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Results
Offshore Environmental Monitoring Management in Oil & Gas Activities: eni Experience on Baseline Acquisition and Operational Phases
Buffagni, M. (eni e&p division) | Zappacosta, I. (eni e&p division) | Cova, C.A. (eni e&p division) | Pedroni, L.V. (eni e&p division) | Aiello, G. (eni e&p division) | Gioia, G. (eni North Africa) | Gasparoni, F. (tecnomare SpA) | Bruni, F. (tecnomare SpA)
ABSTRACT Offshore Environmental Monitoring can be defined as technical and institutional activity aimed at measuring, evaluating and tracking environmental changes induced by an operation or by a combined sum of operations. The overall objective is identifying both predicted and unanticipated changes to the physical, chemical and biological environment caused by all the e&p activities, in order to enable the Company to take the appropriate corrective measures at the right time. Robust baseline monitoring could also be used to assess impacts related to any e&p project in order to reduce potential impacts. According to this approach, the baseline information on pristine conditions is compared against exploration drilling, development and post-development impacts. Mitigation measures can be assessed and their efficiency evaluated through the monitoring activity. Since the first years of 1990, eni e&p has carried out several environmental monitoring campaigns around its offshore installations (e.g. Italy and Norway) with the aim to monitor changes in the current state of the environment, assessing evolutionary trends of environmental key components. These surveys have permitted to determine whether any detected change in environmental components was caused by e&p activities or by natural occurrences. Besides they were able to provide early warning of any potentially serious impact and to provide decision support for strategic decisions. Based on the above considerations, this paper presents significant experiences of work carried out by eni in offshore environmental monitoring management, both during baseline acquisition and operational phases.
ABSTRACT: Innovative technological solutions have been developed and applied since 2004 by Istituto Nazionale di Geofisica e Vulcanologia (INGV) and Tecnomare Spa to detect and monitor anomalies of methane in near-bottom seawaters related to natural gas seepage. These solutions are based on the use of commercial methane sensors, combined with multidisciplinary (oceanographic and geophysical) instruments, operated by customdesigned benthic stations or "inspection" modules. We show examples of long-term continuous gas monitoring performed by seafloor observatories GMM and SN-4, as well as examples of areal exploration surveys by instrumented module MEDUSA. Long-term monitoring at seepage sites showed CH4 variations apparently related to episodic degassing activity, as a sort of "pulsation" events. Exploration surveys allowed to identify areas of gas seepage in correspondence with mounds and tectonic dislocation on the seabed. Analyses of molecular and isotopic composition of gas dissolved in seawater sampled during the exploration surveys, allowed to assess the origin of gas. The surveys also showed a good sensitiveness and reaction time of all sensors (methane, oxygen, temperature, turbidity meter, supported by video camera and lights) approaching gas seeps. In all cases, methane sensor redundancy and specific cross-checks of data from different sensors adopted proved to be fundamental to distinguish weak but actual seepage events from spurious signals related to oceanographic or instrumental variability
- Europe (0.47)
- North America > United States (0.27)
- Information Technology > Communications > Networks (0.47)
- Information Technology > Data Science (0.46)
ABSTRACT: Exploration and production of offshore oil&gas fields is extending to increasingly deep waters and environmental sensitive remote areas. Current plans and projects aim to install and operate platforms with a water depth between 1500 and 3000 m. This puts high demands on platforms, pipelines and risers, in particular in term of design limits and integrity of these structures due to extreme variability of environmental conditions. It is therefore beneficial to rely on a permanent and real time monitoring system, able to give information on static and dynamic structural loads by direct measures of strain levels experienced by critical components during its whole lifetime. Capability to detect and locate leakages in pipelines is another major issue, for the environmental and economic consequences associated to an oil/gas spill at sea. Accurate and continuous temperature monitoring over risers and pipelines may also give important indications for flow assurance purposes. Fiber optic sensors are one of the most promising solutions for the continuous monitoring of structural loads, leakages and temperature on new and existing structures during the whole lifetime. This technology is well known and has many applications in onshore activities like civil engineering (dams, bridges, galleries, buildings), nuclear and industrial plants, aerospace. Transfer to the offshore oil&gas facilities is ongoing, but specific efforts are required for the development of engineered and qualified solutions, capable to meet the demanding requirements of the offshore and deepwater applications (aggressive environment, pressure, installation constraints, capability to operate for lifetime in the order of tens of years). This paper gives an overview of the status and perspectives of fiber optic monitoring in offshore oil&gas applications, including a description of the main results of past and ongoing Eni E&P research projects in this field, that included a field test of a riser strain monitoring system in shallow water, the qualification of a FO strain sensor for deep water applications (3000 mwd) and the design and qualification of fiber optic sensors for pipeline leak detection and temperature profile measurement on long pipelines and sealines
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Carnarvon Basin > Barrow Basin > Greater Gorgon Development Area > Block WA-4-R > Spar Field > Upper Barrow Formation (0.93)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Carnarvon Basin > Barrow Basin > Greater Gorgon Development Area > Block WA-13-L > Spar Field > Upper Barrow Formation (0.93)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Alpha Arch > Barrow Basin > Greater Gorgon Development Area > Block WA-4-R > Spar Field > Upper Barrow Formation (0.93)
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Replat - Reuse Of Offshore Platforms
Alberti di Catenaja, C. (Eni E&P) | Ferraro, M. (Eni E&P) | De Marchi, E. (Tecnomare) | Bruni, F. (Tecnomare) | Gasparoni, F. (Tecnomare) | Lazzarini, M. (Tecnomare) | Prendin, W. (Tecnomare)
ABSTRACT: Many of the oil and gas installations in the Adriatic Sea are reaching the end of their economic production life, and proposals for their decommissioning are being prepared. On this regard Eni E&P Division launched in 2003 an R&D project (REPLAT - REuse of offshore PLATforms) aimed at developing a procedure to support the technical and economic feasibility evaluation of reusing offshore platforms/structures. The project includes a comparative study of strategies and addresses technical, ecological, regulatory, political and economic issues. Various reuse options are systematically considered and evaluated, such as fish-farming, production of energy from renewable sources, scientific applications, technological applications and others. Project partners are Companies of Eni Group (Tecnomare, CEOM, Fondazione Enrico Mattei). Other Organizations that may be involved in the project are ARPA - Agency for Environmental Protection of Emilia Romagna Region, ICRAM - an Institute of the Ministry of Environment for marine research, etc. There are about 5995 oil and gas platforms in the world and 124 are operative in the Adriatic Sea. In future, in Italy a lot of offshore gas installations will be decommissioned. Their average age is 17 years (75% > 11 years, 25% > 22 years). The results of this project can modify or address plans for decommissioning, because the fate of offshore installations will be different if the new hypothetical scenarios are able to minimize costs and environmental impact of the offshore petroleum industry. Often, the best way to achieve these goals is to facilitate the reuse and refurbishment of offshore facilities and their components for non-Oil activities