Academic literature on the topic 'Central Oil Stove Co'

In Ethiopia, the majority of rural household uses firewood with three-stone fire for cooking. Due to poor performance of the stove, there are major health issues created by indoor air pollution. To alleviate this problem, various efforts are undergoing such as the use of plant oil as an alternative fuel for cooking. This plant’s oils are available in the rural areas with minimal effort and water. In this study, Jatropha oil was blended with kerosene to present it as an alternative fuel for the rural poor in Ethiopia. The blends of varying proportions of Jatropha oil and kerosene were prepared, analyzed, and compared with the fuel properties of kerosene. The viscosity of Jatropha oil was reduced in ranges 86.3% to 4.5% by heating the oil from 30°C to 100°C. In order to understand the value of the blended fuel, the blended fuel was used for the evaluation of the performance of a stove for its thermal efficiency and indoor air pollution. Thermal efficiency of the newly designed bio-oil stove (Jatrok stove) was 52–66% with its specific fuel consumption ranging from 30 to 37 g/L and the fire power of the stove ranging from 1398 to 1433 watt using 10% to 40% Jatropha oil in the blend. In the case of emission, the Jatrok stove showed 11.5 to 9.5 grams of carbon monoxide (CO) and 352 to 289 grams of carbon dioxide (CO2) to boil 2.5 liters of water.The performance of the Jatrok stove using blended fuels was evaluated and compared with other domestic cooking stoves available in Ethiopia, making the stove comparable. A wider dissemination of such kind of plant oil blended with a kerosene-operated stove could reduce the environmental load in addition to lessoning the indoor air pollution in the kitchen.

Used cooking oil (Jelantah's oil) is a frying rest oil which can't be used again to fry because it contains compounds that are quite dangerous for human health, which can be destructive for humans healthy. Beside to reduce an ambient contamination, used cooking oil can be recycled as an alternative fuel, in this case as to replace kerosene. The purpose of this study was to determine the effect of the primary Air Fuel Ratio on the combustion process in pressurized stove oil and knowing whether or not the direct combustion process of used cooking oil as an alternative fuel. The filth on used cooking oil must be removed to avoid a streaming gagging on koil. Analyzing used cooking oil water rate. Fuel tank loaded with used cooking oil. Fill the compressor with an air to pressurize the fuel tank. Used cooking oil streamed inside the tank by manages flow rate then stream air with regulatory crane so up to scale which particular on flowmeter gases. Ruled air flow rate with scales regulatory crane flowmeter until up to stable state on appreciative given. Measuring temperature on burn tool with positioning different one (Spuyer, burner, burner's tip, kindled tip). The larger the primary Air Fuel Ratio, the better the mixing so that the total conversion of triglycerides into CO2 and CO products is greater. Used cooking oil may be directly used as an alternative fuel into an oil stove, especially pressured oil stove.

Waste oil empty palm fruit bunches (EFB) one of the renewable energy sources with great potential and is produced approximately 21% of the entire palm oil processing process. Burning EFB briquettes using biomass stoves has a low combustion efficiency, so it has the potential to emit CO. The aim of this research is to determine CO gas emissions resulting from burning empty palm fruit bunch briquettes with variations in the number of holes in the biomass stove and compare them with the quality standards of Minister of Energy and Mineral Resources Regulation No. 047 of 2006. and see how the effect of air hole openings on biomass stoves with empty palm fruit bunch briquettes. In this study, co emission test was conducted using environmental combustion analyzer type 450 and biomass stove performance using water boiling test method. Testing was conducted with variations of air hole openings L1 (3.51 cm2), L2 (7.03 cm2), and L3 (10.55 cm2). The results of CO gas testing obtained by L1, L2 and L3 are 523.54 mg/ Nm3, 425.59 mg/ Nm3, and 351.13 mg / Nm3 and still meet the quality standards of ESDM no. 047 of 2006. Thermal efficiency of briquette stoves obtained in L1, L2 and L3 are 26.51%, 24.28% and 22.28% and for specific consumption rates obtained in L1, L2 and L3 are 3.47 grams/minute, 5.54 grams/minute and 7.17 grams/minute, this result didn’t meet the quality standard of SNI 7926-2013. Based on the results of the study, it was concluded that the smaller the opening of the briquette stove air hole, the more CO emissions produced, the higher the thermal efficiency and the smaller the consumption rate.

