2024-03-28T19:31:27Z
https://hrcak.srce.hr/ojs/index.php/rgn/oai
oai:ojs.pkp.sfu.ca:article/3515
2016-12-17T20:57:59Z
rgn:PEE
nmb a2200000Iu 4500
"220116 2022 eng "
1849-0409
0353-4529
dc
Remediation of the Old Ecological Load in the Protected Area of the Morava River – Re-abandonment of the Oil and Gas Production Wells
Bujok, Petr
Faculty of Mining and Geology, VSB – Technical University of Ostrava; 17. listopadu 15, 708 00 Ostrava Poruba
Klempa, Martin
Faculty of Mining and Geology, VSB – Technical University of Ostrava; 17. listopadu 15, 708 00 Ostrava Poruba
Slivka, Vladimír
Faculty of Mining and Geology, VSB – Technical University of Ostrava; 17. listopadu 15, 708 00 Ostrava Poruba
Porzer, Michal
Faculty of Mining and Geology, VSB – Technical University of Ostrava; 17. listopadu 15, 708 00 Ostrava Poruba
Němec, Igor
Palivový kombinát Ústí, s.p.; Hrbovická 2, 403 39 Chlumec
Šťastná, Věra
Palivový kombinát Ústí, s.p.; Hrbovická 2, 403 39 Chlumec
Smejkalová, Eva
Faculty of Mining and Geology, VSB – Technical University of Ostrava; 17. listopadu 15, 708 00 Ostrava Poruba
Zdvořák, Jaroslav
Faculty of Civil Engineering, VSB – Technical University of Ostrava; 17. listopadu 15, 708 00 Ostrava Poruba
The presence of the former oil and gas producing wells that are or can be improperly abandoned creates a possible environmental hazard in terms of contamination of the groundwater and soil in the present. In the area of the Czech Republic, specifically in South Moravia part, which has a long oil and gas production history, plenty of such wells can be found. Finding out the information about their abandonment in archives is often very demanding (sometimes even impossible). During various survey works and re-abandonment attempts it was found out that many wells are originally abandoned improperly, insufficiently or not at all. The occurrence of such wells is not just potential but also very actual hazard for the cultural landscape of the South Moravia, especially for aquifers, agriculture and natural protected areas of national significance. This paper is focused on the possibility of the definitive abandonment of this particular ecological load. The proposed method was verified in laboratory conditions and in the field. It is now a standard form of the re abandonment of oil and gas wells without precise localization in the South Moravian oil fields.
Faculty of Mining, Geology and Petroleum Engineering
2015-06-03 00:00:00
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https://hrcak.srce.hr/ojs/index.php/rgn/article/view/3515
Rudarsko-geološko-naftni zbornik; Vol. 30 No. 1 (2015): No. 30
eng
Copyright (c) 2015 authors and journal
oai:ojs.pkp.sfu.ca:article/3602
2016-12-17T20:57:35Z
rgn:PEE
nmb a2200000Iu 4500
"150925 2015 eng "
1849-0409
0353-4529
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THE BASICS OF MODEL FOR MARGINAL TESTING OF COSTS FOR DISPOSAL OF EXTRACTED FORMATION WATER
Ivšinović, Josip
INA d.d., Zagreb
Dekanić, Igor
Rudarsko-geološko-naftni fakultet, Sveučilište u Zagrebu
Formation water is extracted throughout the life of the fields ofhydrocarbons together with oil and/or gas. Oil dehydration costs, as well asthose of production water reinjection represent significant component in totalcosts at mature oil and gas fields. The optimization of the aforesaid costs,from the point of technology and economics, can affect both profitability(cost-effectiveness) and development of the oil field in the future.Methodology of calculation of unit cost will be elaborated in this paper fortreatment of produced water (dehydration) and production water reinjection. Themethodology of calculation of unit cost for disposal of produced water will beapplied at production of mature oil and gas field. Unit cost for disposal ofproduced water for the period 2009 – 2014 will be calculated in the selectedexample. Making of this particular model of calculation of disposal costs ofproduced water is crucial for economy analyses of hydrocarbons exploitationfrom mature fields.
Faculty of Mining, Geology and Petroleum Engineering
2015-11-12 00:00:00
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https://hrcak.srce.hr/ojs/index.php/rgn/article/view/3602
Rudarsko-geološko-naftni zbornik; Vol. 30 No. 2 (2015): No. 31
eng
Copyright (c) 2015 authors and journal
oai:ojs.pkp.sfu.ca:article/4216
2016-12-18T17:39:19Z
rgn:PEE
nmb a2200000Iu 4500
"161217 2016 eng "
1849-0409
0353-4529
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The analysis of water injection systems in sandstone hydrocarbon reservoirs, case study from the western part of the Sava Depression
Ivšinović, Josip
INA d.d., Zagreb
Formation water injection is one of the constituent parts of the hydrocarbon production cycle in the secondary exploitation oil recovery phase. The formation water injection system can be divided the into single and central injection systems. The formation water injection costs have been described in this paper using the examples of fi eld A (central injection system) and fi eld B (single injection system). These are located in the western part of the Sava Depression. The reservoir rocks regarding the oil and gas fi elds A and B are fi ne to middle grained sands and quartz micaceous sandstones that belong to the geological age of Lower Pontian. The average porosity (intergranular) in fi eld A is 15–35% and in fi eld B it is 10-31%, depending on the depth and cementation percentage. Regarding the oil and gas fi elds described in this paper, a cost comparison has been made and an injection system sensitivity analysis as well as an analysis of possible injection systems’ costs for optimization and rationalization.
Faculty of Mining, Geology and Petroleum Engineering
2016-12-17 00:00:00
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https://hrcak.srce.hr/ojs/index.php/rgn/article/view/4216
Rudarsko-geološko-naftni zbornik; Vol. 32 No. 1 (2017): No. 35
eng
Copyright (c) 2016 Rudarsko-geološko-naftni zbornik
oai:ojs.pkp.sfu.ca:article/4425
2018-04-20T13:25:04Z
rgn:PEE
nmb a2200000Iu 4500
"161217 2016 eng "
1849-0409
0353-4529
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Types of fiscal regime in hydrocarbon exploration and production
Karasalihović Sedlar, Daria
University of Zagreb, Faculty of Mining Geology and Petroleum Engineering http://161.53.60.11 http://orcid.org/0000-0002-2763-2863
Barbir, Goran
Brkić, Vladislav
The choice of the right fi scal regime represents the main object of the energy policy concerning hydrocarbon exploration and production for the state government. For the operator and service companies it represents the terms and conditions for practical conducting of the process in whole. This paper analyse aspects of agreements used in the petroleum indus-try. Elements of agreement, regardless of regime, have been described together with their advantages and disadvantages. Due to the fact that the fi scal regime has to be chosen to attract companies willing to invest in exploration and produc-tion, it represents a relevant part of the business strategy and also a base for the decision making process during start up. It has to minimize the risk for the both parties involved and maximize the state’s share during the exploitation phase. For the companies, it has to be attractive enough to balance risks during the exploration phase with profi ts gained during the exploitation phase. The aim of this paper is to show the existing fi scal systems in the petroleum industry and to analyze the process for concluding a contract regarding the exploration and production of hydrocarbons. An overview of diff er-ent business practices in the oil and gas industry with a detailed breakdown of the contract terms between the parties involved have been described in the paper. The aim of this paper is to show the diff erent possibilities of fi nancial regimes which could help during the negotiation process for conducting hydrocarbon exploration and production for everyone involved.
Faculty of Mining, Geology and Petroleum Engineering
2016-12-17 00:00:00
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/4425
Rudarsko-geološko-naftni zbornik; Vol. 32 No. 1 (2017): No. 35
eng
Copyright (c) 2016 Rudarsko-geološko-naftni zbornik
oai:ojs.pkp.sfu.ca:article/4620
2017-02-26T11:27:12Z
rgn:PEE
nmb a2200000Iu 4500
"170226 2017 eng "
1849-0409
0353-4529
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Depleted hydrocarbon reservoirs and CO2 injection wells –CO2 leakage assessment
Gaurina-Međimurec, Nediljka
Faculty of Mining, Geology and Petroleum Engineering, Pierottijeva 6, Zagreb, Croatia,
Full Professor
Novak Mavar, Karolina
INA-Industry of Oil Plc., Lovinčićeva 4, Zagreb, Croatia; SD & HSE Expert, Dsc.
Migration risk assessment of the injected CO2 is one of the fi rst and indispensable steps in determining locations for the implementation of projects for carbon dioxide permanent disposal in depleted hydrocarbon reservoirs. Within the phase of potential storage characterization and assessment, it is necessary to conduct a quantitative risk assessment, based on dynamic reservoir models that predict the behaviour of the injected CO2, which requires good knowledge of the reservoir conditions. A preliminary risk assessment proposed in this paper can be used to identify risks of CO2 leakage from the injection zone and through wells by quantifying hazard probability (likelihood) and severity, in order to establish a risk-mitigation plan and to engage prevention programs. Here, the proposed risk assessment for the injection well is based on a quantitative risk matrix. The proposed assessment for the injection zone is based on methodology used to determine a reservoir probability in exploration and development of oil and gas (Probability of Success, abbr. POS), and modifi ed by taking into account hazards that may lead to CO2 leakage through the cap rock in the atmosphere or groundwater. Such an assessment can eliminate locations that do not meet the basic criteria in regard to short-term and long-term safety and the integrity of the site.
Faculty of Mining, Geology and Petroleum Engineering
2017-02-26 12:13:03
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/4620
Rudarsko-geološko-naftni zbornik; Vol. 32 No. 2 (2017): No. 36
eng
Copyright (c) 2017 Rudarsko-geološko-naftni zbornik
oai:ojs.pkp.sfu.ca:article/4936
2017-10-06T17:55:18Z
rgn:PEE
nmb a2200000Iu 4500
"170621 2017 eng "
1849-0409
0353-4529
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Experimental calibration of underground heat transfer models under a winery building in a rural area
Tinti, Francesco
University of Bologna - Department of Civil, Chemical, Environmental and Materials Engineering http://orcid.org/0000-0002-6750-9368
Barbaresi, Alberto
University of Bologna - Department of Agricultural Sciences
Ferrari, Marco
University of Bologna - Department of Civil, Chemical, Materials and Environmental Engineering
Torreggiani, Daniele
University of Bologna - Department of Agricultural Sciences
Tassinari, Patrizia
University of Bologna - Department of Agricultural Sciences
Elkarmoty, Mohamed
University of Bologna - Department of Civil, Chemical, Materials and Environmental Engineering
Bonduà, Stefano
University of Bologna - Department of Civil, Chemical, Materials and Environmental Engineering
Ground temperature and hydrogeological conditions are key parameters for many engineering applications, such as the design of building basements and underground spaces and the assessment of shallow geothermal energy potential.
Especially in urban areas, in the very shallow depths, it is diffi cult to fi nd natural undisturbed underground thermal conditions because of anthropic interventions. The assessment of underground behaviour in disturbed conditions will become more and more relevant because of increasing awareness to energy effi ciency and renewable energy topics. The purpose of this paper is to show a three-dimensional representation - based on models calibrated on experimental data - of the underground thermal behaviour aff ected by a building in a rural area in Italy. Temperature varies in space and time and it depends on ground, climate and building characteristics, and all these parameters are taken into account by the seasonal periodic modelling implemented. The results obtained in a context of low urbanization indirectly suggest the importance of these eff ects in dense urban areas; taking greater account of these aspects could lead to improvements in the design of underground spaces and geo-exchanger fi elds for geothermal energy exploitation.
Faculty of Mining, Geology and Petroleum Engineering
2017-06-21 00:00:00
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/4936
Rudarsko-geološko-naftni zbornik; Vol. 32 No. 3 (2017): No. 37
eng
Copyright (c) 2017 Rudarsko-geološko-naftni zbornik
oai:ojs.pkp.sfu.ca:article/4950
2017-10-06T17:55:18Z
rgn:PEE
nmb a2200000Iu 4500
"170621 2017 eng "
1849-0409
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Development of Tight Oil Resources in USA: Profitability of Exploitation and Effect of Macroeconomic Indicators in Volatile Oil Price Environment
Strpić, Kristina
Faculty of mining-geology and petroleum engineering student
Miličević, Monika
Faculty of mining-geology and petroleum engineering student
Kurevija, Tomislav
Faculty of mining-geology and petroleum engineering
Associate Professor
Large scale development of tight oil resources in US started after 2010. with following five-year period of favorable steady increase in crude oil price. During this relatively short expansion cycle, operating and capital expenses changed drastically for main tight oil plays due to technological improvements in both well drilling and completion, expansion of service sector as well as loose government monetary policy which allowed favorable financing. This paper analyzed trends in costs during expansion period, as well as correlation of oil price to number of operating rigs and production quotas. After 2008/2009. world financial crisis economy recovery in US was somewhat sluggish and it caused extreme volatile environment in both equity and commodity markets. In such volatile environment intra-day crude oil prices, as well as other commodities and equities, show significant reaction to monthly published macroeconomic indicator reports, which give better overviews of trends in economic recovery. Prior to announcement, these reports always have forecasted value determined by consensus among market analysts. Therefore, any positive or negative surprise in real value tends to influence price of oil. This paper investigated influence of such macroeconomic reports to closing intraday oil price, as well as effect of other important daily market indices. Analysis showed that only Producer Price Index (PPI), among other indicators, has statistical significance of affecting intraday closing oil price.
