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Oil gas water metering
- 1. Petroleum Engineering Department Postgraduate Program for M.Sc. Degree Advanced Oil Field Technology Oil , Gas and Water Metering By Hassan Awedan 15 May 2017
- 2. “ What gets measured, gets managed, gets analyzed, gets funded, gets built or renovated, gets done… and saves money”
- 3. Production History for Well/Field - Who need this Plot ? • Res. & Prod. Engineers • Mangers • Traders & Economists • .. etc. - How to get this plot 1. Conventional Method (After separation) 2. Alternative Method (without separation) 3. Downhole Flowmeters
- 4. Contents • Introduction • Production System Layout • Metering System Applications • Conventional Metering • Alternative Metering • Permanente Downhole Flow meter • Summary.
- 5. Why do this? • Volumes for accounting • Well performance - Downhole Pump integrity? - Reservoir performance in general • GOR (Gas/Oil/Ratio) It will change over time. Important to know • Reclamation of water for reinjection & well stimulus
- 6. Why is it difficult? • Crude oil has entrained gas & water • Difficult to measure 3 phase products with any degree of accuracy • Secondary recovery - can contain high ratios of water &/or emulsion layer • Tertiary recovery – separation/recovery seems to be incomplete and contain CO2 entrained gas • Which meter offers the best solution? • Coriolis method – 20-85% water content • Some applications have high water content
- 7. Review: Production System Layout
- 8. Liquid Metering System Applications • Production Wellhead Pipelines Gathering, Transmission • Marine Loading and Unloading Oil tankers on major waterways • Production, storage and offloading Vessel • Refinery Feed/output
- 9. Conventional Metering Back Allocation: What is need to be allocated ? Volumes of Produced oil, gas and water Volumes of injected gas, water It’s a daily must of the upstream and downstream petroleum industry.
- 10. 1. Turbine meter 2. Positive Displacement meter 3. PD meter 4. Coriolis meter 5. Ultrasonic meter Industry Challenge – Common Solutions Q= V * A
- 11. Turbine Meter - A turbine rotates on a shaft. - The speed of the turbine is proportional to the linear velocity (or flow rate) of the fluid moving through the meter. - The speed of the turbine is measured as pulses that give the instantaneous flow rate. - The pulses can also be accumulated to give the total or cumulative flow rate. -Primarily used for waterflood projects -Turbine flowmeters excel at measuring clean, steady, low-viscosity fluids.
- 12. A positive displacement meter - A positive displacement meter measures instantaneous or cumulative flow rate - by counting the number of “ volumes” through the meter. - The “ volume” is based on a selected geometry so that a constant, exact amount of fluid is trapped for each count of the meter. -used extensively in the oilfield on separators for both water and oils.
- 13. The orifice meter_Diferntial Pressure - The orifice meter is a differential pressure device that produces a flow rate that is proportional to the square root of the pressure drop across the orifice. - Physically, the device involves an orifice plate, pressure taps, and a holder for the orifice plate. A transducer, transmitter, or recorder converts the differential pressure into an indication of flow rate. -used extensively in the oilfield on separators for Gas.
- 14. Coriolis Flowmeter • A Coriolis meter consists of a flow tube that vibrates due to fluid flow. • this tube introduces a twisting motion and the magnitude of this twisting motion is proportional to the mass flow-rate. • Similarly, the vibrating frequency of this tube is related to the density of the fluid flowing through it. -No moving part but has some limitations. -They cannot compete with ultrasonic and turbine flowmeters for line sizes 20 inches and up.
- 15. Ultrasonic Flowmeter for Oil & Gas - Each transducer works as transmitter and receiver. - measures the time of flight of acoustic waves propagated between two ultrasonic transducers in both against the flow T1 and on the direction of flow T2. - The difference in time between T1 & T2 is proportional to fluid velocity. ultrasonic meters have no moving parts. Ultrasonic flowmeters can also handle impurities in the flow better than turbine meters.
- 16. Other Flow meters 1. Vortex meter (approved in 2007) -The vortex shedding principle is used primarily for gas measurements, but can also be used for liquid flow rate measurement. - It involves measuring the vortex shed behind a body of a certain shape and then inferring the flow rates from this information.