Study was conducted on coco peat as a low emission pellet form biomass fuel alternative to produce synthetic gas (syngas) through gasification process in use for other processes. Coco peat was first screened and formulated with other materials such as coco peat, starch, and waste cooking oil. These materials were mixed and pelletized using a pelletizer to form coco peat pellet. It was burned on an updraft gasifier to produce synthetic gas (syngas) and then streamed to a stove through a pipe. The syngas was then split and burned and the heat generated was used for boiling water and for drying agricultural products. Air quality around the stove (emission test) was measured and analyzed when gasification took place. The best results of coco peat pellet were made from 85% of coco peat waste, 5% starch (binder), and 10% of waste cooking oil with stronger texture and shiny surface. The experimental gasification using updraft gasifier exhibited better result when half of the volume of gasifier was filled with 5 kg pellet and the syngas produced can be used for 3.5 hours drying and boiling. Air quality surrounding the stove was tested during gasification process. It was done based on the Indonesian Environmental Regulation issued by Indonesian the Ministry of Environment on Standards (KEP-13/MENLH/3/1995 dated March 7th, 1995) regarding standard air quality from static matter and covers NH3, Cl2, HCl, HF, NO2, particles, SO2 and H2S parameters. The result of measurements indicated that all parameters meet the quality standards) including CO and CO2 at 0.0001 mg/kg.

