RECENT OPERATOR INITIATIVES TO IMPROVE THE PERFORMANCES OF WET GAS FLOW MEASUREMENTS BY CONSIDERING THE LIQUID ATOMIZATION IN VENTURI FLOWMETERS
Author(s): Marie LOUSTAU, Jean-Paul COUPUT, Virginel BODOC, Pierre GAJAN
Abstract/Introduction:
In gas chains comprising production, transport, storage & supply, natural gas as well as other gases are not always dry which means they are associated with liquid resulting from condensation as well as entrainments due to process for instance. Such situation has conducted flow metering systems manufacturers, flow labs, standardization bodies 1 & operators 2 with the support of R&D to develop knowhow and wet gas measurement solutions since many years. In oil & gas upstream area, the focus has been up to now the improvement of so-called wet gas flow meters WGFM as per ISO TR 3 especially for monitoring & metering of gas & gas condensate wells (gas with condensate & water entrainments) with significant results & progress both in hardware as well as in associated calculation & correction softwares. In the energy transition period with an anticipated growth on natural gas as well as non-hydrocarbon gases, need for cost effective & accurate wet gas measurement is still expected.
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Document ID:
0DE6616F
Accuracy Testing of Domestic Gas Flow Meters with 20% Hydrogen Blend
Author(s): Marc MacDonald, Dale Anderson, Thomas Isaac, Sikander Mahmood
Abstract/Introduction:
[Abstract Not Available]
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Document ID:
49E36FDC
Gas flow traceability for non-conventional and renewable gases
Author(s): Dr. Jos van der Grinten, Dr. Bodo Mickan, Dr. Henk Riezebos, Dr. Dennis van Putten
Abstract/Introduction:
DNV in Groningen, Netherlands has initiated a Joint Industry Project (JIP) 1 to study the performance of currently available metering technologies when operating non-conventional gases. These gases can contain high-CO2 percentages from biogases or related to carbon capture and storage (CCS). Also, hydrogen can be mixed into natural gases in the gas grids as part of the energy transition. The objective of the study is to understand instrument sensitivity for these gases and to define scaling rules which allow meters to be calibrated on gases different from the field application. For the JIP experiments four turbine gasmeters and nine ultrasonic gasmeters of several manufacturers are tested with different gases. A traceable reference system is needed with proven uncertainty related to type of gas or the composition of the gas mixture.
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Document ID:
F0753575
Paper 12 JIP renewable gases results on performance of turbine and ultrasonic flow meters up to 30% Hydrogen and 20% CO2
Author(s): Dr. Henk Riezebos
Abstract/Introduction:
[Abstract Not Available]
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Document ID:
073D5307
Using Subsea Multiphase Flow Metering Data for Remote Characterization of Fracking Fluid-Containing Liquid Phase
Author(s): Mahdi Darab, Ola-Marius Langelo Ryset,
Abstract/Introduction:
This paper describes a method for remotely detecting impurity in the liquid phase from a subsea producing reservoir in the Gulf of Mexico using multiphase flow metering data. The data was studied, and the outcome of the analysis was a modification of the meter fluid attributes. The new configuration parameters were successfully implemented as an update to the subsea meter. Later experimental analysis of the water phase confirmed the presence of frac fluid and almost identical fluid properties as remotely predicted via multiphase flow metering data. The technique described here demonstrates novelty in accurate characterization of frac fluid-containing liquid phase that can be performed remotely with a robust troubleshooting method for multiphase flow meters. This is specifically of interest for subsea production where minimal intervention is desired due to costly installation access.
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Document ID:
7F7F0E28
Data-driven Modelling for Condition-based Monitoring and Flow Regime
Prediction in Flow Systems
Author(s): Behzad Nobakht,
Yanfeng Liang,
Gordon Lindsay,
Sandy Black
Abstract/Introduction:
Digitalisation strategies are now commonplace throughout manufacturing and engineering
sectors. A major driver for this has been the fact that end-users now have a wealth of
diagnostic data available to them from digital transmitters associated with a wide variety
of devices installed throughout facilities. The data can be accessed in real time, for
example, through OPC (Open Platform Communications) servers or stored in a database
for future analysis. The vast amounts of data now being collected requires intelligent
software to deliver analytics solutions and allow end-users to make better use of the data
which they own.