- 17. 2. Thermal (approved in 2010) - Consists of two temperature meters. -One meter measures normal temperature, other meter is already heated. -Difference in temperature after fluid flow will have a direct relation ship with fluid velocity. Other Flow meters
- 18. Other Flow meters 3.Electormagentic Flowmeter - Although magnetic flow measurements provide obstructionless flow, the fluid has to be electrically conductive; therefore, magnetic techniques will not work in all oil systems. - The magnetic flowmeters have good accuracy, low pressure loss (low head loss due to friction), good rangeability, and the capability for difficult-to-handle fluids such as acids, slurries, and viscous liquids.
- 19. Industry Standards and Measurement Criteria Documents - American Petroleum Institute (API) - International Standards Organization (ISO) - Government Weights and Measuring Requirements - Company specific standards
- 20. Selection of Meter ! Category Definition Example Accuracy It is the difference between the actual and the measured flow rates divided by the actual flow rate. + or - 1% gpm Rangeability It is the ratio, at the specified accuracy, of the maximum flow rate to the minimum flow rate. 3-45 gpm Repeatability It is the ability of a meter to reproduce the same measured readings for identical flow conditions over a period of time Maximum difference of readings Linearity It is a measure of the deviation of the calibration curve from a straight line. offset
- 21. Water Cut Measurement WC= Vw/(Vw+Vo) Well Head Fluid Sample 3 bottles Field Laboratory
- 22. Alternative Metering ? Mutliphase flowmeter used to measure 3-phase flow rates (oil, gas and water) without separation
- 23. Vx* Technology – Calculations overview Phases Hold-ups % Water % Oil % Gas Source & Detector Nuclear model Venturi & Delta P Fluids dynamics model Total mass rate Gas Oil Water Single-phase rates Qg= V * A*Hg Qo= V * A*Ho Qw= V * A*Hw
- 24. Vx* Technology – Flow rate • Venturi (for total mass rate measurement) and Dual energy gamma system (phases fractions) Gamma-rays detector Ba133 source Venturi Flow ΔP mixmix21 4 2 masstotal v f HgPP2 1 1 4 d CQ ρ
- 25. 32 81 Energy Level (Kev) 356 Count s Hold-ups measurement (1/2) Mass attenuation concept • Ba133 gamma ray spectrum shows 3 energy level peaks • When passing through matter, gamma looses energy due to collisions with atomic particles. • Photoelectric Absorption - below 75 keV – f(composition) • Compton Scattering - from 75 keV to 10 MeV – f(density) • Pair Production (above 10 MeV) 25
- 26. Hold-ups measurement (2/2) Application to 3 phases 26 Smart Detector Collimated beam Ba-133 d 3 equations with 3 unknown le waterwaterwater le oiloiloil le gasgasgasle O le X N N Ln d 1 he waterwaterwater he oiloiloil he gasgasgashe O he X N N Ln d 1 81 keV Energy Level 32 keV d eNN OX wateroilgas1 Solution Triangle (graphical representation) Water Oil Gas Operating point (mixture)
- 27. Permanente Downhole Flow meter Down hole fiber Optic multi phase flowmeter
- 29. Down hole fiber Optic multi phase flowmeter
- 30. Raw Data
- 31. Data Analysis
- 32. Companies involved in Metering Business
- 33. Summary : Production History for Well/Field - How to get this plot 1. Conventional Method (After separation) 2. Alternative Method (without separation) 3. Downhole Flowmeters
- 34. References 1. SPE-170853 MS Enhancement in Fraction Measuremnets and Flow Modeling for Mutiphase Flowmeters 2. SPE 76766 Multiphase Flowmeter Application for Well and Fiscal Allocation 3. SPE-176399 MS Swing Rod Flowmeter – A new Downhole Flow Measurement Technology 4. SPE 150195 Review, Analysis and Comparison of intelligent well monitoring Systems 5. SPE 71478 Field Testing Coriolis Mass Flowmeter in Central Ghawar, Sauid Arabia 6. SPE 102351 Real-Time Production-A Virtual Dream or Reality? The case of Remote Surveillance of ESP and Multiphase Flowmeters 7. www.Fugro-Jason.com 8. Internet browsing 9. Surface Operations in petroleum Engineering V2 Book
Editor's Notes
- -What is the Impact? Large consequences of poor back allocation to reservoir management. Companies are requiring more accurate measurement today on allocation applications Royalties are paid on allocation. Separator measurement is the assurance that the valuation allocation to the appropriate parties is correct. Royalty owners can be: Mineral rights owner(s) Government - Severance taxes Investors - R.O.I. Joint Venture Partners. -Effective Parameters and practices : Well Dynamics /Reservoir Fluids : change in PVT , choke change etc Well Completion/Hardware : AL operation Measurement method/instruments : WC% determination, separator test Production operations /producing train : production time , back pressure between wells.
