scholarly journals The expansion of innovative activity on rise of oil production enterprises in Azerbaijan

2021 ◽  
pp. 1-7
Author(s):  
A. G. Huseynov ◽  
◽  
E. A. Huseynov ◽  
Keyword(s):  
Oil And Gas ◽  
Production Condition ◽  
Oil Production ◽  
Gas Production ◽  
Innovative Activity ◽  
Gas Well ◽  
Oil And Gas Production ◽  
Article Analysis ◽  
The Republic ◽  
Innovative Techniques

The article analysis the oil and gas production condition in the Republic on basis of statistical data of many years as well as the level of investment provision. The article estimates the structure of expenses on innovative techniques, the condition of exploitation of oil and gas boreholes, the implementation of geological and technological actions, the ways of exploitation methods as well as the methods of ledge effects and influence on extra oil production. It also shows up the reserves and ways of their rational usage. Keywords: innovative activity; geological and technological actions; oil and gas; well.

scholarly journals Utah

2020 ◽  
Vol 6 (3) ◽  
Author(s):  
Mark Burghardt ◽  
Gage Hart Zobell
Keyword(s):  
Crude Oil ◽  
Oil And Gas ◽  
Oil Production ◽  
Oil And Gas Industry ◽  
Legal Framework ◽  
Gas Production ◽  
Mandatory Reporting ◽  
Gas Industry ◽  
Oil And Gas Production ◽  
Crude Oil Production

Oil and gas production continues to be an important sector of Utah’s economy. Following a 25% loss in production between 2014 and 2015, Utah’s production continues to slowly rebound. Crude oil production in 2019 appears to be slightly ahead of 2018 production. Monthly production averages slightly over three million barrels, placing Utah among the top ten states in crude oil production. Along with the continuing increase in production, the state’s legal framework governing oil and gas continues to develop. This Article examines recent changes in Utah statutes and regulations along with new case law developments involving the oil and gas industry. In particular, this Article discusses a recent federal bankruptcy decision involving midstream agreements, the revision to a Utah statute that now requires mandatory reporting of unclaimed mineral interests, and recent revisions to Utah’s oil and gas regulations.

Subsea Oil and Gas Production Assurance Using Artificial Lifts and Nodal Analysis

2015 ◽  
Author(s):  
Ikenna A. Okaro ◽  
Longbin Tao
Keyword(s):  
System Analysis ◽  
Oil And Gas ◽  
Oil Production ◽  
Gas Production ◽  
Submersible Pump ◽  
Oil And Gas Production ◽  
Nodal Analysis ◽  
Multiphase Pump ◽  
Electrical Submersible Pump ◽  
The Impact

This paper describes how the operation of deep, subsea oil wells can be analyzed and optimized using artificial lift systems. A modest explanation was offered about an enhanced Hubbert model for determining production targets at pre-feed phase of project. In addition, the impact of artificial lifts on the economics of subsea wells facing hyperbolic production decline was illustrated. The principle of Nodal analysis was highlighted and applied to optimize a proposed subsea oil production case. Configurations of a nominally rated rod pump, a multiphase pump and an electrical submersible pump were modelled in a steady-state flow using Pipesim software and the simulated results which were functions of liquid flow rate and pressure distribution across the production system exposed the behavior of the system. The results showed that over 100% volumetric efficiency was achieved using a combination of electrical submersible pump at the bottom hole and a multiphase pump at riser base. A guide is presented on how to predict, analyze and enhance the recovery curve of subsea oil production using artificial lifts and nodal-system analysis. The benefit of this work is an enabling cost-effective approach for ensuring production assurance in deep water oil and gas production.

scholarly journals Financial Performance Analysis Before and After the Decline in Oil Production: Case Study in Indonesian Oil and Gas Industry

2018 ◽  
Vol 7 (3.21) ◽  
pp. 10
Author(s):  
Wiwiek Mardawiyah Daryanto ◽  
Dety Nurfadilah
Keyword(s):  
Financial Performance ◽  
Oil And Gas ◽  
Oil Production ◽  
Oil And Gas Industry ◽  
Gas Production ◽  
Gas Industry ◽  
Oil And Gas Production ◽  
Return On Equity ◽  
Financial Condition ◽  
Before And After

