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Journal articles on the topic 'Of Petroleum and Natural Gas Engineering'

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Published: 4 June 2021

Last updated: 5 February 2022

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1

Schiff, Anshel J. "Petroleum and Gas Facilities." Earthquake Spectra 7, no. 1_suppl (October 1991): 81–89. http://dx.doi.org/10.1193/1.1585652.

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In the earthquake-affected area there are no natural-gas lines and a very limited number of petroleum-product lines. There is a petroleum line from Subic Bay to Clark Air Force Base; however, this line is some distance from the epicenter and was not damaged. Associated with the Port of San Fernando there are two lines used to unload petroleum products and transport them to nearby tank farms operated by several oil companies. Products are distributed by truck from the tank farms. There are no petroleum-processing facilities, such as refineries, in the area.

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2

Wang, Jian Guo, Hai Jie Zhang, Cui Cui Liu, and Li Xia Lou. "The Significance of Shale Gas Development in China." Advanced Materials Research 616-618 (December 2012): 767–69. http://dx.doi.org/10.4028/www.scientific.net/amr.616-618.767.

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China is facing a severe situation of energy resources. High oil dependency is seriously threatening our economy’s fast and stable development. The US has successfully achieved the commercial development of shale gas, which has decreased its oil dependency, and also contributed to its natural gas geology and petroleum engineering technology development. Both Chinese and U.S. geological experts predict that China has similar quantities of shale gas reserves as founded in the United States. This paper aims to clarify that producing shale gas resources has economic significance of energy security and environment protection, and scientific significance of promoting the further development of natural gas geology and petroleum engineering subjects.

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3

Moussavi, Massoum, and Motasem Al‐Turk. "Compressed Natural Gas and Liquefied Petroleum Gas as Alternative Fuels." Journal of Energy Engineering 119, no. 3 (December 1993): 168–79. http://dx.doi.org/10.1061/(asce)0733-9402(1993)119:3(168).

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4

Liu, Wei Fu, Shuang Long Liu, and Li Xin Sun. "Distribution and Accumulation of Energy Resources in Ordos Basin." Advanced Materials Research 912-914 (April 2014): 1621–24. http://dx.doi.org/10.4028/www.scientific.net/amr.912-914.1621.

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Ordos basin is prolific in petroleum, natural gas, and coal resources, and is an important energy base in our country. The petroleum distributes in Jurassic to be subjected by the eroding river valley and Triassic to be subjected by depositional system of delta. The natural gas distributes in Upper Paleozoic to be controlled by the delta depositional system and Lower Paleozoic to be controlled by the fossil weathered crusts. The coal distribute in Permo-Carboniferous, Triassic and Jurassic, which has been controlled by the turning stage of tectonism and palaeokarsts. The distribution of oil, gas and coals present the regulation in the basin, but the styles that the dissimilarity structure unit to places have the bigger difference. In order to reduce the exploration cost, the petroleum, natural gas and coals should carry on comprehensive exploration.

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5

Jin, Yingjie, Sachio Asaoka, Xiaohong Li, Kenji Asami, and Kaoru Fujimoto. "Synthesis of liquefied petroleum gas via methanol/dimethyl ether from natural gas." Fuel Processing Technology 85, no. 8-10 (July 2004): 1151–64. http://dx.doi.org/10.1016/j.fuproc.2003.11.039.

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6

Qin, Shengfei, Guoxiao Zhou, Zheng Zhou, and Yu Yang. "Geochemical characteristics of natural gases from different petroleum systems in the Longgang gas field, Sichuan Basin, China." Energy Exploration & Exploitation 36, no. 6 (March 15, 2018): 1376–94. http://dx.doi.org/10.1177/0144598718763902.

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Located in the Sichuan Basin, China, the Longgang gas field consists of three vertically developed petroleum systems with the Triassic Leikoupo Formation as a dividing interface. There is one marine petroleum system below the interface and one continental petroleum system above it. The marine petroleum system is composed of coal measures, the main source rock in the Longtan Formation, and marine reef reservoirs in the Changxing and Feixianguan formations. The continental petroleum system can also be subdivided into two sets. One is the Xujiahe petroleum system sourced from the Xujiahe coal measures in the Upper Triassic formation. The other is a Jurassic petroleum system that is sourced from Jurassic lacustrine black shales. The gas pools in the marine system contain H2S gas. The gases are very dry and the δ13C1 and δ13C2 values display less negative values with an average of −29.2 and −25.0‰, respectively. The gases are humic origin generated at highly to over mature stages from coal measures of the Longtan Formation. The natural gas in the continental petroleum system does not contain H2S. The natural gases from the Xujiahe petroleum system are mainly wet gases with a few dry gases, and belong to typical humic type sourced from coal measures of the Xujiahe Formation. All the gases from this Jurassic petroleum system are wet gases and the alkane gases show more negative carbon isotopic values typical of sapropels. These are derived from the lower Jurassic lacustrine black mudstone. The three sets of petroleum systems in the Longgang gas field are vertically well separated. Each system has its own source rock, and there are no gases from other sources despite multiple tectonic events in the past. The reservoirs had been in a relatively stable tectonic condition with excellent seals by cap rocks during the gas accumulation period.

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7

YAMAZAKI, Toyohiko. "Fundamental studies on recovery of petroleum and natural gas." Journal of The Japan Petroleum Institute 34, no. 3 (1991): 210–17. http://dx.doi.org/10.1627/jpi1958.34.210.