- Readout devices Positive displacement (PD) meters and turbine meters can usually produce pulses that are directly proportional to flow rate. The signal is then converted to a totalized and, often, an instantaneous flow rate. The blades in a turbine meter cut lines of magnetic force produced by the magnetic pickup unit. The resulting electrical pulses are then transmitted to electronic instrumentation to indicate, totalize, record, and/or control flow rate typically selected for liquid flow rate /can be used for gases Used primarily for waterflood These meters are not necessarily ultra-accurate, about 1 % Low cost cannot be used to measure steam flow Sizes range from 3/8 in. to 24 in
- Readout devices Positive displacement (PD) meters and turbine meters can usually produce pulses that are directly proportional to flow rate. The signal is then converted to a totalized and, often, an instantaneous flow rate. Most positive displacement meters use direct mechanical drives involving gears to indicate totalized flow; however, some companies use magnetic couplings. typically selected for liquid flow rate /can be used for gases Used for fluids having varying or high viscosities Used extensively on separators for both water /oil flow rates
- Orifice meters, however, require the conversion from a pressure differential to a mechanical or electrical output. Also, the flow rate is proportional to the square root of the response, which complicates the data reduction Orifice meters Orifice meters convert a pressure head to a velocity head in order to obtain the flow rate at a particular cross-section. Due to the compressibility of the gas, there is a correction factor for the compressibility. Other correction factors are also presented here. Orifice meters are more difficult to adapt to automation and, therefore, other devices, such as a turbine meter, have been used in their place. Orifice meters have been the traditional device for measuring the flow rate of gases, but are not used as much for liquid flow measurement. The orifice meter, in fact, is still “one of the most important and widely used” flowmeters (F and P General Catalog, p. 1329), even though technology has provided some new sophisticated instrumentation. Advantages include its “simple, rugged, and reliable” (Daniel Basic Fundamentals by Kendall, p. 6) construction. Although they have limited rangeability (typically 3 : l), orifice meters are relatively inexpensive and have good accuracy for most gas metering applications. A typical meter system consists of a concentric, square-edged orifice plate, a fitting that holds the orifice plate and provides taps for differential pressure measurement, and a pressure measuring-recording device. A meter tube provides an orifice fitting, the orifice plate, and both the upstream and downstream piping in one complete package used primarily for gases /can be used for liquids DP flowmeters use multiple measuring points used for stack gas measurement include ultrasonic and thermal Basically, Bernoulli’s equation is used to convert pressure head to velocity head. Velocity can then be determined at a known cross-section of the orifice, which in turn is converted to a flow rate. In the case of gas flow, calculations become more complicated because of compressibility effects.
- High tech and Long term value with Low maintenance Multi variable measurement (density, mass, volume, temp) Can be used to measure gas flows An easier time measuring liquids than gases, liquids are more denser More precise measurement .1% to 0.2 % linearity expensive
- ultrasonic meters are non-intrusive no moving parts. Can handle impurities in the flow better than turbine meters. Ultrasonic flowmeters are widely used for gas flow measurement Inline models are used where high accuracy is required Ultrasonic flowmeters are one of three main types of flowmeters used for custody-transfer of natural gas. In this area, they compete against differential-pressure and turbine flowmeters.
- Energy conservation (Bernoulli) Mass conservation Throat / Inlet diameters ratio