Faculty of Mining, Geology and Petroleum Engineering
2017-06-21 00:00:00
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/4950
Rudarsko-geološko-naftni zbornik; Vol. 32 No. 3 (2017): No. 37
eng
Copyright (c) 2017 Rudarsko-geološko-naftni zbornik
oai:ojs.pkp.sfu.ca:article/5011
2017-10-11T17:41:27Z
rgn:PEE
nmb a2200000Iu 4500
"171010 2017 eng "
1849-0409
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Oil and Gas Futures and Options Market
Nosić, Ante
INA Industrija nafte d.d.
V. Holjevca 10, Zagreb, 10000
Karasalihović Sedlar, Daria
University of Zagreb, Faculty of Mining, Geology and Petroleum Engineering, Pierottijeva 6, 10 000 Zagreb http://161.53.60.11 http://orcid.org/0000-0002-2763-2863
Jukić, Lucija
University of Zagreb, Faculty of Mining, Geology and Petroleum Engineering, Pierottijeva 6, 10 000 Zagreb
Energy mineral resources markets are represented by complex supply and demand ratios which are depending on different factors such as technical (transport) and geopolitical. The main specific of energy markets is represented by an uneven geographic distribution of hydrocarbon reserves and exploration on one hand and energy consumption on the other. World oil markets, although geographically localized, because of specific market trade, represent unique global market with decreasing price difference. Price differences are result of development of a transport possibilities of oil supply. Development of transport routes of natural gas and increasing number of liquefied natural gas terminals in the world give pressure to natural gas market and its integration into global gas market. Integration of regional gas markets into a common European gas market is main energy policy of EU concerning natural gas. On the other hand, there are still significant price differences on some markets (e.g. United States of America - South East Asia). Development of global energy markets is enabled by development of a futures and options contracts of an energy trade which have replaced bilateral contract deals between producers and consumers. Futures contracts are standardized contracts traded on exchanges. Buyer agrees to buy certain quantity of stock for an agreed upon price and with some future delivery date. Option is a contract which gives a buyer the option of the right to buy (or sell, depending on the option) an asset at predetermined price and at a later date. Stocks price risk can be managed with the purchase and selling futures and options contracts. This paper deals with futures and options energy markets and their market strategies.
Faculty of Mining, Geology and Petroleum Engineering
2017-10-10 00:00:00
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/5011
Rudarsko-geološko-naftni zbornik; Vol. 32 No. 4 (2017): No. 38
eng
Copyright (c) 2017 Rudarsko-geološko-naftni zbornik
oai:ojs.pkp.sfu.ca:article/5440
2017-12-18T16:21:56Z
rgn:PEE
nmb a2200000Iu 4500
"171216 2017 eng "
1849-0409
0353-4529
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The Cost Analysis of the Separation of Produced Formation Water from the Hydrocarbon Reservoir Using the Example of the Upper Miocene Sandstone Deposits of the Sava Depression
Ivšinović, Josip
INA d.d., Zagreb
Formation water is gathered during the working life of the hydrocarbon reservoir alongside the oil and/or gas and it mostly constitutes the recovery's dominant fluid. The produced formation water is separated during the process of dehydration. This thesis deals with the formation water separation costs regarding the fields A, B and C which are located in the western part of the Sava Depression. The dehydration process regarding the field A is executed in three locations, and regarding the fields B and C it is executed in one location. The technological system of formation water separation and the geological characteristics of the above mentioned reservoirs is represented. A statistical analysis regarding the formation water separation costs has been made, the costs have been statistically estimated and a correlation between the costs relevant for the usual formation water separation process has also been made.
Faculty of Mining, Geology and Petroleum Engineering
2017-12-16 19:38:17
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/5440
Rudarsko-geološko-naftni zbornik; Vol. 33 No. 1 (2018): No. 39
eng
Copyright (c) 2017 Rudarsko-geološko-naftni zbornik
oai:ojs.pkp.sfu.ca:article/5491
2018-04-03T18:47:39Z
rgn:PEE
nmb a2200000Iu 4500
"180223 2018 eng "
1849-0409
0353-4529
dc
CCS technology: overview of projects, technology and monitoring
Gaurina-Međimurec, Nediljka
Novak Mavar, Karolina
Majić, Matej
Carbon capture and storage (CCS) in terms of geological sequestration presents the process of capturing CO2 from large point sources, transporting it to a storage site, and depositing it into an underground geological formation.
In addition to ecological benefits, underground injection of CO2 shows certain potential risks associated with unwanted migration of CO2 to groundwater and surface, so the possibility of carrying out such projects depends on the possibility of reducing mentioned risks to an acceptable level. For this purpose, a detailed risk assessment and analysis must be carried out, serving as the basis for a monitoring plan. Well designed and implemented monitoring plan and program provide important data on site integrity, well injectivity, and entire storage complex performance.
This paper gives the overview of large scale and pilot projects of CO2 capture and geological storage in operation, under construction and in the phase of development all over the world, technology basics and available monitoring techniques. An example of CCS project monitoring is given through the monitoring program of the Lacq pilot project in France
Faculty of Mining, Geology and Petroleum Engineering
2018-02-23 00:00:00
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/5491
Rudarsko-geološko-naftni zbornik; Vol. 33 No. 2 (2018): No. 40
eng
Copyright (c) 2018 Rudarsko-geološko-naftni zbornik
oai:ojs.pkp.sfu.ca:article/5651
2018-04-03T18:47:39Z
rgn:PEE
nmb a2200000Iu 4500
"180223 2018 eng "
1849-0409
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Slim-tube simulation model for CO2 injection EOR
Vulin, Domagoj
Faculty of Mining, Geology and Petroleum Engineering
Gaćina, Marko
Ina d.d. http://orcid.org/0000-0001-5556-9016
Biličić, Valentina
MET Croatia energy trade d.o.o.
A simulation model of the slim-tube test has been developed to validate the laboratory experiment and used EOS as well as to investigate the possibility of serving as a fast and reliable tool for MMP determination. Sensitivity analyses were performed by testing different grid block sizes (different number of cells), changing Corey’s coefficients for relative permeability curves, varying flow rates and PVT models. Minimum miscibility pressure from the simulation model is estimated as the intersection of the two different trend line curves of oil recoveries versus the injected volume of CO2. The oil recoveries were underestimated by numerical simulation on a basic case model. This is related to the usage of single “X shaped” relative permeability curves in all simulation cases, i.e. for immiscible, near miscible and miscible conditions. In addition, by fine tuning binary interaction parameters in equation of state model and introducing different relative permeability curves for immiscible and near miscible cases, better matching of slim-tube simulation can be achieved.
Faculty of Mining, Geology and Petroleum Engineering
2018-02-23 00:00:00
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/5651
Rudarsko-geološko-naftni zbornik; Vol. 33 No. 2 (2018): No. 40
eng
Copyright (c) 2018 Rudarsko-geološko-naftni zbornik
oai:ojs.pkp.sfu.ca:article/5704
2018-04-03T18:47:39Z
rgn:PEE
nmb a2200000Iu 4500
"180223 2018 eng "
1849-0409
0353-4529
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Steady-state heat rejection rates for a coaxial borehole heat exchanger during passive and active cooling determined with the novel step thermal response test method
Kurevija, Tomislav
Faculty of mining-geology and petroleum engineering http://orcid.org/0000-0002-5469-3653
Macenić, Marija
Faculty of mining-geology and petroleum engineering
Strpić, Kristina
Faculty of mining-geology and petroleum engineering
At three locations in Zagreb, classical and extended thermal response test (TRT) was conducted on installed coaxial heat exchangers. With classic TR test, thermogeological properties of the ground and thermal resistance of the borehole were determined at each location. It is seen that thermal conductivity of the ground varies, due to difference in geological profile of the sites. In addition, experimental research of steady-state thermal response step test (SSTRST) was carried out to determine heat rejection rates for passive and active cooling in steady state regime. Results showed that heat rejection rate is only between 8-11 W/m, which indicates that coaxial system is not suitable for passive cooling demands. Furthermore, the heat pump in passive cooling mode uses additional plate heat exchanger where there is additional temperature drop of working fluid by approximately 1,5 °C. Therefore, steady-state rejection rate for passive cooling is even lower for a real case project. Coaxial heat exchanger should be always designed for an active cooling regime with an operation of a heat pump compressor in a classical vapour compression refrigeration cycle.
Faculty of Mining, Geology and Petroleum Engineering
2018-02-23 00:00:00
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/5704
Rudarsko-geološko-naftni zbornik; Vol. 33 No. 2 (2018): No. 40
eng
Copyright (c) 2018 Rudarsko-geološko-naftni zbornik
oai:ojs.pkp.sfu.ca:article/6433
2018-05-29T21:00:02Z
rgn:PEE
nmb a2200000Iu 4500
"180601 2018 eng "
1849-0409
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Pressure build-up test analysis of the reservoir system with the multiphase flow
Koščak Kolin, Sonja
University of Zagreb, Faculty of Mining, Geology and Petroleum Engineering http://orcid.org/0000-0003-0056-4466
Kurevija, Tomislav
University of Zagreb, Faculty of Mining, Geology and Petroleum Engineering http://orcid.org/0000-0002-5469-3653
Grebenar, Dominik
Faculty of Mining, Geology and Petroleum Engineering
The present work focuses on the determination of absolute permeability in an oil reservoir whose pressure is under the bubble point. The simulation of the reservoir and well with the simultaneous flow of oil and gas is performed using the Eclipse100 software. The main purpose of the simulation is to obtain pressure build-up tests for two reservoir systems, as the well testing technology requires the shut-in period, which increases the costs of the real well production cycle. In the first simulation it is presumed that the well is not damaged, having the skin effect equal to zero, while in the second one, the skin effect of the well in the same reservoir is 9,44. The aim is to compare the results of the pressure build-up test analysis for both cases. In each case, permeability is firstly calculated using four methods, given by different authors. The theoretical background and the process of obtaining the required results are given for each approach. Results are compared with the permeability as determined by the pressure transient analysis, using the Saphir software, for both the ideal and the damaged well. Differences in results are presented and discussed. Conclusions can be applied to real reservoir systems with the multiphase fluid flow in the porous media.
Faculty of Mining, Geology and Petroleum Engineering
2018-05-29 00:00:00
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/6433
Rudarsko-geološko-naftni zbornik; Vol. 33 No. 3 (2018): No. 41
eng
Copyright (c) 2018 Rudarsko-geološko-naftni zbornik
oai:ojs.pkp.sfu.ca:article/6516
2018-09-07T14:49:03Z
rgn:PEE
nmb a2200000Iu 4500
"180706 2018 eng "
1849-0409
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Contribution to the methodology of determining the optimum mud density - a case study from the offshore gas condensate field D in the Persian Gulf
Zadravec, Damir
Krištafor, Zdenko
University of Zagreb
Faculty of Minig, Geology and PEtroleum Engineering
Drilling the wells using water based mud through shale formations, causes their exposure to serious time-dependent wellbore instability due to shale swelling. Operating companies, before drilling operations through demanding shale formations, usually conduct drilling fluid optimization studies in order to define the proper mud type, mud density, salt type and concentration for inhibition. Through the analysis of offset wells, they are interpreting data about mud filtrate breakouts into the rock formations and chemical potential mechanisms to understand their influence on the time-de- pendent wellbore instability. The main objective of this paper is to give an insight in time-dependent and mechanical wellbore instability problems faced while drilling the wells through different shale formations in the gas condensate field D in the Persian Gulf. The importance of drilling fluid design optimization and solutions applied to overcome hole in- stability problems were analysed and highlighted. Besides the development of a model for mud density calculations, a concept of effective hoop stress and its influence on time dependent failure mechanisms is discussed. As a contribution to the method improvement, mud density calculation is verified by taking into the consideration the relationship be- tween pore pressure and effective hoop stress and it is based on measured data from Well A in gas condensate field D from the Persian Gulf.
Faculty of Mining, Geology and Petroleum Engineering
2018-09-07 16:49:03
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/6516
Rudarsko-geološko-naftni zbornik; Vol. 33 No. 4 (2018): No. 42
eng
Copyright (c) 2018 Rudarsko-geološko-naftni zbornik
oai:ojs.pkp.sfu.ca:article/7417
2019-01-18T13:12:46Z
rgn:PEE
nmb a2200000Iu 4500
"181113 2018 eng "
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Simulation of CO2 injection in a depleted gas reservoir: A case study for Upper Miocene sandstone, Northern Croatia
Lekić, Amalia
Jukić, Lucija
University of Zagreb
Arnaut, Maja
Macenić, Marija
Carbon capture and storage (CCS) technology is a beneficial greenhouse gas mitigating strategy carried out in the last 20 years. Depleted gas reservoirs are promising candidates for the storage of carbon dioxide (CO2). Therefore, a depleted gas reservoir in the Upper Miocene sandstone located in Northern Croatia was taken as an example. The purpose of this study was to compare CO2 storage capacity obtained with two analytical equations to total storage capacity obtained through the simulator, in order to validate the equations. The first equation takes the average reservoir pressure and available production data into account, while the other one is more general and includes produced volume, CO2 density and formation volume factor of the original fluid. The tools used for these calculations were Schlumberger PVTi software, in which the equation of state was obtained, and ECLIPSE (E300 Module) which is a reservoir engineering simula- tor used for reservoir behaviour prediction. The results confirmed analytical solutions, indicating that, depending on the depth, the mass of the CO2 that can be injected is twice as big as the mass of CH4 produced. The results of analytical solutions, 16.7 × 10**6 m**3 and 14.6 × 10**6 m**3, are in accordance with the results obtained by the simulation of CO2 injection in depleted reservoirs - 16.2 × 10**6 m**3. Based on this, a conclusion is derived that these analytical solutions can be used as a first approximation of injection in a depleted gas reservoir.