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8

Uri, Noel D., and Mohinder Gill. "Agricultural demands for natural gas and liquefied petroleum gas in the USA." Applied Energy 41, no. 3 (January 1992): 223–41. http://dx.doi.org/10.1016/0306-2619(92)90004-u.

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9

Dickinson, Richard R. "Fuel Oil." Energy Exploration & Exploitation 4, no. 2-3 (May 1986): 125–34. http://dx.doi.org/10.1177/014459878600400204.

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As the price of petroleum has increased, the power industry has displaced a great deal of more expensive petroleum and natural gas with coal and nuclear power. The petroleum industry has installed processing facilities to upgrade its heavy fuel oil to make lighter products. These two actions, when combined, have effectively resulted in producing clean products indirectly from coal. A profitable synfuels industry has been created by the refining and power industries without conscious direction on their part—and without government support. The net effect has been to substantially reduce demand for both crude oil and natural gas, stretching future supplies of petroleum energy. This displacement has contributed to the temporary bubble in natural gas and the present oversupply of crude oil, creating downward price pressures on both crude oil and products. Even so, fuel oil prices have remained relatively stable because the industry has installed sufficient capability through its refinery improvements to upgrade fuel oil into more clean products, thereby reducing production of heavy fuel oil. In the future, we can expect the interaction among these fuels to continue to exert their effects. Since there are many consumers who can use either natural gas or fuel oil, their prices will remain tied to each other. Fuel oil prices will set the upper limits to which the burner tip price of natural gas can rise. Conversely, natural gas prices will tend to set the floor under fuel oil prices.

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10

Ben'yaminovich, O. A. "Industrial processing of helium-containing natural gas and petroleum associated gas in Russia." Chemical and Petroleum Engineering 31, no. 2 (February 1995): 86–88. http://dx.doi.org/10.1007/bf01147380.

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11

Herndon, J. Marvin. "New concept on the origin of petroleum and natural gas deposits." Journal of Petroleum Exploration and Production Technology 7, no. 2 (July 23, 2016): 341–52. http://dx.doi.org/10.1007/s13202-016-0271-5.

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12

Lv, Zhi Kai, Dai Hong Gu, Shun Li He, Hai Yong Zhang, and Shao Yuan Mo. "Principles of Unsaturated Flow in Tight Gas Reservoirs." Advanced Materials Research 772 (September 2013): 761–64. http://dx.doi.org/10.4028/www.scientific.net/amr.772.761.

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The future of the energy sector in the coming years is expected to be significantly affected by unconventional gas resources. Flow through porous media has many applications in the chemical, petroleum, gas, and pulp and paper industries, as well as in soil remediation and material characterization. In petroleum and natural gas production, flow through porous media has significance in the production of gas and/or oil. There are many characteristics of tight reservoir rock resulting in high and complex water saturation such as tiny pore throat, poor sorting, high displacement pressure, and so on. The one hand, the gas seepage is affected by the slippage effect, resulting in the abnormal gas relative permeability. On the other hand, the residual water of the tight core is controlled by displacement pressure. This study is directly related to gas reservoir engineering and is specifically focused to obtain fundamental information for two phase flow through low permeability porous media (Tight Sand Gas).

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13

Michael, Harry A. "Venezuelan Gas Development." Energy Exploration & Exploitation 12, no. 2-3 (March 1994): 167–75. http://dx.doi.org/10.1177/014459879401200207.

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Petroleos de Venezuela, S.A. (PDVSA) is an international energy corporation wholly owned by the Republic of Venezuela, whose principal areas of activity are petroleum, bitumen, natural gas, coal and petrochemicals. The steady expansion of PDVSA's NATURAL GAS INFRASTRUCTURE IN Venezuela and the strong performance of its subsidiaries, has contributed to increase its operational and marketing flexibility, thus allowing it to evolve from a simple exporter of crude oil and refined products to an important supplier of Natural Gas Liquids (NGL) to the world's major energy markets. In this respect Corpoven one of PDVSA's affiliated Companies has made considerable progress with the expansion of its Eastern Venezuela Cryogenic Complex. In 1994 it will produce an incremental volume of 45 thousand barrels per day of natural gas liquids from gas pipe in from northern Monagas region. Also, it has programmed the installation of two other Criogenic Plants in the next ten years, and as a result NGL exports are expected to increase from 175 thousand barrels day in 1994 to 232 thousand barrels day in 1998. Plans are also well underway for Venezuela to become a major exporter of LNG towards the turn of the century. More specifically, at the end of 1992, another PDVSA subsidiary, Lagoven, reached an agreement with Exxon, Shall and Mitsubishi to develop the Cristobal Colon LNG project, which calls for the exploitation of vast reserves of natural gas located in the Gulf of Paria, in northeastern Venezuela. The projected LNG production is in the order of 6 million tons per year.

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14

Rahman, Md Anisur, Md Ariful Islam, and AKM Nazrul Islam. "Popularizing Liquefied Petroleum Gas (LPG) as an Alternative to Piped Natural Gas for Domestic Use: Bangladesh Perspective." Journal of Chemical Engineering 30, no. 1 (December 7, 2017): 16–20. http://dx.doi.org/10.3329/jce.v30i1.34792.

