regenerated and reused (AlHarooni et al 2015, Haghighi et al 2009). Due to the high cost of MEG and significant volumes required to provide effective hydrate control, following the hydrate inhibition process it is essential to separate MEG from the produced water so that it can be recycled and reused to minimize operating costs.…”

Section: Introductionmentioning

confidence: 99%

“…The operating conditions of a MEG recovery column can vary depending upon the operating envelope of the individual distillation unit (AlHarooni et al 2015). Some MEG recovery units operate at temperatures as low as 95°C (Diba, Guglielminetti, and Schiavo 2003), 140°C (Montazaud 2011) and up to temperatures of 160°C (Gonzalez, Alfonso, and Pellegrino 2000), with Psarrou et al (2011) recommending operation between 120°C to 160°C within the reboiler.…”

Section: Introductionmentioning

confidence: 99%

Recovery of mono-ethylene glycol by distillation and the impact of dissolved salts evaluated through simulation of field data

Zaboon

Soames

Ghodkay

et al. 2017

Journal of Natural Gas Science and Engineering

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This study was conducted to investigate the operation of a packed distillation column and analyse its performance during the separation of mono-ethylene glycol from water. The column was designed and constructed by the Curtin Corrosion Engineering Industry Centre (CCEIC) and operated in collaboration with a reputable oil company to generate experimental field data. A secondary investigation was then performed into the impacts of dissolved salts within the rich MEG feed upon the purity of the lean MEG product. It was observed through application of the FUG shortcut distillation design equations that six equilibrium stages were required to attain the experimental separations reported under continuous operation of the column. It was further determined that the packing utilised within the column had a Height Equivalent to a Theoretical Plate (HETP) of approximately 0.34 metres when no dissolved salts were present corresponding to an estimated packing height of approximately 1.7 metres. The impact of dissolved salts upon the performance of the column was evident through lower lean MEG purities observed during experimental operation of the column in comparison to salt free trials. The reduction in column performance was reaffirmed by Aspen HYSYS and Aspen Plus simulations of the field data, where salt trials resulted in lean MEG purities noticeably less than corresponding salt free experimental trials and simulated predictions. Overall, it was observed that the presence of dissolved salts during operation led to a reduction in MEG mass fraction of the final lean MEG product by on average 7.2%. The impact of dissolved salts on lean MEG purity was successfully predicted by Aspen Plus simulation with an average accuracy of 1.61% through the inclusion of monovalent salt cations using the ELECNRTL equation of state with modified binary parameters. The reduction in lean MEG purity was attributed to boiling point elevation of the MEG-Water solution and the impact of the dissolved salts on the systems vapour liquid equilibrium.

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Inhibition effects of thermally degraded MEG on hydrate formation for gas systems

Cited by 60 publications

References 40 publications

Evaluation of Different Hydrate Prediction Software and Impact of Different MEG Products on Gas Hydrate Formation and Inhibition

Evaluation of Different Hydrate Prediction Software and Impact of Different MEG Products on Gas Hydrate Formation and Inhibition

A case study on simulation and optimization of artifi cial lift methods in one of the Iranian oil fi elds

Recovery of mono-ethylene glycol by distillation and the impact of dissolved salts evaluated through simulation of field data

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