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Document ID:
0738240D
Setting up a fit for purpose well testing environment in PETRONAS
Author(s): Wan Adrie Wan Ahmad
Abstract/Introduction:
Lets face it. Well testing can be tough. This paper will chronicle the challenges that has been plaguing well testing activities, especially so when utilizing MPFMs. A catalogue of pain points unearthed by a collaborative effort not limited to metering practitioners, production technologists and planners alike. Complex as it may be, these pain points are identified, compiled and will be described comprehensively as part of the problem statement. Field potential optimizations are often complicated in an oil field with large number of wells, as gas and water production increasing, both can affect each well optimization due to many reasons (lower reservoir pressure, increasing gas-oil ratio, backpressure from produced gas and water, etc.). Achieving optimum production for the total field requires good understanding on the well performance and flow characteristic as accurately as possible. Accurate well data can help operations to effectively plan well activities such as choke optimization and gas lift optimization. Without good and accurate data, the efficiency of optimization programs will not be significant - resulting in lower revenue return on investment made for these activities.
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Document ID:
9E2CB564
How to Reduce OPEX (i.e. Calibration/Maintenance
Frequency) thru Generic In-Situ Flow Validation for any
Wet Gas and Multiphase Flowmeter
Author(s): Dr Bruno PINGUET,
Dr Brian MILLINGTON,
Hamza MATTALA
Abstract/Introduction:
[Abstract Not Available]
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Document ID:
8A4ACE67
Multiphase Metering Using a Dual Frequency Coriolis Mass Flow Meter
Author(s): Sakethraman Mahalingam, Hao Zhu, Liyun Lao
Abstract/Introduction:
Coriolis meters are used on the liquid line coming out of many first-stage separators to measure the mass flow rate of the produced hydrocarbon liquid. In addition to the mass flow rate, the liquid density from the meter is conveniently interpreted as a water-cut measurement. However, given that many of these separators are at least a decade old, they are often operating outside of their design specifications and may have gas carry-under issues. In many cases, the Gas Volume Fraction (GVF) may be as much as 25% on the liquid line while they are designed to have less than 1% GVF. Unfortunately, many of Coriolis meters on these separators today are unable to tolerate a GVF of even 5%. When most of the time, the gas is present as free bubbles, in some cases, it may be trapped within the oil. There is a big need for getting accurate and reliable flow measurements from these facilities to enable proper reservoir management 1.
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Document ID:
5EC70F01
Non-Radioactive Multiphase Flowmeter for Quantifying Solid Particles Entrained in Fluid Flow
Author(s): Cornelius Emeka Agu, Evgeniy Tantserev, Arne Tobias Elve, Audun Aspelund
Abstract/Introduction:
Knowledge of solid flow rate or solid fraction in a multiphase flow is essential for management and controlling of the related operational challenges in Oil & Gas companies. For example, the production of sand particles in an aging well can lead to pipeline blockage and erosion. The concentration of drilling cuttings above the threshold may result in poor circulation of drilling fluid. In this paper, ABBON AS proposes an approach by which a non-radioactive multiphase meter can be used to measure the flowrate of solid particles entrained in a fluid flow. The measurement principle and approach proposed are similar to those used in the ABBON 3PM but with additional pressure loss measurement to account for the solid phase loading. To ensure proper splitting of flows into individual rates, this paper also reports the investigation carried out on verification of the response of the impedance sensors under fluid-solid environment using clay particles of density 1855 kg/m3 and different mean particle sizes, 700, 1200 and 5000 m. The fluids used in the test include air, oil with permittivity of 2.2 and water with three different salinities in the range, 1 - 15%. The results confirm that both the capacitive and conductive sensors respond appropriately to solids entrained in the fluids, which also agrees with the classical mixing models proposed to use in this metering concept. Furthermore, theoretical error analysis shows that the uncertainties in predicting the mixture density and solid flowrate over the GVF range, 1 - 100% lie below 5% and 10%, respectively. In a fluid-solid mixture with no gas, the errors can be significantly reduced to 1.5% and 7.5%, respectively.
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Document ID:
5BDC2FE2
Gas USMs: A Guide to Creating a Condition-Based
Monitoring System
Author(s): Patrick Arnould,
James Trail
Abstract/Introduction:
Ultrasonic flowmeters (USMs) have been used within the fiscal side of the oil & gas
industry for at least 25 years. During this time a wealth of experience and
understanding of the capabilities of this technology has been documented in journal
articles and in numerous papers from various conferences around the world.