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The basic objective of this paper has been to carry out comparative cost analyses for popularizing Liquefied Petroleum Gas (LPG) as a commensurate alternative to piped natural gas for domestic use in Bangladesh. Costing of LPG in three alternative scenarios of LPG utilization-LPG in cylinder, LPG supply in pipeline network for certain area and LPG in reticulated system-have been studied. Pricing of LPG and piped natural gas for domestic use have also been studied so as to recommend cross-subsidy option in LPG pricing that involves raising the price of natural gas for domestic use in order to finance LPG for expected lowering of its price, thus ensuring its access to the common people of the country. Reticulated LPG option, a semi-automatic system, has been found to be suitable as an alternative to piped natural gas for domestic use in terms of cost, flexibility and safety consideration.Journal of Chemical Engineering, Vol. 30, No. 1, 2017: 16-20

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15

Noskova, Yu A., V. A. Kazakov, and M. A. Perederii. "Adsorption method for the recovery of hydrocarbons from natural gas and associated petroleum gas." Solid Fuel Chemistry 42, no. 6 (November 30, 2008): 349–53. http://dx.doi.org/10.3103/s0361521908060049.

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16

Sun, Wen Lei, Yi Ping Yuan, Yi Fang Zhong, Li He, and Jao Guo. "Research and Application on Reverse Design of Complicated Petroleum Aiguille." Advanced Materials Research 97-101 (March 2010): 4046–49. http://dx.doi.org/10.4028/www.scientific.net/amr.97-101.4046.

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The petroleum aiguille, whose capabilities directly affect the quality, speed and cost of artesian well, is the primary rock breaker in the petroleum and natural gas industry. This paper has researched the reverse design of imported and high-powered petroleum aiguille, including the numerical reverse design, the revivification of dimension, the finite element analysis of numerical model, the simulation of Numerical Control（NC）machining and so on. Through analyzing and redesigning the complicated parts of petroleum aiguille and numerical making server, the manufacturer could absorb quickly and develop the overseas advanced products, step up the development-level of petroleum exploitation facilities, and reduce the cost of petroleum exploitation.

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17

Ostendorf, David W., Sharon C. Long, Theodore H. Schoenberg, and Samuel J. Pollock. "Aerobic Biodegradation of Petroleum-Contaminated Soil: Simulations from Soil Microcosms." Transportation Research Record: Journal of the Transportation Research Board 1546, no. 1 (January 1996): 121–30. http://dx.doi.org/10.1177/0361198196154600114.

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The capacity of natural bacteria to aerobically degrade hydrocarbon vapors was measured and modeled to assess the potential of bioventing to reduce exhaust vapor treatment requirements at a petroleum spill site. Five sets of aerobic soil microcosms from the vadose zone of a Massachusetts Highway Department contaminated right-of-way were dosed with different initial petroleum vapor standard concentrations, then monitored by gas chromatographic analysis over a 55-day period. The five sets yielded an average maximum reaction rate of 20 μg/m3 (soil gas)-sec, which compared favorably with studies of light hydrocarbon vapor degradation in sandy soils from other sites. The calibrated rate was incorporated into a steady-state bioventing model that simulated the evaporation of 34 000 L of petroleum over a 170-year natural release period and an 8-year accelerated release period for 10-day residence time. Aerobic degradation for a 10-day residence time reduced exhaust vapor concentrations by over 100 percent for natural release rates, with a 13 percent reduction under accelerated conditions.

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18

Laine, Jorge, and Maria Tosta. "Basic Engineering of a Two-Stage Process for Co-Upgrading Natural Gas and Petroleum Coke." Advances in Chemical Engineering and Science 05, no. 02 (2015): 129–33. http://dx.doi.org/10.4236/aces.2015.52014.

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19

Lv, X. F. F., J. Gong, W. Q. Q. Li, B. H. H. Shi, D. Yu, and H. H. H. Wu. "Experimental Study on Natural-Gas-Hydrate-Slurry Flow." SPE Journal 19, no. 02 (June 27, 2013): 206–14. http://dx.doi.org/10.2118/158597-pa.

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Summary To better understand hydrate-slurry flow, a series of experiments was performed, including water, natural gas, and diesel oil, under 4-MPa system pressure and 1.25-m/s initial linear velocity. The experiments have been conducted in a high-pressure hydrate-flow loop newly constructed at China University of Petroleum (Beijing), and dedicated to flow-assurance studies. A focused-beam reflectance measurement (FBRM) probe is installed in this flow loop, which provides a qualitative chord length distribution (CLD) of the particles/droplets in the system. First, the influence of flow rate on the hydrate-slurry flow was discussed. Then, we studied other influencing factors—such as water cut and additive dosage—on the hydrate induction period and the CLD before/after hydrate formation. Third, a new correlation was fitted between the dimensionless rheological index n′ and water cut as well as additive dosage, according to these experimental data. Finally, a laminar-flow model for the prediction of the pressure drop for the quasisingle-phase hydrate slurry was established, and tested by comparison with the experimental results in this paper.

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20

Birky, Alicia K., John D. Maples, James S. Moore, and Philip D. Patterson. "Future World Oil Prices and the Potential for New Transportation Fuels." Transportation Research Record: Journal of the Transportation Research Board 1738, no. 1 (January 2000): 94–99. http://dx.doi.org/10.3141/1738-11.

