Level Of Oil Production Research Articles

Modeling Emissions and Ozone Air Quality Impacts of Future Scenarios for Energy and Power Production in the Rocky Mountain States.

This study examines air quality impacts of scenarios for energy production and use in 2030 across Colorado, northern New Mexico, Utah, and Wyoming. Scenarios feature contrasting levels of oil and gas production and shares of electricity from coal, natural gas, and renewables. Hourly emissions are resolved for individual power plants; oil and gas emissions are basin-specific. Ozone decreased from 2011 to the 2030 baseline, with median and 90th percentile reductions in maximum daily 8 h average (MDA8) ozone across the four-state domain of 3.5 and 7.1 ppb, respectively, resulting in 200 fewer premature deaths annually. Relative to the 2030 baseline, MDA8 ozone increased in the "cheap gas" scenario, with median and 90th percentile increases of 0.1 and 1.0 ppb, and declined in a scenario with greenhouse gas (GHG) emissions fees, with median and 90th percentile reductions of 0.2 and 1.5 ppb. Reduced coal generation lowered SO2 emissions in all future scenarios compared to 2011. GHG emissions from electricity and oil and gas production declined by 4% (CO2-equivalent) from 2011 to the 2030 baseline, increased by 10% from the 2030 baseline to the cheap gas scenario, and declined by 28% from the 2030 baseline to the GHG fees scenario.

Estimating the Impact of Energy Price Reform on Saudi Arabian Intergenerational Welfare using the MEGIR-SA Model

This paper investigates the intergenerational welfare impact of raising administered retail energy prices in Saudi Arabia, an example of an oil-exporting country with a fast growing population. To achieve this, we develop a dynamic model with overlapping generations (called MEGIR-SA), which we believe is the first empirical application of its type to be developed for an oil-exporting country. The model is used to analyze the effects of the increase in some Saudi administered energy prices implemented at the end of December 2015. In particular, the model analyzes how these price increases might affect the welfare of Saudis through a direct increase in energy expenditures, an indirect rise in Saudi public income stemming from a lower domestic demand for oil that fosters oil exports at a given level of domestic oil production, and a direct increase of the turnover of the energy sector. The two latter effects can be redistributed by the Saudi public authorities to private agents through higher current public spending and/or public investment. The analysis suggests that the increase in end-user energy prices results in a net overall favorable effect on the intertemporal welfare of all households. This mirrors the impact on the income of private agents of the surplus in public oil income associated with lower domestic consumption of oil products and recycled to private agents. Moreover, it is shown that the additional oil income associated with the increase in domestic energy prices tends to be relatively more beneficial to future generations if it is recycled through public investment. This is reinforced if the future price of oil remains relatively low. In a possible future situation of declining oil prices and domestic production, a policy that would help meet the Saudi Arabian objectives may consist of gradually increasing the fraction of the additional oil income that is recycled through public capital spending.

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Hard-to-recover reserves of Yugra oil (West Siberia)

In 2017, the Yugra’s share of the all-Russian production was 43.0 %, it’s 235.3 million tons in absolute units. This is 3.9 million tons less than in 2016 and 43.1 million less than in 2007. The Neocom shelf sandstones are the main development object. 44 % of the expected resources of Russia in prospective D1 category reserves (resources of sediments and territories with proven oil) are concentrated in Yugra. The key challenge for the oil industry of Yugra is prevention of decline and the stabilization of oil production. It can be obtained by the active involving hard-to-recover reserves to the development. Criteria of hard-to-recover reserves, results and opportunities of their using for development in the conditions of Yugra fields are analyzed in the article. These are oil deposits with abnormal physical and chemical properties, under-gas-cap zone of deposits, sediments of the AB11–2 reservoir “Hazel Grouse” of type, Achimov Formation, Tyumen Formation, rocks of the Pre-Jurassic play and Bazhenov Formation. Increase in the oil production for only three plays (Achimov, Bazhenov-and-Abalak and Tyumen) was almost 4 million tons in 2017. This is comparable with the rate of decline in oil production for Yugra in general. Geological initial resources of the Bazhenov play are estimated at 11 billion tons, recoverable oil resources, at 3.1 billion tons. The primary source of the stabilization of oil production level in Yugra is involvement in the development of hard-to-recover reserves of Achimov and Tyumen plays. The production growth of the hard-to-recover reserves of the Pre-Jurassic play is possible. Now its annual production is 2—3 million tons. Resources of Bazhenov play will replenish the declining production trend by 2030.

