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Glibovytska, Nataliia, and Lesya Plaksiy. "The drilling solution components’ impact on the environment and directions of its reduction." Biolohichni systemy 12, no. 1 (June 25, 2020): 52–57. http://dx.doi.org/10.31861/biosystems2020.01.052.
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The problem of the oil wells operation influence on the environmental ecological state is considered. The technical and biological aspects of the impact of drilling solution components used in the process of oil production on the biotic and abiotic environment are analyzed. The methods of preserving the cleanliness of reservoirs and soil during the wells operations and preventing pollutants from entering the environment are described. Possible effects of the toxic compounds of the drilling fluid on living organisms, in particular plants, have been identified. The components of drilling fluids of different types are characterized by different levels of environmental hazard. The lowest level of threat to environmental safety is inherent in the clay type of solution, and the polymer-potassium solution is characterized by the highest potentially dangerous impact on the biota. Despite belonging to the third class of moderately hazardous substances, sodium salts, calcium and chlorides, as components of drilling fluids, have the highest destructive effects on the environment. Soil salinization has the most detrimental effect on plants, as it breaks the osmotic equilibrium in the soil-plant system, disrupts the transport of organogenic elements throughout the plant, and reduces the availability of moisture and minerals. Increasing soil pH due to the ingress of calcium and sodium hydroxides as components of drilling fluids adversely affects plant growth and development. Stability of some groups of plants to the influence of components of drilling fluids and ability of phytoobjects to resist stress influence are noted. Halophytes are well adapted to the growth in conditions of excessive soil salinization due to the specific metabolic and structural features of the organization. Low oil content in drilling fluids can be released into the environment and, when accumulated in the aquatic and soil environments, lead to a number of destructive processes in living systems. Plants sensitive to oil pollution respond by reducing growth processes, increasing catabolic processes, and reducing assimilation function. In order to minimize the negative impact of chemicals on the environment of oil production territories, it is necessary to apply a comprehensive approach that combines the technical aspects of pollution control with effective biological methods. The urgent task of modern environmental science is to search for oil-resistant plant species that are effectively capable of converting toxic petroleum products to biota-safe compounds. Technological recommendations for the prevention of environmental pollution by drilling fluids are proposed, as well as phytorecultivation methods for controlling already polluted ecosystems.
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Liu, Fei, and Yan Ling Wang. "Synthesis and Performance Study of the Nanomaterial Used to Stabilize the Reversible Invert Emulsion Drilling Fluid." Key Engineering Materials 744 (July 2017): 498–505. http://dx.doi.org/10.4028/www.scientific.net/kem.744.498.
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The reversible invert emulsion drilling fluids can achieve performance of oil based drilling fluid and solve the disadvantages associated by the oil based drilling fluid. This reversible invert emulsion drilling fluid can also focus the advantages of both oil based and water based drilling fluids. The surfactant emulsifier is the currently reported emulsifier used in the reversible invert emulsion. The stability of the reversible invert emulsion drilling fluid is very poor that can be known from the low emulsion breaking voltage. The dosage of the surfactant emulsifier is so much that it can increase the drilling cost and environmental pollution. In this paper, organic amine surfactant-modified nanoparticles are prepared and the modified nanoparticle which can be used to stabilize the reversible invert emulsion drilling fluid is chosen. The stability of the reversible invert emulsion drilling fluid stabilized by modified nanoparticles (emulsion breaking voltage>1100V) is better than the reversible invert emulsion drilling fluid stabilized by surfactant (450V<emulsion breaking voltage<600V). The dosage of the organic amine surfactant-modified nanoparticle emulsifier (2.4 wt.%) is less than the dosage of the surfactant emulsifier (4 wt.%), hence, reducing the drilling cost and environmental threat. The reversible invert emulsion drilling fluid stabilized by modified nanoparticles perform similar to the reversible invert emulsion drilling fluid stabilized by surfactant in the aspect of oiliness cuttings treatment. The reversible invert emulsion drilling fluid stabilized by modified nanoparticles also perform well in the aspect of oiliness cuttings treatment.
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Rossi, Arley Silva, Marina Seixas Pereira, Jéssika Marina dos Santos, Irineu Petri Jr., and Carlos Henrique Ataíde. "Fundamentals of Microwave Heating and Drying of Drilled Cuttings." Materials Science Forum 899 (July 2017): 528–33. http://dx.doi.org/10.4028/www.scientific.net/msf.899.528.
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Drilled cuttings contaminated by non aqueous drilling fluids are the major waste from oil well drilling activities. More restrictive environmental legislation has led to the search for alternative technologies to promote cuttings decontamination according to the law. The mixture of cuttings and fluid returning from the well goes through a set of separation equipments, called solids control systems, in order to recover the drilling fluid for reuse. The cuttings from the solids control system must be decontaminated before they can be discharged into the sea. Microwave heating has been studied over the past few years as an alternative to promote the decontamination of this waste and has been shown to be a promising technology. This work aimed to investigate fundamental aspects of microwave heating and drying of drilled cuttings. The heating curve of two different drilling fluids commonly employed in well-drilling operations was obtained. The kinetics of drying of cuttings contaminated with these drilling fluids was also investigated. It was evaluated the behavior of organic phase and water removal in the microwave drying process.
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STAN, Marius, Valentin Paul TUDORACHE, Lazăr AVRAM, Mohamed Iyad AL NABOULSI, Claudiu TĂNASĂ, and Georgeta ALECU. "Elements constituent for the design of a riser system in areas deep water and extreme deep water applied for offshore drilling." EMERG - Energy. Environment. Efficiency. Resources. Globalization 6, no. 3 (2020): 127–44. http://dx.doi.org/10.37410/emerg.2020.3.10.
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Riser systems are integral components of the offshore developments used to recover oil and gas stored in the reservoirs below the earth’s oceans and seas. These riser systems are used in all facets of the development offshore process including exploration and exploitation wells completion/intervention, and production of the hydrocarbons. Their primary function is to facilitate the safe transportation of material, oil and gases between the seafloor oceans and seas and the marine platform. As the water depth increases, the working conditions of this system becomes challenging due to the complex forces and extreme environmental conditions which are impacting the operational mode as well as the stability. In this paper several aspects concerning riser mechanics and the behaviour of the riser column will be evaluated against different operational situations.
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Gaurina-Međimurec, Nediljka, Borivoje Pašić, Petar Mijić, and Igor Medved. "Deep Underground Injection of Waste from Drilling Activities—An Overview." Minerals 10, no. 4 (March 27, 2020): 303. http://dx.doi.org/10.3390/min10040303.
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Oil and gas exploration and production activities generate large amounts of waste material, especially during well drilling and completion activities. Waste material from drilling activities to the greatest extent consists of drilled cuttings and used drilling mud with a smaller portion of other materials (wastewater, produced hydrocarbons during well testing, spent stimulation fluid, etc.). Nowadays, growing concerns for environmental protections and new strict regulations encourage companies to improve methods for the reduction of waste material, as well as improve existing and develop new waste disposal methods that are more environmentally friendly and safer from the aspect of human health. The main advantages of the waste injection method into suitable deep geological formations over other waste disposal methods (biodegradation, thermal treatment, etc.) are minimizing potentially harmful impacts on groundwater, reducing the required surface area for waste disposal, reducing the negative impact on the air and long-term risks for the entire environment. This paper gives a comprehensive overview of the underground waste injection technology, criteria for the selection of the injection zone and methods required for process monitoring, as well as a comprehensive literature overview of significant past or ongoing projects from all over the world.
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Duarte, Victor Magalhães, Luciano Matos Queiroz, Ednildo Andrade Torres, and Asher Kiperstok. "Energetic aspects and opportunities for reusing water on offshore platforms in Campos Basin, Brazil." Ambiente e Agua - An Interdisciplinary Journal of Applied Science 12, no. 5 (August 23, 2017): 786. http://dx.doi.org/10.4136/ambi-agua.2121.
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In the drilling and production of oil at sea, a large quantity of potable water used is most commonly transported to oil platforms using offshore supply vessels (OSVs). Sea water desalination is used as well, but only in a few oil platforms. To minimize energy consumption, water supply options were studied. The desalination of seawater and the reusing of streams of grey water and black water were evaluated and compared with the characteristics of the current supply via OSVs. In both desalination and OSV water supply options an electrolytic wastewater treatment plant is used. The objective of this study was to analyze the current situation regarding water supply on offshore platforms located in the Campos Basin, Rio de Janeiro, Brazil, and to propose measures to take advantage of opportunities to reuse water and reduce energy expenditure. Two alternative scenarios were developed that involved the reuse of water that comes from the effluent of a biological wastewater treatment plant (WWTP). Information on the logistics of supplying water to platforms was obtained through direct consultation with companies and sources in the literature. The results show that annual energy consumption (uptake, treatment, transportation, use and waste water treatment) of water on offshore platforms is currently 1.89 GWh, and that a reduction of 1.8 GWh of the energy consumed can be achieved using advanced reuse treatments. Energy consumption in the water reuse treatment is more competitive than those of transport by OSVs or seawater desalination.
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Di Martino, Gianluca, Roumen Sankoff, Craig Marshall, and Bobby Chopra. "The Coniston development: another offshore challenge in Western Australia." APPEA Journal 54, no. 2 (2014): 475. http://dx.doi.org/10.1071/aj13048.