Eni Starts Area 1 Production off Mexico via MODEC FPSO MODEC said first oil has flowed through FPSO MIAMTE MV34 operating in the Offshore Area 1 block in the Bay of Campeche off Mexico. The contractor was appointed by Eni Mexico for the supply, charter, and operation of the FPSO in the Eni-operated Offshore Area 1 block in 2018. The charter contract will run for an initial 15 years, with options for extension every year thereafter up to 5 additional years. Moored in a water depth of approximately 32 m some 10 km off Mexico’s coast, the FPSO is capable of handling 90,000 B/D of oil, 75 MMcf/D of gas, and 120,000 B/D of water injection with a storage capacity of 700,000 bbl of oil. The FPSO boasts a disconnectable tower yoke mooring system, a first-of-its-kind design in the industry. The system was developed to moor the FPSO in shallow water, while also allowing the unit to disconnect its mooring and depart the area to avoid winter storms and hurricanes in the Gulf of Mexico. The mooring system was developed by MODEC subsidiary SOFEC Inc. The mooring jacket was fabricated in Altamira, Mexico. Eni Starts Production from Ndungu EP Development Italy’s Eni has started production from the Ndungu Early Production (EP) development in Block 15/06 of the Angolan deep offshore, via the Ngoma FPSO. With an expected production rate in the range of 20,000 B/D, the project will sustain the plateau of the Ngoma, a 100,000-B/D, zero-discharge, and zero-process-flaring FPSO, upgraded in 2021 to minimize emissions. A further exploration and delineation campaign will be performed in Q2 2022 to assess the full potential of the overall assets of Ndungu. Ndungu EP is the third startup achieved by Eni Angola in Block 15/06 in the past 7 months, after Cuica Early Production and the Cabaca North Development Project. Block 15/06 is operated by Eni Angola with a 36.84% share. Sonangol Pesquisa e Produção (36.84%) and SSI Fifteen Ltd. (26.32%) comprise the rest of the joint venture. Aramco Discovers Natural Gas in Four Regions Saudi Aramco has discovered natural gas fields in four regions of the kingdom, the Saudi Press Agency (SPA) reported, citing Energy Minister Prince Abdulaziz bin Salman. The fields were found in the Empty Quarter desert located in the central area of the kingdom, near its northern border and in the eastern region, he said, according to SPA. Saudi Arabia wants to increase gas production and boost the share of natural gas in its energy mix to meet growing electricity consumption and to make more crude available for export. The minister said an unspecified number of fields were discovered and he mentioned five by name: Shadoon, in the central region; Shehab and Shurfa, in the Empty Quarter in the southeastern region; Umm Khansar, near the northern border with Iraq; and Samna in the eastern region. Two of the gas fields, Samna and Umm Khansar, were said to be “nonconventional” and possibly shale finds. Lukoil Completes Area 4 Deal in Mexico Russian producer Lukoil has completed a deal to become a lead stakeholder in an Area 4 shallow-water asset adjacent to Tabasco and Campeche in Mexico. Under the deal, Lukoil has acquired a 50% stake in the asset from US independent Fieldwood Energy, which filed for US bankruptcy protection in August 2020, for $685 million. The original deal was priced at $435 million; the additional $250 million is related to expenditures Fieldwood incurred since 1 January 2021. Fieldwood committed to invest $477 million to increase oil production from the Ichalkil and Pokoch fields from the current level of 25,000 B/D to a plateau level of 115,000 B/D. Situated in water depths between 35 and 45 m, the fields’ recoverable hydrocarbon reserves amount to 564 million BOE, more than 80% of which is crude oil. Production started in Q4 2021; current average oil production has exceeded 25,000 B/D. The approved work program includes drilling three development wells (two on Ichalkil and one on Pokoch), upgrading three production platforms, and performing seismic reprocessing and petrophysical studies. The remaining 50% stake in Area 4 is held by operator PetroBal, a subsidiary of Mexico’s GrupoBal. Petrobras Sells Polo Norte Capixaba Field Cluster In line with its strategy to concentrate resources on deepwater and ultradeepwater assets, Brazil’s Petrobras has sold 100% of its interest in Norte Capixaba cluster to Seacrest Exploração e Produção de Petróleo Ltda for $544 million, including a $66-million contingent payment. The cluster comprises four producing fields—Cancã, Fazenda Alegre, Fazenda São Rafael, and Fazenda Santa Luzia—and produced 6,470 BOE/D in 2021. The deal also includes the Norte Capixaba Terminal (TNC) and all production facilities. NewMed Targets Morocco Market Entry Israel-based NewMed Energy, formerly Delek Drilling, has identified Morocco as “a country with enormous geological and commercial potential,” in particular the Moroccan coastal areas in the Mediterranean and North Atlantic. The announcement comes a day after the Moroccan Minister of Industry and Trade, Ryad Mezzour, and his Israeli counterpart, Orna Barbivai, signed an MOU aimed at promoting investments and exchanges between the two countries in the digital design, food, automotive, aviation, textile, water technologies and renewable energies, medical equipment, and the pharmaceutical industries. In September 2021, the Israeli oil and gas exploration company obtained from the Moroccan ministry the exploration and study rights of the Dakhla Atlantic Block, which has an area of about 109000 km2. ExxonMobil Sells Nigerian Assets to Seplat ExxonMobil has agreed to sell its shallow-water assets in Nigeria to Seplat Energy for $1.28 billion plus a contingent consideration of $300 million. Seplat said it is acquiring a 40% operating stake in four oil leases to nearly triple its annual net production