Indonesia’s oil and gas industry is the huge contributor to government export revenues and foreign exchange and contributes a substantial amount to state revenue. However, the total of oil production declined around 4,41% per year since 2007, and the sharpest decline was in 2013. This situation gives impact to the performance of oil and gas industry, especially government revenues. Therefore, the purpose of this study is to measure the financial performance of Oil and Gas Industry and to examine the significance differences between the financial performance before and after the decline in oil and gas production. The data were collected from financial report and the period was divided into two periods, before the decline in production (2011 – 2012) and after the decline in production (2014 – 2015). Paired sample t-test and financial ratio analysis (FRA) were used to analyzed the data. The finding shows that the largest oil and gas company in Indonesia is still in good financial condition, although it gained loss. In addition, current ratio and return on equity had significance difference during the period of before and after a decline in oil and gas production. The authors believe that the findings will be helpful for managers who continuously attempt to explore opportunities to provide a higher return. 

scholarly journals Life Cycle Assessment as a Tool of Eco-Efficiency of Oil And Gas Production Facilities

2019 ◽  
pp. 83-92
Author(s):  
T. M. Yatsyshyn
Keyword(s):  
Life Cycle Assessment ◽  
Life Cycle ◽  
Oil And Gas ◽  
Gas Production ◽  
Assessment Methodology ◽  
Life Cycle Assessment Methodology ◽  
Gas Well ◽  
Oil And Gas Production ◽  
Technological Processes ◽  
Production Facilities

Aiming at improving the eco-efficiency of the oil and gas industry, the author suggests the use of life cycle assessment methodology to study oil and gas production facilities as illustrated by the oil-and-gas well. The peculiarities of the research object are the complexity of technological processes and equipment and the multifactorial effects on the environment. The basic principles of the methodology of life cycle assessment have been analyzed. The author specifies the boundaries of the investigated system which includes all stages of the life cycle of an oil-and-gas well: site preparation, rigging up, well drilling, testing, rigging down, assembly of production equipment, well development, well operation, closing-in, well decommissioning. The inventory of single processes of the production system was carried out. It gives a possibility to identify incoming and outgoing elementary flows at each stage. The histograms to determine the power and diversity of incoming and outgoing flows have been built. The approximate duration of each stage is given. This duration makes it possible to estimate the exposure time of single processes and to identify the potential effects on the environment. The most resource-consuming stages have been established. They are drilling, rigging up, rigging down, and decommissioning of wells. Based on to the results of analytical studies of the outgoing flows, the stages with the greatest diversity and flow capacity are established. The potential risk of hazardous environmental emergencies during the life cycle of the investigated facility is determined. The obtained data give a possibility to start researching those processes and / or equipment with which there is intense movement of flows with significant effects on the environment, as well as to develop innovative technical solutions and improve technological processes to reduce the harmful effects on the environment. The conducted research determines a number of advantages of the life cycle assessment methodology for improving the indicators of eco-efficiency. The advantages include a systematic study of the effects of the activities, the multivariate analysis, the identification of the potential for the reduction of impacts and constant improvement throughout the life cycle.

The Research of Oil Production Plant of Reservoir Operation and Management Improvement

2014 ◽  
Vol 962-965 ◽  
pp. 1900-1903
Author(s):  
Ai Ling Wang ◽  
Jiao Wang
Keyword(s):  
Oil And Gas ◽  
Comprehensive Evaluation ◽  
Reservoir Management ◽  
Oil Production ◽  
Gas Production ◽  
Production Plant ◽  
Oil And Gas Production ◽  
The Subject ◽  
Development And Management ◽  
Operation And Management

As the subject of oil and gas production, reservoir management is the oil production plant’s core business. But at present, there are some problems in reservoir management. For example: the development and management unit is not clear; the organizational structure is not streamlining; management mechanism is not perfect; evaluation is not systematic and so on. So, the oil production plant should focus on those four aspects to explore reservoir management---“unified the ground and underground, clear the input-output” “flattened the management layers, specialized functions structure” “market-oriented economy development, optimize the production process” “long-efficiency business goal , comprehensive evaluation of analysis”

scholarly journals 2010–2015 North American methane emissions, sectoral contributions, and trends: a high-resolution inversion of GOSAT observations of atmospheric methane

2021 ◽  
Vol 21 (6) ◽  
pp. 4339-4356
Author(s):  
Joannes D. Maasakkers ◽  
Daniel J. Jacob ◽  
Melissa P. Sulprizio ◽  
Tia R. Scarpelli ◽  
Hannah Nesser ◽  
...  
Keyword(s):  
High Resolution ◽  
Analytical Solution ◽  
Oil And Gas ◽  
Oil Production ◽  
Methane Emissions ◽  
Gas Production ◽  
Anthropogenic Emissions ◽  
Atmospheric Methane ◽  
Oil And Gas Production ◽  
Best Estimate

