1bp why a multiphase flowmeter can significantly reduce the rejection rate of well test versus...
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Why a Multiphase Flowmeter can significantly reduce the Why a Multiphase Flowmeter can significantly reduce the Rejection Rate of Well Test versus SeparatorRejection Rate of Well Test versus Separator
Bruno PINGUET & Samia BIFOUTMay 2013
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Contents
Why Well Testing? History & Vx Technology Data Principle How to set a multiphase flow meter (Vx technology) New Model Development for faster and better measurement in Periodic Testing Conclusion Surface mapping of production data: the 4-D model for large field.
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Why Well Testing & Who Needs Measurement Data?
Allocation• Hydrocarbon Accounting• Reservoir Management• Regulatory Reporting
Reservoir Management• Model verification• Drive Management
• EOR
Production Management• Lift & Injection Optimization
• Decline curves• PI monitoring
Facilities Management• De-bottlenecking
• Water management• Flow assurance
Production Measurements• Rate Measurements
• Trending• Sampling
Everyone
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Some Indication of Performance Indicators (KPI) & Schlumberger
Allocation factors– oil volume 0.80 to 0.90– water volume 0.70 to 0.90– gas volume 0.60 to 0.90
Rejection rate ~ 15- 40% Reproducibility - Repeatability Data delivery time, including QA and
“validation”
Well Testing Operations > 80 years Culture of Excellence in Training 24/7 Support Helpdesk Pride in Technology & Service Quality Dedicated Engineering, Reservoir and
Production Engineers QHSE Culture and performance
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Conventional Test Separators
Gas meteringDaniel differential orifice meter
Liquid metering Low flow rate High flow rate‘Floco’ positive displacement ‘Rotron’ Vortex
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Vision of Schlumberger for Periodic Well testing
Back to the beginning of the 1990’s; Schlumberger had a vision of being much more time and cost effective by developing of a multiphase flowmeter for Periodic Well Testing
Accurate flow rate measurements
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Vx Technology Description
Data AcquisitionFlow ComputerGamma Ray
Detector
Barium-133
Differential pressureTransmiter
PressureTransmitter
Bernoulli Equation
or ISO 5167
Fraction Meter based on the
attenuation of -ray and
composition dependent
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Introduced in 1998 Continuous rate measurements No stabilization required No phase separation, No moving parts No Emulsion, No foaming dependency No Sensor in direct contact with the fluid No tuning factor, No flow calibration High Pressure Solution > 5,000 psia Compact Solution: 1.6x1.7x1.8 m3
Lightweight: 1,500 kg Different sizes: 29, 52, 88 (100 – 150,000 bpd) Lowest Total Pressure Lost
PhaseTester*:Periodic Testing (service/rental)
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Cumulative Years of experience with Vx
Technology:
TOP SIDE: > 5000 years
SUBSEA: > 1500 years
PERIODIC WELL TESTING: > 1000 years
Vx Technology Overview
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Fraction Measurement & “Full” Gamma Ray Spectrum
0
2,500
5,000
7,500
10,000
12,500
15,000
17,500
1 11 21 31 41 51 61 71 81 91 101 111 121 131 141 151 161 171 181 191 201 211 221 231 241 251 261
Channel #
AA
EXS80A
DWA
5%WA
10%WA
15%WA
Photo-electric effectf (composition, density)
Compton interaction f (density, composition)
Energy Level
GasOilFresh Water 5% Salinity10% Salinity15% Salinity
Compton interaction f (density)
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Photo-electric effectf (composition, density)
Compton interaction f (density, composition)
Low Energy Linear attenuation
High Energy Linear attenuation
0
w
g
o
Gas
OilWater
Coun
ts R
atio
at h
igh
ener
gy
Counts Ratio at low energy
Gamma Ray Spectrum & Solution Triangle
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Gas
OilWater
o
w
g
Line
ar A
ttenu
atio
n at
hig
h en
ergy
Linear Attenuation at low energy
WLR = 0.63
GVF = 0.24
Coun
ts R
atio
at h
igh
ener
gy
Counts Ratio at low energy
Accurate Measurement means proper setting of the meter
It is a reference measurement made at the Venturi throat giving the fluid mass attenuations.
It reflects the ability of each phase to absorb gamma rays or scatters gamma rays
Every fluid has its own specific mass attenuation (a kind of finger print).
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In-Situ Reference Mass Attenuations
Gamma rays countsMass Attenuations
Density of given fluid Accurate flow rates
In-situ Reference: Pouring oil sample into the Venturi
30-45 minutes
for each fluid
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How to be more efficient?