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World petroleum demand is projected to continue increasing after the world enters the 21st century. The Energy Information Administration (EIA) forecasts low world oil prices for the indefinite future despite an expected 54 percent rise in consumption by the year 2020. In its reference case, EIA also assumes an 80 percent increase in Organization of the Petroleum Exporting Countries (OPEC) oil production over the same time period. In contrast to this, a popular world oil market projection model demonstrates that OPEC could increase its production profitability significantly by substantially slowing the rate of its expanded production. However, OPEC’s potential market control also is influenced by the prospective availability of fuels produced from natural gas, especially remote unconventional natural gas resources. The unconventional natural gas resource is potentially enormous compared with all other fossil fuels combined. Considerations of energy security, greenhouse gas curtailment, emissions control, and cost will act to dictate widespread production and use of these unconventional reserves. Estimates are provided for the amount of alternatives that might be available at various oil prices. Because of cost considerations, much of this added production is likely to occur outside the United States.

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21

Huo, Rong, and Kai Bo Duan. "Research Status and Trend of Natural Gas Hydrate in China." Advanced Materials Research 978 (June 2014): 165–68. http://dx.doi.org/10.4028/www.scientific.net/amr.978.165.

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With the further development of national economy, people have become more concerned about the environment quality. Especially in recent years, due to the frequent occurrence of hazy weather, there has been a growing demand for clean energy [Fig. 1]. As one kind of non-conventional energy, natural gas hydrate, featured by large reserves and relatively clean products of combustion, is considered by the scientific community to be an alternative energy resource in replacement of coal and petroleum. This paper gives a brief introduction of the research progress of natural gas hydrate both at home and abroad, presents the research results and the obstacles in the next step to be taken for China, and then looks into the future development trend.

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22

Jin, Zhijun, Guoping Bai, and G. Ali Mansoori. "An introduction to petroleum and natural gas exploration and production research in China." Journal of Petroleum Science and Engineering 41, no. 1-3 (January 2004): 1–7. http://dx.doi.org/10.1016/s0920-4105(03)00138-4.

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23

Kandlikar, Satish G., Jacqueline Sergi, Jacob LaManna, and Michael Daino. "Hydrogen Horizon." Mechanical Engineering 131, no. 05 (May 1, 2009): 32–35. http://dx.doi.org/10.1115/1.2009-may-3.

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This review focuses on the role of hydrogen technologies in transition from petroleum production to new fuel to power transportation system. At present, the looming crisis caused by the decline in petroleum production and the need to control greenhouse gas emissions exemplifies the need for new energy solutions. The key component of a hydrogen-powered transportation sector will be the proton exchange membrane (PEM) fuel cell. PEM fuel cells use hydrogen and oxygen to generate electricity, with water and heat as by-products of the electro-chemical reaction. The review also discusses that to compete favorably with internal combustion engines and hybrid cars, PEM fuel cells need to address several issues, including performance, durability, and cost. Hydrogen from natural gas could provide a firm stepping stone as the energy system evolves away from petroleum.

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24

Tussing, A. R. "Natural Gas: Fuel of the Decade and Bridge to the Millennium." Energy Exploration & Exploitation 10, no. 2 (April 1992): 112–23. http://dx.doi.org/10.1177/014459879201000208.

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Despite a secure supply, economic advantages and environmental benefit, North American energy use has not significantly shifted from the traditional use of petroleum, coal and nuclear fuels. Electrical generation is a case in point where combustion turbines and their combined cycle variants are superior to the coal and nuclear fuelled equivalents. The reasons for natural gas not having a greater market share include an absence of confidence in the adequacy of the supply and an affordable cost.

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25

Gaganis, Vassilis, Dirar Homouz, Maher Maalouf, Naji Khoury, and Kyriaki Polychronopoulou. "An Efficient Method to Predict Compressibility Factor of Natural Gas Streams." Energies 12, no. 13 (July 4, 2019): 2577. http://dx.doi.org/10.3390/en12132577.

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The gas compressibility factor, also known as the deviation or Z-factor, is one of the most important parameters in the petroleum and chemical industries involving natural gas, as it is directly related to the density of a gas stream, hence its flow rate and isothermal compressibility. Obtaining accurate values of the Z-factor for gas mixtures of hydrocarbons is challenging due to the fact that natural gas is a multicomponent, non-ideal system. Traditionally, the process of estimating the Z-factor involved simple empirical correlations, which often yielded weak results either due to their limited accuracy or due to calculation convergence difficulties. The purpose of this study is to apply a hybrid modeling technique that combines the kernel ridge regression method, in the form of the recently developed Truncated Regularized Kernel Ridge Regression (TR-KRR) algorithm, in conjunction with a simple linear-quadratic interpolation scheme to estimate the Z-factor. The model is developed using a dataset consisting of 5616 data points taken directly from the Standing–Katz chart and validated using the ten-fold cross-validation technique. Results demonstrate an average absolute relative prediction error of 0.04%, whereas the maximum absolute and relative error at near critical conditions are less than 0.01 and 2%, respectively. Most importantly, the obtained results indicate smooth, physically sound predictions of gas compressibility. The developed model can be utilized for the direct calculation of the Z-factor of any hydrocarbon mixture, even in the presence of impurities, such as N 2 , CO 2 , and H 2 S, at a pressure and temperature range that fully covers all upstream operations and most of the downstream ones. The model accuracy combined with the guaranteed continuity of the Z-factor derivatives with respect to pressure and temperature renders it as the perfect tool to predict gas density in all petroleum engineering applications. Such applications include, but are not limited to, hydrocarbon reserves estimation, oil and gas reservoir modeling, fluid flow in the wellbore, the pipeline system, and the surface processing equipment.