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This extended abstract discusses the key challenges associated with the Coniston development; particular emphasis is on engineering, operations, and project management aspects. The Coniston development will produce oil and gas from the Coniston and Novara hydrocarbon accumulations, located in permit WA-35-L, about 100 km north of Exmouth, in water depths of about 400 m. The Coniston development will consist of a sub-sea tieback to the existing Van Gogh sub-sea infrastructure and the Ningaloo Vision FPSO, currently producing from the Van Gogh Field. The project was sanctioned by Apache in 2011 and will be on production in 2Q 2014. To maximise reservoir exposure, multilateral wells will be drilled, and completed, employing inflow control devices of latest generation and monitoring production with the installation of tracers. To take advantage of project synergies, gas lift will be provided by Van Gogh wells through a dedicated gas production manifold. The Coniston development represents a remarkable multidisciplinary effort to develop a relatively small-size oil reservoir offshore WA. Some of the challenges achieved are the high oil viscosity, the complexity of the engineering to install new sub-sea infrastructure while minimising the impact on Van Gogh production and maximising the synergies of the tie back, the constant increase in drilling and facilities costs while maintaining attractive project economics, and the more stringent regulations environmental permits and the ability to optimise drilling and operation to achieve production as quickly as possible.
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Miller, Jessica, and Nick Quinn. "EXERCISE WESTWIND – A COLLABORATIVE OIL SPILL RESPONSE BY OIL & GAS OPERATORS AND AGENCIES." International Oil Spill Conference Proceedings 2017, no. 1 (May 1, 2017): 2851–62. http://dx.doi.org/10.7901/2169-3358-2017.1.2851.
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Abstract On June 9th, 2015, ACME Oil Company’s rig suffered a dynamic positioned ‘run-off’. The mobile drilling unit lost its station above the wellhead and a loss of well control was experienced. “A massive environmental emergency unfolded…affecting pristine coastline and masses of wildlife”. Incident Management and Field Response Teams were activated in a multi-agency operation, bringing together 200 personnel from 16 oil and gas companies and 18 government agencies and third party providers. Source control, aerial, offshore, nearshore, shoreline and oiled wildlife response capabilities were deployed and national/international support was utilised. Jointly managed by the Australian Marine Oil Spill Centre (AMOSC), the Australian Maritime Safety Authority (AMSA), the Federal Department of Industry and Science, and the Western Australian Department of Transport -Exercise Westwind was a successful multi-faceted marine spill response, demonstrating Australia’s collective Industry/Government capacity to respond to a large, offshore loss of well control incident in a remote and isolated location. ACME Oil Company was a fictitious company formed to enable the amalgamation of Australian petroleum companies to exercise industry arrangements under one ‘banner’ during the exercise period. ACME Oil Company had its own set of credentials, company website and Oil Pollution Emergency Plan. The company also held real time memberships with a number of service providers including AMOSC, Oil Spill Response Ltd, Trendsetter Engineering International, Oceaneering Australia and addenergy. Representing an innovative approach to spill response exercising, ACME Oil Company was a valuable and critical aspect to industry and governments participation under a non-attributable banner. Additionally, it enabled safe, widespread lessons to be observed, allowed for real-time testing of arrangements and provided a safe environment for regulators, stakeholder and industry interplay. The exercise was an efficient and practical solution for Industry titleholders and their third party supporting organisations, to test shared response resources and to ensure Industry arrangements for responding to oil pollution are in accordance with the Offshore Petroleum and Greenhouse Gas Storage (Environment) Regulations 2009. This paper will discuss the development program behind the exercise and the experience of managing an exercise of this nature. It will highlight the successes including the creation and implementation of a fictitious company and the extensive collaboration between the industry and government personnel involved. It will also look forward – where are we 11-months later? Can the history of exercising and/or response help us improve for the future-implementation of change and continued testing is critical in furthering our oil spill response capability and capacity.Exercise Westwind – Operational Phase TwoExercise Westwind – Operational Phase Two
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Wiesłw, Wiesław, and Marcin Rzepka. "Zjawiska chemiczno-technologiczne podczas zabiegu cementowania otworu w aspekcie projektowania rur okładzinowych." Nafta-Gaz 77, no. 2 (February 2021): 92–105. http://dx.doi.org/10.18668/ng.2021.02.04.
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Borehole design is a complex and multidimensional question in terms of the number of issues to be resolved in terms of mechanical, environmental and public safety engineering requirements. In this article contains a review and evaluation of chemical phenomena and processes (not always correctly evaluated) that occur during the preparation of cement slurry and after its displacement during the formation of the gel structure of cement and cement sheath. As a result of the chemically complicated process of slurry gelation, a new structure is formed, i.e. steel pipe – sheath (cement stone) – a rock which in a specific way produces a specific type of load and stress in the annular space, and thus influences changes in hydrostatic pressure distribution. Such phenomena described in this article allow to understand the methodical approach to the process of designing pipes, especially in the aspect of collapse and burst of pipes with big diameter >13⅜″ and thin wall (in the 4th load regime). This does not mean that the tensile strength of pipes is not an important issue in pipe design, but it mainly concerns very deep boreholes, while collapse and burst of pipes occurs in special (often unforeseen) cases of full or partial evacuation for shallow pipe foundation in the hole. The article is based on extensive professional literature, as well as on numerous tests carried out at Oil and Gas Institute – National Research Institute on different types of cement slurries and drilling muds, and, moreover, on the relevant experience of the authors of the article, both in the field of slurry design and supervision of cement operations, as well as in the design and supervision of works related to drilling of various types of boreholes, including cement job and running casing.
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Herber, R., and J. de Jager. "Geoperspective Oil and Gas in the Netherlands – Is there a future?" Netherlands Journal of Geosciences - Geologie en Mijnbouw 89, no. 2 (September 2010): 91–107. http://dx.doi.org/10.1017/s001677460000072x.
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AbstractThe impact of oil and, in particular, gas fields discovered in the Dutch subsurface has been very significant. However, 50 years after the discovery of the giant Groningen gas field the Netherlands has become very mature for exploration of oil and gas, and the gas volume left to be discovered in conventional traps is insignificant compared to what has been found already. The total portfolio of conventional prospects held by the industry contains several 100s of billions of cubic metres (bcm), as reported by the Ministry of Economic Affairs, but many of these prospects are unattractive to drill because of their small size or other geologically unfavourable aspects. Hence, for planning purposes of future national gas production the risk should be taken into account that the size of the conventional portfolio is overestimated. The major E&P companies have reduced their exploration efforts and the number of wells drilled as well as the size and total volume of discovered gas reserves has seen a steady decline over the last 10 years. Some surprises may still be in store and can occasionally add a welcome addition of gas. But the follow-up potential of new play and trapping concepts has been disappointing for many years now, and it is concluded that this is unlikely to be different in the future. Remaining conventional discoveries will mainly be in small near-field targets that as a result of technological advances made in the last few decades can be drilled with high confidence, despite their small volumes.This leaves the so-called unconventional gas (UG) resources for a real and significant increase in the exploration potential of the Netherlands. UG resources occur outside conventional structural or stratigraphic traps in tight (low permeability) rocks and are of regional or sub-regional extent, without well-defined hydrocarbon-water contacts. The potential for Basin Centred Gas, Shale Gas and Coal Bed Methane is reviewed. As, according to present-day technology, development of UG requires very dense drilling at low costs with well spacing of a few 100s of metres, only the onshore potential can be commercial, even in the longer term.Recent geological uplift is a characteristic for all North American commercial UG developments. Uplift helps bringing the resources close to the surface and facilitates development of fractures, which are essential for achieving commercial flow rates. This significantly reduces the area where commercial UG resources may occur in the Netherlands. In addition, sweet spots, where commercial flow rates and ultimate recovery per well can be achieved, represent only a fraction of the total ‘play area’. The UG plays in the Dutch subsurface remain to be proven, and there is still a significant technical risk associated with these plays, on top of the commercial risk. Therefore, despite potentially enormous in-place gas volumes in these unconventional plays, recoverable volumes are much less. If UG resources can be proven and are commercially developable, their cumulative volume potential is estimated by us in the order of a few tens to one or two hundreds bcm of recoverable gas at best. Finally, as UG resources produce at very low rates and require large numbers of wells to develop, the environmental impact in a densely populated country like the Netherlands is enormous, and needs to be seriously considered, already in the exploration phase.In a mature area like the Netherlands, industry focus should be on technology development to reduce risk, increase recovery, reduce cost and minimize surface impact. Cooperation between Operators to build multi-well campaigns is therefore strongly recommended to reduce mobilisation cost. In addition, government incentives should be targeted at the development phase, in order to increase economic attractiveness for difficult reservoirs, both conventional and unconventional. In this way State and industry will both be able to maximize their returns on the remaining potential for gas and oil in the next two to three decades.
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FUKUSHIMA, MUTSUO. "On environmental issues in U.S. oil well drilling industry." Journal of the Japanese Association for Petroleum Technology 55, no. 5 (1990): 354–57. http://dx.doi.org/10.3720/japt.55.354.
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Pedrosa, Camilo, Arild Saasen, Bjørnar Lund, and Jan David Ytrehus. "Wet Drilled Cuttings Bed Rheology." Energies 14, no. 6 (March 16, 2021): 1644. http://dx.doi.org/10.3390/en14061644.