CONCERNING TO REMOVAL METHODS HYDRATE FORMATION (ON EXAMPLE OF URENGOY FIELD)

Background At present, the development of gas fields is in most cases complicated by the increase in moisture content in natural gas. The main reason for this phenomenon is a decrease in pressure, gas temperature and, as a result, this leads to the appearance of water vapor that has condensed and accumulated in wells and gas pipelines. Further saturation of natural gas at an elevated pressure and positive temperature can lead to the formation of solid physicochemical compounds - hydrates. The occurrence of such crystalline substances can lead to the blockage of wells, gas pipelines, separators, disruption of the work of stabilizing and gauging devices, and as a result to a decrease in the level of oil production. Often, pressure regulators and fittings fail, gas is throttled, accompanied by a sharp decrease in temperature, and the disruption of the normal operation of the oil and gas production equipment. Aims and Objectives Determination of factors affecting the intensity of hydrate formation, and the study of methods to combat the formation of gas hydrates on the example of the Urengoy field. Results The factors that directly affect the intensity of hydrate formation are determined: moisture content, temperature, pressure, component composition of the gas. The possible places for gas hydrates formation are given: at fittings, in piping of pipes, in separators, in loops, on diafragms of metering sections. The main methods of preventing the hydrate formation and removal of hydrate plugs are present: increasing the gas temperature, reducing the gas pressure, removing moisture from the gas using absorbents and adsorbents, inhibitors. Methods for the control of hydrate formation, using in Urengoi field, are presented. A thermal calculation of the plume was performed, which allows determining the temperature change along the gas pipelines and determining the possible place of hydrate formation.

OPTIMAL OPERATION OF ELECTRICAL POWER GENERATORS FOR OIL WELLS OPERATED BY ARTIFICIAL LIFTING AT RUMILA FIELD

Numerous oil wells within Rumaila field contain Electrical Submersible Pumps (ESPs). ESPs are utilised to maximise the oil production from existing wells by providing artificial lift where pressure is low, which helps maintain oil production levels. The number of ESPs installed throughout the Rumaila. Field is growing consistently to sustain oil field production. Due to the remote locations for each of the ESPs the current strategy is to supply power to ESPs using individual diesel engine generators located at each remote ESP well site. This is an inefficient design, as individual diesel engines are resource intensive due to maintenance and frequent diesel filling. The generators are also a source of significant unreliability causing ESP shutdowns/trips resulting in extended downtime. Given the above a Pre-FEED has been carried out considering supplying ESPs using OHTL’s supplying electrical power from EPP to ESPs in Area C. by uses parallel operation of diesel Generators , we could to constrict 124 from 184 and use 60 only ,by this we get high economic gain and technique, in additional that environmental protection by decreasing pollution.