USMs were identified early on as having potential for condition-based monitoring
(CBM), where the user makes use of the diagnostic data provided by the USM to
target manual interventions where required. Once collected and analysed, the data
can be used to determine when flow calibration should be scheduled (condition-
based calibration).
USMs vary widely in design which creates complexity in understanding design
characteristics and interpreting certain diagnostic parameters. Whilst the
information is available in literature, it could be a lengthy task for the metering
engineer to find and review all this information.
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Document ID:
832D3029
Venturi Meters, Wet Gas Flow, and the ISO TR 11583 XLM f(PLR) Correlation
Author(s): Richard Steven
Abstract/Introduction:
A seminal paper by de Leeuw 1 in 1997 showed that a standard horizontally installed Venturi meter with a downstream pressure tap and read permanent pressure loss, PPL, could be developed into a rudimentary wet gas flow meter (see Fig. 1). De Leeuw presented a wet gas Venturi meter correlation that predicted the liquid induced gas flow prediction bias, i.e. over-reading (OR), for a known liquid loading, e.g. Lockhart Martinelli parameter (XLM). This correlation was specifically for a horizontal 4, 0.4 Venturi meter with gas and liquid hydrocarbon, OR f(XLM). The concept of a XLM f(PLR) relationship, i.e. where the Lockhart Martinelli parameter could be predicted via the ratio of the PPL and primary DPs (i.e. the Pressure Loss Ratio, PLR), was also introduced, but no correlation was given.
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Document ID:
5C8BDD5D
Gas Coriolis performance on renewables gases,
based on several testing and analysis
Author(s): Aart Pruijsen
Abstract/Introduction:
This paper gives an overview of the current and future activities of Micro Motion, a
business unit of Emerson and manufacturer of Coriolis meters, to get ready for the
measurement of renewable gases under flowing conditions.
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Document ID:
B8D7CF85
Towards the Unmanned Platform
Author(s): Mark Jiskoot, Keith Lawson
Abstract/Introduction:
Reduction in manning requires the simplification of the measurement of product quality by reducing the need to operate and maintain complex sampling systems. At this point, concerns over the bias and repeatability of a Water Content Analyser (WCA) has prevented their universal acceptance. By deploying on-line density and a WCA in conjunction with a spot sampling technique will enable calibration of these on-line devices and confidence, ultimately, in their use as the primary measurement devices thus allowing simplification to the design and operation of sampling systems.
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Document ID:
69A4605C
Impacts of metering technology, BS&W and temperature on the metrological performance of oil fiscal flowmeters
Author(s): Augusto Silva, Jose Alberto Pinheiro
Abstract/Introduction:
After more than 40 years of oil and gas exploration and production, Brazilian mature offshore fields have been producing more water than ever. Besides the effects of the high amount of water on the oil processing, the oil metering system performance is also impacted by this condition. According to the Brazilian Technical Regulation for Petroleum and Natural Gas Measurement (RTM), which is a joint resolution from Brazilian Regulatory Agency (ANP) and Brazilian National Institute of Metrology (INMETRO), for an oil fiscal metering system, the oil must be stable and with a BS&W value lower than 1%.
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Document ID:
93606E03
A new over-reading correlation for vertical Venturi tubes in wet-gas flow
Author(s): G. Chinello
Abstract/Introduction:
Venturi tubes are one of the most common types of device used for wet-gas flow measurement as they are a simple, robust, and cost-effective flow meter. The majority of research and development for Venturi tubes in wet-gas flow are for horizontal installation and there are not many over-reading correlations developed for vertical Venturi tubes in the public domain. The ISO Technical Reports for measuring wet-gas flows (ISO/TR 11583:2012 1 and ISO/TR 12748:2015 2) only cover Venturi tubes horizontally installed. Correlations developed for horizontal orientation are inappropriate for vertical installations, and their performance decrease for decreasing values of the gas Froude number with errors in gas mass flow rate exceeding 10 % 3-7. Moreover, the over-reading correlation included in ISO/TR 11583:2012 is limited to density ratio greater than 0.02 and was not extensively tested at density ratio greater than 0.1.