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The cuttings transport efficiency of various drilling fluids has been studied in several approaches. This is an important aspect, since hole cleaning is often a bottleneck in well construction. The studies so far have targeted the drilling fluid cuttings’ transport capability through experiments, simulations or field data. Observed differences in the efficiency due to changes in the drilling fluid properties and compositions have been reported but not always fully understood. In this study, the cuttings bed, wetted with a single drilling fluid, was evaluated. The experiments were performed with parallel plates in an Anton Paar Physica 301 rheometer. The results showed systematic differences in the internal friction behaviors between tests of beds with oil-based and beds with water-based fluids. The observations indicated that cutting beds wetted with a polymeric water-based fluid released clusters of particles when external forces overcame the bonding forces and the beds started to break up. Similarly, it was observed that an oil-based fluid wetted bed allowed particles to break free as single particles. These findings may explain the observed differences in previous cutting transport studies.
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Veliyev, H. O., and E. A. Kazimov. "Consideration of abnormal changes of seismo-geodynamic aspects in drilling process." Azerbaijan Oil Industry, no. 12 (December 15, 2020): 17–24. http://dx.doi.org/10.37474/0365-8554/2020-12-17-24.
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The paper deals with the study of seismo-geodynamic aspects associated with mud volcanoes, the analysis of the impact of earthquake factors outcome on construction process of oil-gas, gascondensate wells and the development of preventive measures towards reduction of risks in the drilling process in active zones. The task set has been solved by gathering and analyzing the seismo-geodynamic factors of the fields where drilling operations are carried out. Based on the study of seismic data of the active and dormant volcanoes the preventive measures are recommended for the optimum well drilling regime. Dynamic and kinematic parameters of seismic waves in the rocks have been analyzed in the context of Umid, Babek, Neft Dashlary fields and the regularities in their behavior specified as well. It was defined that the well drilling in geodynamic conditions for which complicated industry-related phenomenon is characteristic, particularly earthquakes, their epicenter is located at the depth of 10-15 km. It is recommended in such active zones with stress-deformed state to conduct drilling operations exactly in regulated regime with minimum risks to avoid various failures and complications.
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Li, XiangGuo, Yang Lv, BaoGuo Ma, ShouWei Jian, HongBo Tan, and Bei Wu. "UTILIZATION OF OIL WELL-DERIVED DRILLING WASTE IN SHALE-BRICK PRODUCTION." Environmental Engineering and Management Journal 13, no. 1 (2014): 173–80. http://dx.doi.org/10.30638/eemj.2014.021.
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Zazarli Shah, Mohamad Safwan, Arina Sauki, Wan Zairani Wan Bakar, Nurul Aimi Ghazali, and Azlinda Azizi. "Drilling Fluid Design for Shale Gas Drilling." Advanced Materials Research 1113 (July 2015): 617–24. http://dx.doi.org/10.4028/www.scientific.net/amr.1113.617.
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Shale gas nowadays is an important source of unconventional gas. The limited conventional gas supply makes the unconventional sources as a new source of gas. In this research, the aim is to design a mud formulation that can carry out essential functions of mud for shale gas drilling. Commonly for shale gas drilling, water based mud is used. However, water based mud is ineffective when dealing with water-sensitive shale. The alternative way to deal with this type of shale is using synthetic-based mud (SBM) or oil-based mud (OBM). OBM is an effective mud while drilling well. However, it is toxic and gives negative impact to environment. SBM somehow is more environmental friendly compared to oil based and ester is one of the synthetic based fluids. In order to prove this statement, a toxicity test was carried out to investigate the impact of ester based mud on selected marine life. The results of the test were compared with past research results. The ester use in this research is methyl-ester C12-C14 derived from palm oil and the mud was formulated at different oil-water ratios which are 70/30, 80/20 and 90/10, respectively and the best rheological performance can be seen at 80/20 oil-water ratio. Then, the performance of this mud had been compared to other types of mud which are sarapar-based and WBM. The findings revealed that the rheological performance of ester based mud is comparable with common based mud used for shale gas drilling. Apart from that, it is less toxic than other based mud which can maintain 60% prawn’s survival even after 96 hours exposure in 100,000 ppm of mud concentration in artificial seawater.
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Blair, Benjamin D., Stephen Brindley, Eero Dinkeloo, Lisa M. McKenzie, and John L. Adgate. "Residential noise from nearby oil and gas well construction and drilling." Journal of Exposure Science & Environmental Epidemiology 28, no. 6 (May 11, 2018): 538–47. http://dx.doi.org/10.1038/s41370-018-0039-8.
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Wu, Pengcheng, Chengxu Zhong, Zhengtao Li, Zhen Zhang, Zhiyuan Wang, and Weian Huang. "Oil-Based Drilling Fluid Plugging Method for Strengthening Wellbore Stability of Shale Gas." Geofluids 2021 (February 16, 2021): 1–13. http://dx.doi.org/10.1155/2021/6674574.
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Finding out the reasons for wellbore instability in the Longmaxi Formation and Wufeng Formation and putting forward drilling fluid technical countermeasures to strengthen and stabilize the wellbore are very crucial to horizontal drilling. Based on X-ray diffraction, electron microscope scanning, linear swelling experiment, and hot-rolling dispersion experiment, the physicochemical mechanism of wellbore instability in complex strata was revealed, and thus, the coordinated wellbore stability method can be put forward, which is “strengthening plugging of micropores, inhibiting filtrate invasion, and retarding pressure transmission.” Using a sand bed filtration tester, high-temperature and high-pressure plugging simulation experimental device, and microporous membrane and other experimental devices, the oil-based drilling fluid treatment agent was researched and selected, and a set of an enhanced plugging drilling fluid system suitable for shale gas horizontal well was constructed. Its temperature resistance is 135°C and it has preferable contamination resistibility (10% NaCl, 1% CaCl2, and 8% poor clay). The bearing capacity of a 400 μm fracture is 5 MPa, and the filtration loss of 0.22 μm and 0.45 μm microporous membranes is zero. Compared with previous field drilling fluids, the constructed oil-based drilling fluid system has a greatly improved plugging ability and excellent performance in other aspects.
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Mody, Rustom, David Gerrard, and Jim Goodson. "ELASTOMERS IN THE OIL FIELD." Rubber Chemistry and Technology 86, no. 3 (September 1, 2013): 449–69. http://dx.doi.org/10.5254/rct.13.86999.
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ABSTRACT Even before Spindletop “gushered” in the great Texas oil boom in 1901, rubber chemistry and technology played a key role in the pressure and flow control of hydrocarbons from petroleum reservoirs. This key role for rubber in the oil field continues today, where the cost of construction of an oil or gas well can exceed a billion dollars. Almost all equipment used in downhole drilling and completion operations currently depends on elastomers and other sealing materials to provide steady, reliable performance during service. Although the cost of the individual seals used downhole in a well represents only a fraction of the total well cost, the seals are critical to well performance and safety. Sealing mechanisms are at the heart of any drilling, completion, or production system and are the primary components on which the functional success and longevity of the system rests. Modern drilling systems, with their significant use of onboard electronic components and sensors, rely heavily on nonmetallic seals to prevent well environmental contamination while withstanding sustained dynamic loadings throughout service. Well completion systems can be categorized by either relatively short-term applications, after which seals can be changed or maintained, or long-term applications, in which seals are expected to perform without change or maintenance for 20 years or longer. The assurance of these systems' continued performance throughout the life of the well, whether the expected life is short or long, is of vital importance.
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Qaiser, Muhammad, Iftikhar Ahmad, Sajid Ahmad, Muhammad Afzal, and Abdul Qayyum. "Assessing Heavy Metal Contamination in Oil and Gas Well Drilling Waste and Soil in Pakistan." Polish Journal of Environmental Studies 28, no. 2 (December 20, 2018): 785–93. http://dx.doi.org/10.15244/pjoes/85301.
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Lira, William Wagner Matos, Giancarlo de Gusmão Gonçalves, Catarina Nogueira Araujo, Adeildo Soares Ramos Junior, and Alejandro César Frery. "Thermomechanical effect of vertical well drilling in salt rocks in selected cases." Engineering Computations 32, no. 5 (July 6, 2015): 1307–22. http://dx.doi.org/10.1108/ec-04-2014-0092.
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Purpose – The purpose of this paper is to present an analysis of the effect of the temperature on the creep deformation during vertical well drilling in salt rocks in selected cases. Design/methodology/approach – The authors performed numerical simulations by Finite Element Method, using non-linear viscoelastic models and weak thermomechanical coupling. The authors evaluated, in selected cases, the effect of temperature during salt rock vertical well drilling. Numerical examples were performed to validate the studies. More specifically, the authors considered the problem of vertical well drilling for oil exploration below these salt layers. Findings – The authors concluded that the biggest reduction in the wellbore closure rate occurs when the wellbore is at low temperature with respect to the rock initial. This is due to two factors, namely, a reduced salt viscous strain rate and the thermal strain contrary to the well radial closure caused by the temperature variation. Beyond the creep effect, the thermal strain also affects the stress in the creep constitutive equation. Practical implications – With recent oil discoveries in deep water, for example, in the pre-salt, where temperatures are high, the study of the influence of temperature is important, since it contributes to the increase of the creep. The results here presented are relevant, although the engineering aspects of a practical solution for reducing the wellbore displacement based on temperature variation is challenging. Such approach requires cooling mechanisms that delay the heating of the drilling fluid, which is surrounded by rocks at high temperature. Originality/value – The main contribution of this paper is to present a numerical study, in selected cases, of the effect of temperature on the creep deformation during vertical well drilling in salt rocks, analyzing a possible reduction of these deformations when subjected to a temperature variation.