Preliminary Assessment of 22Cr and 15Cr Materials Selection for CO2 Enhanced Oil Recovery Program

Enhanced Oil Recovery (EOR) program to increase oil production from mature fields are now being implemented in Indonesia amid concern over the continuous decrease of oil production level. The mature fields and EOR process have the tendency to carry relatively high impurities components (CO2, H2S, chloride ions) that results in early corrosion occurrence, creating damages in the subsurface equipment (wellhead, tubing, Xmas tree, etc). In Java area with 0.09 TSCF potential gas reserves, 49.3 MMSTB oil and + 23% CO2 content, such amount of CO2 gas and possibility of H2S and chloride from the reservoir will require a higher grade material than the conventional carbon steel. This paper discuss the preliminary materials selection process in the program plan based on the existing condition. The material selection based on the evaluation of closest field data, literature review as a comparison, material, and fluid analysis test. Duplex 22Cr-15 Cr materials are the main study in the paper as the candidate for the tubing material in high CO2, high H2S and chloride environment. The polarization result in 27°C and 50°C showed that the chrome 22 %Cr material had pitting tendency in chloride ion 25,000 ppm, while at high temperature (80 °C) the pitting tendency shifted to 5,000 ppm of chloride ion.

Forecasting Methods Applied to Oil Production Deposits at Bazhenov Formation

Analysis of the experience of operating wells in the territory of the Khanty-Mansiysk Autonomous Okrug - Ugra (KhMAO-Yugra) using the displacement characteristic “ALGOMES-2”, presented in the work, allows to identify trends in the development of these sediments taking into account the presence of a dual environment of the productive reservoir, to estimate the nearest and medium term prospect of development taking into account application of modern technologies and influence on a layer. According to the results of the assessment, it is established that the profitability of the development of the Bazhenov formation does not provide more than 80 percent of the wells that drain less than 30,000 tons of oil, the development of these deposits in modern conditions is possible with the use of hydraulic fracturing, HS and Multistage hydraulic fracturing of the reservoir (MGRP). The forecast of oil production levels using the ALGOMES-2 methodology and the Monte Carlo probability-statistical simulation method used in Petroleum Resources Management System (PRMS) showed that the oil production level is expected to be around 700000-800000 tons per year in the period up to 2030. These figures indicate the advisability of involving in the development of bituminous shales taking into account the technology of impact on these layers. The work noted that the development of deposits Bazhenov formation should be conducted selectively, it is necessary to rely on the data obtained as a result of the amplitude-frequency characteristics of the seismic exploration of the Bazhenov formation, and the wells should be located in fractured rocks.

Visualization study of the effects of oil type and model geometry on oil recovery under ultrasonic irradiation in a glass micro-model

If the current trends of oil recovery from the oil reservoirs continue, the level of oil production will significantly reduce soon. This intense reduction will challenge the current methods for enhanced oil recovery since they will lose their capability and efficiency to meet the required targets. Accordingly, applying new and efficient methods to improve oil recovery are essential. In this study, ultrasound waves were applied to investigate its effect on oil recovery during distilled waterflooding under temperature control. The effect of ultrasound on the oil recovery was studied in a glass micro-model for different model geometries. Experiments were conducted using two types of oil (different in their viscosities) and micro models (different in their geometries). One of the micro models had three types of different geometries and fluid after passing through each geometry enters into the next geometry. Results showed that ultrasonic waves improved oil recovery, oil mobility and eventually oil percolation paths. However, the ultimate recovery of the oil not only depends upon the viscosity of the oil but also the geometry of the micro-model used. The effect of ultrasonic waves was more significant for the oil with lower viscosity. The ability of ultrasonic waves on fluid flow in a porous medium depends on the stratigraphy and geometry of these media. Consequently, if ultrasonic waves are used for EOR/IOR, the type of oil and geometry of porous media should be considered.

Peak oil, 20 years later: Failed prediction or useful insight?

20 years ago, in 1998, Scientific American published a paper by Colin J. Campbell and Jean H. Laherrère titled “The End of Cheap Oil” [1], starting a debate on oil depletion continuing to the present day. It was the return of a viewpoint on oil depletion which had been proposed more than 40 years before by Marion King Hubbert [2]⁠ and, in later years, largely forgotten. In their paper, Campbell and Laherrère updated Hubbert’s model with new reserve estimates and proposed that the world’s crude oil production would peak around 2004–2005, and then start an irreversible decline. Shortly afterward, Colin Campbell proposed the term “peak oil” for the highest global oil production level. The term was to become popular over the following decade, generating a true movement of ideas sometimes called the “peak oil movement.” Today, these predictions turn out to have been only partially correct, mainly because the role of “non-conventional” oil was underestimated. The peak oil movement seems to have faded away, while the concept seems to have disappeared from the debate and to be commonly described has having been “wrong.” The present paper reviews the cycle of the peak oil movement, examining how the peak oil concept was understood with the public and the decision makers and what caused its diffusion and its demise, at least up to the present time.