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26

Bian, Hai Jun, Wen Dong Xu, Xiu Xi Li, and Yu Qian. "A Novel Natural Gas Liquids Recovery Process from Oil Field Associated Gas with LNG Cryogenic Energy Utilization." Advanced Materials Research 236-238 (May 2011): 820–24. http://dx.doi.org/10.4028/www.scientific.net/amr.236-238.820.

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A novel LNG cryogenic energy utilization process to recovery natural gas liquids from oil field associated gas is proposed. The proposed process uses the cryogenic energy of LNG and saves 62.6% of electricity, which is compared to the current electric refrigeration process. The proposed process recovers ethane, liquid petroleum gas (propane and butane) and heavier hydrocarbons, with total recovery rate of natural gas liquids up to 96.8%. Exergy analysis method is used to assess the new process. The results show that exergy efficiency of the new process is 44.3%, and compared to the current electric refrigeration process, exergy efficiency of the new process is improved by 16%. The proposed process has been applied in a conceptual design scheme of the cryogenic energy utilization and implemented for a 300 million tons/yr LNG receiving terminal in a northern Chinese harbor.

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27

Hu, P. S., M. Q. Wang, A. Vyas, M. Mintz, and S. C. Davis. "Potential Coverage of Alternative Fuel Industries under EPACT Section 501." Transportation Research Record: Journal of the Transportation Research Board 1520, no. 1 (January 1996): 147–55. http://dx.doi.org/10.1177/0361198196152000118.

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The Energy Policy Act (EPACT) has the goal of replacing 10 percent of transportation petroleum fuel with alternative fuels and replacement fuels by the year 2000 and 30 percent by 2010. Sections 501 and 507 of EPACT mandate use of alternative fuel vehicles (AFVs) in fleet applications. In particular, Section 501 requires that certain percentages of new light-duty vehicles (LDVs) acquired by alternative fuel providers be AFVs. The first step in estimating the effects of these mandates entails identifying affected fleets that are covered by the act. An assessment of potential fleet coverage of Section 501 is presented. This assessment concludes that a limited number of companies in the methanol, ethanol, propane, and hydrogen industries are likely to be covered by this mandate. On the other hand, many of the large crude-oil producers, petroleum refiners, natural-gas producers and transporters, and natural gas and electric utilities are likely to be subject to this mandate.

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Wang, Chia-Nan, Lei-Chuan Lin, and Dhanabalan Murugesan. "Analyzing PSU’s Performance: A Case from Ministry of Petroleum and Natural Gas of India." Mathematical Problems in Engineering 2013 (2013): 1–9. http://dx.doi.org/10.1155/2013/802690.

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The high economic growth in the past few years and increasing industrialization coupled with a burgeoning population have created a lot of concern for India’s energy scenario. India’s crude oil production has not shown significant growth in the last 10 or more years whereas its refining capacity has grown by more than 20% over the last 5 years. Oil consumption is growing at approximately 4.1% per year and natural gas consumption is growing at 68% per year. Therefore, evaluation performances and pushing energy companies to improve become important issues. The purpose of this research is of evaluation the performance of Indian energy industry under multiple different inputs and outputs criteria. The data envelopment analysis (DEA) and grey theory are used to conduct this study. There are total 14 public sector undertakings (PSUs) under this industry and no any private company. However, only 10 of them are mature enough to be published in India stock markets. Therefore, the realistic data of all 10 companies are used for this evaluation. The results demonstrate that Gas Authority of India Limited (GAIL), Chennai Petroleum Corporation Limited (CPCL), and Oil India Limited (OIL) are the top 3 of ranking influences. This integrated numerical study gives a better “past-present-future” insights into evaluation performance in India energy industry.

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29

Peredel’skii, V. A., Yu V. Lastovskii, R. V. Darbinyan, A. I. Savitskii, and A. A. Savitskii. "Analysis of the desirability of replacing petroleum-based vehicle fuel with liquefied natural gas." Chemical and Petroleum Engineering 41, no. 11-12 (November 2005): 590–95. http://dx.doi.org/10.1007/s10556-006-0024-2.

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30

Jaric, Marko, Sanja Petronic, Nikola Budimir, Aurel Valentin Bîrdeanu, and Srdajn Tadic. "Inspection and Repair Quality Plan of Regeneration Gas Heater." Advanced Materials Research 1157 (February 2020): 149–53. http://dx.doi.org/10.4028/www.scientific.net/amr.1157.149.

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Gas heaters used in oil and petrol industry transfer heat to the produced gas stream. Heaters are especially used when producing natural gas or condensate to avoid the formation of ice and gas hydrates. In this work, the inspection practices for process heaters used in petroleum refineries and petrochemical plants is presented as well as critical places for crack formation. After the inspection of the Regeneration Gas Heater the cracks were found and immediately repaired. The inspection is performed using visual, liquid penetrant and ultrasonic testing. The inspection and plan repair by welding is covered according to API 573:2013 and ASME IX:2017. In this work, the results before and after repair are presented and discussed.