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Ben Rahmoune, Mohamed, Mouloud Guemana, and Ahmed Hafaifa. "Reliability modelling using Weibull distribution on real-time system in oil drilling installations." Algerian Journal of Signals and Systems 2, no. 4 (December 15, 2017): 189–98. http://dx.doi.org/10.51485/ajss.v2i4.44.
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Recently, reliability has become a key parameter of quality and decision support, covering many aspects, such as failure analysis systems. A reliability analysis is essential for the study of operating safety in industrial systems. In this paper, we summarised evaluation methods and real-time reliability analyses. This work proposes solutions to real-time reliability modelling, as applied to an industrial pump. The model will be used to increase the lifespan of the equipment, to help develop suitable maintenance plans and to assign a probability to good operating system examined to choose the best dedicated industrial pump technology solutions
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Prantera, M. T., C. A. Mauro, and M. D. M. Marins. "Landfarming of Drilling Wastes." Water Science and Technology 24, no. 12 (December 1, 1991): 177–82. http://dx.doi.org/10.2166/wst.1991.0382.
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Use of the soil as a receptor in the biodegradation of oily wastes is a widespread practice in the petroleum industry. Generated during drilling, these oily wastes may have intrinsic properties that inhibit microbial soil activity. CENPES, the Petrobrás research centre, has been studying disposal of these wastes. The results of physical and chemical analyses were used to select factors that may limit the application of these wastes in soil. High salinity and high baritine (BaSO4) contents, as well as substantial concentrations of some heavy metals, have been studied with the aim of ascertaining the maximum concentration of each at which degradation is still observed. Microbiological assays indicated maximum oil application rates varying from 1 to 20%, suggesting that each waste tested displays a different toxicity.
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Ismail, Abdul Razak, Radzuan Junin, Issham Ismail, and Mohd Fauzi Hamid. "The Effectiveness of Cationic and Polymer Inhibitors on Shale." Advanced Materials Research 1125 (October 2015): 205–9. http://dx.doi.org/10.4028/www.scientific.net/amr.1125.205.
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Maintaining the borehole stability while drilling oil and gas wells is a major problem when drilling through water sensitive formation. Drilling using oil-based drilling fluid is the most effective solution to control shale. Due to the increasing environmental constraints on the use of mineral oil-based drilling fluid system, expensive research has been studied to optimize oil well operations and minimize drilling cost using new water-based drilling fluid system. In this study, the effectiveness of three commonly used shale inhibitors were tested, where cationic polymer and KLA-Gard are cationic type inhibitors and PHPA is polymer type inhibitor. Two types of shale samples were used in this study, both were taken from Malaysia. Each shale sample represents different degree in swelling and dispersion characteristic. The testing procedures were employed for the shale reactivity evaluation, inhibitors’ performance evaluation, rheology and filtration loss effect evaluation as well as the character of the recovered shale from dispersion test. Result showed that the cationic type inhibitor is suitable to be used for swelling shale. For disperse shale, polymer type inhibitor is the best selection to be added in the drilling fluid system. The combination of cationic inhibitor used along with the polymer inhibitor showed reduction in dispersion and swelling tendency. It is also found that the cationic inhibitors showed well compatibility with other polymers in the ionic solution. Cationic inhibitors do not affect the rheology and filtration loss properties but polymer inhibitors affect these properties.
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Sun, Yu Xue, Yu Ning Xie, and Chang Xiao. "MEG and its Application in Drilling Fluid." Advanced Materials Research 287-290 (July 2011): 2088–93. http://dx.doi.org/10.4028/www.scientific.net/amr.287-290.2088.
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Recently, oil-based drilling fluids are used mainly in horizontal wells, which are highly cost and have a poor performance to carry cuttings and may result in environmental problems because of the ineffective dispose of drilling waste. Therefore, a study is commenced to develop a water-based drilling fluid system (MEG drilling fluid system) that can satisfy the needs of horizontal well. The study begins with the molecular structure and properties of monomers about MEG. Then it selected the treatment agent which has a good compatibility with MEG, and confirms a best formula of MEG drilling fluid system. By the comparison between MEG and other drilling fluids, the former has evident advantages in cave preventing, lubricity, solid carrying and formation damage controlling; also it can minimize the environmental effects. The above proves that MEG drilling fluid system can well meet the need for horizontal well drilling.
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Geertsma, J. "Some Rock-Mechanical Aspects of Oil and Gas Well Completions." Society of Petroleum Engineers Journal 25, no. 06 (December 1, 1985): 848–56. http://dx.doi.org/10.2118/8073-pa.
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Abstract Elementary borehole- and perforation-stability problems in friable clastic formations for unrestricted fluid flow between reservoir rock and underground opening are treated on the basis of linear poroelastic theory. Thermal stress effects caused by a temperature difference between reservoir and borehole fluids can be predicted from the mathematical similarity of poro- and thermoelasticity. A tension-failure condition applies for the prediction of hydraulic fracture initiation in a formation around injection wells. The resulting equations are partially well-known. Similarly, a uniaxial compression-failure condition should predict perforation failure leading to sand influx in production wells. The major difference between these situations is that, at sufficient depth of burial, the tensile strength of a friable rock mass has only a minor effect on the fracturing pressure level, but the actual value of the compressive strength plays a crucial role in the prediction of sand-influx conditions. Practical suggestions for resolving the latter are given. Introduction This paper discusses borehole- and perforation-stability problems as encountered in friable sandstone formations that have in common free fluid flow between a reservoir and an underground opening. Such a condition prevailsduring fluid production through either casing perforations or open hole andduring injection of fluids into a reservoir for pressure maintenance, gas conservation, tertiary oil recovery, or well stimulation. In the absence of a membrane (such as a filter cake) at the rock/hole interface, the effective stress normal to the rock surface is zero. Rock failure can result either in tension during fluid injection or in compression during fluid production. Because one of the principal effective stresses (the radial stress) is zero and the effect of the intermediate principal effective stress is small, failure is of either the unconfined tension or compression type. Rock failure resulting from fluid production from friable sandstones causes sand-particle influx. Failure caused by fluid injection means either planned or unintentional formation fracturing. The production technologist has to foresee such failure conditions as a function of changes in the stress regime with time. He has to start with a best possible estimate of the initial in-situ state of stress. On the basis of log data and core sample analysis, relevant rock deformation and strength properties must be determined next. Finally, an estimate of changes in the stress field resulting from prolonged production or injection must be made. Problem Areas Formation Particle Influx in Production Wells. Although significant improvements have been made in well-completion techniques aimed at sand-particle retention by both gravel packing and sand consolidation, straightforward production through casing perforations is the preferred production method because of minimum costs and maximum usage of well-flow potential. Moreoever, gravel packing long intervals of strongly deviated holes remains a difficult, expensive operation to perform, while sand consolidation processes for oil wells at temperatures above 75 degrees C [167 degrees F] are not available commercially. Friable formation sands i.e., formations that have some strength of their own-do not necessarily present a sand-influx problem initially. Sand production may develop gradually in time, once total drawdown increases and/or water breakthrough occurs. Deviated boreholes may encounter less favorable stress concentrations around perforations than vertical holes. All in all, it is necessary to predict the sand-influx potential of a well as soon as possible after drilling to serve as a basis for a completion policy. A perforation pattern that both results in production from only the more competent zones and enables delivery of the required well production capacity could be implemented. Formation Fracturing Around Injection Wells. A familiar type of formation failure is fracturing in tension around injection wells. Formation fracturing always occurs when the injection pressure surpasses the formation breakdown pressurei.e., the fluid pressure that brings the hoop stress around the opening in a tension equal to the tensile strength. Once initiated at or below this pressure level (because the formation may contain natural fractures), fracturing proceeds while the injection pressure surpasses the least principal in-situ total stress. The instantaneous shut-in pressure recorded during or after a fracturing job provides the best value of the least principal total stress component. The in-situ state of stress is not necessarily a constant during the production life of a reservoir. Changes both in reservoir pressure and in temperature adjacent to a well affect the local stress field in the formation. The effect of reservoir pressure variations on formation fracturing potential is well-known. Breckels and van Eekelen explicitly account for this effect. It is less recognized that in deeper formations cooling of the borehole surroundings by injection of liquids at near-surface temperature causes reservoir-rock shrinkage, leading to a reduction in both fracture initiation and propagation pressure. SPEJ P. 848^
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Park, John M., and Michael G. Holliday. "Occupational-health Aspects of Marine Oil-spill Response." Pure and Applied Chemistry 71, no. 1 (January 1, 1999): 113–33. http://dx.doi.org/10.1351/pac199971010113.