to 146,000 BOE/D. The deal also includes the Qua Iboe export terminal and a 51% interest in the Bonny River Terminal and natural gas liquids recovery plants at EAP and Oso. It does not include any of ExxonMobil’s deepwater fields in Nigeria. TotalEnergies Discovers Large Oil Field off Namibia TotalEnergies has made a significant discovery of light oil with associated gas on the Venus prospect, located in block 2913B in the Orange Basin, offshore southern Namibia. The Venus 1-X well encountered approximately 84 m of net oil pay in a good-quality Lower Cretaceous reservoir. The find’s potential reserves are estimated at 2 billion bbl of oil. “This discovery offshore Namibia and the very promising initial results prove the potential of this play in the Orange Basin, on which TotalEnergies owns an important position both in Namibia and South Africa,” said Kevin McLachlan, senior vice president exploration at TotalEnergies. “A comprehensive coring and logging program has been completed. This will enable the preparation of appraisal operations designed to assess the commerciality of this discovery.” Block 2913B covers approximately 8215 km2 in deep offshore Namibia. TotalEnergies is the operator with a 40% working interest, alongside QatarEnergy (30%), Impact Oil and Gas (20%), and NAMCOR (10%). CNPC Scoops Ishpingo Drilling Contract The first drilling contract at the Ishpingo oil field near Ecuador’s Yasuni National Park has been awarded to China National Petroleum Corp. (CNPC), Energy Minister Juan Carlos Bermeo told Reuters. Following the approval of a new hydrocarbon law and legislation, Ecuador plans to move forward with auctions and competitive processes for securing foreign and domestic capital for oil and gas exploration, production, transportation, and refining projects. The first drilling campaign to start after an environmental license was granted for the sensitive area will involve 40 wells over the next 18 months. It will focus on the field’s allowed zone without touching an area protected by a court ruling that has prevented extending drilling. Ishpingo is the latest part of the ITT-43 oil field in Ecuador’s Amazonia region to start drilling after Tambococha and Tiputini. It is expected to produce heavy oil to be added to the nation’s output of flagship Napo crude, Bermeo said. BP Brings Hershel Expansion Project On Line in US GOM BP has successfully started production from the Herschel Expansion project in the Gulf of Mexico—the first of four major projects scheduled to be delivered globally in 2022. Phase 1 comprises development of a new subsea production system and the first of up to three wells tied to the Na Kika platform in the Mississippi Canyon area. At its peak, this first well is expected to increase platform annual gross production by an estimated 10,600 BOE/D. The BP-operated well was drilled to a depth of approximately 19,000 ft and is located southeast of the Na Kika platform, approximately 140 miles off the coast of New Orleans. The project provides infrastructure for future well tie-in opportunities. BP and Shell each hold a 50% working interest in the development. Petrobras Kicks off Gulf of Mexico Asset Sales Petrobras has begun an asset sale program in the Gulf of Mexico, in line with the company’s strategy of debt reduction and pivot toward Brazilian deepwater production. The package for sale includes the company’s 20% stake in MP Gulf of Mexico (MPGoM) which holds ownership stakes in 15 fields in partnership with Murphy Oil. In addition to partnership-operated fields, MPGoM owns nonoperated interests in Occidental’s Lucius, Kosmos’ Kodiak, Shell’s Habanero, and Chevron’s St. Malo fields. During the first half of 2021, Petrobras’ share of production was 11,300 BOE/D. ExxonMobil Liza Phase 2 Underway off Guyana ExxonMobil started production of Liza Phase 2, Guyana’s second offshore oil development on the Stabroek Block; total production capacity is now more than 340,000 B/D in the 7 years since the country’s first discovery. Production at the Liza Unity FPSO is expected to reach its target of 220,000 bbl of oil later this year. The Stabroek Block’s recoverable resource base is estimated at more than 10 billion BOE. The current resource has the potential to support up to 10 projects. ExxonMobil anticipates that four FPSOs with a capacity of more than 800,000 B/D will be in operation on the block by year-end 2025. Payara, the third project in the block, is expected to produce approximately 220,000 BOPD using the Prosperity FPSO vessel, currently under construction. The field development plan and application for environmental authorization for the Yellowtail project, the fourth project in the block, have been submitted for government and regulatory approvals. The Liza Unity arrived in Guyana in October 2021. It is moored in water depth of about 1650 m and will store around 2 million bbl of crude. ExxonMobil affiliate Esso Exploration and Production Guyana Ltd. is the operator and holds 45% interest. Hess Guyana Exploration Ltd. holds 30% interest and CNOOC Petroleum Guyana Ltd. holds 25%. Dragon Finds Oil in Gulf of Suez UAE’s Dragon Oil has discovered oil in the Gulf of Suez, according to a statement from the Egyptian Minister of Petroleum and Mineral Resources. The field contains potential reserves of around 100 million bbl inside the northeastern region of Ramadan. That estimate makes it one of the largest oil finds in the region over the past 2 decades. Development plans were not reported but reserve numbers could expand, the ministry said. The oil field is the first discovery by Dragon Oil since it acquired 100% of BP’s Gulf of Suez Petroleum assets in 2019. Dragon Oil, wholly owned by Emirates National Oil Co., holds 100% interest in East Zeit Bay off the southern Gulf of Suez region. The 93-km2 block lies in shallow waters of 10 to 40 m.