Numerical simulation of the impact of geological heterogeneity on performance and safety of THAI heavy oil production process

The Toe-to-Heel Air Injection (THAI) in-situ combustion process is an efficient way to extract heavy oil and bitumen. However, such reservoirs are often geologically heterogeneous. This work studied the impact of a range of different geological heterogeneities, often found in bitumen deposits, on the performance and safety of THAI. These heterogeneities included random heterogeneity, layered reservoirs, shaly reservoirs, and semi-permeable cap-rocks. A further aim was to also develop potential remedial measures, such as selective well placement. It was found that the degree of symmetry assumed for the reservoir model had a substantial impact on the predicted level of oil production. This is of particular relevance to otherwise apparently symmetrical well placement designs such as staggered line drive. While the presence of impermeable zones resulted in the decrease in the overall oxygen utilisation for shaly reservoirs, compared to simply low permeability reservoirs, there was no evidence of oxygen breakthrough due to preferential channelling into the production well. In layered reservoirs, the development of a rich oil bank during THAI operation depended upon the distribution of permeability around the horizontal producer (HP), and did not occur when there was high permeability just above the HP. It has been shown that the proper representation of the cap-rock in reservoir models for the simulation of THAI is essential in order to accurately mimic the full pattern of heat distribution into the oil zone of the reservoir, and, thence, fuel lay-down. While THAI can operate stably with a permeable cap-rock, vertical permeabilities above ∼1–3 mD led to significant loss of combustion gases from the reservoir.

Multilayer Network Analysis of Oil Linkages

This manuscript proposes a new approach for unveiling existing linkages within the international oil market across multiple driving factors beyond production. A multi-layer, multi-country network is extracted through a novel Bayesian graphical vector autoregressive model, which allows for a more comprehensive, dynamic representation of the network linkages than traditional or static pairwise Granger-causal inference approaches. Building on the complementary strengths in Espinasa et al. (2017) and Rousan et al. (2018), the layers of the network include country- and region-specific oil production levels and rigs, both through simultaneous and lagged temporal dependences among key factors, while controlling for oil prices and a world economic activity index. The proposed approach extracts relationships across all variables through a dynamic, cross-regional network. This approach is highly scalable, and adjusts for time-evolving linkages. The model outcome is a set of time-varying graphical networks which unveil both static representations of world oil linkages and variations in micro-economic relationships both within and between oil producers. An example is provided, illustrating the evolution of intra- and inter-regional relationships for two major inter- connected oil producers: the United States, with a regional decomposition of its production and rig deployment, and Arabian Peninsula and key middle east producers, with a country-based decomposition of production and rig deployment, while controlling for oil prices and global economic indices. Production is less affected to concurrent changes in oil prices and the overall economy than rigs. However, production is a lagged driver for prices, rather than rigs, which indicates that the linkage between rigs and production may not be fully accounted for in the markets.

Idioblasts formation and essential oil production in irrigated Piper aduncum

ABSTRACT The growing of Piper aduncum for essential oil extraction has increased, but there is a lack of basic information about its management and cultivation, which allows the productivity and quality of the oil, in order to attend the market demands. This study aimed to evaluate the relation between the production of essential oils from P. aduncum and soil water pressure heads (20 kPa, 40 kPa, 60 kPa, 100 kPa and non-irrigated). The assessment comprised the quantification of idioblasts and the production of essential oil extracted from leaves of cultivated plants. The variation in the soil water pressure head alters the amount of idioblasts in P. aduncum leaves, with impacts on the essential oil production. A soil water pressure head range of 20-60 kPa is sufficient for this species to express the highest amount of idioblasts and the highest level of essential oil production. The species adapts itself to different water availability conditions in the soil. Under stress conditions, due to water deficit or excess, the production of essential oil is reduced.