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Introduction: This chapter addresses chemical aspects of occupational health and marine oil-spill response and is restricted to exposures to crude oil in its various forms. Thus in-situ burning of oil is included, but ancillary chemicals such as surfactants or bioremediation agents are not. The content of this chapter is largely based on the literature published after 1985, the date of a comprehensive review conducted by Politzer et al. [1985] for the American Petroleum Institute, and on a review carried out for the Marine Spill Response Corporation early in 1993 [Holliday and Park, 1993].Concern about health and safety is a normal part of every oil spill. In general, safety is easier to understand and address than are concerns about exposure to crude oil and other chemicals which might be used in the response. At one level, human exposure can be addressed through the enforcement of very conservative requirements for the use of personal protective equipment (PPE). In the real world, however, conditions at a spill site make the use of such equipment inconvenient or even hazardous, and so the goal becomes to balance the risk from exposure with the appropriate level of PPE.While oil-spill cleanup is a comparatively new aspect of occupational-health practice, and dates from the formalization of response measures by companies and national and international agencies (something that occurred over the last 30 years), exposure to crude oil itself is a "mature" occupational-health matter. Workers have been exposed, both by inhalation and dermally, to the effects of crude oil for the past century. The exposure of response workers during the early phases of the oil-spill response can be likened to that experienced by oil-well-drilling crews and, to a lesser extent, by oil-well-maintenance personnel or fighters of oil-well fires. In contrast, exposures in the later stages of the cleanup are less clearly related to occupations within the oil industry. The crude oil will have been altered by weathering, and exposure to cleanup chemicals (e.g., dispersants, bioremediation agents) will become relatively more prominent. Such substances are beyond the scope of this chapter, and in any event, few data are available on the compositions or mammalian toxicity of dispersants. Although there are frequent references to toxicity in connection with dispersants, these invariably seem to refer to ecotoxicity. Human hazard does not appear to be an issue. For example, in a recently published paper entitled, "Effectiveness and safety of biosurfactants as agents of oil spill response" [Lepo et al., 1997], "safety" refers to possible toxicity to crustaceans and fish.
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Veliyev, H. O., R. M. Zeynalov, E. A. Kazimov, and T. M. Ahmadov. "Necessity of recording seismological and seismic properties associated with geodynamic tensions in deep well drilling." Azerbaijan Oil Industry, no. 2 (February 15, 2021): 10–15. http://dx.doi.org/10.37474/0365-8554/2021-2-10-15.
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The paper reviews the major ways of reducing failure cases during drilling works on the territory of Azerbaijan and South Caspian basin, as well as in oil-gas bearing structures of the Caspian Sea considering geodynamic tension of reservoirs, seismic activity and the occurrences of velocity changes. If not considering such aspects as seismodynamic activity of the territory and geodynamic tensions, failure and complication risks in the process of deep well drilling sharply increase. Physical-chemical features of rocks in the same formation are not similar and various patterns of complicated seismic record can be seen. It is necessary to study in detail the patterns of seismic record in different directions of seismic profile passing near the location selected for the project well. Foremost, it is significant to reveal the interval of drilled reservoir, where the complicated record is occurred and specify the reasons for the sharp difference in wave field patterns. Moreover, while conducting drilling works in the areas with complicated features, the failure case risks should be considered as well.
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Levine, Robert A. "DRILLING FOR REALITY1." International Oil Spill Conference Proceedings 1995, no. 1 (February 1, 1995): 1036–37. http://dx.doi.org/10.7901/2169-3358-1995-1-1036.
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ABSTRACT ARCO Marine, Inc. (AMI) has been holding regular oil spill drills for its spill team members since the mid-1970s. Over the years the drills have gotten more elaborate and more costly, employing equipment and testing initial response and transition management. By the 1993 drill, it was found, the drills were losing their educational benefits and for the most part had become well-rehearsed stage plays, with spill team members and other participants as actors and equipment as props. The drills were not providing the education necessary to develop team members for their roles as response managers. AMI rethought the drill process and, with the concurrence of the U.S. Coast Guard, the Alaska Department of Environmental Conservation, and the Ship Escort and Response Vessel System, decided that it was time to “drill for reality.”
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Zhang, Fang Fang, Chun Feng, Li Juan Zhu, and Wen Wen Song. "Research Progress on Corrosion Resistance of Titanium Alloy Oil Well Tubing." Materials Science Forum 1035 (June 22, 2021): 528–33. http://dx.doi.org/10.4028/www.scientific.net/msf.1035.528.
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Compared with aluminum alloy and alloy steel, titanium alloy has higher specific strength, lower modulus of elasticity, and better toughness, fatigue performance and corrosion resistance. In terms of oil well tubing, the development of titanium alloy lags behind that of aluminum alloy and alloy steel. Aluminum alloy tubing is sensitive to pitting, fatigue corrosion and stress corrosion cracking. At the same time, it is not suitable for ultra-deep wells due to temperature limitations. Easily interact with corrosive media to cause corrosion and cracking. Titanium alloy oil well tubing is expected to solve this corrosion problem, but its corrosion resistance research is still incomplete. Therefore, it is necessary to develop titanium alloy oil well tubing with good corrosion resistance to improve corrosion fatigue (CF), fatigue during deep oil well and natural gas drilling operations. Catastrophic brittle fracture caused by hydrogen induced cracking (HIC), pitting corrosion and sulfide stress cracking (SSC). In this paper, by investigating a large number of domestic and foreign documents, the corrosion types of titanium alloy oil well pipes are analyzed, and the research status of corrosion resistance of titanium alloy oil well pipes is reviewed from three aspects: oil pipes, casings and drill pipes.
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Smith, Barry, Julie Martine, and Graeme D. Hubbert. "ENVIRONMENTAL STUDIES FOR A PERMIT-WIDE DRILLING PROGRAM IN A SENSITIVE MARINE ENVIRONMENT." APPEA Journal 34, no. 1 (1994): 750. http://dx.doi.org/10.1071/aj93055.
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An integrated program of environmental studies was undertaken in support of an application to conduct permit-wide exploratory drilling in a shallow, sensitive marine environment. The program comprised permit and well site specific work which was carried out in parallel with a corporate due diligence program established by the permit Operator.Scientific studies undertaken for permit area EP 341 off the north west coast of Western Australia comprised underwater surveys, aerial video reconnaissance, surface current tracking surveys and oil spill trajectory modelling to characterise the local environment and identify sensitive resources at risk of impact from oil spills. Survey data were used to prepare an environmental impact assessment report and an oil spill contingency plan, which provide a set of site-specific environmental management guidelines for use by field and office personnel involved with the drilling program. A 3D oil spill trajectory model successfully predicted current flows in the complex hydrodynamic environment of the permit areas, demonstrating its usefulness as a real time tool for oil spill response planning.
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Rasouli, Vamegh. "Some lessons learnt from drilling a shale gas well in Western Australia." APPEA Journal 54, no. 1 (2014): 15. http://dx.doi.org/10.1071/aj13006.
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The Arrowsmith–2 well is the first dedicated shale gas well in WA. The well is situated in the central eastern area of Permit EP413, with the surface location being about 30 km north of the township of Eneabba. Norwest, as the operator and on behalf of its joint venture partners, drilled the Arrowsmith–2 exploration well in mid-2011. In 2012 the well was subsequently perforated and fracture stimulated in five discrete stages across four formations: the High Cliff Sand Stone (HCSS); Irwin River Coal Measures (IRCM); Carynginia Formation; and, Kockatea Shale. The fraccing results have shown excellent rates of gas flow for the size of the intervals fracced, and have produced oil and/or condensate to surface from the two intervals flowed back. This paper discusses some drilling operation and design aspects of Arrowsmith–2. A review of the regional geology, basic well design, and well objectives will be given. The importance of geomechanical studies for minimising wellbore-related problems during drilling and after that for hydraulic fracturing operation will be discussed, and the results of the studies undertaken presented. The wireline logging suite run in this well was used to interpret the formations’ mechanical properties. Also, laboratory tests were performed to estimate hydro-mechanical properties of the formations. The lessons from drilling this well will be used for drilling future wells in the area with the objective of saving time and costs.
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Crawford, Mark. "Fracturing Rocks to Unlock New Oil." Mechanical Engineering 135, no. 12 (December 1, 2013): 24–29. http://dx.doi.org/10.1115/1.2013-dec-1.
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This article discusses various uses and benefits of hydraulic fracturing technology in the field of oil industry. Engineers continue to increase hydraulic fracturing efficiency by developing better multistage stimulation systems. These systems enable treatment of many intervals along a horizontal wellbore with a minimum number of pull-outs, or even in a single continuous operation. Many key advances in drilling and hydrofracturing have resulted from sophisticated modeling programs. Mechanical engineers play key roles in many aspects of hydrofracturing, especially the design of better down-hole tools, new materials, and improved numerical models. With the advances in modeling and real-time measurement, operators can deliver just the right type of fracking pressure, exactly where they want it, and repeat the process as needed, either in the same well, one that parallels it, or one that radiates out from the same central drill pad. The experts feel that if the world wishes to fully use its oil-and-gas resources, it will go hand-in-hand with hydraulic fracturing.
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Rasti, Arash, Adel Ameri, and Mohammad Ali Riahi. "Aerobic degradation of oil-based mud drilling fluid by in situ bacteria in the Hawizeh Marshes." Journal of Petroleum Exploration and Production Technology 11, no. 10 (August 26, 2021): 3775–83. http://dx.doi.org/10.1007/s13202-021-01263-6.