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Document ID:
A72A08A3
Influence of fluid compositions and process parameters on allocation uncertainties
Author(s): K. Folger, K. Haukalid, A. M. Skalvik, T. Helsr, M. B. Holstad, B. Syre, K. . Maudal, A. Johnsen, E. Westgaard
Abstract/Introduction:
Current focus on cost-effective developments of new hydrocarbon fields aims at exploiting the capacity of existing production infrastructure to the maximum. Thus, many developments involve tie-backs where the satellite may have different fluid compositions compared to the mother field. This generates the need for a more in-depth understanding of how the fluid properties and the production process affect the allocation uncertainty for the involved fields. In order to establish a foundation for industry best practice related to allocation uncertainty and risk-cost-benefit calculations, NORCE has initiated a joint industry project (JIP), which is supported by Wintershall Dea Norge, DNO Norge, and Lundin Energy Norway. In this paper, results from the ongoing work related to influence of fluid compositions and process parameters on allocation uncertainties are presented.
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Document ID:
C0CDAE8A
How to give specifications of a flow meter in a precise and useful way
Author(s): Kjell-Eivind Frysa
Abstract/Introduction:
Flowmeters are essential parts of a metering station for custody transfer measurements of oil and of natural gas. Such measurements have a large focus from operator, partners, customers, transporters and authorities, because of the large monetary values involved. It is therefore critical to ensure that the flow meters are of a type with expected performance, and that the flow meters are maintained and operated as they should. As an example, the Measurement Regulations of the Norwegian Petroleum Directorate 1 specify uncertainty limits at 95 % confidence level for oil metering for sales and allocation purposes of 0.30 % of standard volume. For gas metering for sale and allocation purposes the similar limit is 1.0 % of mass. In order to document compliance with such uncertainty requirements, a combination of flow meter specifications, calibration results and field data are used, in addition to uncertainty from other instruments like pressure and temperature measuring units and online gas chromatographs.
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Document ID:
8412F088
Proving ultrasonic flowmeters with small volume prover
Author(s): Pico Brand, Peter van Brakel, Dick Laan
Abstract/Introduction:
Custody transfer flowmeters for hydrocarbons may have to be calibrated or verified in the field using
provers. Provers come in several variants. There are provers with a large volume. These ball or pipe
provers are generally stationary. In some regions mobile provers are used for reasons of flexibility or
based on available space. For practical reasons mobile provers can be small volume or compact
provers. Also stationary or mobile master meters may be used for calibration and/or verification.
In North America ultrasonic flowmeters must be proven in the field as there are no regulations to
control the installation effect or viscosity (Reynpolds) dependency. For proving of ultrasonic
flowmeters in the field API chapter 5.8 was created.
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Document ID:
954609D1
The challenges of designing a custody transfer metering system for CO2
Author(s): Hilko den Hollander, Edward Jukes, Yessica Arellano, Sigurd W. Lvseth
Abstract/Introduction:
During the Paris climate conference (COP21) in December 2015, over 190 countries agreed to limiting global warming to well below 2C, and to pursue efforts to limit it to 1,5C. There are many different ideas on how to achieve these goals, for example the Rapid and Net Zero scenarios per BP Energy Outlook 2020.
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Document ID:
43C07E27
Meeting the Challenges of CO2 Measurement with a new kind of Orifice Meter
Author(s): Phil Stockton, Allan Wilson, Richard Steven
Abstract/Introduction:
The flow measurement of Carbon Dioxide (CO2) rich streams, such has high CO2 concentration natural gas and CO2 mixes and Carbon Capture and Storage (CCS) processes, presents a number of potential challenges. One of these challenges concerns the physical properties of CO2. For example, its compressibility exhibits significant non-ideal behaviour, notably at pressures and temperatures likely to be encountered in CCS processes. Additionally, through a process called molecular thermal relaxation the molecular structure of CO2 has the ability to attenuate ultrasonic meter acoustic signals. Furthermore, CO2 can undergo phase changes through the CCS processes ranging from single phase gas, liquid, dense phase to two-phase. Though the properties of CO2 can be reliably predicted by several equations of state, the common presence of impurities, (N2, H2, CH4, etc) can have a significant impact on these properties and therefore compromise uncertainty in the field.
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Document ID:
6AFBA2FA
Flow meter performance under CO2 gaseous conditions
Author(s): Dennis van Putten,Robert Kruithof
Abstract/Introduction:
The transport and energy measurement and billing of natural gas in pipeline systems is well understood in the gas industry. ISO standards and best practice specifications and procedures to facilitate transport and custody transfer are widely available and under constant improvement and review. With decarbonization ambitions moving forward, the transport of CO2 is becoming increasingly important to facilitate carbon capture, utilization, and storage (CCUS). As well as for natural gas systems, accurate measurement and subsequent billing for CCUS is required to show compliance with national and international emissions-reduction regulations, like the EU Emission Trading System (ETS). The ETS is based on the principle of cap and trade, meaning that the capped emission rights can be traded between parties. The ETS states that all CO2 reported amounts above 500 kilotons/year should be within an uncertainty of 2.5% (k2) independent of the thermodynamic state of the CO2, i.e. gas, liquid or dense phase.