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31

Evans, P. R. "Australia's Potential for Petroleum." Energy Exploration & Exploitation 4, no. 4 (August 1986): 255–83. http://dx.doi.org/10.1177/014459878600400402.

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The viability and direction of future exploration for petroleum in Australia appear to have been set, particularly by the results of the petroleum industry's endeavours over the past four years. The limited local markets for the abundance of natural gas, with which Australian basins are characterised, will control the direction and rate of exploration for many years. Even so, the local markets for petroleum should provide a continued incentive to search for oil. The Gippsland Basin is at a mature stage of exploration, and a replacement for it is still required in order that Australia maintain its present position of supplying the bulk of its needs for crude oil into the 1990s. Sectors of the Timor Sea are the most likely areas of relatively untested continental shelf to produce the requisite large fields. The previously disregarded Mesozoic plays of the Eromanga Basin hold promise for continued small discoveries that cumulatively may provide a substantial contribution to the nation's needs. The Canning Basin is the most promising of the still generally non-productive basins, but realisation of its potential will be expensive.

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32

Shehata, Walaa M., Ahmed A. Bhran, Abeer M. Shoaib, Ashour A. Ibrahim, and Fatma K. Gad. "Liquefied petroleum gas recovery enhancement via retrofitting the refrigeration system of an existing natural gas liquid plant." Asia-Pacific Journal of Chemical Engineering 14, no. 2 (February 7, 2019): e2292. http://dx.doi.org/10.1002/apj.2292.

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33

Riazi, M. R., and Y. A. Roomi. "Potential Approaches Toward Characterization and Property Estimation of Heavy Petroleum Fluids and Natural Gas Systems." Petroleum Science and Technology 26, no. 18 (December 2008): 2159–69. http://dx.doi.org/10.1080/10916460701429548.

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34

McAlexander, Benjamin L. "Feasibility of greenhouse gas emissions offsets for natural source zone depletion of petroleum hydrocarbons." Remediation Journal 29, no. 2 (February 28, 2019): 53–62. http://dx.doi.org/10.1002/rem.21592.

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Aina, Adebayo. "The Impact of New Technologies on Nigeria's Oil Reserves." Energy Exploration & Exploitation 11, no. 5 (October 1993): 414–22. http://dx.doi.org/10.1177/014459879301100502.

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Two key technological developments in petroleum exploration - three dimensional seismic survey (3-D Seismic) and integrated seismic interpretation workstations - have led to significant discoveries of oil and gas in the various Nigerian oil provinces where they have been introduced. These new technologies were introduced in Nigeria in the mid-1980s and have since resulted in significant additions to the country's proven crude oil and natural gas reserves.

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36

Willman, Bert, and Amyn S. Teja. "Prediction of dew points of semicontinuous natural gas and petroleum mixtures. 2. Nonideal solution calculations." Industrial & Engineering Chemistry Research 26, no. 5 (May 1987): 953–57. http://dx.doi.org/10.1021/ie00065a018.

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Arutyunov, Vladimir S., Valery I. Savchenko, Igor V. Sedov, Alexey V. Nikitin, Ilya G. Fokin, Iren A. Makaryan, Parvaz K. Berzigiyarov, and Sergey M. Aldoshin. "Perspective tendencies in development of small scale processing of gas resources." Pure and Applied Chemistry 89, no. 8 (July 26, 2017): 1033–47. http://dx.doi.org/10.1515/pac-2016-1203.

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AbstractThis paper analyses alternative routes for production of chemicals from different hydrocarbon gases by their direct, without syngas production, oxidative conversion to oxygenates or ethylene. Main of these routes are direct oxidation of methane to methanol (DMTM) and selective oxy-cracking of heavier natural or associated petroleum gas components which can be used for production of high value-added petrochemicals (in combination with carbonylation processes) and fuel gases, useful for gas piston engines. The advantages and practical capabilities of such technologies are discussed.

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Ellis, A. J. "Changing Efficiencies in Petroleum Energy Use in New Zealand." Energy Exploration & Exploitation 13, no. 2-3 (May 1995): 187–98. http://dx.doi.org/10.1177/0144598795013002-309.

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The paper introduces the work of the Energy Efficiency and Conservation Authority relating to gas and petroleum usages, with the dual imperatives to gain technical and economic efficiencies; and to reduce greenhouse gas emissions. Factors inhibiting greater efficiency include current investments, competition for new investment capital, price structures, and public attitudes. The current usage of petroleum products is presented with trends in sectors. Current gas use, from our history of development, wastes resources and produces high carbon dioxide emissions. Alternative trends can gradually be imposed to improve efficiency and lower environmental effects. Particular opportunities are in substituting direct use of natural gas and cogeneration for gas-fired electricity generation. There is a continuing upward trend in transport fuel use. Changing utilisation efficiencies in various modes of transport are reviewed and compared with overseas trends. While some progress has been made, considerable further improvement is possible by implementing regulatory, behavioural, and technical changes. The rising diesel and petrol usage relating to CNG and LPG is of concern. Overall, improvements in energy efficiency in New Zealand do not compare well with most OECD countries, but there are some positive trends in a number of sectors. The scope for improved efficiencies in New Zealand from newer technologies is reviewed with respect to domestic, commercial, industry and transport sectors. Means are outlined for taking opportunities with today's technologies through changing attitudes, standards, improved design of buildings, improved industrial processes, and financial packaging.