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AbstractThe increasing global demand for hydrocarbon has brought new challenges in the petroleum reservoir's drilling process. Non-biodegradable chemical additives are used in drilling fluid and it leads to endangering the environment and personnel safety. Thus, there is a great need for new biodegradable drilling fluid additives that can protect the environment and personal safety while drilling is done well. This study with help of microbial analysis investigates the effects of in situ bacteria to degenerate the gasoline inside the oil-based mud, in the returned lubricant from one of the oil wells next to the Hawizeh Marshes. Four types of bacteria inside the oil-based mud were observed. According to the high growth and degradation of crude oil, one strain was selected. Determination of the coagulase and clumping test shows that the isolated strain belongs to staphylococcus. We investigate the performance of the staphylococcus bacterium on the lubricant from biological degradation aspects, using a gas chromatography technique. It was observed that the exposure of a small amount of the bacteria against 10 mL of lubricant indicates a considerable degree of degeneration, only in a few days. The residual crude oil in the culture medium was analyzed by gas chromatography (GC) and SARA. The results confirmed that the strain can degrade crude oil and produce lighter hydrocarbon. The saturate fraction increased about 23%, while the Resin and Asphaltene fractions decreased about 11% and 12%, respectively. This research is the first report on the characterization of crude oil-degrading bacteria from in situ bacteria at Hawizeh Marsh and by using this bacterium in the field the effect of oil pollution can be reduced on this marsh environment in a few days.
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E. O, Kalu,, Okeke O. C, Amadi, C. C, Akudike, J. C, Dozie, O. T, Sunday, E. U, and Okonkwo, S. I. "A Review on the Geologic Occurrence, Development and Associated Environmental Problems of Unconventional Hydrocarbon Energy Resources." Volume 5 - 2020, Issue 8 - August 5, no. 8 (September 11, 2020): 1411–23. http://dx.doi.org/10.38124/ijisrt20aug809.
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Unconventional hydrocarbon energy resources are non renewable energy resources whose major constituents are hydrogen and carbon. They have indistinct source rock- reservoir rocks-trap rocks characteristics/boundaries and unique exploitation technologies including mining and processing (surface and underground production using retorts for exploitation of oil shale and coking units for exploitation of bitumen; in-situ treatment and recovery (underground production using thermal treatment, chemical flooding and gas injection for exploitation of heavy oils in particular); and well production /underground production using vertical drilling, horizontal drilling and hydraulic fracturing. Only well production technology is applicable to conventional hydrocarbon energy resources, that is petroleum and natural gas exploitation. There are five classes of unconventional hydrocarbon energy resources including: coal bed methane (CBM), oil shale, shale gas/shale oil, heavy oil/bitumen, and natural gas hydrates. Worldwide, the recoverable methane from coal bed methane resources is about 2625 tcf. Similarly, the recoverable billions of barrels of oil from shale oil, heavy oil and bitumen, resources worldwide are 28626,443 and 651, respectively. Over 90% of these, that is, shale oil, heavy oil and bitumen are found in USA Venezuela and Canada respectively. The environmental problems associated with development of unconventional hydrocarbon energy resources include: surface/groundwater pollution; water depletion; air pollution and hazards of solid wastes from oil shale and bitumen mining/ processing. However, energy produced from unconventional hydrocarbon energy resources are similar to those produced from other (conventional) energy resources and can be equally used for various purposes including industrial, residential, transportation and commercial.
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Papp, R., and S. J. Fisher. "DRILLING FLUIDS AND THEIR ENVIRONMENTAL MANAGEMENT: CHARACTERISATION OF BASE FLUIDS AND THE INTRODUCTION OF QUALITY CONTROL PROCEDURES." APPEA Journal 39, no. 1 (1999): 628. http://dx.doi.org/10.1071/aj98042.
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Since the early 1990s, a variety of invert emulsion base fluids have been introduced into the drilling fluid market. The chemical composition of these fluids has evolved with the focus on minimising the environmental impact of discharged cuttings that contain adhered drilling fluids.The trend within Australia and other regions in which drilling fluids are extensively used, is that the life span of these fluids has become increasingly shorter, due to environmental impact pressures from the regulatory authorities in the North Sea and Australia, as well as public perception within these regions.The Well Construction Department within Woodside Energy Ltd. (WEL) has identified the need to characterise these base fluids in a manner that was both reproducible and definitive. The need was driven by the availability of a large number of commercial base fluids claiming technical and environmental superiority and the requirement for robust quality control systems for the base fluids from production to discharge—a cradle to grave philosophy.To this end, a study was initiated in 1997 where several drilling fluids were analysed using gas chromatography- mass spectrometry (GC-MS) techniques. From this work, four classifications of invert emulsion, non-water based fluids (NWBF) have been identified. They include low toxicity oil based fluids (LTOBF), enhanced mineral oil based fluids (EMOBF), synthetic based fluids (SBF), and oxygen based fluids (OBF). The definition of these fluids and the rationale for this classification is presented here.The GC-MS characterisation has provided an insight into the structure of the base fluid, rheological characteristics, quality control/quality assurance, and in the future, the ability to develop a robust link to minimising environmental impact of the discharge.All of these benefits will aid in developing drilling fluids which achieve the technical objectives of drilling fluids as well as minimising the environmental impact. The quality control procedures for the base fluid also allow an auditable process for benchmarking with input from the regulator, operator, fluid service company and manufacturer.
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Ferreira, Hélder O., Alexandre Cabrai, and Álvaro Souza Junior. "An Application of Worst Case Scenario Concept in Oil Spill Response Planning for Offshore Drilling Operation in Brazil." International Oil Spill Conference Proceedings 2003, no. 1 (April 1, 2003): 371–76. http://dx.doi.org/10.7901/2169-3358-2003-1-371.
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ABSTRACT The Brazilian oil and gas E&P sector has been experiencing important changes since the end of the state monopoly in 1998. These changes include a new regulatory environment which is still under construction, in particular the requirements for environmental protection. In this context, Resolution 293 of Brazilian National Environmental Council (CONAMA) was enacted regulating Facility Response Plans for oil spill incidents. These plans, which should be approved by the competent authority, include a vulnerability analysis that should discuss the probability of oil reaching certain areas as well as the environmental sensitivity of these areas. Oil spill modeling is an important tool to estimating the areas likely to be affected by an oil spill. Although oil spill modeling is also part of the environmental studies required in the environmental permitting process for oil E&P activities, there are not well defined criteria to compose the oil spill scenarios to be modeled. In order to demonstrate the impacts of different approaches in the results of oil spill modeling, a case study is presented related to an offshore drilling activity.
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Błaż, Sławomir. "Odwracalne ciecze emulsyjne o wysokim stężeniu fazy wewnętrznej (HIPR)." Nafta-Gaz 77, no. 3 (March 2021): 175–86. http://dx.doi.org/10.18668/ng.2021.03.04.
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Invert muds are the most commonly used oil-based drilling muds. The oil to water phase ratio in invert drilling muds ranges from 65/35 up to 90/10, with the most common ones ranging from 70/30 to 80/20. At these oil to water phase ratios, the drilling mud is characterized with high stability and appropriate rheological and structural parameters allowing to adjust drilling mud density in a wide range. One of the disadvantages of invert muds is their cost (due to oil content) and environmental problems associated with waste and management of oily drill cuttings. Taking into account the properties of oil-based muds, the article presents laboratory tests aimed at developing the composition of an invert mud with a limited oil phase content and high internal phase ratio (HIPR). Drilling muds with an o/w ratio less or equal to 50/50 vary from conventional inversion muds in terms of their composition and properties. Due to the higher concentration of the dispersed inner phase, muds have reduced stability and high rheological and structural parameters. Maintaining the appropriate rheological and structural parameters of the drilling mud and its high stability is possible only through the use of appropriate chemicals adapted to the emulsion system with a specific oil to water phase ratio. In the drilling muds of this type it is also possible, due to the higher concentration of the internal phase, to partially adjust the density of the mud with the water phase, such as salt solutions, thus limiting the solids content (weighting agents) in the mud. The developed mud system should be more economical, have a reduced toxicity, while maintaining the operational advantages of invert mud. These types of muds can be used during the drilling of reactive shale formations, salt layers, gypsum and anhydrite layers, as well as for drilling productive horizons and for reconstruction works carried out in oil and gas wells.
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Carpenter, Chris. "Drilling Dynamics, Mechanical Specific Energy Data Help Drill Record Extended-Reach Well." Journal of Petroleum Technology 73, no. 05 (May 1, 2021): 59–60. http://dx.doi.org/10.2118/0521-0059-jpt.