Residual oil zones (ROZs) could present a new, potentially large and commercially viable oil resource for Australia and provide an avenue for geological storage of carbon dioxide (CO2) through CO2 enhanced oil recovery (CO2-EOR). These reservoirs, which can contain a moderate amount of residual oil and resemble water-flooded oil fields, can be associated with conventional fields (brownfields) or occur with no associated main pay zone (greenfields). Both types of ROZ are currently produced commercially through CO2-EOR in the Permian Basin, USA, and are of growing interest internationally, but our understanding of the occurrence and economic viability of oil production from ROZs in Australia is limited. We are employing geological and petrophysical methods to identify, map and quantify the potential oil resources of ROZs, initially in central Australian basins. Complementing this, we are conducting a series of CO2 core-flooding experiments combined with reservoir modelling to investigate the techno-economic feasibility of producing oil and storing CO2 in these formations. We aim to establish and test a workflow for characterising and evaluating ROZs in Australia. ROZs could prove to be good targets for CO2-EOR+, potentially even producing carbon-neutral or carbon-negative oil by using CO2 from anthropogenic sources, such as from blue hydrogen production.

Field work undertaken in central East Greenland during August 1985 was a follow-up of the oil geological studies by GGU expeditions to Jameson Land in 1982 and 1983 (Surlyk, 1983; Surlyk et al., 1984a). Three major subjects were covered by the field work. The Permian-Triassic boundary was studied along the western margin of the Jameson Land basin (Surlyk et al., 1984b). A series of closely sampled sections along the exposures of the eastern part of the Schuchert Dal was completed. The sampled material will be analysed with respect to source rock quality, maturity and stratigraphy. Secondly, the analysis of the regional maturity in southern Jameson Land based on the material from the 1982-83 expeditions indicates a specific surface maturation pattern (Piasecki, 1985; Thomsen, 1985) which had to be confirmed or rejected by analyses of further material from localities throughout the area. New material was collected along Hurry Inlet and in the southern llnd western parts of Jameson Land. Maturity studies will be supplemented by stratigraphical and geochemical analyses at these localities. The third target of the field work was to start oil geological studies of the area north of Kong Oscar Fjord, and to locate drill sites for shallow-core drilling in immature potential source rocks. The island of Traill ø was visited for two days of helicopter reconnaissance. Wollaston Forland was visited for two days at the end of the season in co-operation with geologists of a British Petroleum (BP) party working in this area. Material was collected for preliminary source rock studies and biostratigraphy.

Olive co-processing consists of the addition of ingredients either in the mill or in the malaxator. This technique allows selecting the type of olives, the ingredients with the greatest flavoring and bioactive potential, and the technological extraction conditions. A new product—a gourmet flavored oil—was developed by co-processing olives with Thymus mastichina L. The trials were performed using overripe fruits with low aroma potential (cv. ‘Galega Vulgar’; ripening index 6.4). Experimental conditions were dictated by a central composite rotatable design (CCRD) as a function of thyme (0.4−4.6%, w/w) and water (8.3−19.7%, w/w) contents used in malaxation. A flavored oil was also obtained by adding 2.5% thyme during milling, followed by 14% water addition in the malaxator (central point conditions of CCRD). The chemical characterization of the raw materials, as well as the analysis of the flavored and unflavored oils, were performed (chemical quality criteria, sensory analysis, major fatty acid composition, and phenolic compounds). Considering chemical quality criteria, the flavored oils have the characteristics of “Virgin Olive Oil” (VOO), but they cannot have this classification due to legislation issues. Flavored oils obtained under optimized co-processing conditions (thyme concentrations > 3.5−4.0% and water contents varying from 14 to 18%) presented higher phenolic contents and biologic value than the non-flavored VOO. In flavored oils, thyme flavor was detected with high intensity, while the defect of “wet wood”, perceived in VOO, was not detected. The flavored oil, obtained by T. mastichina addition in the mill, showed higher oxidative stability (19.03 h) than the VOO and the co-processed oil with thyme addition in the malaxator (14.07 h), even after six-month storage in the dark (16.6 vs. 10.3 h).

The leaf and stem essential oils of Artemisia monosperma from the desert region of central Saudi Arabia were analysed by gas chromatography-based techniques (GC–FID, GC–MS, Co-GC, LRI determination, database and literature search) using polar as well as non-polar columns, which resulted in the identification of 130 components, of which 81 were common to both oils. In the leaf oil 120 compounds were identified, while 91 were identified in the stem oil accounting for 98.4% and 99.7% of the oil composition, respectively. The major constituents of the leaf oil were β-pinene (50.3%), α-terpinolene (10.0%), limonene (5.4%) and α-pinene (4.6%), while the major constituents of the stem oil were β-pinene (36.7%), α-terpinolene (6.4%), limonene (4.8%), β-maaliene (3.7%), shyobunone (3.2%) and α-pinene (3.1%). The two oils showed an important qualitative similarity. However, some specific constituents (39 in the leaf oil and 10 in the stem oil) allow differentiation of the two essential oils.

