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

22

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.

33

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)

44

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

55

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

66

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.

1414

7

6

3

2

1

4

5

11

9

8

10