Engineering xylose metabolism in thraustochytrid T18

BackgroundThraustochytrids are heterotrophic, oleaginous, marine protists with a significant potential for biofuel production. High-value co-products can off-set production costs; however, the cost of raw materials, and in particular carbon, is a major challenge to developing an economical viable production process. The use of hemicellulosic carbon derived from agricultural waste, which is rich in xylose and glucose, has been proposed as a sustainable and low-cost approach. Thraustochytrid strain T18 is a commercialized environmental isolate that readily consumes glucose, attaining impressive biomass, and oil production levels. However, neither thraustochytrid growth capabilities in the presence of xylose nor a xylose metabolic pathway has been described. The aims of this study were to identify and characterize the xylose metabolism pathway of T18 and, through genetic engineering, develop a strain capable of growth on hemicellulosic sugars.ResultsCharacterization of T18 performance in glucose/xylose media revealed diauxic growth and copious extracellular xylitol production. Furthermore, T18 did not grow in media containing xylose as the only carbon source. We identified, cloned, and functionally characterized a xylose isomerase. Transcriptomics indicated that this xylose isomerase gene is upregulated when xylose is consumed by the cells. Over-expression of the native xylose isomerase in T18, creating strain XI 16, increased xylose consumption from 5.2 to 7.6 g/L and reduced extracellular xylitol from almost 100% to 68%. Xylose utilization efficiency of this strain was further enhanced by over-expressing a heterologous xylulose kinase to reduce extracellular xylitol to 20%. Moreover, the ability to grow in media containing xylose as a sole sugar was dependent on the copy number of both xylose isomerase and xylulose kinase present. In fed-batch fermentations, the best xylose metabolizing isolate, XI-XK 7, used 137 g of xylose versus 39 g by wild type and produced more biomass and fatty acid.ConclusionsThe presence of a typically prokaryotic xylose isomerase and xylitol production through a typically eukaryotic xylose reductase pathway in T18 is the first report of an organism naturally encoding enzymes from two native xylose metabolic pathways. Our newly engineered strains pave the way for the growth of T18 on waste hemicellulosic feedstocks for biofuel production.

A dynamic network analysis of the world oil market: Analysis of OPEC and non-OPEC members

We characterize the dynamic network structure of major oil producing countries. We examine the oil production coordination of 13 Organization of the Petroleum Exporting Countries (OPEC) and 17 non-OPEC members. We construct the dynamic network structure using the network connectedness measure of Diebold and Yilmaz (2009). We investigate the structural changes in connectedness of OPEC and non-OPEC members. Additionally, we study how the influence of OPEC members, non-OPEC countries and major oil producers evolve. We find that the network structure of major oil-producing countries changes significantly over time. Specifically, the impact of changes in oil-production of all OPEC members on global oil production declines, whereas the impact of non-OPEC on global oil production increases. OPEC's “increase” decisions have a significant and positive impact on OPEC and non-OPEC coordination. However, “cut” decisions do not affect coordination. We find that OPEC countries and developing countries have significantly higher levels of connectedness. Additionally, countries with high oil production levels have significantly more influence. The empirical results provide intuition about the recent developments in global oil production.