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This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 203335, “Using MSE and Downhole Drilling Dynamics in Achieving a Record Extended-Reach Well Offshore Abu Dhabi,” by Nashat Abbas and Jamal Al Nokhatha, ADNOC, and Luis Salgado, Halliburton, et al., prepared for the 2020 Abu Dhabi International Petroleum Exhibition and Conference, Abu Dhabi, held virtually 9–12 November. The paper has not been peer reviewed. Complex extended-reach-drilling (ERD) wells often present challenges with regard to geological aspects of data requirement and transmittal, reactive geosteering response times, and accuracy of well placement. Such scenarios may require innovative approaches in Middle East carbonate reservoirs. The objective of the complete paper is to illustrate that, by assessing the details of reservoir geology and key operational markers relevant for best practices, drilling approaches can be customized for each reservoir or scenario. Reservoir Background and Geology The planned reservoir section is a single horizontal of approximately 25,000-ft lateral length at a spacing of 250 m from adjacent injectors. The well was drilled from an artificial island. Field A, a shallow-water oil field, is the second-largest offshore field and the fourth-largest field in the world. Horizontal drilling was introduced in 1989, and an extensive drilling campaign has been implemented since then using steerable drilling technologies. This study is concerned only with wells drilled to develop Reservoir B in Field A, which contributes to the main part of initial oil in place and production. The thick limestone reservoir is subdivided into six porous layers, labeled from shallow to deep as A, B, C, D, E, and F. Each porous layer is separated by thin, low-porosity stylolites. The reservoir sublayer B, consisting of approximately 18-ft-thick calcareous limestones, was selected as the target zone for the 25,420-ft horizontal section. ERD, constructed on artificial islands, began on 2014 with a measured depth (MD)/true vertical depth (TVD) ratio approaching 2.2:1 or 2.4:1. A recent ERD well, Well A, was drilled at the beginning of 2020 with a MD/TVD ratio of 5:1. This value is a clear indication of progressively increasing challenges since the start of the project. Mechanical specific energy (MSE) has long been used to evaluate and enhance the rate of penetration (ROP); however, its use as an optimization tool in ERD wells has not been equally significant. This may have been mostly because of historical use of surface-measured parameters, which do not necessarily indicate the energy required to destroy the rock, particularly in ERD wells. Using optimization tools as part of the bottomhole assembly (BHA) downhole close to the bit provides actual weight-on-bit (WOB) and torque-on-bit (TOB) applied to the drilling bit to destroy the rock and, thus, results in more-representative MSE measurements to optimize drilling parameters and ROP in ERD wells.
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Galitskova, Yulia Mikhailovna. "USE OF DRILLING MUDS." ENVIRONMENT. TECHNOLOGIES. RESOURCES. Proceedings of the International Scientific and Practical Conference 1 (June 20, 2019): 59. http://dx.doi.org/10.17770/etr2019vol1.4101.
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Drilling of wells is accompanied by pollution of all environmental components with drilling and process waste. With drilling operations carried out, terrain and soil mass disturbance occur first. Waste generated during the drilling process includes drilling muds, return drilling muds, drilling wastewater. The contaminating ability of drilling waste is determined by the use of chemical reagents and components involved in the preparation and processing of drilling muds. The use of additives and reagents is necessary to make sure the solution displays certain properties that ensure effective well drilling. The resulting waste is usually disposed of at landfills or is buried at the site of formation in mud pits, ensuring minimal environmental impact. The use of drill muds in other spheres is hindered by the complex composition of oily waste.The composition of liquid and solid fractions of drilling muds from several deposits were studied in laboratory setting. Waste samples were analyzed for moisture content, organic substances, oil products and other substances. According to the results of the research, measures for improving the properties of drilling muds were developed and proposed. For this purpose, an introduction of high sorption substances to the waste is proposed.The most effective should be the use of a sorbent capable of retaining organic matters and heavy metals. The resulting homogeneous soil-like mixture can be used for land reclamation in the city areas and other settlements, when performing planning works at the initial and final stages of construction, as well as at landscaping residential areas.
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Gomes, R. S., J. D. R. Lopes Gomes, M. L. L. Costa, and M. V. F. E. S. Miranda. "Relevant aspects of radiation protection in oil and gas well logging." Journal of Radiological Protection 33, no. 4 (October 1, 2013): 839–53. http://dx.doi.org/10.1088/0952-4746/33/4/839.
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Portilla, Carlos, Alamir Alvarez, and Romel Erazo. "Análisis comparativo técnico - económico de producción de crudos pesados en pozos horizontales y direccionales, arena “m-1” formación napo, bloque 16, oriente ecuatoriano." Revista Científica y Tecnológica UPSE 3, no. 3 (December 23, 2016): 165–71. http://dx.doi.org/10.26423/rctu.v3i3.208.
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Los tipos de perforación ejecutados en el campo Amo son: perforación vertical, direccional y horizontal. El objetivo de este trabajo es analizar qué tipo de perforación conviene hacer en el campo Amo. La selección del pozo a perforar, es mediante un análisis comparativo técnico-económico entre un pozo horizontal y un pozo direccional. Para este análisis es necesario disponer de la información técnica de los pozos seleccionados que se obtuvo a través de la operadora del Bloque 16. La formación Napo (arenisca M-1) son areniscas delgadas permeables. La completación de cada pozo está diseñada para extraer grandes cantidades de fluidos; la parte más elemental de este trabajo se basa en la comparación técnico-económica de los dos pozos seleccionados. En la evaluación técnica, se puede decir que el pozo horizontal Tigre 1, tiene una mayor producción de petróleo y agua, lo cual tiene un mejor rendimiento de ganancias. Finalmente, la perforación de los pozos, horizontal como direccional, ayuda a disminuir considerablemente la deforestación. Se concluye que la perforación de un pozo horizontal, comparado con un direccional, es más conveniente tanto técnica como económicamente, para los intereses de la empresa operadora de un campo. Abstract The types of drilling well executed in the Amo oilfield are vertical, directional and horizontal. The main objective of this paper is to analyze the best drilling way should be made in the Amo oilfield. The drilling well selection is by a techno-economical comparative analysis of a horizontal well and a directional well. For to make this analysis was necessary the use technical information of the selected wells, the data was obtained through the operator-company of Block 16 (Amo Oil field). The Napo (sandstone M-1) sandstones are thin and permeable. The completion of each well is designed to extract large quantities of fluids. The most important part of this work is based on technical and economic comparison of the two selected wells. In the technical evaluation, we can say that the Tiger (horizontal well) has increased production of oil and water, which performs better profit. The horizontal and directional well drilling would help to significantly reduce deforestation on the oilfield and increase the oil production. And, the horizontal drilling is more convenient than directional well according techno-economical aspects.
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Liakh, Mykhailo, Teodoziia Yatsyshyn, Svitlana Gavryliv, Yuriy Gavryliv, Lesia Shkitsa, Katarina Monkova, Peter Pavol Monka, and Vasyl-Danylo Liakh. "Environmentally-efficient approaches to oil and gas producing sites." E3S Web of Conferences 280 (2021): 09002. http://dx.doi.org/10.1051/e3sconf/202128009002.
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We have offered the investigations aimed at the design of eco-efficient technologies during oil and gas producing sites life cycle. The authors have conducted the analysis of conditions causing environmentally hazardous situations at oil and gas producing sites. We have established the necessity of quick maintenance of operation during emergencies that makes it possible to reduce material costs and environmental pollution. The increase of environmental safety in the process of winding up oil and gas wells emergencies that took place as a result of catching drilling string or some other pipe is crucial. We have analyzed different ways and various structural designs of the devices for pipe unscrewing from caught strings. We have established the ways of negative environmental impact reduction in the winding up emergencies at operating as well at stack oil and gas rigs. The recommendations regarding the structural design of the device are given. The device design is patented and the prototype model of the device is designed and manufactured. The device functions as the transformer of clockwise drilling string rotation into anticlockwise rotation of fishing tools. We have highlighted the positive effects after the implementation of the given device. We have noted the importance of innovative technologies design as well as the importance of forming adequate response skills during emergencies when wellsites are being constructed. The technical solutions and recommendations we have introduced make it possible to prevent negative environmental impact and reduce resource flows at different stages of wellsite life cycle.
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Biasetto, Bruno Henz. "Shock against nature: a comparative environmental history of oil drilling and oil Boomtowns in Brazil and Canada during the oil shock era (1967-1981)." Esboços: histórias em contextos globais 28, no. 47 (March 30, 2021): 115–34. http://dx.doi.org/10.5007/2175-7976.2021.e75947.
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This article focuses on the environmental impact of the oil industry during the Oil Shock years in the 1970s. During this period, Brazil and Canada explored new oil sources in order to deal with the lack of supply from the Middle East. The expansion of the national oil industry in both countries affected the fragile environment of several regions and the urban life of these places, as well. In understanding how these factors affected the urban environment and nature, it is possible to achieve a new understanding about what the Oil Shock meant on a global scale.
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Mohamed, Abdulrahman. "Novel approach for anti-collision planning optimization in directional wells." International Journal of Engineering & Technology 9, no. 2 (April 3, 2020): 333. http://dx.doi.org/10.14419/ijet.v9i2.30306.
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One of the most application of the directional drilling is drilling multiple wells from one location or platform. In drilling multiple wells from one location the major problem that faced is avoiding the collision with the offset wells that drilled near the proposed well in the same region. Therefore, the Potential of Collison between the wells can cause severe catastrophic accidents such as an explosion or oil spill. Several measurements of proximity calculation or methods have been adopted to control the distance between the wells, avoid the Collison, increas-ing the clearance along with smoothing the trajectory, Reducing the drilling time based on the anti-collision rules. A real case study of an offshore directional horizontal well drilled from the platform is studied through the paper. The proposed well is drilled in the neighboring of three Offset wells that should be Planned completely to avoid the Collison with them. The well is planned through an advanced anti-collision method that results in preventing the collision of well with optimized drilling performance through Oriented separation factor (OSF). This factor yields appropriate separation with OSF greater than 5. This yield efficient separation with offset well 1, offset well 2 and offset well 3 greater thant5, In addition to optimized drilling performance of 84% drilling versus 16% sliding that results in the completion of the well in 50 days with positive income that result in 8.55 Return on Investment (ROI).