Chapter 5 identifies the core Arab concerns that preoccupied Riyadh between 1953 and 1962, when King Sa‘ud ruled. A tested hand, Yassin realized that Arab revolutions threatened the Sa‘udi monarchy and, relying on the Palestine Question, developed appropriate policies. Two fundamental questions are tackled here to better assess Riyadh’s critical contributions. How did the 1948 creation of the State of Israel redefine Arab dilemmas and were they ready to confront this existential challenge through joint political and defense mechanisms developed within the League of Arab States (LAS)? Arab revolutions that threatened Sa‘udi stability are assessed, especially the 1952 Nasir Coup in Egypt and how the latter goaded Sa‘udi officials to use oil as a political weapon. Riyadh pushed for the creation of its Tapline conduit, in part to circumvent the rise of the Nasir-inspired mobilizations against “imperialists,” and how Yassin navigated the Sa‘ud–Nasir relationships were major developments worthy of attention. Likewise, the serious ideological rivalries between Sa‘ud and Faysal, which were routinely used by foreign powers to meddle in internal Sa‘udi affairs, led the counselor to help save the day-by-day co-counseling both his sovereign and his long-time advisor. The chapter further assesses regional convulsions starting with the 1956 Suez War, the Eisenhower Doctrine, successive crises in Jordan and Lebanon, the formation of the United Arab Republic, and the Cold War in Arabia that culminated with the Ankara, Turkey-based Central Treaty Organization.

The greater McArthur Basin of northern Australia is a vast frontier exploration province for basin-hosted resources, both hydrocarbons (oil and natural gas) and metals (critical metals [e.g. rare earth elements, Co], Cu, Pb, Zn and Au). This basin system covers much of northern Australia and may have included much of North China that lay off northern Australia when the basin formed—ca. 1820–1325 Ma. Hydrocarbon and metal deposits in the basin are largely controlled by host sediment composition and ‘redox traps’ related to ancient water chemistry, which, in-turn, are modulated by biological activity, tectonism and relative sea level change. None of these controls are fully understood or constrained throughout the basin.

Abstract Oil demand continues to rise and is not projected to peak until at least 2030, according to the International Energy Agency, or possibly even later as per OPEC. Despite this, many publicly listed oil companies have announced aggressive emissions reduction targets. For instance, Canadian companies Cenovus and CNRL have committed to achieving net zero by 2050. Cenovus aims for a 35% absolute reduction of GHGs by 2035, and CNRL targets a significant reduction from oil sands operations by 2030. CEOs often cite the challenge of generating acceptable returns on emissions reduction projects as a major barrier to decarbonization, as reported by the Boston Consulting Group in 2023. Abatement technologies such as Carbon Capture, Usage, and Storage (CCUS) require substantial investment and are unlikely to yield positive returns for several years. Furthermore, they are expected to remain relatively small in scale and impact in the near to mid-term future, according to the World Economic Forum in 2023. The traditional and conventional method of heavy oil extraction in Alberta and Saskatchewan has been marked by inefficiencies, primarily due to low recovery rates that leave upwards of 90% of the resource untapped. The process is characterized by high emissions and significant capital investment, rendering the development of smaller deposits economically unfeasible. Heavy oil production typically necessitates a substantial upfront capital investment in large, permanent central facilities, leading to a planning horizon of five to ten years for the optimization of a steam plant and production installation. Additionally, securing regulatory approvals for land disturbance and water supply requires considerable time and effort.

Heat activated cooling provides an opportunity to recover and utilize wasted heat. In terms of thermal management of electronics, a heat-activated cooling cycle could be used to thermally manage a space such as a central computing facility. A microscale, fractal-like branching flow heat exchanger was designed and used to desorb ammonia from an aqueous ammonia solution. The fractal-like pattern employed in the present study was previously studied for high heat flux single-phase and two-phase boiling flow heat sink applications. For compatibility, the desorber was fabricated in 316 stainless steel. The desorber is compact, approximately 38 mm in diameter and 6.4 mm thick, and lightweight, weighing 20 grams. Heating was accomplished using Paratherm NF oil between 350 and 400 K. The mass fraction of ammonia in the strong solution inlet stream was 0.30 and the temperature was 300 K. Given a range of inlet solution mass flow rates between 0.42 and 0.92 g/s and oil flow rates between 1.67 and 10 g/s, the mass flow rate of vapor generated varied from 0.02 to 0.13 g/s. The mass fraction of ammonia in the exiting vapor stream varied between 0.8 and 0.96 while circulation ratios varied between 3.5 and 20. Heat exchanger performance is presented using LMTD and ε-NTU analyses. Overall heat transfer coefficients ranged from 7500 to 15,000 for the flow rates and driving temperature differences investigated. The configuration of the desorbers is such that the oil stream can be introduced to flow parallel or counter to the ammonia solution stream. The nature of the microchannels is such that desorption occurs in a co-flowing manner, limiting the vapor mass fraction. However, the advantages of the present design are lightweight, compact, modularity and orientation independence.

