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SGTPIPE SGTPIPE / / SGTFLOW SGTFLOW vs vs
PIPESIMPIPESIMbenchmarkingbenchmarking
Sunbury on Thames (London), UK 09.04.2007
Copyright © Dmitry Prytkov, R&D «SibGeoTech»
By the instrumentality of By the instrumentality of EPTG Pipelines Team, BP EPTG Pipelines Team, BP
ExplorationExploration
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Examined oil gathering Examined oil gathering systemssystems
““Oilfield 1” Oilfield 1” (North America, USA)(North America, USA)
Actual state on 2005Actual state on 2005 Prediction on 2012 yearPrediction on 2012 year
““Oilfield 2” Oilfield 2” (Western Siberia, Russia)(Western Siberia, Russia) Actual state on 2006Actual state on 2006
“Oilfield 1” “Oilfield 2”Dead oil density, kg/m3
876-960 850
Water cut, % 1 - 99 78-96
Gas-Oil Ratio, nm3/m3 208 – 17810 88
All data are real. They are chosen and are provided by All data are real. They are chosen and are provided by EPTG Pipeline Systems Team, BP Exploration, Sunbury (London), UK. EPTG Pipeline Systems Team, BP Exploration, Sunbury (London), UK.
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Multiphase flow Multiphase flow correlationscorrelations
PIPESIM:PIPESIM: Beggs-Brill RevisedBeggs-Brill Revised OLGA-S 2000OLGA-S 2000
SGTPIPE / SGTFLOW:SGTPIPE / SGTFLOW: SGTFLOW correlation (developed on SGTFLOW correlation (developed on
the base of VNIIGAS methodology)the base of VNIIGAS methodology)
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Multiphase flow simulationMultiphase flow simulation oil physical properties in operating oil physical properties in operating
conditionsconditions single oil degassing in operating conditionssingle oil degassing in operating conditions natural gas physical properties in operating natural gas physical properties in operating
conditionsconditions oil-water mixture and physical properties in oil-water mixture and physical properties in
operating conditionsoperating conditions actual estimated gas content and actual estimated gas content and
multiphase flow regime according to a multiphase flow regime according to a pipeline relief in operating conditionspipeline relief in operating conditions
hydrostatic and friction pressure losses in hydrostatic and friction pressure losses in operating conditionsoperating conditions
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PIPESIM to SGTPIPE / SGTFLOWPIPESIM to SGTPIPE / SGTFLOWmodel movingmodel moving
Average of black oil properties Average of black oil properties Average of fluid temperature by Average of fluid temperature by
pipeline network (pipeline network (««Oilfield 1Oilfield 1»»)) Summarize of well flow rates by padsSummarize of well flow rates by pads
((««Oilfield 1Oilfield 1»»)) Refine upon free gas flow ratesRefine upon free gas flow rates
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Oil gathering system of “Oilfield 1”Oil gathering system of “Oilfield 1”(actual state at 18.04.2005)(actual state at 18.04.2005)
1.
2.
3.
4.
5.
L Pad
V Pad
Z Pad
W Pad
GS-26.
7.
8.
PIPESIMPIPESIM SGTPIPESGTPIPESGTPIPESGTPIPE
77
Oil gathering system of “Oilfield 1”Oil gathering system of “Oilfield 1”(actual state at 18.04.2005)(actual state at 18.04.2005)
1011121314151617181920212223242526
L Pad V Pad Z Pad W Pad
Pre
sure
, at
ma_
_
Actual pressure PIPESIM (Beggs-Brill Rev) PIPESIM (OLGA-S) SGTFLOW
88
Oil gathering system of “Oilfield 1” Oil gathering system of “Oilfield 1” (prediction on 2013)(prediction on 2013)
Model
1.
Gas Water Oil
GPP2.
3.
1.
4.
5.
I Pad
L Pad
V Pad
Z Pad
W Pad
PIPESIMPIPESIM SGTPIPESGTPIPE
99
Oil gathering system of “Oilfield 1” Oil gathering system of “Oilfield 1” (prediction on 2013)(prediction on 2013)
101112131415161718192021222324252627282930
I Pad L Pad V Pad W Pad Z Pad
Pre
ssur
e, a
tma_
__
PIPESIM (Beggs-Brill Rev) PIPESIM (OLGA-S) SGTFLOW
1010
Oil gathering system ofOil gathering system of “Oilfield 2” “Oilfield 2”
PIPESIMPIPESIM SGTPIPESGTPIPEМодель
Сток
1605
1599b
1602
1604
1598
1590
1584
2435
1.
2.
3.4.5.
6.
4.
7.
8.
9.
10.
9.
11.
9.
13.
12.
14.
9.2
15.
9.3
Вода Газ Нефть
1111
Comparison between predicted and actual Comparison between predicted and actual pressure by pads ofpressure by pads of “Oilfield 2” “Oilfield 2”
(with OLGA-S correlation)(with OLGA-S correlation)
12,0
14,0
16,0
18,0
20,0
22,0
24,0
26,0
28,0
30,0
K1584 K1590 K1598 K1599B K1602 K1604 K1605 K2435
Pre
ss
ure
, atm
a_
_
Actual Beggs-Brill Rev OLGA-S 2000 SGTFLOW
1212
Average difference between Average difference between actual and estimated pad actual and estimated pad
pressurepressure
0,0
0,5
1,0
1,5
2,0
2,5
3,0
3,5
"Oilfield 2" "Oilfield 1"
Ave
rag
e d
elta
, atm
a_
_
Beggs-Brill Rev OLGA-S 2000 SGTFLOW
1313
ConclusionsConclusions PIPESIM with Beggs-Brill Revised correlation shows PIPESIM with Beggs-Brill Revised correlation shows
the worst convergence with actual data in case of the worst convergence with actual data in case of elevation pipelines with high gas-liquid ratio and/or elevation pipelines with high gas-liquid ratio and/or low flow rate. In this case it is not recommended to low flow rate. In this case it is not recommended to use Beggs-Brill Revised correlation for calculation of use Beggs-Brill Revised correlation for calculation of such systemssuch systems
SGTFLOW and PIPESIM with OLGA-S 2000 correlation SGTFLOW and PIPESIM with OLGA-S 2000 correlation shows similar simulation result in all examined cases shows similar simulation result in all examined cases of the oil gathering systemsof the oil gathering systems
SGTPIPE / SGTFLOW can be effectively used to SGTPIPE / SGTFLOW can be effectively used to simulate of complex on-shore pipeline networks simulate of complex on-shore pipeline networks (including elevation and/or high gas-liquid ratio cases)(including elevation and/or high gas-liquid ratio cases)
The study results were discussed during BP Pipeline Systems Team technical meetings and accepted by them.
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6
3
2
1
4
5
11
9
8
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