Faculty of Mining, Geology and Petroleum Engineering
2019-01-18 00:00:00
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/7417
Rudarsko-geološko-naftni zbornik; Vol. 34 No. 1 (2019): No. 44
eng
Copyright (c) 2018 authors and journal
oai:ojs.pkp.sfu.ca:article/8117
2019-07-04T16:48:02Z
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"190318 2019 eng "
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Application of machine learning models in predicting initial gas production rate from tight gas reservoirs
Ikpeka, Princewill Maduabuchi
Federal University of Technology Owerri
Amaechi, Ugwumba Chrisangelo
Oil and Gas Field Development Engineering, Xi’An Shiyou University
Xianlin, Ma
Oil and Gas Field Development Engineering, Xi’An Shiyou University
Ugwu, Johnson Obunwa
School of Science, Engineering and Design, Teesside University, United Kingdom
Driven by advancements in technology, tight-gas field development has become a significant source of hydrocarbon to the energy industry. The amount of data generated in the process is immense as most platforms are now being digitized. Machine learning tools can be used to analyse this data in order to build patterns between several dependent and independent variables. Forecasting initial gas production rates has important implications in the planning production/processing facilities for new wells, affects investment decisions and is an important component of reporting to regulatory agencies. This study is based on the analysis of reservoir rock/fluid properties and selected well parameters to build decision-based models that can predict initial gas production rates for tight gas formations. In this study, two machine learning predictive models; Artificial Neural Network (ANN) and Generalized Linear Model (GLM), were used to determine the expected recovery rate of planned new wells. Production data was retrieved from 224 wells and used in developing the model. The results obtained from these models were then compared to the actual recorded initial gas production rate from the wells. Results from the analysis carried out revealed a Mean Square Error (MSE) of 1.57 on a GLM model whereas the ANN model gave an MSE of 1.24. Key Performance Index for the ANN model revealed that reservoir thicknesshad the highest (36.5%) contribution to the initial gas production rate followed by the flowbackrate (29%). The reservoir/fluid properties contribution to the initial gas production rate was 53% while the hydraulic fracture parameters contribution to the initial gas production rate was 47%.
Faculty of Mining, Geology and Petroleum Engineering
2019-07-04 18:48:02
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https://hrcak.srce.hr/ojs/index.php/rgn/article/view/8117
Rudarsko-geološko-naftni zbornik; Vol. 34 No. 3 (2019): No. 46
eng
Copyright (c) 2019 authors and journal
oai:ojs.pkp.sfu.ca:article/9522
2019-11-14T10:57:06Z
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"191014 2019 eng "
1849-0409
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The influence of TiO2 and SiO2 nanoparticles on filtration properties of drilling muds
Mijić, Petar
University of Zagreb, Faculty of Mining, Geology and Petroleum Engineering https://orcid.org/0000-0003-3690-5787
Gaurina-Međimurec, Nediljka
University of Zagreb, Faculty of Mining, Geology and Petroleum Engineering https://orcid.org/0000-0003-2922-4780
Pašić, Borivoje
University of Zagreb, Faculty of Mining, Geology and Petroleum Engineering https://orcid.org/0000-0003-1919-1129
Medved, Igor
University of Zagreb, Faculty of Mining, Geology and Petroleum Engineering https://orcid.org/0000-0002-8738-6983
During the drilling of a well, differential pressure causes filtration of the mud liquid phase into the surrounding rocks. To reduce the filtrate invasion in the rock, it is necessary to maintain the density of the mud. Also, Wellbore Strengthen- ing Materials (WSM) can be preventively added to the mud to increase the fracture initiation pressure of the drilled formation. The solid particles from the mud create a mud cake on the wellbore wall, which, for conventional drilling, implies the use of bentonite and barite whose particle dimensions range from 0.1 to 100 μm. While drilling shales, rocks which contain pores that have an average pore size of 10 to 30 nm, it is not possible to create a high-quality mud cake, so water passes into the shale and creates wellbore instability problems. To stabilize the shale, the petroleum industry uses oil-based muds, but due to their environmental impact, it is not always possible to implement them. Nanoparticles, because of their small dimensions, can enter into the nanopores and fill this space and strengthen the rock, resulting in decreased filtration. In this paper, a review of previous laboratory research of adding nanoparticles on filtration is shown. Also, the impact of adding nanoparticles on API and HTHP filtration is examined by adding TiO2 and SiO2 nanoparticles in concentrations of 0.5 wt% and 1 wt% to the five water-based muds. The best result was obtained with TiO2 nanoparti- cles at a concentration of 0.5 wt%.
Faculty of Mining, Geology and Petroleum Engineering
2019-11-11 00:00:00
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https://hrcak.srce.hr/ojs/index.php/rgn/article/view/9522
Rudarsko-geološko-naftni zbornik; Vol. 34 No. 4 (2019): No. 47
eng
Copyright (c) 2019 authors and journal
oai:ojs.pkp.sfu.ca:article/10631
2020-07-21T11:01:07Z
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"200603 2020 eng "
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Toe-to-Heel Air Injection In-situ Combustion Process: Case study from the Azraq Basin, Jordan
Mahasneh, Mehaysen
Al-Balqa Applied University Al Huson University College https://orcid.org/0000-0003-1638-0872
The exploration and drilling operations for oil in the Wadi Rajil region of the Azraq Basin in northeast Jordan confirmed the existence of quantities of asphalt and heavy oil in several formations of limestone and dolomite within layers of sandstone. The estimated area was 1200 km2 (120000 hectare) and possibly contained 800 million m3 (five billion barrels) of original oil. The aim of this study is to obtain in-situ combustion and to suggest the application of the drilling of two wells by an in-situ combustion process called Toe-to-Heel Air Injection In-situ Combustion in the Wadi Rajil-Hamzeh field. This approach proposes a pilot project of drilling two wells. One vertical injection well in the upper production zone and another horizontal production well at the bottom of the reservoir. Through this technique, the productivity will increase, the viscosity of the oil will decrease, and consequently the sweep efficiency will be higher. This pilot project’s potential production reaches 212.94 m3/d of oil. The total time for the project to be completed is around 450 days. The efficiency of recovery in this study reached around 65 to 69%. This result can lead to the possible expansion of the approach applied in this project throughout the Wadi Rajil-Hamzeh region.
Faculty of Mining, Geology and Petroleum Engineering
2020-07-21 13:01:07
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https://hrcak.srce.hr/ojs/index.php/rgn/article/view/10631
Rudarsko-geološko-naftni zbornik; Vol. 35 No. 3 (2020): No. 50
eng
Copyright (c) 2020 authors and journal
oai:ojs.pkp.sfu.ca:article/11326
2020-11-09T14:14:30Z
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"200818 2020 eng "
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Intelligent natural dump flooding well - Case study from the area of the western Persian/Arabian Gulf and possible application in the Croatian mature oil field Beničanci
Zadravec, Damir
Fika Eco d.o.o., A.G. Matoša 1, 10310 Ivanić Grad, Croatia https://orcid.org/0000-0001-9039-9868
Brkić, Vladislav
https://orcid.org/0000-0003-2075-1832
In the process of oil reservoir waterflooding, natural water dump flood technology for reservoir pressure decline prevention is considered as an unconventional but technically less demanding, more economical and safer method in comparison to surface power water injection. With natural dump flood technology, a single well serves as a water producer from a water bearing layer (aquifer) and simultaneously through gravity and the pressure difference between the aquifer and the depleted oil reservoir, it serves as a water injector inside the oil reservoir without expensive and complex injecting water treatment facilities at the surface. With the use of such technology and the running of intelligent well completion, it allows for the permanent monitoring of water production, injection rates and temperature inside the chosen reservoir. In addition, in offshore operations, the use of a subsea wellhead with a mud line suspension system allows for the placing of the injector well at the best predetermined position for water injection in a targeting reservoir and, together with an efficient subsurface acoustic data acquisition system, leads to better reservoir management and well integrity improvement. The overview and critical reflection of the drilling and intelligent completion of a natural dump flooding well for reservoir pressure support in partially depleted oil reservoirs in the Persian/Arabian Gulf has been given, referring to both their preparation and execution phase. The possibility of applying natural water dump flood was also considered in the Croatian onshore Beničanci oil field through a pilot project of water injection into the Be-62 well.
Faculty of Mining, Geology and Petroleum Engineering
2020-11-09 15:14:30
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https://hrcak.srce.hr/ojs/index.php/rgn/article/view/11326
Rudarsko-geološko-naftni zbornik; Vol. 35 No. 4 (2020): No. 51
eng
Copyright (c) 2020 authors and journal
oai:ojs.pkp.sfu.ca:article/11421
2020-11-09T14:14:30Z
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"200831 2020 eng "
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Croatian natural gas balancing market analysis
Kevo, Dominik
INA-Industrija nafte, d.d., Av. V. Holjevca 10, 10000 Zagreb https://orcid.org/0000-0001-5567-2734
Smajla, Ivan
University of Zagreb, Faculty of Mining, Geology and Petroleum Engineering https://orcid.org/0000-0002-1009-6726
Karasalihović Sedlar, Daria
University of Zagreb, Faculty of Mining, Geology and Petroleum Engineering, Pierottijeva 6, 10000 Zagreb https://orcid.org/0000-0002-2763-2863
Božić, Filip
https://orcid.org/0000-0002-9706-200X
The Network Code on Gas Balancing of Transmission Networks stimulates the development of the wholesale gas market by encouraging balance responsible parties to use standardized balancing mechanisms. To balance their portfolios, balance responsible parties can use renominations of quantities at entry and exit points, trade on a virtual trading point or trade on a trading platform. In the event of a system imbalance, Plinacro, as the operator of the gas transmission system in the Republic of Croatia, activates the balancing energy to return the system within acceptable limits. In accordance with the Rules on the Organization of the Gas Market, the Croatian Energy Market Operator performs a monthly calculation of the daily imbalance charge, trades conducted on the trading platform for balancing activities, a neutrality charge and a charge for deviation from the nominated quantities which have been analysed in this paper based on the case study of a chosen balancing group. The analyses conducted in the paper have shown that the balance responsible party may be entitled to compensation or be liable to pay compensation based on the monthly calculation of the Croatian Energy Market Operator, HROTE, depending on the value of each charge. Plinacro as the forecasting party is preparing a new model for the allocation of gas quantities that will affect the operations of gas suppliers, DSOs and especially BRPs. Based on this analysis, it could be concluded that more accurate estimated consumption for a balancing group leads to cost optimization and a more transparent gas market.
Faculty of Mining, Geology and Petroleum Engineering
2020-11-09 15:14:30
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https://hrcak.srce.hr/ojs/index.php/rgn/article/view/11421
Rudarsko-geološko-naftni zbornik; Vol. 35 No. 4 (2020): No. 51
eng
Copyright (c) 2020 authors and journal
oai:ojs.pkp.sfu.ca:article/11515
2020-11-09T14:14:30Z
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"200917 2020 eng "
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Potential of Croatian liquefied natural gas (LNG) terminal in supplying regional natural gas markets
Smajla, Ivan
University of Zagreb, Faculty of Mining, Geology and Petroleum Engineering https://orcid.org/0000-0002-1009-6726
Crneković, Romana
Čulinečka cesta 31, 10040 Zagreb https://orcid.org/0000-0001-7807-0912
Karasalihović Sedlar, Daria
University of Zagreb, Faculty of Mining, Geology and Petroleum Engineering, Pierottijeva 6, 10000 Zagreb https://orcid.org/0000-0002-2763-2863
Božić, Filip
Bernarda Vukasa 7, 10000 Zagreb https://orcid.org/0000-0002-9706-200X
This paper analyzes the possible role of liquefied natural gas (LNG) in the region in reducing carbon dioxide (CO2) emissions by replacing a certain part of solid fossil fuels. Increasing natural gas consumption, declining North Sea natural gas reserves and increased natural gas production costs in Europe combined have created new opportunities for LNG in Europe. The Energy Strategy of Croatia is focused on intensifying the transit position for natural gas that could establish Croatia as a primary LNG market for countries from the region, which shows that the Energy Strategy supports LNG. Concerning LNG’s introduction into the regional gas market, this paper analyses the possibility of establishing a regional gas hub. The region in this paper includes the following countries: Croatia, Serbia, Bosnia and Herzegovina, Hungary, Slovenia, and North Macedonia. On the other hand, the observed markets are not organized and sufficiently liquid, which is a crucial precondition for hub establishment. In order to decrease the region’s dependence on pipeline natural gas, it is necessary to construct gas interconnections between Croatia – Serbia, Croatia – Bosnia and Herzegovina and Serbia – North Macedonia. With the mentioned interconnections, the region could achieve greater security of natural gas supply. This paper discusses the possibility of utilizing the full capacity of a LNG terminal as a source of natural gas supply for the purpose of replacing solid fossil fuels in the region’s primary energy consumption. By replacing solid fossil fuels with natural gas, it is possible to achieve significant savings on CO2 emissions, which contributes towards a green and sustainable future.