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Teodoriu, Catalin, and Opeyemi Bello. "An Outlook of Drilling Technologies and Innovations: Present Status and Future Trends." Energies 14, no. 15 (July 26, 2021): 4499. http://dx.doi.org/10.3390/en14154499.
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The present article analyzes the technological advancement and innovations related to drilling operations. It covers the review of currently proven and emerging technologies that could mitigate the drilling operational deficiencies and instabilities that could hinder operational performance activities and the economic part of drilling development with great effort to minimize their environmental footprint. Drilling system design and operations are among the major aspects and cost-effective endeavors of the oil and gas industries, which are therefore technology dependent. They are also considered to be among the most expensive operations in the world, as they require huge expenses daily. Drilling success, depending on prevalent conditions, is a function of several general factors. These include the selection of the best technologies and tools, procedural optimization, concrete problem-solving, accurate prediction, and rapid decision-making. Consequently, any sorts of tools or advanced technologies that can improve the time-efficient operational and economic performance of drilling activities are essential and demanded. The paper provides a review of available technologies and developmental innovations based on both company-based and academic research-enabled drilling solutions over the past 5 years in the field of drilling systems and technological design. The paper further highlighted potential technologies that could be tapped in from other industries and could possibly be adopted by pushing the conventional boundaries of drilling operations.
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Li, Xiang-Guo, Yang Lv, Bao-Guo Ma, Shou-Wei Jian, and Hong-Bo Tan. "Influence of sintering temperature on the characteristics of shale brick containing oil well-derived drilling waste." Environmental Science and Pollution Research 18, no. 9 (May 24, 2011): 1617–22. http://dx.doi.org/10.1007/s11356-011-0526-0.
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Ismail, Abdul Razak, Muhammad Syafiq Ab Rashid, Nurul Jannah Ismail, Wan Rosli Wan Sulaiman, and Mohd Zaidi Jaafar. "Improved Coefficient of Friction Using Different Types of Lubricants in Drilling Operation." Advanced Materials Research 1125 (October 2015): 210–14. http://dx.doi.org/10.4028/www.scientific.net/amr.1125.210.
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The key performance of any drilling operation depends heavily on the choice of drilling fluid used as well as how good it can overcome the drill pipe friction. It is essential that the drilling fluid be able to reduce bit wear, torque and drag. Drilling with oil-based drilling fluid offer less torque and drag. However, water based drilling fluid are cheaper and environmental friendly compared to oil-based and synthetic-based drilling fluids. Lubricants are added to drilling fluid to produce a thin film of liquid that separates the solid surfaces in contact to reduce the friction to an acceptable range. This study focused on the performance evaluation of two different commercial lubricants, which are EBL and EME salt to improve the lubricity of water based drilling fluid. The performances of lubricants were evaluated by ranging the concentrations from 1%, 2% and 3%. Fann Lubricity Tester is used to test the lubricity of these lubricants. The results reveal that the coefficients of friction for all lubricants were reduced after reaching the optimum concentration at the range of 1 - 2%. Some improvements were observed on the rheological properties such as plastic viscosity, yield point and gel strength when the lubricants were added to the drilling fluid. The values satisfy the requirement accepted by the industry. This study also showed that the applicants of EBL lubricant is better than EME salt in term of reducing the coefficient of friction in drilling fluid.
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Terrens, G. W., D. Gwyther, and M. J. Keough. "ENVIRONMENTAL ASSESSMENT OF SYNTHETIC-BASED DRILLING MUD DISCHARGES TO BASS STRAIT, AUSTRALIA." APPEA Journal 38, no. 1 (1998): 610. http://dx.doi.org/10.1071/aj97037.
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Esso Australia Ltd. (Esso) on behalf of the Esso/BHP joint venture undertakes exploration and development drilling activities to produce oil and gas from the Gippsland Basin in eastern Bass Strait. As part of the environmental management of the operation, a field monitoring program was undertaken to verify the predicted limited effect on the seabed of the discharge of residual synthetic based mud (SBM) adhered to drill cuttings.Reservoir studies of the mature Fortescue oil field identified scope to more efficiently deplete existing reserves as well as develop undrained oil pools within the known reservoir system. As such, 18 additional wells were drilled from the Fortescue platform in 1994-1996 following the original development drilling program when 21 wells were drilled in 1983-1985.Esso's standard drilling fluid in Bass Strait is an environmentally acceptable water based mud (WBM). However, due to the high frictional forces involved the greater lubricating properties of a non-water based drilling mud were required to drill the long reach, high angle sections of seven of the additional wells. The ester SBM was chosen on the basis of its lubricity and biodegradability, to reduce any potential environmental effects from the persistence of non-water based mud in seabed sediments.A seabed monitoring program was undertaken around the Fortescue platform by taking seabed samples from August 1995 to August 1997 at sites along a transect following the predominant ocean current and at control sites, before, during and after the period in which SBM cuttings were discharged. The seabed sediments were measured for esters, barium, biological changes and grain size. Results show clearly the increase in esters concentration in sediments during drilling, then the rapid decrease after completion of cuttings discharge. After a recovery period of 11 months from completion of SBM drilling, SBM esters were not detected in sediments. Sediment barium concentration was also found to be elevated, but only after SBM had been used, indicating greater dispersion of WBM than the more cohesive SBM. The barium concentrations found generally do not have measurable effects on biota. The impact on the sediment biology was found to be limited to the sampling site 100 m from the platform discharge point with recovery evident within four months of completion of drilling.Mechanisms for recovery of the minimal zone of effect are thought to be a combination of the biodegradation of the ester SBM used and the physical seabed dispersion process evident in eastern Bass Strait generated by the continuous series of storms which pass through especially in winter.
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Hussein, Maher Falih, Ahmed Rahman Shabib, and Salah Faisal Abood. "Optimized Well Construction Cost Estimate in South of Iraqi Fields/ Case Study from Zubair Field." Journal of Petroleum Research and Studies 11, no. 1 (May 7, 2021): 168–85. http://dx.doi.org/10.52716/jprs.v11i1.438.
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Cost estimation and control is a crucial activity for well engineering and construction. Inaddition to the technical preparation before drilling an oil well, well construction cost is one ofthe essential activities leading to AFE (authorization for expenditure). Recently theprobabilistic method for cost estimate became necessary for understanding the risk anduncertainty of a certain cost range instead of a single (deterministic) value. This work describesthe main types of drilling contracts have been used in Basra oilfields and discusses theprinciples of well construction cost estimate according to those contracts. In addition, itsummarize the relevant cost breakdown for drilling operations. The research also illuminatesthe probabilistic method for effective well cost estimating along with deterministic method. thestudy subdivided the process of well construction into segments for cost tracking, emphasizedthe main aspects influence the well cost and leading to a methodology that can be applied bythe operator for onshore well in the south of Iraqi fields. The methodology used in this workincludes, first, analyzing data from offset wells to facilitate the possible cost out comes, andsecond, subdivide the well construction activities into fixed costs, time dependent and depthdependent costs. A probabilistic model (Monte Carlo simulation) for cost estimating isconstructed using @ Risk software. The results released for risked drilling operation, whichincludes the NPT. While revising the historical cost performances in Zubair field, it has foundthat the best practices and lesson learned of the previous activities has significantly contributedin time and cost reduction of well operation. The findings of this work contributes to improvethe decision-making by managers for best investment, enhance the planning for next activitiesand confident choice of well budget. It also helps to investigate the critical factors and actions
that can be applied on operational and contractual parameters to achieve cost reduction. A casestudy from Zubair field will be presented in order to illuminate the mentioned points.
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Flemming, H. C., and J. Wingender. "Relevance of microbial extracellular polymeric substances (EPSs) - Part II: Technical aspects." Water Science and Technology 43, no. 6 (March 1, 2001): 9–16. http://dx.doi.org/10.2166/wst.2001.0328.
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Extracellular polymeric substances (EPSs) are involved in both detrimental and beneficial consequences of microbial aggregates such as biofilms, flocs and biological sludges. In biofouling, they are responsible for the increase of friction resistance, change of surface properties such as hydrophobicity, roughness, colour, etc. In biocorrosion of metals they are involved by their ability to bind metal ions. In bioweathering, they contribute by their complexing properties to the dissolution of minerals. The EPSs represent a sorption site for pollutants such as heavy metal ions and organic molecules. This can lead to a burden in wastewater sludge; on the other hand, the sorption properties can be used for water purification. Other biotechnological uses of EPS exploit their contribution to viscosity, e.g., in food, paints and oil-drilling ‘muds’; their hydrating properties are also used in cosmetics and pharmaceuticals. Furthermore, EPSs may have potential uses as biosurfactants, e.g., in tertiary oilproduction, and as biological glue. EPSs are an interesting component of all biofilm systems and still hold a large biotechnological potential.