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E. A. Emam/Petroleum & Coal 57(5) 532-555, 2015 538 4.1 Government legislation Gas flaring and venting measurement has been identified as an important issue where the GGFR could make a meaningful contribution to the global flaring reduction agenda by collecting and disseminating a best practice [23]. On the Norwegian continental shelf, regulations were implemented in 1993 relating to the measurement of fuel and flare gas for calculation of CO2 tax in the petroleum activities [36]. Recently, with gas prices elevated, and new government legislation on the horizon, producers, refineries and chemical plants have been looking for a cost effective solution to reduce emissions, and to provide control for both leak detection and mass balance. The Alberta Energy and Utilities Board (EUB) guide 60 will soon be improved with regards to flare, and other regions in Canada are expected to follow suite [37-38]. The guide will state that measurement will be required for continuous or routine flare and vent sources at conven- tional oil-gas production and processing facilities where an average total flared and vented volumes per facility exceed 500 m3/day [38-39]. Acid gas flared, either continuously or in emergencies, will required to be measured from gas sweetening systems regardless of volume and fuel (dilution or purge) gas added to acid gas to meet minimum acid gas heating value requirements and SO2 ground level concentra- tion guidelines. EUB Guide 60 references EUB Directive 017: Measurement Requirements for Upstream Oil and Gas Operations officially released February 1, 2005 [40]. In this directive it specifies the following uncertainties that must be met: • measurement uncertainty for gas flaring must be ± 5 %, • measurement uncertainty for dilution gas must be ± 3 %, • measurement uncertainty for acid gas must be ± 10 %, • accuracy specifications apply to the overall rangeability of the process conditions. 4.2 Flow meter challenges Gas flaring flow measurement applications present several unique challenges to plant, process and instrument engineers when selecting a flow meter system. There are many challenges when trying to measure gas flaring, including diameters of large pipe, high flow velocities over wide measuring ranges, gas composition changing, low pressure, dirt, wax and condensate. The applications of flared gas measurement have uniquely challenged with two various and critically important flow conditions: very low flow under normal conditions and sudden very high flows during an upset blow-down condition. Additionally, several other important criteria must be considered when selecting, constraints and considerations a flow meter for flared gas applications, plant operators, managers, process and instrument engineers, such as the following [23,34,39- 41]: Operating range, the meter should be sized to accommodate the anticipated range of flows. Accuracy, the minimum required accuracy of the instrument will depend on the final use of the measurement data and applicable regulatory requirements. Installation requirements, the flow meter should be installed at a point where it will measure the total final gas flow to the flare and be located downstream of any liquids knock-out or disengagement drum. Maintenance and calibration requirements, all flow meters are susceptible to deteriorated performance with time and use; although, some are more robust than others. Composition monitoring, most types of flow meters are composition dependent. There are two primary options for composition monitoring: (1) sampling and subsequent laboratory analysis, or (2) the use of continuous analysis. Temperature and pressure corrections, the flow meter will need temperature and pressure compensation features to correct the measured flow to standard conditions (101.325 kPa and 15°C) or normal conditions (101.325 kPa and 0°C). Multi-phase capabilities, normal practice, if the gas stream contains high concentrations of condensable hydrocarbons, the gas flow meter should be installed as close as possiblePDF Image | GAS FLARING IN INDUSTRY
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