Shale Oil & Gas as an Alternative Source of Energy Management Strategy in Modern Industrial Development

Shale oil & gas is rapidly emerging as a significant and relatively low cost new unconventional resource in the world. There is potential for shale oil & gas production to spread globally over the next couple of decades. If it does, it would revolutionise global energy markets, providing greater long term energy security at lower cost for many countries. It is analysed that global shale oil & gas production has the potential to reach up to 14 million barrels of oil per day by 2035, this amounts to 12% of the world’s total oil supply. It is estimated that this increase could reduce oil prices in 2035 by around 25%-40% relative to the current baseline EIA projection of $133/barrel in 2035, which assumes low levels of shale oil & gas production. In turn, it could increase the level of global GDP in 2035 by around 2.3%- 3.7%. However, the benefits of such oil & gas price reductions will vary significantly by country.

Optimal Management of Oil Field Development in the Buckley–Leverett Model

We consider the problem of two-phase filtering (oil and water) in a horizontal layer of an oil deposit. We propose an asymptotic method for calculating both the filtering process and related optimal control problems, namely the problems of choosing optimal control actions to achieve maximum oil production at a given level of water resource consumption or a minimum water flow rate that provides the level of oil production required by the plan.

Thermodynamics and Optimal Control of Porous Media Flows in Oil Field Development

The nonisothermal two-phase porous media flow of oil and hot water in a horizontal oil reservoir is considered. An asymptotic method for calculating the flow and solving related optimal control problems is proposed. Namely, the problem of choosing optimal control actions to maximize the oil production for a given level of financial costs and to minimize the costs for a given level of oil production is considered.

MODELING OF FEDOROVSKOE OIL FIELD DEVELOPMENT

Background The geological model is an integral part of the modern design of field development. Based on the results of the simulation, a rational oil field development system is selected, which makes it possible to provide a given level of oil production and optimal protection of the environment. Aims and Objectives Analysis of geological models of the oil field on the basis of geological, hydro-dynamic and field data. Results An analysis of geological models of the Fedorovskoye oil field was carried out, which revealed: o oil reserves involved in the process of hydrodynamic modeling correspond to geological reserves (discrepancies do not exceed 5 %); o in general, the objects obtained a good convergence of actual and modeled development indicators; presented three-dimensional digital geological and filtration models of reservoirs of the Fedorovskoe oil field can be used to calculate predictive technological development indicators.

Combining low-carbon economic development and oil exploration in Brazil? An energy–economy assessment

ABSTRACTBrazil's nationally determined contribution (NDC) pledged under the Paris Agreement has marked a new stage in its climate policy towards strengthening low-carbon economic development beyond the recent drastic cuts in emissions from deforestation. Brazil especially means to limit oil consumption driven by future economic growth and to increase energy efficiency and biofuel use in the transport sector. On the other hand, Brazil still aspires to become a major petroleum province given its huge reserves of ‘pre-salt’ oil. This article aims to clarify under what conditions low-carbon economic development and oil exploration can possibly be combined in Brazil and what would be the energy system, environmental and macroeconomic implications of enabling policies for doing so. To address these questions, an energy–economy computable general equilibrium (CGE) model of the Brazilian economy is used to simulate alternative scenarios up to 2030. The results first show that implementing the most recent energy plans, which take into account the new economic reality in Brazil, should lead to over 20% lower domestic CO2 emissions in 2030 than the indicative NDC target, and to the export of the bulk of newfound crude oil. Second, with the same level of oil production, deeper domestic decarbonization, triggered by additional carbon pricing and sustainable efficiency measures, appears achievable with very small gross domestic product (GDP) loss and maximum oil exports, while being aligned with a 2°C emission pathway. However, (i) extra oil exports may induce net additional emissions outside Brazil and be seen as a perverse incentive and (ii) the economic growth strategy based on high oil exports may hinder the necessary diversification of the Brazilian economy.Key policy insightsLow-carbon development goals will strongly interact with oil policy in Brazil.The 2030 NDC target should be easy to achieve considering the new economic reality in Brazil.Deeper domestic decarbonization is achievable with very limited GDP loss and significant oil exports, while being aligned with a 2°C emission pathway.A broad strategic vision is needed to reconcile climate policy, energy policy and other economic development objectives.