Faculty of Mining, Geology and Petroleum Engineering
2020-11-09 15:14:30
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https://hrcak.srce.hr/ojs/index.php/rgn/article/view/11515
Rudarsko-geološko-naftni zbornik; Vol. 35 No. 4 (2020): No. 51
eng
Copyright (c) 2020 authors and journal
oai:ojs.pkp.sfu.ca:article/12357
2021-01-22T17:21:12Z
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"210122 2021 eng "
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Hydraulic fracturing design improvements by proppant flowback mitigation method application during hydrocarbon production
Jatykov, Temirlan
Kazakh-British Technical University https://orcid.org/0000-0002-2309-464X
Sagindykov, Bimurat
Satbayev University https://orcid.org/0000-0002-5349-1961 https://orcid.org/0000-0002-5349-1961
Bimuratkyzy, Kuralay
Expert Team LLP https://orcid.org/0000-0002-8541-8945
Proppant flowback after hydraulic fracturing treatment is quite a serious challenge that causes damage to both downhole and surface equipment, leading to unwanted workovers and production suspension, or other negative outcomes. Some special methods including preventive as well as corrective measures already exist in the industry to overcome the proppant flowback problems. However, there is no clear guidance on how to choose the method for certain conditions, particularly during the hydraulic fracturing design stages. Therefore, the authors conducted a comprehensive review of fourteen preventive technologies to systematize them and to propose an initial decision-making approach. The following methods were considered in this paper: Resin Coated Proppants (RCP), RCP with Activator, RCP with Nanoparticles, Proppant with Liquid Resin Systems (LRS), Proppant with Surface Modification Agents (SMA), Proppant with Proppant Consolidation Aid (PCA), Cylindrical Proppant, Microfibers, Thermoset Resin Fibers, Thermoset Film Strips, Deformable Isometric Particles (DIP), Expandable Proppants, Polymer Surface Modified Proppants, and In-situ Formulated Proppants. The review reveals physical, chemical, and technological properties of each method to select criteria for effective screening. So, the reader could find the appropriate proppant flowback mitigation method corresponding to a particular reservoir and the well conditions during the initial hydraulic fracturing design stages.
Faculty of Mining, Geology and Petroleum Engineering
2021-01-22 00:00:00
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/12357
Rudarsko-geološko-naftni zbornik; Vol. 36 No. 1 (2021): No. 52
eng
Copyright (c) 2020 authors and journal
oai:ojs.pkp.sfu.ca:article/12938
2021-03-18T16:58:07Z
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The effect of pressure depression on the water inflow volume to wells which cover carbonate rocks in the Carpathian Foredeep basement, SE Poland
Rzyczniak, Mirosław
AGH University of Science and Technology, Faculty of Drilling, Oil & Gas
Solecki, Marek
AGH University of Science and Technology, Faculty of Drilling, Oil & Gas https://orcid.org/0000-0001-8637-8300
Zeljaś, Dagmara
AGH University of Science and Technology, Faculty of Drilling, Oil & Gas https://orcid.org/0000-0001-7241-0285
Dubiel, Stanisław
AGH University of Science and Technology, Faculty of Drilling, Oil & Gas
This paper presents an analysis of well testing data, performed with a Drill stem test (DST). The carbonate levels of Mesozoic reservoir rocks were investigated in the research area of the Carpathian Foredeep. Based on the results of 17 two-cycle DST reservoir tests, the dependence of the volume of the reservoir water flow rate from the Mesozoic carbonate
reservoirs (Upper Jurassic, Lower Cretaceous) to the wells as a function of the mean depression of bottom pressure was researched in the selected oil exploration area in the Carpathian Foredeep basement, SE Poland. Using methods of statistical analysis, a satisfactory correlation between variables for power and the exponential model was found, and a weak correlation for the linear model was found. A decrease in the value of the reservoir water flow rate along with an increase in pressure depression was found for the Mesozoic carbonate reservoirs, which may indicate the occurrence of fractures and micro-fractures shortening under extreme pressure depression and blockage phenomena of fractures and cavernous pores in the perimeter area by solid particles (cuttings, salt, polymers, etc.).
Faculty of Mining, Geology and Petroleum Engineering
2021-03-18 17:58:07
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/12938
Rudarsko-geološko-naftni zbornik; Vol. 36 No. 2 (2021): No. 53
eng
Copyright (c) 2021 authors and journal
oai:ojs.pkp.sfu.ca:article/13299
2021-03-18T16:58:07Z
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Drilling bit selection in a formation with different sedimentary facies using the Markov chain: A case study at one of the oil fields in the south of Iran
GHaffari Rad, Afsaneh
https://orcid.org/0000-0003-3579-0295
Negahban, Sajjad
Shahrood University of Technology https://orcid.org/0000-0002-8548-2357
Tokhmechi, Behzad
Faculty of Mining, Petroleum and Geophysics Engineering, Shahrood University of Technology, Shahrood, Iran
Mostafavi, Hossein
Exploration Directorate of National Iranian Oil Company, Tehran, Iran
The selection of drill bit is an essential issue in the well planning. Furthermore, identification and evaluation of sedimentary rocks before well drilling plays a crucial role in choosing the drill bit. Moreover, the Markov chain as a stochastic model is one of the powerful methods for identifying lithological units, which is based on the calculation of the transition probability matrix or transition matrix. The Markov chain experiences transitions from one state (a situation or set of values) to another according to specified probabilistic rules. In this paper, this is the first time that the Markov chain was implemented for bit selection in a formation with different sedimentary facies (such as Dashtak formation). Therefore, proper drill bit was recommended by utilizing the transition matrix of rock facies and available bits. This process was carried out in two wells where the thicknesses of Dashtak formation are 960 meters and 1410 meters. Consequently, the results indicate that the Markov chain is a practical method for selecting bits in a sequence of rock facies based on an acceptable matching between the reality mode (the used bits in the well) and the Markov chain results. Besides, in the case of using an improper bit in a well, and using a bit in washing and reaming operation, there were differences between the real used bits and the Markov chain outputs.
Faculty of Mining, Geology and Petroleum Engineering
2021-03-18 17:58:07
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/13299
Rudarsko-geološko-naftni zbornik; Vol. 36 No. 2 (2021): No. 53
eng
Copyright (c) 2021 authors and journal
oai:ojs.pkp.sfu.ca:article/13629
2021-06-23T10:01:27Z
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"210623 2021 eng "
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Two-component fluid front tracking in fault zone and discontinuity with permeability heterogeneity
Shiri, Yousef
Shahrood University of Technology https://orcid.org/0000-0002-4003-8017
Hassani, Hossein
Amirkabir University of Technology (Polytechnic of Tehran)
Fluid front tracking is important in two-phase/component fluid flow in porous media with different heterogeneities, especially in the improved recovery of oil. Three different flow patterns of stable, viscous fingering, and capillary fingering exist based on the fluids’ viscosity and capillary number (CA). In addition, fluid front and sweep efficiency are affected by the heterogeneity of the porous medium. In the current study, the heterogeneous porous media are: (1) normal fault zone or cross-bedding with heterogeneity in permeability, and (2) a fracture or discontinuity between two porous media consisting of two homogeneous layers with very low and high permeabilities, in which immiscible water flooding is performed for sweep efficiency and streamlines tracking purposes. By considering the experimental glass micromodel and the simulation results of discontinuity, a crack is the main fluid flow path. After the breakthrough, fluid inclines to penetrate the fine and coarse grains around the crack. Moreover, an increase in flow rate from 1 and 200 (ml/h) in both the experimental and simulation models causes a reduction in the sweep efficiency from 14% to 7.3% and 15.6% to 10% by the moment of breakthrough, respectively. In the fault zone, the sweep efficiency and the streamline of the injected fluid showed a dependency on the interface incident angle, and the layers’ permeability. The presented glass micromodel and Lattice Boltzmann Method were consistent with fluid dynamics, and both of them were suitable for a precise evaluation of sweep efficiency and visualization of preferential pathway of fluid flow through cross-bedding and discontinuity for enhanced oil recovery purposes.
Faculty of Mining, Geology and Petroleum Engineering
2021-06-23 12:01:27
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/13629
Rudarsko-geološko-naftni zbornik; Vol. 36 No. 3 (2021): No. 54
eng
Copyright (c) 2021 authors and journal
oai:ojs.pkp.sfu.ca:article/15392
2021-09-20T16:12:16Z
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"210920 2021 eng "
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Oil Spill in a Marine Environment: Requirements Following an Offshore Oil Spill
Govindarajan, Suresh Kumar
Indian Institute of Technology- Madras https://orcid.org/0000-0003-3833-5482
Mishra, Avanish
Indian Institute of Technology - Madras https://orcid.org/0000-0002-9754-8253
Kumar, Abhishek
Indian Institute of Technology - Madras https://orcid.org/0000-0001-8184-2071
The global lifestyle of this modern world has become more dependent on petroleum-based products, whose applications are involved almost everywhere. Since a large quantity of oil is being used on a daily basis, the spilling of oil by various means during its storage and transportation has become inevitable. This work focuses on the spilling of oil in a marine environment, generally referred to as an offshore oil spill, in contrast to an onshore oil spill associated with a terrestrial environment. These oil spills not only devastate the natural resources and unsettle the economy, they also jeopardize marine life, as well as human health. The remediation of an oil spill remains very challenging, when the disaster is associated with a large aerial extent. In this context, a sound understanding is required on the origin, seeping, composition and properties of the spilled oil in order to better monitor the spreading of the oil spill. In this manuscript, a detailed list of fundamental queries, which will be required to be addressed at the instance of an oil spill has been deduced, which will be extremely useful for the oil spill respondents as there are no previous studies that exclusively provide the type and nature of data required to be collected, immediately following an oil spill. Furthermore, this manuscript has deduced a list of sensitive and essential plots that will be required in order to analyse and forecast the spreading of an oil spill. An essence of weathering and its associated movement of oil spill has been included.
Faculty of Mining, Geology and Petroleum Engineering
2021-09-20 18:12:16
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/15392
Rudarsko-geološko-naftni zbornik; Vol. 36 No. 4 (2021): No. 55
eng
Copyright (c) 2021 authors and journal
oai:ojs.pkp.sfu.ca:article/16069
2021-06-23T10:01:27Z
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"210623 2021 eng "
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Numerical Investigation of Fluid Flow Instabilities in Pore-scale with Heterogeneities in Permeability and Wettability
Shiri, Yousef
Shahrood University of Technology https://orcid.org/0000-0002-4003-8017
Shiri, Alireza
Department of Civil and Environmental Engineering, Tennessee Technological University, Cookeville, TN, United States, P.O.Box: 38501 https://orcid.org/0000-0001-7702-9694 https://orcid.org/0000-0001-7702-9694
Quadrant geometry with permeability and wettability contrast occurs in different events, such as faults, wellbore damage, and perforation zones. In these events, understanding the dynamics of immiscible fluid displacement is vital for enhanced oil recovery. Fluid flow studies showed that viscous fingering occurs due to viscous instabilities that depend on the mobility of fluids and capillary forces. Besides, the porous domain heterogeneity is also effective on the formation of fingering. So, the purpose of the current research is to numerically investigate the effect of heterogeneity in wettability and permeability, and flow properties in Saffmann-Taylor instabilities. Numerical simulations with different flow rates in the permeability contrast model illustrated the nodal crossflow, growth of viscous fingering in the nodal part, and bypass flow in the second zone. In the wettability contrast model, a capillary fingering pattern is observed and fluid patches are isolated because of capillary force and the end effects are trapped within the quadrant. Moreover, the consequences of wettability on apparent wettability that alters the fluid-front pattern and displacement efficiency are shown.