The purpose of this study is to examine the movements of capital markets in Austria (ATX), Serbia (BELEX 15), Hungary (BUX), Croatia (CROBEX), Russia (IMOEX), the Czech Republic (PRAGUE PX), Slovenia (SBI TOP), and Po­land (WIG) from September 18th, 2017 to September 15th, 2022. To obtain more robust results, we divide the sample into two sub-periods: the Quiet period, from September 18th, 2017, to December 31st, 2019; and the Stress Period, from January 1st, 2020, to September 15th, 2022, marked by the global pandemic (COVID-19), the oil price war in 2020, and the Russian invasion in 2022. The time series exhibit non-normal distributions due to the presence of fat tails, a characteristic that is common in periods of extreme volatility. The results of the VAR Granger Causality/Block Exogeneity Wald Tests model verified the existence of 16 pairs of markets showing co-movements between them dur­ing the quiet subperiod. The market that causes more co-movements is the Austrian stock market (ATX), while the Russian stock index (IMOEX) does not cause shocks in the markets under analysis. In the Stress subperiod, we ver­ify the presence of 42 pairs of markets causing (each other in the Grangeri­an sense. The stock indexes ATX, BUX, CROBEX, and PRAGUE PX show 6 caus­al relations in 7 possible, while the capital markets of Russia (IMOEX) and Po­land are the ones that cause less (4 in 7 possible). In conclusion, we verify that the events that occurred in 2020 and 2022 have significantly increased the movements in these regional markets. Such findings could put into question the implementation of efficient portfolio diversification strategies and even­tually some gains above the market average due to arbitrage levels. The au­thors consider this evidence to be relevant for supervisors, regulators, and in­vestors operating in these regional markets.

Abstract Semut Field is a small brown field located in Central Sumatra basin produced since 1966 and waterflooded since 2009. Semut Field production has already depleted at 1/10 from its peak production and produced with high water cut. Earlier production strategy had been targeted at waterflooded thick and good permeability (~1 Darcy) reservoir and produced comingle. Deep dive and comprehensive analysis on G&G and rock properties on sand basis will be the answer to reveal any hidden opportunity on mature reservoir to increase oil production in Semut Field. The approach to increase oil production is done by using and analyzing new data from Carbon-Oxygen (CO) logs and new infill well in 2021 to map the unrevealed potential of remaining by-passed oil. This field opportunity is hidden in lower permeability thin sand (<300 mD) with limited distribution that was previously overlooked in wide scale stratigraphic analysis. Comprehensive analysis of high-resolution stratigraphy also could figure out some thin sand that separated from the main sand lobes in each formation. More analysis on historical production and completion of old wells that have thin sand opportunity should be done to find out the earlier sand performance. High-resolution stratigraphy approach analysis by layer sand is proven for revealing hidden opportunity in Semut Field. The remaining oil was found stored in a thin sand layer with perm ~200 mD which is lower than the average overall sand formation permeability. There are two main recommendations to unlock the opportunity at Semut Field based on the analysis result. First, completion strategy by selecting and precising perforation depth is critical since the separation between sand layer could only be between 2-3 ft shale. Second, production strategy by producing single or commingle with other sand that have similar PI and reservoir pressure. This approach gives outstanding results with oil gain 1,600 BOPD and oil cumulative 28 MBO within 1 month production, it is doubling Semut Field production. This effective approach could be an alternative strategy to be applied in other Mature waterflood field or Primary field. This is a good case of how workovers on old wells can increase oil production in cheap way and dramatically extended good economic life.