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Yevi, G. Y., and R. E. Rogers. "Storage of Fuel in Hydrates for Natural Gas Vehicles (NGVs)." Journal of Energy Resources Technology 118, no. 3 (September 1, 1996): 209–13. http://dx.doi.org/10.1115/1.2793864.

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The need for alternative fuels to replace liquid petroleum-based fuels has been accelerated in recent years by environmental concerns, concerns of shortage of imported liquid hydrocarbon, and congressional prompting. The fact is accepted that natural gas is the cheapest, most domestically abundant, and cleanest burning of fossil fuels. However, socio-economical and technical handicaps associated with the safety and efficiency of on-board fuel storage inhibit its practical use in vehicles as an alternative fuel. A concept is presented for safely storing fuel at low pressures in the form of hydrates in natural gas vehicles. Experimental results lead to gas storage capacities of 143 to 159 volumes/volume. Vehicle travel range could be up to 204 mi. Controlled decomposition rate of hydrates is possible for feeding an automotive vehicle. Upon sudden pressure decrease in the event of a vehicle accident, the rate of release of hydrocarbons from the hydrates at constant temperature is 2.63 to 12.50 percent per min, slow enough to prevent an explosion or a fireball. A model is given for predicting the rates of gas release from hydrates in a vehicle wreck. A storage tank design is proposed and a process is suggested for forming and decomposing hydrates on-board vehicles. A consistent fuel composition is obtained with hydrates.

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Wang, Yueming, Jianqun Wu, Xiaolong Li, Dunxi Yu, Minghou Xu, and Jost O. L. Wendt. "Ash aerosol partitioning and ash deposition during the combustion of petroleum coke/natural gas mixtures." Fuel 256 (November 2019): 115982. http://dx.doi.org/10.1016/j.fuel.2019.115982.

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Katz, H. R. "A Historical Review of Petroleum Exploration in New Zealand." Energy Exploration & Exploitation 6, no. 2 (April 1988): 89–103. http://dx.doi.org/10.1177/014459878800600203.

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Active exploration for petroleum in New Zealand is over 120 years old. While some sporadic, commercial production was obtained already in the earliest part of this century, exploration until 1920 was entirely guided by the occurrence of natural seepages. 1925–1944 was the first period of scientifically-oriented exploration, spurred particularly by the requirements of the second World War. In 1955 began the present period of more intensified prospecting, which in 1965 extended to New Zealand's very large ofshore area. The onshore Kapuni gas/condensate field was discovered in 1959, and the giant offshore Maui field in 1969. Production started in 1970 and 1979, respectively. Exploration enormously increased and expanded all over the country in the late 1960's and early 1970's, with concession holdings reaching a record high in 1970/71:131,673 km2 onshore and 1,003,669 km2 offshore. But a sharp decline followed in the mid-late 1970's, which was partly Government-induced and political, partly due to a prolonged lack of success. A change of Government policy in 1980 started a new cycle of intense exploration, with enthusiasm rapidly fuelled by a string of new, though small discoveries in Taranaki onshore, and, in 1986/87, by what is believed to be a large oil and gas discovery in Taranki offshore. Drilling activity has reached record levels over the last years, while exploration in general is branching out again to many other areas and basins, outside Taranaki. Total production in 1986 amounted to 4,546 million m3 of gas (plus 744 million m3 re-injected), 1.208 million m3 of condensate, 186,700 m3 of LPG and smaller amounts of natural gasoline and butane, and 0.501 million m3 of oil.

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Qyyum, Muhammad Abdul, Kinza Qadeer, Le Quang Minh, Junaid Haider, and Moonyong Lee. "Nitrogen self-recuperation expansion-based process for offshore coproduction of liquefied natural gas, liquefied petroleum gas, and pentane plus." Applied Energy 235 (February 2019): 247–57. http://dx.doi.org/10.1016/j.apenergy.2018.10.127.

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43

Mousavi Dehghani, S. A., M. Vafaie Sefti, and G. A. Mansoori. "Simulation of Natural Depletion and Miscible Gas Injection Effects on Asphaltene Stability in Petroleum Reservoir Fluids." Petroleum Science and Technology 25, no. 11 (November 27, 2007): 1435–46. http://dx.doi.org/10.1080/10916460600695264.

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44

Barakat, H. Z., M. M. Kamal, H. E. Saad, and B. Ibrahim. "Blending effect between the natural gas and the liquefied petroleum gas using multiple co- and cross-flow jets on NOx emissions." Ain Shams Engineering Journal 10, no. 2 (June 2019): 419–34. http://dx.doi.org/10.1016/j.asej.2019.01.006.

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Wu, Chuan Yan. "Energy Usage Structure Adjustment in Kern River Oilfield and Illumination for Self-Used Oil Substitution in Chinese Oilfield." Advanced Materials Research 962-965 (June 2014): 1599–603. http://dx.doi.org/10.4028/www.scientific.net/amr.962-965.1599.

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The substitution of the crude oil for private use in Chinese oilfield is one of the reducing oil production costs and relieving oil shortage ways. This paper introduced the energy usage adjustment and its contribution on energy saving in Kern River oilfield, as well as analyzed the advantage of using natural gas, coal, petroleum coke and renewable resources to replace the self-used oil in Chinese oil field.