Faculty of Mining, Geology and Petroleum Engineering
2021-06-23 12:01:27
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/16069
Rudarsko-geološko-naftni zbornik; Vol. 36 No. 3 (2021): No. 54
eng
Copyright (c) 2021 authors and journal
oai:ojs.pkp.sfu.ca:article/16170
2021-09-20T16:12:16Z
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Investigation of the effect of the discontinuity direction on fluid flow in porous rock masses on a large-scale using hybrid FVM-DFN and streamline simulation
Namdari, Sajad
Isfahan University of Technology, Isfahan, Iran
Baghbanan, Alireza
Isfahan University of Technology https://orcid.org/0000-0001-8616-5807
Hashemolhosseini, Hamid
Understanding the fluid behaviour in rock masses is of great importance in various rock mass-related engineering projects, such as seepage in tunnels, geothermal reservoirs, and hazardous waste disposal. Different approaches have been implemented to study the flow pattern in fractured porous rock masses. Laboratory experiments can provide good information regarding this issue, but high expenses aside, they are time-consuming and suffer the lack of ability to study field scale mediums. Numerical methods are beneficial in simulating such mediums with the Discrete Fracture Network (DFN) method in terms of costs and time as they offer sufficient flexibility and creativity. In this paper, a Matlab code was extended to study the flow regime in a Dual Permeability Media (DPM) with two point sources in the right and left side of the model as an injector and a producer well, respectively. A high permeability discontinuity with different angles was embedded in a very low-permeability limestone matrix. Pressure equations were solved implicitly with a two-point flux approximation scheme of the Finite Volume Method (FVM). Streamlines were traced in the medium and used to analyse the model’s hydraulic behaviour with the aid of Time Of Flight (TOF) for each point. The results show that the FVM-DFN hybrid method can be used as a fast method for fluid flow in DPM with the aid of streamline simulation to study the fluid flow in a large model with discontinuity.
Faculty of Mining, Geology and Petroleum Engineering
2021-09-20 18:12:16
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/16170
Rudarsko-geološko-naftni zbornik; Vol. 36 No. 4 (2021): No. 55
eng
Copyright (c) 2021 authors and journal
oai:ojs.pkp.sfu.ca:article/16553
2021-06-23T10:01:27Z
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"210623 2021 eng "
1849-0409
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Defining geoexchange extraction rates in the same geological environment for different borehole geometry settings – Pilot results from the HAPPEN - HORIZON 2020 project
Kurevija, Tomislav
University of Zagreb, Faculty of Mining, Geology and Petroleum Engineering https://orcid.org/0000-0002-5469-3653
Macenić, Marija
https://orcid.org/0000-0002-7632-033X
Sabolić, Tea
https://orcid.org/0000-0003-3482-051X
Jovanović, Dalibor
https://orcid.org/0000-0002-2372-2677
Kindergarten Grdelin in the city of Buzet, Istria, Croatia, was chosen to undergo a deep retrofit of the current thermotechnical system, as a part of the HORIZON 2020 HAPPEN project1. The existing shallow spiral heat exchanger field is insufficient to cover heating loads of the building. Therefore, additional BHEs were drilled and completed to determine optimal borehole heat exchanger type within the same geological environment. Four BHEs, either single U (1U) or double U (2U), with different geometrical setting and depth were tested: BHE-1 (50 m, 2U DN32 ribbed), BHE-2 (75 m, 2U DN40 ribbed), BHE-3 (100 m, 2U DN32 smooth) and BHE-4 (150 m, 1U DN45 ribbed). A thermal response test (TRT) was performed to obtain the ground thermal properties. Furthermore, synthetic TRT curves were calculated to describe temperature response in the case of different heat pulses. This was done to determine heat extraction rates and the capacity of each BHE type, according to EN14511 norm. It was established that the BHE-4 is the optimal design for heating and cooling purposes on the selected site due to positive impact of the geothermal gradient, higher initial borehole temperature and a positive effect of the ribbed inner wall.
[1] This paper reflects only the view of the authors and the Commission is not responsible for any use that may be made of the information it contains.
Faculty of Mining, Geology and Petroleum Engineering
2021-06-23 12:01:27
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https://hrcak.srce.hr/ojs/index.php/rgn/article/view/16553
Rudarsko-geološko-naftni zbornik; Vol. 36 No. 3 (2021): No. 54
eng
Copyright (c) 2021 authors and journal
oai:ojs.pkp.sfu.ca:article/16727
2021-09-20T16:12:16Z
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Discrete Fracture Network (DFN) Modelling of Fractured Reservoir Based on Geomechanical Restoration, a Case Study in the South of Iran
Shiri, Yousef
Shahrood University of Technology https://orcid.org/0000-0002-4003-8017
Shiri, Alireza
Department of Civil and Environmental Engineering, Tennessee Technological University, Cookeville, TN, United States, P.O.Box: 38501 https://orcid.org/0000-0001-7702-9694 https://orcid.org/0000-0001-7702-9694
Fractured reservoirs have always been of interest to many researchers because of their complexities and importance in the oil industry. The purpose of the current study is to model the fractured reservoir based on geomechanical restoration. Our target is the Arab Formation reservoir which is composed of seven limestone and dolomite layers, separated by thin anhydrite evaporate rock. First of all, in addition to the intensity, the dip, and the azimuth of the fractures, the magnitude and the direction of the stresses are determined using wireline data e.g. photoelectric absorption factor (PEF), sonic density, neutron porosity, a dipole shear sonic imager (DSI), a formation micro imager (FMI), and a modular formation dynamics tester (MDT). Then, the seismic data are interpreted and the appropriate seismic attributes are selected. One of our extracted attributes was the ant tracking attribute which is used for identifying large-scale fractures. Using this data, fractures and faults can be identified in the areas away from wells in different scales. Subsequently, the initial model of the reservoir is reconstructed. After that, the stress field and the distribution of fractures are obtained using the relationship between the stresses, the strains, and the elastic properties of the existing rocks. The model is finely approved using the azimuth and the intensity of fractures in the test well. Our findings showed that the discrete fracture network (DFN) model using geomechanical restoration was positively correlated with real reservoir conditions. Also, the spatial distribution of fractures was improved in comparison to the deterministic-stochastic DFN.
Faculty of Mining, Geology and Petroleum Engineering
2021-09-20 18:12:16
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https://hrcak.srce.hr/ojs/index.php/rgn/article/view/16727
Rudarsko-geološko-naftni zbornik; Vol. 36 No. 4 (2021): No. 55
eng
Copyright (c) 2021 authors and journal
oai:ojs.pkp.sfu.ca:article/17082
2021-09-20T16:12:16Z
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Comparative analysis of historic predictions and actual global natural gas market trends for the period from 1997 to 2020
Šamarinec, Domagoj
https://orcid.org/0000-0001-5761-0537
Karasalihović Sedlar, Daria
https://orcid.org/0000-0002-2763-2863
Smajla, Ivan
University of Zagreb, Faculty of Mining, Geology and Petroleum Engineering https://orcid.org/0000-0002-1009-6726
Jukić, Lucija
An accurate prediction of energy indicators is critical for orientation in the energy market, and it could give direction for policymakers and market participants. The aim of this research was to examine the accuracy of projections of natural gas market indicators. This paper presents a comparative analysis of historic predictions and actual global natural gas movements in several segments, namely production, consumption, and regional import dependence, as well as forecasted and actual price movements. The goal of this paper is to compare projected and actual natural gas market indicators. Predictions of market movements 20 years into the future are very useful, but they do have certain limitations. Those limitations especially apply to goods whose prices are regional and linked to price movements of another good, as is the case with natural gas. External influences have a direct impact on production and consumption, and it is rather clear that changes in one of the fundamental factors entails and magnifies the error of further predictions. Despite that, predictions of global production and consumption have proven to be very accurate. Based on the research results, it could be emphasized that for strategical planning and policy-making purposes, the predictions of natural gas production, consumption, or even import independence could be considered with great certainty, while price assumptions in the case of natural gas have shown significant mismatching, therefore, should be very carefully perceived.
Faculty of Mining, Geology and Petroleum Engineering
2021-09-20 18:12:16
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https://hrcak.srce.hr/ojs/index.php/rgn/article/view/17082
Rudarsko-geološko-naftni zbornik; Vol. 36 No. 4 (2021): No. 55
eng
Copyright (c) 2021 authors and journal
oai:ojs.pkp.sfu.ca:article/17452
2021-09-20T16:12:16Z
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An Evaluation of Cyclic Loading Conditions and Computed Tomography for the Strength and Petrophysical Properties of Anhydrite Caprock
Farrokhi, Mostafa
Department of Petroleum Engineering, Shahid Bahonar University of Kerman, Kerman, Iran https://orcid.org/0000-0002-1125-0764
Jalalifar, Hossein
Department of Petroleum Engineering, Shahid Bahonar University of Kerman, Kerman, Iran
Karimi Nasab, Saeed
Department of Mining Engineering, Shahid Bahonar University of Kerman, Kerman, Iran https://orcid.org/0000-0001-5775-2383
Underground gas storage (UGS) in depleted reservoirs affects caprock properties. The resemblance of Qom anhydrite outcrop with cutting obtained from a 2629 m depth was confirmed using X-ray diffraction (XRD) results and scanning electron microscope (SEM) tests. The anhydrite specimens unconfined compressive strength (UCS) changed under static cyclic loading conditions, and also petrophysical properties, such as porosity and permeability altered under 10, 20, and 30 cycles of loading. The magnitude of loading ranged from 30 to 43% of intact anhydrite UCS. The loading rate used for cyclic loading tests was 0.004 mm/s. The samples’ UCS decreased between 3.5 to 23.9% under cyclic loading conditions. The study of specimens computed tomography (CT) imaging with porosity and permeability indicated the growth of cracks, the cracks did not initiate in all lengths of specimens, hence the incremental increase in porosity did not increase the permeability of specimens. Even being under cyclic loads, the permeability of specimens stayed lower than 10-15 m2 (0.001 mD) but the trend of pressure versus time for measuring permeability shows a higher drop in pressure due to changes in permeability. The study indicated that the CT imaging results are in good accordance with petrophysical findings.
Faculty of Mining, Geology and Petroleum Engineering
2021-09-20 18:12:16
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/17452
Rudarsko-geološko-naftni zbornik; Vol. 36 No. 4 (2021): No. 55
eng
Copyright (c) 2021 authors and journal
oai:ojs.pkp.sfu.ca:article/17791
2021-11-29T08:58:42Z
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"211124 2021 eng "
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Simulation of aquifer remediation from low-permeable lenses by back-diffusion phenomenon
Dehqani Tafti, Mojtaba
1Shahrood University of Technology, Faculty of Mining, Petroleum and Geophysics Engineering, Shahrood https://orcid.org/0000-0002-1203-7797 https://orcid.org/0000-0002-1203-7797
Doulati Ardejani, Faramarz
2School of Mining, College of Engineering, University of Tehran, Tehran https://orcid.org/0000-0002-4951-8850
Fatehi Marji, Mohammad
3Department of Mining and Metallurgical Engineering, Yazd University, Yazd https://orcid.org/0000-0003-2917-6264 https://orcid.org/0000-0003-2917-6264
Shiri, Yousef
4Shahrood University of Technology, Faculty of Mining, Petroleum and Geophysics Engineering, Shahrood https://orcid.org/0000-0002-4003-8017 https://orcid.org/0000-0002-4003-8017
Fluid flow in a dual permeable medium (DPM) is essential in solute transport in mining and aquifer studies. In this paper, water flushing into a contaminated DPM containing fine-grained lenses with different geometries was investigated with the Lattice Boltzmann Method (LBM). The LBM model used in this study was D2Q9 with a relaxation time of 1, a cohesion value of 3 for a fluid density of 1 (mu.Lu-3). The saturated fluid in the DPM was a contaminant that usually stays in low permeable lenses and after flushing, it is leaked into the porous medium by a second fluid (water). This phenomenon is predominant when the displacing fluid has a lower concentration than the contaminated fluid. Diffusion and advection are the main mechanisms that control fluid flow in the porous medium. The results of the simulations showed: (1) advection controlled solute transport through the flushing phase, and back-diffusion occurred after the change in phase; (2) the lenses’ geometry influenced the fluid flow pattern and the remediation process. As a result, aquifer remediation strategies based on the lenses’ geometry and their permeability can help us select the appropriate environmental protection.
Faculty of Mining, Geology and Petroleum Engineering
2021-11-24 00:00:00
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https://hrcak.srce.hr/ojs/index.php/rgn/article/view/17791
Rudarsko-geološko-naftni zbornik; Vol. 36 No. 5 (2021): No. 56
eng
Copyright (c) 2021 authors and journal
oai:ojs.pkp.sfu.ca:article/17884
2021-11-29T08:58:42Z
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Prediction of penetration rate of drilling by using rock engineering system approach case study: a well in Azadegan oilfield
Saeedi, Hamidreza
Jalali, Seyed Esmaeil
Noroozi, Mehdi
Shahrood University of Technology, Iran (Faculty of Mining Eng., Petroleum and Geophysics) https://orcid.org/0000-0001-6206-8121
Behraftar, Somayeh
As factors directly related to the costs of drilling, time and operational efficiency are of major significance in the drilling operations. One of the criteria in the operational efficiency of drilling is the rate of penetration of the drilling bit. Numerous factors affect the rate of penetration. Identification of the effective factors on rate of penetration may lead to a more accurate assessment of drilling time and as a result the controlling of operational costs. The concurrent effect of the entire influential factors as well as the differing significance of each of them on the rate of penetration makes the study and optimization of drilling operations much more complicated and difficult. Using the rock engineering systems (RES), the impact of effective operational and environmental factors on the rate of penetration has been assessed in this article and a model has been proposed for prediction of the rate of penetration. Data from one of the wells within Azadegan oilfield have been used in order to study the impact of effective factors on the rate of penetration. To this end, the effective factors on rate of penetration are initially identified and then an index called “the penetration index” is proposed through application of the rock engineering systems approach. This index has been calculated at four different depths along the aforesaid well. The results suggested the compliance of penetration rate predictions with field observations. Moreover, porosity and uniaxial compressive strength are the most effective factors on the rate of penetration whereas the unit weight of drilling fluid has the least impact.