How to improve Quality Measurement?
Truck mounted PhaseTester Unit
The Wish to Reduce Time
& Improve Quality
is always a challenge
Production Testing with PhaseTester
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Let’s see the Water Mass Attenuation Modeling: H2O +NaCl
Quality check and/or Replacement of Water InSitu Reference
1- Mix volumes dilution water + saturated formation water
2- Create a range of salinities
3- Made water insitu reference for all samples
4- Study resulting model Water Mass Attenuation
Correlation was a success
i
Eii
E
i : mass fraction of components i
iE : mass attenuation for
component i and energy E
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How modeling the Oil Mass Attenuations?
Challenges of oil mass attenuation Different compositions are expected Different fraction of elemental components Composition may change with age of the well
Source : National Institute of Standards and Technology
Green is less than 1% change
Yellow is less than 2% change
Components 32 81 356
(cm2/g) (cm2/g) (cm2/g)
H2S 1.7627 0.2584 0.1092CO2 0.3216 0.1651 0.1019
C1 0.2731 0.1980 0.1270C2 0.2670 0.1901 0.1220C3 0.2650 0.1871 0.1200C4 0.2643 0.1861 0.1190C5 0.2638 0.1851 0.1182C6 0.2629 0.1850 0.1180C7 0.2628 0.1841 0.1179C8 0.2628 0.1841 0.1179C9 0.2628 0.1841 0.1172C10 0.2627 0.1831 0.1172C11 0.2622 0.1831 0.1170C12+ 0.2618 0.1831 0.1170
i
Eii
E
i : mass fraction of components i
iE : mass attenuation for component i and energy E
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One first field: Complete Analysis with > 1,600 well tests
Validation
Execution
Study
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Isolation principle of high deviant points
Average(A)
Model (B)
23-Feb-09 (C )
A/B [%]
A/C [%]
LE(32keV) 0.02525 0.02545 0.02665 0.77 5.24HE(81keV) 0.01705 0.01687 0.01794 1.10 4.95XE(356keV) 0.01182 0.01184 0.01240 0.11 4.63
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Linear model created 3 levels of energy
Building Correlations for Oil Linear Attenuations
Model simulation
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Study possible effects on accuracy of Mass Attenuation of the model versus field measurement
Field Test & Mass Attenuation Model Validation
Errors study for all energy levels (32keV, 81keV, and 356keV)
Deviation [%]
LE (32 keV)
HE (81 keV)
XE(356 keV)
<0.5 49.7% 41.9% 44.7%<1.0 76.1% 72.7% 78.6%<1.5 86.7% 88.6% 94.4%<2.0 94.3% 96.7% 98.4%<2.5 98.8% 98.7% 99.3%<3.0 99.9% 99.9% 99.9%
2/3 of the data set
used for modeling
1/3 data to validate &
200 well tests laterLE Input (32 keV)
HE Input (88keV)
XE Input (356kev)
Oil Rate Output
Gas Rate Output
GVF Output
Real Case 0.49% 0.42% 0.39% 0.53% 0.12 % 0.08%Worst Case 3% 3% 3% 1.57% 0.77% 0.34%
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Conclusion (#1)
Vx Technology is based on fluid properties measurement directly no combined factor to build following the fluid, or fuzzy logic used in the interpretation.
The PhaseTester setting requires only the inputs of density measurement and mass attenuation for each phase (with several ways to get it) – No Combined Factor like on a separator
On large field, and high activity it is demonstrated that using an in-situ modeling leads to uncertainty – < 0.5% on oil flow rate – < 0.1% on the gas flow rate (Oil well).
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Conclusion (#2)
Either, it is possible to skip the in-situ reference now for the entire field and then be able to set the meter and start to flow immediately, saving time at the well site by up to 2:00
Or doing a real-time quality control at the well site and then guarantee that the field data measurement are immediately correct.
Overall one solution or another will lead to reduce drastically the rejection rate of the Periodic Well Testing <1% for comparison in some fields with local well test operators > 40%
Rejection rate is dollars not used in optimum way for oil companies and leads to poor reservoir management in the best case! (Middle East and One Watery Well)
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Any question?Any question?Bruno Pinguet
Marketing & Technical ManagerOneSubsea & Schlumberger Testing
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A way beyond – The 4 D Production Data Mapping
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Production Data Mapping: Gas Density
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Low SG
High SG
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Production Data Mapping: GOR
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Low SG & High GOR
High SG & Low GOR
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Any question?Any question?Bruno Pinguet
Marketing & Technical ManagerOneSubsea & Schlumberger Testing