Multiphase Well-Rate Measurements Applied to Reservoir Analysis
- Slavko Tosic (ExxonMobil) | Parviz Mehdizadeh (Production Technology)
- Document ID
- Society of Petroleum Engineers
- SPE Production & Operations
- Publication Date
- May 2010
- Document Type
- Journal Paper
- 155 - 160
- 2010. Society of Petroleum Engineers
- 2.4.3 Sand/Solids Control, 5.6.4 Drillstem/Well Testing, 5.3.4 Integration of geomechanics in models, 5.4.2 Gas Injection Methods, 2.4.6 Frac and Pack, 3.3 Well & Reservoir Surveillance and Monitoring, 5.6.9 Production Forecasting, 5.1.1 Exploration, Development, Structural Geology, 5.5 Reservoir Simulation, 3 Production and Well Operations, 4.1.5 Processing Equipment, 4.3.3 Aspaltenes, 4.2 Pipelines, Flowlines and Risers, 4.3 Flow Assurance, 4.1.2 Separation and Treating, 4.4.3 Mutiphase Measurement, 5.6.11 Reservoir monitoring with permanent sensors, 4.5 Offshore Facilities and Subsea Systems, 4.6 Natural Gas, 5.6.3 Pressure Transient Testing, 7.6.2 Data Integration, 5.2 Reservoir Fluid Dynamics, 5.2.1 Phase Behavior and PVT Measurements, 3.2.3 Hydraulic Fracturing Design, Implementation and Optimisation, 5.4.1 Waterflooding
- inflow performance, flux rate, pressure transient analysis
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- 732 since 2007
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New technology of multiphase measurement has been widely adopted by the oil industry. The meters that use this technology are either permanently installed or periodically used for well testing during, for example, flowback, well appraisal, and trials. Consistent, reliable, and accurate flow measurement plays an important role in reservoir and production engineering. However, industry trends show that many practitioners do not fully use the potential of continuous online measurements for reservoir- and production-engineering assessments. This paper will show how online-multiphase-measurement data can be applied to reservoir and production analyses and how additional useful results can be obtained. Field examples from the Gulf of Mexico (GOM) will be presented to support the process.
To start, the paper reviews the role of pressure-transient analysis (PTA) and flux rate for assessing the health of the reservoir. PTA gives useful information about the health of the well (skin) and the reservoir properties. It is an established analysis methodology that requires two important inputs--bottomhole pressure and flow rate. If the flow rates are not accurate, the results from PTA would be erroneous, and calculation of downhole-flow velocity would be incorrect. These uncertainties could result in wells producing below or above optimal levels. Either case would lead to production loss or well damage and the need for remedial workover. Unfortunately, the maximum safe-rate term is not easy to predict. With high-producing wells, minor measurement error can result in significant inaccuracies in related calculations for reservoir or well parameters. For instance, if the well-flow velocity in the formation exceeds the critical velocity for fines movement, formation fines would start moving. Once they start moving, additional near-wellbore-region damage would be created or the screen may get eroded.
Production-data analysis (PDA) such as rate-normalized-pressure (RNP) analysis in conjunction with continuous flow-rate measurements, provided by an online multiphase flowmeter (MPFM), can be used to obtain additional reservoir parameters. In applications discussed in this paper, flow rates from the multiphase meters were used extensively for reservoir and well surveillance, flow assurance, and the well-production allocation.
|File Size||532 KB||Number of Pages||6|
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