Faculty of Mining, Geology and Petroleum Engineering
2021-11-24 00:00:00
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/17884
Rudarsko-geološko-naftni zbornik; Vol. 36 No. 5 (2021): No. 56
eng
Copyright (c) 2021 authors and journal
oai:ojs.pkp.sfu.ca:article/18010
2021-11-29T08:58:42Z
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A new eco-friendly and low cost additive in water based drilling fluids
Yalman, Emine
PhD student, University of Miskolc, Petroleum engineering department; Iskenderun Technical University, petroleum and natural gas department https://orcid.org/0000-0002-1782-3543
Federer-Kovacs , Gabriella
(Dr.) University of Miskolc, Petroleum engineering department
Depci, Tolga
(Dr.), Iskenderun Technical University, petroleum and natural gas department https://orcid.org/0000-0001-9562-8068
Al Khalaf, Hani
(PhD student), University of Miskolc, Petroleum engineering department https://orcid.org/0000-0002-3175-0264
This study investigates the possibility of using rice husk ash as an additive to develop an environmentally friendly and low-cost drilling fluid system. The rice husk ash was added as an additive to water-based bentonite drilling fluids at different concentrations ranging from 2 wt% to 15 wt%. Rheological and filtration properties of each drilling fluid developed were measured by using a viscometer and standard low-pressure low-temperature filter press. Subsequently, cutting carrying index, minimum annulus velocity required to clean bottom of the well efficiently, flow behaviour index and permeability of mud cakes of the formulated systems were calculated in order to assess performance of the systems. The results demonstrated that the rheological and properties were improved depending on concentration of rice husk ash introduced. With the introduction of 15 wt% concentration of rice husk ash, while apparent viscosity and yield point increased by 60% and 183%, respectively, thixotropy and plastic viscosity decreased by 29% and 63%, respectively. On the other hand, drilling fluid with 4% wt% content of rice husk ash reduced the fluid loss by 10%. Moreover, results showed that cutting carrying index, minimum annulus velocity required to clean bottom of the well efficiently and flow behaviour index of the enhanced with the exploitation of rice husk ash in the drilling fluid. This study showed that rice husk ash as a promising additive to use in the water-based bentonite drilling fluids when properly implemented, and hence reducing the impact on the environment, and the total cost for drilling.
Faculty of Mining, Geology and Petroleum Engineering
2021-11-24 00:00:00
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/18010
Rudarsko-geološko-naftni zbornik; Vol. 36 No. 5 (2021): No. 56
eng
Copyright (c) 2021 authors and journal
oai:ojs.pkp.sfu.ca:article/18227
2021-11-29T08:58:42Z
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Experimental study of the effect of cooling/lubricating fluids on penetration rate in hard and soft rock drilling process
Khosravimanesh, Shahrokh
Department of mining engineering, Isfahan University of Technology (IUT), Isfahan, Iran https://orcid.org/0000-0003-2256-3245
Cheraghi Seifabad, Masoud
Department of mining engineering, Isfahan University of Technology (IUT), Isfahan, Iran https://orcid.org/0000-0001-9460-6000
Mikaeil, Reza
Department of Mining and Metallurgical Engineering, Urmia University of Technology https://orcid.org/0000-0001-8404-3216
Bagherpour, Raheb
Department of mining engineering, Isfahan University of Technology (IUT), Isfahan, Iran https://orcid.org/0000-0002-7235-9966
Rock drilling is the process of penetrating and crushing rocks, which is characterized by the low rate of penetration (ROP) and drilling rate because of the amount of cuttings that remain in the drilling environment and the thermal stresses generated at the bit-rock interface. Any improvement in ROP and drilling rate can be of great technical and economic value for drilling projects. ROP can be improved through the proper use of cooling-lubricating fluids during drilling. ROP is a key indicator of drilling performance and the ability to predict this rate can be very useful for mining projects. ROP prediction can also be used to estimate the total cost of a drilling operation. ROP depends on a variety of parameters, which, when available, can be used to estimate ROP. To reach a better understanding of the parameters affecting ROP and how it can be optimized, in this study, the results of 492 laboratory drilling tests were analyzed by linear and nonlinear multivariate regression in SPSS to build a number of models for ROP prediction. These tests were conducted on seven soft and hard rock samples while using six fluids as the cooling-lubricating agent. The tests were performed with a laboratory-scale drilling rig on cubic specimens at several different rotation speeds and thrust forces. The results showed that the drilling achieved significantly higher ROP in the presence of the cooling-lubricating agent. After reviewing the results, several models that were able to produce ROP predictions with the lowest average estimation error were picked as suitable choices for predicting ROP in the presence of cooling-lubricating fluids. The results of statistical tests of these models showed with over 90% confidence that they can produce highly accurate ROP estimates based on mechanical properties of the rock, physical characteristics of the cooling-lubricating fluid, and operating parameters of the drilling rig.
Faculty of Mining, Geology and Petroleum Engineering
2021-11-24 00:00:00
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/18227
Rudarsko-geološko-naftni zbornik; Vol. 36 No. 5 (2021): No. 56
eng
Copyright (c) 2021 authors and journal
oai:ojs.pkp.sfu.ca:article/18683
2022-02-01T12:19:57Z
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"220201 2022 eng "
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Experimental Evaluation of Locally Synthesized Biodiesel Drilling Fluid
Duru, Ugochukwu Ilozuruike
Federal University of Technology Owerri https://orcid.org/0000-0001-7920-8047 https://orcid.org/0000-0001-7920-8047
Nduwuba, George O.
Federal University of Technology Owerri
Onyejekwe, Ifeanyichukwu
Ikpeka, Princewill Maduabuchi
Teesside University https://orcid.org/0000-0002-1174-1491
Diesel oil has been the preferred base fluid for the formulation of oil-based drilling mud. Diesel oil has negative effects on the environment and there is a growing need for more environmentally sustainable alternatives that can be technically compared to diesel base oil. In recent times, the use of vegetable oils as drilling fluid base oil has been of interest. In this study, 1378 kg/m3 of palm kernel oil-base mud (PKOBM) and palm kernel oil biodiesel base mud (BDBM) were experimentally formulated. The BDBM was synthesized by the transesterification of vegetable (palm kernel) oil. The performance of PKOBM and BDBM was then evaluated against conventional diesel oil-base mud (DOBM). The evaluation performed was based on the rheological, filtration and wall building properties, emulsion and thermal stabilities, and acute toxicity of the formulated drilling fluid systems.Results obtained from the study reveal that the mud systems (PKOBM and BDBM) show a typical Herschel-Bulkley (modified power-law) drilling mud rheological pattern at temperatures of 49 oC, 66 oC and 80 oC. BDBM showed comparable rheological properties with better hole cleaning capacity as indicated by a lower flow index. For the filtrate loss test, BDBM exhibited slightly lower filtrate loss of 3.2 ml compared to DOBM with 3.2 ml, whereas PKOBM had a higher fluid loss of 4.4 ml. For the filter cake and thermal stability test, there were no significant changes between DOBM and BDBM whereas PKOBM had the least desirable performance. BDBM exhibited the most stable emulsion of 1274 volts breaking voltage and PKOBM, least with 739 volts compared to 1169 volts breaking voltage of DOBM. This study concludes that BDBM could be used as an environmentally sustainable substitute for diesel oil-based mud (DOBM).
Faculty of Mining, Geology and Petroleum Engineering
2022-02-01 13:19:57
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https://hrcak.srce.hr/ojs/index.php/rgn/article/view/18683
Rudarsko-geološko-naftni zbornik; Vol. 37 No. 1 (2022): No. 57
eng
Copyright (c) 2021 authors and journal
oai:ojs.pkp.sfu.ca:article/18882
2021-11-29T08:58:42Z
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Potential of using plant extracts as green corrosion inhibitors in the petroleum industry
Žbulj, Katarina
University of Zagreb, Faculty of Mining, Geology and Petroleum Engineering https://orcid.org/0000-0002-1387-7616
Bilić, Gordana
University of Zagreb, Faculty of Mining, Geology and Petroleum Engineering https://orcid.org/0000-0002-2733-1702
Hrnčević, Lidia
University of Zagreb, Faculty of Mining, Geology and Petroleum Engineering https://orcid.org/0000-0001-8990-0985
Simon, Katarina
University of Zagreb, Faculty of Mining, Geology and Petroleum Engineering https://orcid.org/0000-0001-7527-6173
In this paper, preliminary studies of ten different plant extracts as potential corrosion inhibitors of carbon steel were examined. For each extract, the concentration range in which it shows anti-corrosion action was first determined, and then the most effective concentration was determined for each extract. The tests were performed in a brine solution saturated with CO2 at room temperature. The aim of this study was to isolate extracts with high effectiveness and subsequent electrochemical and surface methods to determine the mechanism of inhibitory action. For this purpose, potentiodynamic polarization was performed with Tafel extrapolation. Among all the tested extracts, lady’s mantle (92.17%) and dandelion root (95.07%) stood out with their effectiveness. Both tested extracts showed the behaviour of a mixed corrosion inhibitor with a dominant influence on the anode process.
Faculty of Mining, Geology and Petroleum Engineering
2021-11-24 00:00:00
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/18882
Rudarsko-geološko-naftni zbornik; Vol. 36 No. 5 (2021): No. 56
eng
Copyright (c) 2021 authors and journal
oai:ojs.pkp.sfu.ca:article/18908
2022-03-15T10:48:19Z
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"220315 2022 eng "
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Evaluation of using waste pinecones as an eco-friendly additive to water-based mud
AL Khalaf, Hani
University of Miskolc https://orcid.org/0000-0002-3175-0264
Alhaj Mohammed , Nagham
https://orcid.org/0000-0001-7323-2441
Federer, Gabriella
https://orcid.org/0000-0002-3165-8169
This study is investigating the possibility of using pinecones as additive materials to develop a water-based drilling mud. Pinecones are environmentally friendly agricultural wastes and have no practical applications. Therefore, this study is of great importance in that it highlights the investment of these natural waste materials in practical fields. The study focused on the effectiveness of pinecone powder in a water-based drilling mud. To this end, an experimental study on five types of pinecones (Austrian pinecones, Black Hills Spruce, Sitka Spruce, Norway Spruce, and White pinecones) was performed and tested to determine their ability to reduce filter loss and also the effect of those eco-friendly materials on the rheological properties and density of the mud. In the study, 26 samples of water-based mud mixed with the different types of pinecones at different concentrations based on the weight of mud sample (1 wt%, 2 wt%, 3 wt%, 4 wt%, and 5 wt%) were used to perform the experiments. The results of the study showed that pinecones have a great ability to reduce filter loss, particularly Norway Spruce cones, which, based on this study, are considered the superior type with a concentration of 3 wt%.
Faculty of Mining, Geology and Petroleum Engineering
2022-03-15 11:48:19
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/18908
Rudarsko-geološko-naftni zbornik; Vol. 37 No. 2 (2022): No. 58
eng
Copyright (c) 2021 authors and journal
oai:ojs.pkp.sfu.ca:article/19080
2022-03-15T10:48:19Z
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"220315 2022 eng "
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Development of Water-Based Drilling Fluid in Mitigation of Differential Sticking Tendency
yalman, emine
University of miskolc, petroleum engineering department; Iskenderun Technical University, petroleum and natural gas department https://orcid.org/0000-0002-1782-3543
Federer-Kovacs , Gabriella
University of miskolc, petroleum engineering department https://orcid.org/0000-0002-3165-8169
Depci, Tolga
Iskenderun Technical University, petroleum and natural gas department https://orcid.org/0000-0001-9562-8068
The objective of the study is to design a drilling fluid that prevents differential pressure pipe sticking tendency caused by drilling fluid with fly ash that is an industrial waste generated from the combustion of coal. To this end, drilling fluid samples were prepared with different particle sizes obtained through the sieving and grinding process and increasing concentrations of fly ash. Differential pipe sticking tests of the samples were performed by applying 3.447 MPa (500 psi) pressure and using a Fann Model 21150 Differential Sticking Tester in order to determine how the coefficient of sticking and torque reading varied with the fly ash. From the results, it was observed that the coefficient of sticking and torque reading of the water-based drilling fluids decreased up to a specific concentration as the concentration of fly ash increased. Furthermore, particle size analysis illustrated that the coefficient of sticking and torque of the drilling fluid differs depending on the particle size of fly ash introduced. The drilling fluid designed with ground fly ash demonstrated lower sticking coefficient and torque reading than that of drilling fluids formulated with raw and sieved fly ashes. The experimental study revealed that fly ash is a promising additive in the mitigation of differential sticking tendency caused by water-based drilling fluids.