The present work is aimed at the experimental measurement of the two-phase heat transfer coefficient in the intermittent horizontal gas-liquid flow pattern, as well as its comparison with some existing correlations. The intermittent flow pattern is very common in oil production flow lines. In order to reach this objective an experimental apparatus was built, consisting of a 5 cm i.d., 6.0 m long pipe test section fed up with several air-water mixtures pre-heated at different inlet temperatures. Heat transfer was accomplished by surrounding the pipe with a cooling water jacket under various inlet flow rates and temperatures, flowing co-currently with the central pipe gas-liquid mixture. The heat transfer coefficient was experimentally determined and compared with four published correlations. Among then, a mechanistic model was selected for further improvement, with very satisfactory results.

Biofuels offer reduced CO2 emissions for both industrial and aero gas turbines. Industrial applications are more practical due to low temperature waxing problems at altitude. Any use of biofuels in industrial gas turbines must also achieve low NOx and this paper investigates the use of biofuels in a low NOx radial swirler, as used in some industrial low NOx gas turbines. A waste cooking oil derived methyl ester biodiesel (WME) has been tested on a radial swirler industrial low NOx gas turbine combustor under atmospheric pressure and 600K. The pure WME and its blends with kerosene, B20 and B50 (WME:kerosene = 20:80 and 50:50 respectively), and pure kerosene were tested for gaseous emissions and lean extinction as a function of equivalence ratio. The co-firing with natural gas (NG) was tested for kerosene/biofuel blends B20 and B50. The central fuel injection was used for liquid fuels and wall injection was used for NG. The experiments were carried out at a reference Mach number of 0.017. The inlet air to the combustor was heated to 600K. The results show that B20 produced similar NOx at an equivalence ratio of ∼0.5 and a significant low NOx when the equivalence ratio was increased comparing with kerosene. B50 and B100 produced higher NOx compared to kerosene, which indicates deteriorated mixing due to the poor volatility of the biofuel component. The biodiesel lower hydrocarbon and CO emissions than kerosene in the lean combustion range. The lean extinction limit was lower for B50 and B100 than kerosene. It is demonstrated that B20 has the lowest overall emissions. The co-firing with NG using B20 and B50 significantly reduced NOx and CO emissions.

Abstract Oil & Gas offshore platforms are industrial "towns", ranked among the most hazardous working environments. Emergency situations in such environments are unpredictable and characterized by time pressure and rapidly changing conditions. OffshoreMuster brings together the latest technological advancements in real-time personnel tracking and e-mustering, complementing the existing Health and Safety (HSE) procedures, by enabling situation awareness over personnel location and status which is a key factor supporting better decision-making towards zero casualty in emergency situations. The system's underlying technology, developed after years of dedicated research and development efforts, consists of specialised low-power wireless wearable devices, customised gateways and a secure backbone network infrastructure feeding a modular decision support software system with real-time streams of data for processing and visualisation of information relevant to personnel situation assessment. HSE processes have been transformed into systematic procedures, allowing additional computer-aided decision support features, like the real-time observation of the fire-fighting team response status, the concentration of people in specific areas, instant alerting or the last-known position of a missing person. Lightweight ubiquitous devices in the form of a bracelet or embedded in the uniform are assigned to People on Board (PoB) and periodically transmit real-time location and status awareness data. A network of dedicated gateways, which are placed at specific locations on the platform or vessel, connected through the infrastructure's ethernet or wireless network, relay the data to a central decision support system. Specialised localisation algorithms and data analytics tools process the data to estimate the personnel positions and PoB status information, interactively visualising in real-time location awareness, incident escalation and alerting, which can significantly reduce response time and speed up a safe evacuation procedure. Computer-aided decision support combined with ultra-low power autonomous IoT technologies systems play a significant role in controlling, managing, and preventing critical incidents in harsh working environments, contributing into minimisation of accidents occurrence in Oil & Gas environments. The presented underling technology has been validated in maritime environments with more than 500 people taking part in real drills (TRL-8). The technology has been tailored to enhance the safety of personnel working in offshore Oil & Gas assets, currently being under laboratory testing and evaluation while a full-scale industrial deployment is scheduled for the autumn of 2021. The OffshoreMuster hardware and software components, integrated into a unified solution tailored for the offshore Oil & Gas industry, are presented for the first time. The system has been designed and developed with the support of the European Commission, co-funded by the Fast Track to Innovation Program (Grant Agreement Number 878950).