Abstract. We use 2010–2015 Greenhouse Gases Observing Satellite (GOSAT) observations of atmospheric methane columns over North America in a high-resolution inversion of methane emissions, including contributions from different sectors and their trends over the period. The inversion involves an analytical solution to the Bayesian optimization problem for a Gaussian mixture model (GMM) of the emission field with up to 0.5∘×0.625∘ resolution in concentrated source regions. The analytical solution provides a closed-form characterization of the information content from the inversion and facilitates the construction of a large ensemble of solutions exploring the effect of different uncertainties and assumptions in the inverse analysis. Prior estimates for the inversion include a gridded version of the Environmental Protection Agency (EPA) Inventory of US Greenhouse Gas Emissions and Sinks (GHGI) and the WetCHARTs model ensemble for wetlands. Our best estimate for mean 2010–2015 US anthropogenic emissions is 30.6 (range: 29.4–31.3) Tg a−1, slightly higher than the gridded EPA inventory (28.7 (26.4–36.2) Tg a−1). The main discrepancy is for the oil and gas production sectors, where we find higher emissions than the GHGI by 35 % and 22 %, respectively. The most recent version of the EPA GHGI revises downward its estimate of emissions from oil production, and we find that these are lower than our estimate by a factor of 2. Our best estimate of US wetland emissions is 10.2 (5.6–11.1) Tg a−1, on the low end of the prior WetCHARTs inventory uncertainty range (14.2 (3.3–32.4) Tg a−1), which calls for better understanding of these emissions. We find an increasing trend in US anthropogenic emissions over 2010–2015 of 0.4 % a−1, lower than previous GOSAT-based estimates but opposite to the decrease reported by the EPA GHGI. Most of this increase appears driven by unconventional oil and gas production in the eastern US. We also find that oil and gas production emissions in Mexico are higher than in the nationally reported inventory, though there is evidence for a 2010–2015 decrease in emissions from offshore oil production.

scholarly journals Analysis of comorbid pathology in oil producers

2021 ◽  
Vol 100 (5) ◽  
pp. 464-470
Author(s):  
Olga Y. Ustinova ◽  
Nina V. Zaitseva ◽  
Vitalii G. Kostarev ◽  
Elena M. Vlasova ◽  
Alyona A. Vorobyova ◽  
...  
Keyword(s):  
Working Conditions ◽  
Work Experience ◽  
Oil And Gas ◽  
Comparison Group ◽  
Significant Risk ◽  
Oil Production ◽  
Gas Production ◽  
Observation Group ◽  
Oil And Gas Production ◽  
Average Work

Aim of the study. To analyze the patterns of the comorbidity pathology formation in employees occupied in oil production. Materials and methods. Observation group - 292 employees of the oil production enterprise (100% men). The average age was 39.4 ± 10.6 (20-65) years. Average work experience is 13.1 ± 9.6 (3-22) years. The comparison group included 65 employees working in the management of the enterprise. The average age is 40.2 ± 9.8 (20-65) years. Average work experience is 18.5 ± 9.5 (5-23) years. Observation group - 292 oil and gas production operators (OGP) - 100% men. The study involved a comprehensive research program, results analysis, and mathematical modeling. Results. It is typical for oil and gas production operators to be exposed to a complex impact of harmful production factors: industrial noise, the intensity of work, and physical overload combined with chemical factors. A prior occupational risk to the employees under mentioned working conditions was classified from low (moderate) risk to medium (significant) risk. The age of employees with developed comorbid pathology in the observation group was 31.7 ± 5.4 years, work experience in the specified working conditions was 4.6 ± 1.1 years; the age of workers in the comparison group was 35.4 ± 3.9 years, work experience was 7.4 ± 2.7 years. The results of functional studies have demonstrated a complex of abnormalities in workers with little expressed clinical symptomatology. Analysis of comorbid pathology showed an increase in n according to CIRS score, increasing the working experience among oil and gas operators. Conclusion. Comorbid pathology occurs in oil production workers within ten years of working experience under conditions of combined occupational and non-occupational factors. In the comorbid pathology development, both induced intrasystemic and intersystemic disorders significantly worsens the working life prognosis.