Faculty of Mining, Geology and Petroleum Engineering
2022-03-15 11:48:19
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/19080
Rudarsko-geološko-naftni zbornik; Vol. 37 No. 2 (2022): No. 58
eng
Copyright (c) 2021 authors and journal
oai:ojs.pkp.sfu.ca:article/19795
2022-02-01T12:19:57Z
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"220201 2022 eng "
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Application of Solid Expandable Tubulars in the Petroleum Industry
Gaurina-Međimurec, Nediljka
University of Zagreb, Faculty of Mining, Geology and Petroleum Engineering https://orcid.org/0000-0003-2922-4780
Mesarić, Pavao
ENSOLX d.o.o., Hebrangova ul. 30, 10 000 Zagreb, Croatia https://orcid.org/0000-0001-7956-990X
The development of solid expandable tubular (SET) technology and products (open hole liner, open hole clad, cased hole liner, liner hanger, internal casing patch, etc.) has enabled operators to plan well design in a new way and solve various problems that arise during drilling and exploitation on land and offshore. By including an expandable open hole liner, monobore open hole liner or monobore openhole clad in well design, it is possible to achieve a slim hole design and/or resolve unwanted situations that occur during the drilling of problem zones with minimal hole size reduction and reach hydrocarbon reserves which cannot be achieved economically by conventional technology. By installing an expandable cased hole liner or internal casing patch in production wells to cover the intervals of a corroded casing or to close old perforations, it is possible to extend the life cycle of a production well and increase the final hydrocarbon recovery and speed up the return on investment. The aim of the paper is to systematically review the relevant literature and give an overview of solid expandable tubular technology and its applications in the petroleum industry, as well as the cementing technology of open hole expandable liners. The available data for 21 case studies of SET application in onshore and offshore wells were analyzed in detail. Based on an extensive review of the literature and analyzed data, it can be concluded that SET technology is being successfully applied worldwide and that expandable liners with a diameter of 114.3 mm to 339.72 mm are being run in wells to ever greater depths (up to 5166 m) and in ever more extreme downhole conditions.
Faculty of Mining, Geology and Petroleum Engineering
2022-02-01 13:19:57
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/19795
Rudarsko-geološko-naftni zbornik; Vol. 37 No. 1 (2022): No. 57
eng
Copyright (c) 2021 authors and journal
oai:ojs.pkp.sfu.ca:article/20733
2022-08-24T10:46:17Z
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nmb a2200000Iu 4500
"220824 2022 eng "
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Sorption of oil by mechanochemicaly activated shungite
Ongarbayev, Yerdos
Al-Farabi Kazakh National University https://orcid.org/0000-0002-0418-9360
Baigulbayeva, Moldir
Al-Farabi Kazakh National University https://orcid.org/0000-0003-4049-4319
Tileuberdi, Yerbol
Al-Farabi Kazakh National University; Institute of Combustion Problems https://orcid.org/0000-0001-9733-5015
Zhumakhan, Kairat
Al-Farabi Kazakh National University
In the
paper the sorption capacity of shungite rocks of the Koksu field (Kazakhstan) in relation to the oil from the Karazhanbas and Tengiz fields (Kazakhstan) were studied.
Oil spills occurring during production, gathering, transportation, storage and refining, and repair work on wells are an urgent environmental problem.
There are effective methods of soil purification, including particular interests addressed to sorption process.
The aim of this research is to study oil sorption by shungite rocks of the Koksu deposit after mechanochemical activation.
The mechanochemical activation of shungite rock samples was carried out in a planetary ball mill at different speeds of rotation and ratios of ball mass to the sample.
The developed sorbents based on shungite rocks of the Koksu deposit were tested for cleaning samples of oil-contaminated soils and their sorption capacities under dynamic and static conditions were determined. For the sorption of oil, the sorbent based on shungite of shale grade (TS) after mechanochemical activation is recommended, which sorption capacity under dynamic conditions is 2.57-2.85 g/g. Sorption of oil from 10 % of oil contaminated soil samples with the sorbents based on shungite after mechanochemical activation showed sorption capacity of 0.44-0.45 g/g in 60 days under static conditions. The practical significance of the research lies in the prospects of using shungite rocks to clean up oil spills.
Faculty of Mining, Geology and Petroleum Engineering
2022-08-24 12:46:17
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/20733
Rudarsko-geološko-naftni zbornik; Vol. 37 No. 4 (2022): No. 60
eng
Copyright (c) 2022 authors and journal
oai:ojs.pkp.sfu.ca:article/21464
2022-08-24T10:46:17Z
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nmb a2200000Iu 4500
"220824 2022 eng "
1849-0409
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Prediction of shear wave velocity and modification of Castagna and Carroll relationships in one of the Iranian oil fields
Mahmoudian, Mohammad Sadegh
Shahrood University of Technology, Faculty of Mining, Petroleum and Geophysics Engineering, Shahrood, Iran, P.O. Box: 36199-95161
Shiri, Yousef
Shahrood University of Technology https://orcid.org/0000-0002-4003-8017
Vaezian, Ahmad
Shahrood University of Technology, Faculty of Mining, Petroleum and Geophysics Engineering, Shahrood, Iran, P.O. Box: 36199-95161
Shear wave velocity is one of the essential parameters for describing hydrocarbon reservoirs that have several applications in petrophysical, geophysical, and geomechanical studies. Shear wave velocity usually does not exist in all wells, especially in old oil fields. In the current study, two equations of Carroll and Castagna have been modified, and linear and nonlinear multi-regressions were used to estimate shear wave velocity in an oil reservoir in southwestern Iran. Initially, compressional wave velocity and porosity were determined as the most effective wire-line logs on shear wave velocity by comparing their correlations. Then, two equations of Carroll and Castagna were modified. In addition, new equations based on porosity and compressional wave velocity for estimating the shear wave velocity were obtained. Shear wave velocity was estimated by new exponential equations in the wells of the current oil field with excellent goodness of fit by determination coefficients of 0.80 in the whole well, 0.72 in the Ghar-Shale-1, and 0.78 in Ghar-Shale-3 in X-07 well.
Faculty of Mining, Geology and Petroleum Engineering
2022-08-24 12:46:17
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/21464
Rudarsko-geološko-naftni zbornik; Vol. 37 No. 4 (2022): No. 60
eng
Copyright (c) 2022 authors and journal
oai:ojs.pkp.sfu.ca:article/21556
2022-08-24T10:46:17Z
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"220824 2022 eng "
1849-0409
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Quantitative Risk Assessment of the Effect of Sand on Multiphase Flow in Pipeline
Duru, Ugochukwu
Federal University of Technology, Owerri, Nigeria
M. Ikpeka, Princewill
Federal University of Technology, Owerri
Ndukwe-Nwoke, Chiziterem
Federal University of Technology, Owerri
Oladunde Arinkoola, Akeem
Ladoke Akintola University of Technology, Ogbomoso
I. Onwukwe, Stanley
Federal University of Technology, Owerri
The presence of sand particles flowing along with reservoir fluids in a pipeline increases the probability of pipeline failure. The risk of pipeline failure is either accentuated or abated by the flow conditions of the fluids in the pipeline. In this study, a quantitative risk analysis of the effect of sand on pipelines during multiphase flow, under the pipeline failure modes; sanding up, erosion, and encountering abnormal pressure gradient was conducted. Three piping components were considered: line pipe (nominal size 1.5 in [3.8 cm]), swing check valve (nominal size 12.007 in [ 30.5cm]) and 90 deg LR Elbow (nominal size 2.25 in [5.7cm]). Correlations that indicate the critical velocities and the critical sand concentrations above/below which these failures occur were employed and implemented in a Visual Basic program. The analysis was conducted at a temperature of 204 oC and pressure of 604 psi [4.2×106 Pa]. A probability distribution, simulating real-life scenario was developed using Monte Carlo simulation. This determines the probability of deriving critical sand concentration values that fall beyond the set statistical limits which indicates the probability of occurrence of the failure being investigated. For all three failures, the severity of occurrence (represented by CAPEX incurred in solving the failures) was multiplied with the probability of failure which gave rise to the risk indexes. Based on the histogram plot of average risk index and analysis, the study reveals that larger diameter components are prone to turbulence which lead to greater risk of erosion. The risk of abnormal pressure drop and sanding up were considerably lower than that for erosion (abrasion)..
Faculty of Mining, Geology and Petroleum Engineering
2022-08-24 12:46:17
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/21556
Rudarsko-geološko-naftni zbornik; Vol. 37 No. 4 (2022): No. 60
eng
Copyright (c) 2022 authors and journal
oai:ojs.pkp.sfu.ca:article/22151
2022-08-24T10:46:17Z
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"220824 2022 eng "
1849-0409
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Comparative analysis on impact of water saturation on the performance of in-situ combustion
Tummuri Naga Venkata Pavan
Indian Institute of Technology Madras
Devarapu, Srinivasa Reddy
Govindarajan, Suresh Kumar
Indian Institute of Technology Madras
The amount of oil together with the water Originally in Place (OIP), makes up the liquid phase in heavy oil reservoir systems. This amount of liquid present in the pores of the reservoir system is known as liquid saturation, plays a vital role in improving oil recovery through In-Situ Combustion (ISC) process. The oil phase acts as fuel in generating thermal energy required for viscosity reduction and the water phase supports in the formation of an enlarged condensation zone that aids in higher mobility of the low viscous oil. A numerical investigation is carried out to study the role of water saturation on the performance of in-situ combustion in a heavy oil reservoir. A finite-difference based numerical model is developed and validated for water recovery. The model is then used to carry out the impact of liquid saturation on the performance of the ISC, as it plays a vital role in screening criteria for the selection of ISC. The numerical results projected a significant effect on the thermal and production profile during the process. A comparison between the effect of variation in water and oil saturations projected a significant increase in reservoir temperatures with increased water saturation than the oil saturation. The highest reservoir temperatures are observed at the maximum liquid (oil and water together) saturation. Further, the additional water drive provided by increased water saturation is observed to contribute to early production rates.
Faculty of Mining, Geology and Petroleum Engineering
2022-08-24 12:46:17
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/22151
Rudarsko-geološko-naftni zbornik; Vol. 37 No. 4 (2022): No. 60
eng
Copyright (c) 2022 authors and journal
oai:ojs.pkp.sfu.ca:article/22227
2022-11-28T16:17:45Z
rgn:PEE
nmb a2200000Iu 4500
"221128 2022 eng "
1849-0409
0353-4529
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Improving mechanical properties of oil well cement using polypropylene fibers and evaluating a new laboratory method for measuring the casing cement bonding strength
AL Khalaf, Hani
University of Miskolc
Federer Kovacsne, Gabriella
Alhaj Mohammed, Nagham
Remeczki, Ferenc
The main objective of this study is to enhance the poor performance of oil well cement in terms of mechanical properties by using pure polypropylene fibers. Polypropylene fibers were added in increasing concentrations from 0 to 0.1%, 0.3%, 0.5%, 0.7%, and 0.9% by weight of cement (BWOC). Rheological parameters, density, fluid loss, permeability, porosity, compressive strength, tensile strength, and flexural strength were all tested. A new method for measuring the tensile strength of cement samples in the presence of a casing is also evaluated in this research. In addition, the interfacial bonding shear strength, which represents the strength of cement adhesion to the casing, was measured using a new laboratory procedure. The influence of adding polypropylene fibers on rheology, density, and fluid loss can be ignored, according to the results of the experiments. The permeability and porosity of cement samples increased as the proportion of polypropylene fibers increased, according to the findings. Further, an increase in polypropylene fibers concentration up to 0.3%BWOC led to improving the mechanical properties at different curing times. The bonding strength of the casing cement interface improved with increasing polypropylene fibers concentration up to 0.5% BWOC.
Faculty of Mining, Geology and Petroleum Engineering
2022-11-28 17:17:45
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/22227
Rudarsko-geološko-naftni zbornik; Vol. 37 No. 5 (2022): No. 61
eng
Copyright (c) 2022 authors and journal
oai:ojs.pkp.sfu.ca:article/23969
2023-03-06T14:05:47Z
rgn:PEE
nmb a2200000Iu 4500
"230306 2023 eng "
1849-0409
0353-4529
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One-step electrochemical synthesis of PEDOT based composites for supercapacitor applications
Ljubek, Gabrijela
https://orcid.org/0000-0001-5842-5915
Marijana Kraljić Roković
Faculty of Chemical Engineering and Technology, University of Zagreb https://orcid.org/0000-0001-5953-9885 https://orcid.org/0000-0001-5953-9885
The aim of this work was to determine the optimal synthesis conditions for the preparation of a poly(3,4-ethylenedioxythiophene) (PEDOT) layer by the electrochemical method from an electrolyte containing graphene oxide (GO) and a sodium dodecylsulfate (SDS) micellar solution. Besides an SDS anion, GO is also incorporated within the PEDOT layer as a negative counter ion. Therefore, this is a one-step electrochemical method for a PEDOT/GO composite layer preparation. The results displayed that PEDOT composites were successfully synthesised by applying a potential in the value range from 0.94 to 1.00 V, and with a synthesis duration of up to 600 s. It was concluded that the optimal concentration of EDOT monomer is 0.02 mol dm-3, and SDS 0.01 mol dm-3. The incorporation of GO into the PEDOT layer improved the polymer response in KCl solution influencing the pseudocapacitive properties, which is significant for its supercapacitor applications. The morphological and structural properties of the obtained layers were characterized by means of scanning electron microscopy and ultraviolet-visible spectrophotometry. The pseudocapacitive properties were determined in a 0.1 mol dm-3 KCl solution by using cyclic voltammetry and electrochemical impedance spectroscopy methods.
