Production of hydrocarbons from weakly consolidated sandstone reservoirs in the Croatian part of the Pannonian Basin System

Ivšinović, Josip; Pleteš, Vjekoslav; Marinić, Marko

doi:10.15407/mining12.02.116

Cited by 5 publications

(3 citation statements)

References 6 publications

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“…The costs also include equipment maintenance. In case of the occurrence of sand during the production of hydrocarbons for the Klostar Ivanic Formation, according to [26,27], continuous production of hydrocarbons is ensured, and thus in the model the given production time. The observed period is 10 years, and desired response in recovered fluid has been set at 0.5%, 1% and 2%.…”

Section: Risk-neutral Value For Future Water Injectionmentioning

confidence: 99%

Increasing Efficiency of Field Water Re-Injection during Water-Flooding in Mature Hydrocarbon Reservoirs: A Case Study from the Sava Depression, Northern Croatia

Malvić

Ivšinović²,

Velić

et al. 2020

Sustainability

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The authors analyse the process of water re-injection in the hydrocarbon reservoirs/fields in the Upper Miocene sandstone reservoirs, located in the western part of the Sava Depression (Croatia). Namely, this is the “A” field with “L” reservoir that currently produces hydrocarbons using a secondary recovery method, i.e., water injection (in fact, re-injection of the field waters). Three regional reservoir variables were analysed: Porosity, permeability and injected water volumes. The quantity of data was small for porosity reservoir “L” and included 25 points; for permeability and injected volumes of water, 10 points each were measured. This study defined selection of mapping algorithms among methods designed for small datasets (fewer than 20 points). Namely, those are inverse distance weighting and nearest and natural neighbourhood. Results were tested using cross-validation and isoline shape recognition, and the inverse distance weighting method is described as the most appropriate approach for mapping permeability and injected volumes in reservoir “L”. Obtained maps made possible the application of the modified geological probability calculation as a tool for prediction of success for future injection (with probability of 0.56). Consequently, it was possible to plan future injection more efficiently, with smaller injected volumes and higher hydrocarbon recovery. Prevention of useless injection, decreasing number of injection wells, saving energy and funds invested in such processes lead to lower environmental impact during the hydrocarbon production.

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Section: Risk-neutral Value For Future Water Injectionmentioning

confidence: 99%

Increasing Efficiency of Field Water Re-Injection during Water-Flooding in Mature Hydrocarbon Reservoirs: A Case Study from the Sava Depression, Northern Croatia

Malvić

Ivšinović²,

Velić

et al. 2020

Sustainability

View full text Add to dashboard Cite

show abstract

“…The costs also included equipment maintaining. In case of occurrence of sand during the production of hydrocarbons for Klostar Ivanic Formation, according to [23,24], continuous production of hydrocarbons is ensured, and thus in the model the given production time. The observed period in 10 years and asked response in recovered fluid has been set at 0.5, 1 and 2 %.…”

Section: Risk Neutral Value For Future Water Injectionmentioning

confidence: 99%

Increasing Efficiency in the Field Water Re-injection during Mature Hydrocarbon Reservoirs Water-Flooding, Case Study from the Sava Depression, Northern Croatia

Malvić¹,

Ivšinović²,

Velić³

et al. 2019

Preprint

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Here is analysed the process of water re-injection in the two hydrocarbon reservoirs/fields in the Upper Miocene sandstone reservoirs, located in the western part of the Sava Depression (Croatia). Namely, those are the "A" field with "L" reservoir and the "B" field with "K" reservoir. Both currently produce hydrocarbons using a secondary recovery method, i.e. water injection (in fact re-injection of the field waters). Three regional reservoir variables had been analysed, namely porosity, permeability and injected water volumes. The number of data was small in all three cases. For porosity: reservoir “L” included 25 data, reservoir “K” 19 data; for permeability: reservoir “L” 10 data, reservoir “K” 18 data; for injected volumes of water: reservoir “L” 10 data; reservoir “K” 3 data. It defined selection of mapping algorithms mostly designed for small datasets (less than 20 points), i.e. Inverse Distance Weighting, Nearest and Natural Neighbourhood. Additionally, the Ordinary Kriging was used, but only with jack-knifed variograms, producing many “artificial points”. Results are extensively tested, using cross-validation and shape recognitions, and the Inverse Distance Weighting method is described as the most appropriate approach for mapping permeability and injected volumes in both reservoirs (“K” and “L”). The Kriging could be slightly outlined as the best approach for porosity. Obtained maps made possible application of the modified geological probability calculation as tools for prediction of successfulness of future injection (probability of 0.56). Consequently, results made possible to plan future injection more efficiently, with smaller injected volumes and same of higher hydrocarbon recovery. That could prevent useless injection, decrease number of injection wells, and save energy and funds invested in such processes.

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“…Most problems are being caused by sand infl ux into the well, which leads to equipment erosion, bottom-hole collapses and may result in well control incident. A lot of researches were made for accompanies of this problem -petrophysical, rheological and hydromechanical papers give wide performance about it (Hall, 1970;Naveed, 2009;Ivšinović, 2018;Vieira and Jureszik, 2019).…”

Section: Introductionmentioning

confidence: 99%

Sand management approach for a field with high viscosity oil

Grigorev¹,

Tananykhin²,

Poroshin³

2020

J Appl Eng Science

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Oil production from weakly consolidated sandstone wasn't needed for decades, but as the time goes on, traditional oil reserves deplete and possibility of these reserves being produced is growing up. In the case of high viscosity oil, located in such reservoir, problem gets even worse. Traditional sand control methods cause lower production rates, thus, making production not profi table enough. In the industry there was need for new approach and it appearedsand management. Sand management is a risky business, but it allows some reservoirs to be produced with good enough profi t. But with right amount of preparations risk can be minimized and production becomes more likely. One of the most promising instruments of sand management is chemical treatment with UTTA. It allows to sand particles and fi nes to be held in the reservoir so they won't cause so much erosion and won't plug pore throats and fi ltration channels.

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Production of hydrocarbons from weakly consolidated sandstone reservoirs in the Croatian part of the Pannonian Basin System

Cited by 5 publications

References 6 publications

Increasing Efficiency of Field Water Re-Injection during Water-Flooding in Mature Hydrocarbon Reservoirs: A Case Study from the Sava Depression, Northern Croatia

Increasing Efficiency of Field Water Re-Injection during Water-Flooding in Mature Hydrocarbon Reservoirs: A Case Study from the Sava Depression, Northern Croatia

Increasing Efficiency in the Field Water Re-injection during Mature Hydrocarbon Reservoirs Water-Flooding, Case Study from the Sava Depression, Northern Croatia

Sand management approach for a field with high viscosity oil

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