2013 PESA production and development review

2014 ◽  
Vol 54 (1) ◽  
pp. 451
Author(s):  
Geoff O'Brien ◽  
Monica Campi ◽  
Graeme Bethune
Keyword(s):  
Oil And Gas ◽  
Oil Production ◽  
Gas Production ◽  
Oil And Gas Development ◽  
Oil And Gas Production ◽  
North West ◽  
The North ◽  
Western Flank ◽  
Under Construction ◽  
Gas Fields

The boom in Australian oil and gas development continued in 2013, with record overall investment of $60 billion. This investment resulted from spending on the seven LNG projects under development, together with that on numerous other oil and gas developments. These projects are expected to collectively contribute up to 665 million barrels of oil equivalent (MMboe) to Australia’s oil and gas production, which totaled 513.8 MMboe in 2013. LNG, presently Australia’s seventh largest export, is likely to soon rival the nation’s largest export, iron ore. By the end of 2013, three of the LNG projects under construction—Gorgon, Queensland Curtis LNG (QCLNG) and Gladstone LNG (GLNG)—were more than 70% complete; first LNG will be before the end of 2014 for QCLNG and in 2015 for Gorgon, GLNG and Australia Pacific LNG (APLNG). The other three LNG projects—Wheatstone, Prelude and Ichthys—are close behind. These new LNG projects follow Pluto, Australia’s third LNG project, which commenced production in 2012. A full year of production from Pluto drove increased gas production in 2013. Woodside also completed the North Rankin redevelopment and continued development of the Greater Western Flank, both of which will extend the life of the North West Shelf (NWS) project. A number of other projects also commenced production. In the Carnarvon Basin, oil production began at Santos’s Fletcher-Finucane Field, and at BHP Billiton’s Macedon project, domestic gas production started. In the Timor Sea, PTTEP’s Montara Field began production of oil. In Victoria, the ExxonMobil Kipper-Turrum-Tuna project came online, with the production of gas from Tuna and oil from Turrum. Production of gas from Origin Energy’s Geographe Field (as part of the Otway Gas Project) commenced in mid-2013. Onshore oil production grew in 2013, with the Cooper-Eromanga Basin now producing more oil than any other onshore Australian basin. A major effort is underway to increase production from the western flank oil trend and to develop both the conventional and unconventional gas fields in the Cooper Basin. Spending on the development of new projects probably peaked in 2013 and there is growing concern about a dearth of future projects, with expansion of existing LNG projects and development of new projects being pushed back due to a combination of increased costs and growing international competition. There are also ongoing industry concerns about impediments to onshore gas exploration and development generally.

Designing Oil and Gas Exploration Strategy For The Future National Energy Sustainability Based on Statistical Analysis of Commercial Reserves and Production Cost in Indonesia

2018 ◽  
Vol 1 (1) ◽  
pp. 66-81
Author(s):  
Ahmad Abdul Azizurrofi ◽  
Dian Permatasari Mashari
Keyword(s):  
Production Cost ◽  
Oil And Gas ◽  
National Level ◽  
Oil Production ◽  
Gas Production ◽  
Oil Price ◽  
Production Costs ◽  
Energy Investment ◽  
Oil And Gas Production ◽  
The Future

Indonesia's declining oil production and rising domestic oil consumption have been a big issue for the last few decades which has turned Indonesia into a net oil importer from 2004 onward. The lack of exploration activities and other investments in oil and gas sector have resulted in the decline of Indonesia's oil production. This condition is a result of the plunge of global oil price which has fallen to its lowest level, i.e., US$43.14/Bbl (average oil price in 2016) over the last 12 years. The purpose of this paper is to analyze the distribution of oil and gas production in Indonesia along with the production cost. This analysis will allow investors to find and map working areas in Indonesia with potential commercial reserves while maintaining the lowest possible production costs. The approach of this empirical study is to divide Indonesia into 6 (six) geographical areas, namely Sumatera, Natuna Sea, Java, Kalimantan, Sulawesi and Papua. We have collected relevant data about commercial reserves and production cost from existing working areas. Our preliminary results depict that Kalimantan has the highest commercial reserves (i.e., 18.60 MMBOE per contract area) and Papua has the lowest production cost (i.e., US$3.24/BOE). Sulawesi, meanwhile, has the lowest commercial reserves (i.e., 5.39 MMBOE/Contract Area) and Natuna has the highest production cost (i.e., US$16.46/BOE). In summary, this study has shown that Eastern area of Indonesia might hold more oil and gas reserves which can be further managed by Contractor for the benefit of the Country. This study also recommends the Government of Indonesia to be aware of the condition of each working areas to maintain a sustainable oil and gas production on a National level and create attractiveness for investors in the future. Keywords: Commercial reserves, cost per barrel, energy, investment, production cost, working areas.

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