Faculty of Mining, Geology and Petroleum Engineering
2023-03-06 15:05:47
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/23969
Rudarsko-geološko-naftni zbornik; Vol. 38 No. 1 (2023): No. 62
eng
Copyright (c) 2023 authors
oai:ojs.pkp.sfu.ca:article/24446
2023-06-10T06:56:21Z
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nmb a2200000Iu 4500
"230610 2023 eng "
1849-0409
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Numerical investigation on the impact of initial water saturation distribution on hot water flooding performance under non-isothermal conditions
Ansari, Md Irshad
Reservoir Simulation Laboratory, Petroleum Engineering Programme, Department of Ocean Engineering, Indian Institute of Technology, Madras, India https://orcid.org/0000-0002-1784-1151
Kumar Govindarajan , Suresh
https://orcid.org/0000-0003-3833-5482
The heterogeneity in the spatial distribution of initial water saturation influences the performance of hot water flooding. The prospect of a reduction in oil recovery arises from the development of viscous instability. In the present study, a numerical simulation model has been developed by coupling heat transport, and multiphase flow in porous media integrated with the non-isothermal flow, and the numerical model has been verified with the existing analytical solution by Buckley and Leverett. The formation of a wavy temperature profile at the condensation front was found with a decreased depth of temperature penetration. The average rise of temperature is drastically affected by the spatial distribution of initial water saturation. The formation of viscous fingering was highly dominating in the reservoir, with initial water saturation randomly distributed and causing the front to move in an irregular pattern from the initial stage of the flooding. The heterogeneous reservoir with initial water distribution showed the earlier formation of viscous fingering than the homogeneous reservoir. The heterogeneity in the spatial distribution of initial water saturation had caused viscous instability, lower viscosity reduction, lower displacement sweeps efficiency, and higher residual oil saturation. The present study is limited to spatial distribution in initial water saturation to a certain degree of heterogeneity. The heterogeneity in the spatial distribution of initial water saturation highly impacted the production performance of hot water flooding. The present study provides an idea for the implementation and future development of hot water flooding in a randomly initial water saturation distributed environment.
Faculty of Mining, Geology and Petroleum Engineering
2023-06-10 08:56:21
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/24446
Rudarsko-geološko-naftni zbornik; Vol. 38 No. 2 (2023): No. 63
eng
Copyright (c) 2023 Md Irshad Ansari, Suresh Kumar Govindarajan
oai:ojs.pkp.sfu.ca:article/25162
2023-06-10T06:56:21Z
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"230610 2023 eng "
1849-0409
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The influence of mandarin peel powder on filtration properties and temperature stability of water-based drilling mud
Medved, Igor
https://orcid.org/0000-0002-8738-6983
Pašić, Borivoje
University of Zagreb; Faculty of Mining, Geology and Petroleum Engineering https://www.rgn.unizg.hr/hr/djelatnici?djelatnik=borivoje-pasic https://orcid.org/0000-0003-1919-1129
Mijić, Petar
https://orcid.org/0000-0003-3690-5787
The growing energy demand in the world, as well as the current geopolitical situation, require countries to additional investments in the exploration and production of hydrocarbons from their own sources. This means that companies must develop new fields which have remained undeveloped until now mostly because extremely harsh environment where they are located (deep sea, high temperature, high pressure, heavy oils, etc.). The development of these new fields requires the development and adoption of new technology, among other things, and the development of a temperature-stable drilling fluid system able to fulfil all tasks according to the new technical challenges. Except for the technological challenges, there are also growing concerns related to the influence of the drilling operation on the environment. All of the above encourage the industry to develop new, inexpensive, and environmentally friendly additives which will be able to satisfy all technical and technological requirements and challenges of modern drilling. In the last few years, there has been a growing trend of laboratory research that includes different types of biodegradable waste as a potential additive that can achieve useful properties in mud. In this paper, the influence of mandarin peel powder on the filtration properties of mud after the aging process at elevated temperatures is examined. This eco-friendly additive was added to water-based muds in concentrations of 1% and 2% by volume of water. Laboratory research have shown stable filtration properties of the water-based mud containing mandarin peel powder even after exposing the mud to temperatures higher than 130 °C.
Faculty of Mining, Geology and Petroleum Engineering
2023-06-10 08:56:21
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/25162
Rudarsko-geološko-naftni zbornik; Vol. 38 No. 2 (2023): No. 63
eng
Copyright (c) 2023 Borivoje Pašić, Igor Medved, Petar Mijić
oai:ojs.pkp.sfu.ca:article/26768
2023-12-04T07:44:52Z
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"231204 2023 eng "
1849-0409
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Application of Neutron Computed Tomography in Enhanced Oil Recovery for Analysing Oil Distribution in Berea Sandstone using Bagasse Surfactant
Setiati, Rini
Universitas Trisakti
Akbar, Fahrurrozi
National Research and Innovation Agency https://orcid.org/0000-0002-8838-1842
Prasucipto Karisma, Gabriel
National Research and Innovation Agency https://orcid.org/0000-0002-2956-0963 https://orcid.org/0000-0002-2956-0963
Ramadhani, Achmad
National Research and Innovation Agency https://orcid.org/0000-0002-5437-8493 https://orcid.org/0009-0007-3318-3594
Setiawan, Setiawan
National Research and Innovation Agency https://orcid.org/0000-0002-7819-5843
Aditya, Renato
Universitas Trisakti https://orcid.org/0009-0007-4206-4896
Taufiq Fathaddin, Muhammad
Universitas Trisakti https://orcid.org/0000-0003-2351-0292 https://orcid.org/0000-0003-2351-0292
Giat Sukaryo, Sulistioso
https://orcid.org/0009-0003-4830-3406 https://orcid.org/0009-0003-4830-3406
Bharoto, Bharoto
https://orcid.org/0000-0003-0108-7673 https://orcid.org/0009-0008-4780-9890
Sumirat, Iwan
https://orcid.org/0000-0002-4764-1767 https://orcid.org/0000-0002-4764-1767
The Neutron Computed Tomography (NCT) technique was adopted to study oil content within sandstone. In recent times, oil industries have turned to the Enhanced Oil Recovery (EOR) technique that uses chemicals/surfactants to reduce interfacial tension to maximize oil production from mature oil fields. The Berea core played a crucial role in investigating surfactant effectiveness for liberating trapped oil. The presented research is based on laboratory experiments carried out at the National Research and Innovation Agency and at the Trisakti University, Indonesia. The research proceeded in three steps. The first step was observation on the Berea core that is saturated with a low salinity brine of 40,000 ppm and 60,000 ppm and assessment of the total porosity of the sandstone. The second step included injecting oil into the sample and examining the water distribution. The final step was to inject sugarcane bagasse surfactant with 2% surfactant concentration to extract oil from the sandstone, then it was subjected to NCT analysis. The observations show that the pores are evenly distributed in the middle, the oil content accumulates at the edge, almost no oil remains in the middle of the Berea core after water injection, and the remaining oil returns to the main flow after surfactant injection. The results show that oil movement in the Berea core with 40,000 ppm salinity is better than oil movement with 60,000 ppm. The salinity of the brine can affect the mobility of oil droplets in the Berea core, and surfactant injection processes have better performance at lower salinity and are susceptible to higher salinity.
Faculty of Mining, Geology and Petroleum Engineering
2023-12-04 08:44:52
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/26768
Rudarsko-geološko-naftni zbornik; Vol. 38 No. 5 (2023): No. 66
eng
Copyright (c) 2023 Rini Setiati, Fahrurrozi Akbar, Gabriel PRASUCIPTO KARISMA, Achmad Ramadhani, Setiawan Setiawan, Renato Aditya, Muhammad Taufiq Fathaddin, Sulistioso Giat Sukaryo, Bharoto Bharoto, Iwan Sumirat
oai:ojs.pkp.sfu.ca:article/27137
2023-12-04T07:44:52Z
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"231204 2023 eng "
1849-0409
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The The Impact of Adding Waste Pineapple Peel on the EOR Process to Increase Crude Oil Production
Samsol
Universitas Trisakti https://orcid.org/0000-0002-5386-8546
Pauhesti
Petroleum Engineering Department, Faculty of Earth and Energy Technology Universitas Trisakti, Jakarta Indonesia 11440 https://orcid.org/0000-0002-9305-1610
Pramadika, Havidh
Petroleum Engineering Department, Faculty of Earth and Energy Technology Universitas Trisakti, Jakarta Indonesia 11440 https://orcid.org/0000-0002-2934-3678
Zainal Abidin, Muhammad
Petroleum Engineering Department, Faculty of Earth and Energy Technology Universitas Trisakti, Jakarta Indonesia 11440
Ridaliani, Onnie
Petroleum Engineering Department, Faculty of Earth and Energy Technology Universitas Trisakti, Jakarta Indonesia 11440
Wijayanti, Puri
Petroleum Engineering Department, Faculty of Earth and Energy Technology Universitas Trisakti, Jakarta Indonesia 11440 https://orcid.org/0000-0003-1953-0610
Nugrahanti, Asri
Petroleum Engineering Department, Faculty of Earth and Energy Technology Universitas Trisakti, Jakarta Indonesia 11440
As the demand for energy continues to rise, it is still primarily met by fossil fuels and non-renewable energy sources. In addition, oil production, particularly in older fields, is declining. The enhanced oil recovery (EOR) method utilized in this study is surfactant injection with the addition of waste pineapple peel. The experiment was carried out in a controlled laboratory setting, using surfactant and brine solutions with salinities of 5,000 ppm and 12,000 ppm, respectively. The concentration range of alpha olefin sulfonate (AOS) surfactant employed ranged from 0.2% to 0.6% (2×10-6 m3 and to 0.6% from 1×10-3 m3). The solution was tested at two different temperatures, specifically 30°C and 60°C. The solution was tested with the addition of the pineapple peel and without pineapple peel. The density, viscosity, and interfacial tension of the two solutions were determined using laboratory measurements. The subsequent procedure involves the injection of the core sample in order to determine the oil recovery factor. The interfacial tension (IFT) values obtained were 17.5 mN/m in the absence of additives and 15.4 mN/m in the presence of additives derived from pineapple peel. The recovery factor for a solution with a salinity of 12,000 ppm and a concentration of 0.6% is determined to be 42.01%. Additionally, the recovery factor for a surfactant solution with the addition of pineapple peel is found to be 44.26%. Based on the findings of this study, the utilization of waste pineapple peel demonstrates a beneficial impact on the process of oil production.
Faculty of Mining, Geology and Petroleum Engineering
2023-12-04 08:44:52
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/27137
Rudarsko-geološko-naftni zbornik; Vol. 38 No. 5 (2023): No. 66
eng
Copyright (c) 2023 samsol, Pauhesti, Havidh Pramadika, Muhammad Zainal Abidin, Onnie Ridaliani, Puri Wijayanti, Asri Nugrahanti
oai:ojs.pkp.sfu.ca:article/28377
2024-03-01T17:41:40Z
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"240301 2024 eng "
1849-0409
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A Review on Glycerol-Based Drilling Fluids and Glycerine as a Drilling Fluid Additive
Momeni, Ali
Faculty of Petroleum and Natural Gas Engineering, Sahand University of Technology https://orcid.org/0000-0001-7789-1217
Tabatabaee Moradi, Seyyed Shahab
Faculty of Petroleum and Natural Gas Engineering, Sahand University of Technology, Tabriz, Iran, https://orcid.org/0000-0002-1484-6926 https://orcid.org/0000-0002-1484-6926
Tabatabaei-Nejad, Seyyed Alireza
Faculty of Petroleum and Natural Gas Engineering, Sahand University of Technology, Tabriz, Iran
A significant increase of energy demands all over the world and production decline from available oil and gas reservoirs have led the industry to invest in major offshore petroleum resources. However, drilling operations in offshore environments are usually restricted by environmental constraints. Therefore, recent studies are devoted to the development of environmentally compatible fluids with adequate technical properties. Glycerine is a non-toxic, lubricating, colorless, odorless substance with a higher density than water. Due to the properties of glycerine, it can be used as the base of drilling fluid to formulate synthetic-based fluids. This research aimed to review the studies on the applications of glycerine in the composition of drilling fluid. Based on the results, glycerine-based fluids can be considered as an environmentally compatible fluid with sufficient technical properties to replace other drilling fluids. However, there is a lack of experimental studies on the glycerine fluid properties for a reliable decision. For the application of glycerine fluids, an economic feasibility study is mandatory for both pure and crude glycerine. Also, the thermal stability of glycerine fluids is an important aspect, which should be covered in future research studies.
Faculty of Mining, Geology and Petroleum Engineering
2024-03-01 18:41:40
application/pdf
https://hrcak.srce.hr/ojs/index.php/rgn/article/view/28377
Rudarsko-geološko-naftni zbornik; Vol. 39 No. 1 (2024): No. 67
eng
Copyright (c) 2024 Ali Momeni, Seyyed Shahab Tabatabaee Moradi, Seyyed Alireza Tabatabaei-Nejad