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Document ID:
6CDC7E5E
Measuring Wet gas with an Adjustable DP Cone Meter (Poster)
Abstract/Introduction:
GM Flow have developed an adjustable DP cone flow meter for gas
measurement. Described as the most significant development in DP
measurement in 20 years, Aramco plan to deploy the meter in a wet
gas environment in Q4 2021. The meter was dry and wet gas
calibrated at NEL, with N2 and Exxsol D80 fluid, to obtain pressure
loss ratio and over-read data for varying flow rates, pressures and
liquid loadings.
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Document ID:
64FB2129
MPFM Bayesian model for uncertainty-aware predictions
Author(s): Luca Frau, Tommaso Barbariol, Gian Antonio Susto, Enrico Feltresi
Abstract/Introduction:
[Abstract Not Available]
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Document ID:
0E2C2CBE
Differences in Uncertainty Calculation of Gas Parameters: Comparison of Different Standards and Analysis of the Effects of Normalisation and Covariance (Poster)
Abstract/Introduction:
[Abstract Not Available]
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Document ID:
F23C056D
Poster title: Digital Transformation - GC and Measurement Validation (Poster)
Author(s): Anwar Sutan, Paul Daniel
Abstract/Introduction:
[Abstract Not Available]
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Document ID:
788135F9
LNG quality release software based on on-line instrumentation and automated
data as alternative to off-line manual sample processing.(Poster)
Author(s): Hilko den Hollander, John de Viet
Abstract/Introduction:
On request of a large LNG producer, KROHNE developed an LNG quality release software solution
that allows for real time release of the quality certificate and the bill of lading. Using on-line gas
chromatograph readings and being and compliant with a.o. ISO 8943, GPA 2172, ASTM 4784, and
GIIGNL, the software provides the quality release certificate directly after loading has been
completed. To minimize the risk for disputes, the calculation methods have been validated by
NMi and control charting techniques and statistical process control are used to determine the
performance and availability of the process analyzers and other critical instruments.
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Document ID:
329E6EFF
A new geometrical approach to measure two-phase flow by means of differential pressure measurement with a V-Cone (Poster)
Author(s): Carsten Hersberger Christoph Gossweiler Rainer Hcker
Abstract/Introduction:
Flow measurements of two-phase flows by means of differential pressure measurement via a flow resistance, e.g. a V-Cone, are state of the art. By using two differential pressure measurements, which responds independent on the liquid phase, both phases can be computed. In this work, various geometric approaches to measure the differential pressure of a V-Cone were investigated experimentally. With a suitable choice of the pressure tap positions, the length of the device can be reduced and the gas mass flow can be determined independently of the liquid phase.
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Document ID:
2623411B
Enhanced Quadrature Design for Chordal Ultrasonic Flowmeters (Poster)
Author(s): Patrick Arnould, Dr. M. G. Droubi, Dr. S. Z. Islam
Abstract/Introduction:
Some previous work has proposed tailoring designs
to specific profiles to reduce integration errors due
to axial distortion. This work instead aims to
improve resilience across a range of axial profiles.
We propose a change to the method used for
calculating Legendre 4 chord weighting factors
which improves performance in axial distortion.
Can new 4 & 5 chord quadrature designs be found
which outperform Chebyshev & OWICS designs?
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Document ID:
F004F480
Addressing CCS Flow Assurance and Measurement Challenges:
Determination of Water Content in Gaseous Streams (Poster)
Author(s): Edris Joonaki,Marc MacDonald
Abstract/Introduction:
The concentration of water in gas streams is
of significance across the energy sector,
including oil and gas, carbon capture and
storage (CCS), and hydrogen containing
systems. When natural gas and carbon
dioxide are transported in pipelines,
alterations in temperature or pressure could
lead to water-condensing phenomena
resulting in flow assurance challenges, such
as corrosion and clathrate hydrates
formation. The dehydration of natural gas
and CCS streams must therefore be a key
process in any natural gas or blue hydrogen
processing plants.
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Document ID:
9833C778