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46

Vieira, Lenise, Maria Buchuid, and Elizabete Lucas. "The influence of pressure and dissolved gases in petroleum on the efficiency of wax deposition inhibitors." Chemistry & Chemical Technology 2, no. 3 (September 15, 2008): 211–15. http://dx.doi.org/10.23939/chcht02.03.211.

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Evaluations of wax inhibitors carried out in laboratories are generally performed on stabilized oil samples, that is, without the presence of natural gas and at atmospheric pressure. Therefore, the effects of two important factors that influence wax solubility – the light fractions and temperature – are not considered, and the results may not reflect what really happens in production lines and facilities. This work evaluates the efficiency of two wax inhibitors based on ethylene copolymer and vinyl acetate, at four concentrations, in a sample of paraffinic oil in the presence of light fractions and under pressure. The parameter employed in the evaluation was the wax appearance temperature (WAT), or the cloud point, determined by high-pressure differential scanning calorimetry. The gas used was a mixture of eight components and the tests were run at three pressures. In general, the inhibitors had little influence on the cloud point and a pronounced effect on the pour point and viscosity. In this case it was possible to observe changes in the WAT with both wax inhibitors in the tests conducted at atmospheric pressure up to 150 bar and in the presence of the multi-component gas mixture, suggesting that one of the mechanisms through which wax deposition inhibitors work is polynucleation.

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47

Ghose, M. K., and B. Paul. "A Perspective of Petroleum, Natural Gas, and Coal Bed Methane on the Energy Security of India." Energy Sources, Part B: Economics, Planning, and Policy 3, no. 4 (September 30, 2008): 411–19. http://dx.doi.org/10.1080/15567240701620275.

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48

Uri, Noel D. "Estimating the agricultural demand for natural gas and liquefied petroleum gas in the presence of measurement error in the data." International Journal of Energy Research 18, no. 9 (December 1994): 783–97. http://dx.doi.org/10.1002/er.4440180904.

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49

Saricks, Christopher L., Donald M. Rote, Frank Stodolsky, and James J. Eberhardt. "Alternatives to Diesel Fuel in California: Fuel-Cycle Energy and Emission Effects of Possible Replacements due to the Toxic Air Contaminant Diesel Particulate Decision." Transportation Research Record: Journal of the Transportation Research Board 1738, no. 1 (January 2000): 86–93. http://dx.doi.org/10.3141/1738-10.

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Limitations on the use of petroleum-based diesel fuel in California could occur pursuant to declaration by the California Air Resources Board (CARB) that the particulate matter component of diesel exhaust is a toxic air contaminant subject to the state’s Proposition 65. It is the declared intention of CARB not to ban diesel fuel, per se, at this time. Assuming no total ban, Argonne National Laboratory (ANL) explored two feasible “midcourse” strategies that result in some degree of (conventional) diesel displacement. In the first case, substantial displacement of compression-ignition (CI) by spark-ignition engines occurs and diesel fuel remains admissible for ignition assistance as a pilot fuel in natural gas–powered heavy-duty vehicles. Daily gasoline demand in California increases by 32.2 million L (8.5 million gal) overall, about 21 percent above the 2010 baseline demand projected by California’s energy and environmental agencies. Daily natural gas demand increases by 13.6 million diesel L (3.6 million gal) equivalents, about 7 percent above projected (total) consumption level. In the second case, CI engines utilize substitutes having similar ignition and performance properties for petroleum-based diesel. For each case, ANL estimated localized air emission plus generalized greenhouse gas and energy changes. Fuel replacement by dimethyl ether yields the greatest overall reduction in nitrogen oxide emissions. All scenarios bring about fine particulate matter (PM10) reductions relative to the 2010 baseline, with greatest reductions from the CI-displacement case and the least from fuel replacement by Fischer-Tropsch synthetic diesel. Institutional and cost implications of vehicle and engine replacement were not formally evaluated.

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Kornfield, Thomas, and Michael F. Lawrence. "Impacts on Home Heating Costs of Incentives for Alternative Fuel Vehicles." Transportation Research Record: Journal of the Transportation Research Board 1520, no. 1 (January 1996): 131–39. http://dx.doi.org/10.1177/0361198196152000116.

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Regulatory incentives for increased usage of alternative fuels in motor vehicles could have an impact on home heating costs, potentially increasing the price of natural gas and liquefied petroleum gas (LPG, or propane) while decreasing the price of home heating oil. The Alternative Fuels Trade Model (AFTM) is used to estimate these end-use cost impacts by comparing price results from two scenarios: a base case and an unconstrained case. The AFTM is a macroeconomic simulation model for determining prices and quantities that balance the interrelated world oil and gas markets given assumptions about supply, demand, and costs. Under the base case, alternative fuel usage is set at 5.5 percent of total light-duty motor vehicle fuel usage, while under the unconstrained case, alternative fuel-usage levels increase to 32 percent. All prices and expenditures are estimated for the year 2010 and are expressed in 1992 dollars. Increased usage of compressed natural gas (CNG) and LPG by alternative fuel vehicles as a result of either regulatory incentives or market forces will tend to increase annual natural gas and LPG home heating costs, while reducing distillate fuel-oil home heating costs. Per household, natural gas and LPG annual home heating costs are predicted to increase by $4.14 and $20.65, respectively, while annual distillate fuel-oil home heating costs are predicted to decrease by $3.17. The increase for LPG amounts to a 3.7 percent increase over the base case expenditures. These cost impacts are estimated at the national and regional levels and by income classification.

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