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REGIONAL ASSOCIATION OFOIL, GAS & BIOFUELS SECTOR COMPANIES

IN LATIN AMERICA AND THE CARIBBEAN

Integrated Model for Compression Visualization in

Gas-Condensate FieldsPeru

Carlos Bilbao.

Repsol Exploración Peru.

86th ARPEL Experts Level Meeting (RANE) “Management of Reservoirs”

October 6-7, 2014 – Buenos Aires, Argentina.

86th ARPEL Experts Level Meeting (RANE) “Management of Reservoirs“ – October 6-7 – Buenos Aires, Argentina 2

Gas & condensate fields located in the sub Andean Peruvian

rain forest, Madre de Dios basin.

The largest distance from well to processing plant is 95.5 km.

The average pressure drop 10 psi/Km.

Harsh logistic area, fluvial and heli-transported operation.

Weather window from december to march.

INTRODUCTION

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86th ARPEL Experts Level Meeting (RANE) “Management of Reservoirs“ – October 6-7 – Buenos Aires, Argentina 3

Asset Description

FIELD “M”

PAD “S1”PAD “S2”

PAD “K”

LOGISTIC

BASE

SPLITING

POINT

PROCESSING PLANT

86th ARPEL Experts Level Meeting (RANE) “Management of Reservoirs“ – October 6-7 – Buenos Aires, Argentina

Asset Description

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2 PLANNED WELLS

(PAD S2)

THIRD PARTY FACILITIES

FLOWLINE 16’’

7 Km

SHARED FLOWLINE 18’’

42.5 Km

Cryogenic Plant

FLOWLINE 14”

10 Km

FLOWLINE 16”

14 KmFLOWLINE 16”

22 Km

BLOCK AA

FLOWLINE 8”

8 Km

FUTURE

LOOP 20”

THIRD PARTY

FIELD “P”

FIELD “M”(3 PRODUCER WELLS)

APPRAISAL WELL ATA

(PAD S1)

3 PRODUCER WELLS

(PAD K)

COMPRESSION

PLANT

LOGISTIC BASE

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86th ARPEL Experts Level Meeting (RANE) “Management of Reservoirs“ – October 6-7 – Buenos Aires, Argentina 5

INTEGRATED MODEL

RESERVOIRS B-AA (ECLIPSE 300):Compositional Model (14 components, includes water)

152x26x84m, 266448 cells, 6 Kr sets, 4 EOS - PR.

RESERVOIRS FIELD “M” (MBAL):Compositional Model (14 components, includes water)

WELL & SURFACE NETWORK (GAP):Well model uses VLP curves built using its mechanical

configuration and data from PDHG and WH.

Surface flowlines uses VLP curves built using Petroleum

Experts 4 mechanistic calculation.

COMPRESSION MODELS (HYSYS):Considering limits for Pout/Pin=3 and maximum temperature

300 °F.

The power calculated is the hydraulic power.

PROCESSING PLANT(HYSYS):Cryogenic plant, which products are Dry Gas and Natural Gas

Liquids.

REPORT (MS EXCEL)Given that Hysys do not save the solution each time step, then

results from compression models are saved within a Excel file.

RESOLVE

86th ARPEL Experts Level Meeting (RANE) “Management of Reservoirs“ – October 6-7 – Buenos Aires, Argentina 6

RESERVOIR

����� � ���

� �� � �

Where "a" is the turbulence coefficient and

"b" is the laminar flow coefficient, both can be

calculated from reservoir properties or, as in

this case is determined from a multi-rate test.

0

0.1

0.2

0.3

0.4

0.5

0.6

0.7

0.8

0.9

1

0 10 20 30 40 50 60 70 80 90 100

Pr/

Pi

RECOVERY FACTOR (%)

Pr/Pi vs RF

RF

COMPRESSION

NO COMPRESSION

0

0.1

0.2

0.3

0.4

0.5

0.6

0.7

0.8

0.9

1

0 10 20 30 40 50 60 70 80 90 100

Pr/

Pi

RECOVERY FACTOR (%)

Pr/Pi vs RF

RF

COMPRESSION

NO COMPRESSION

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86th ARPEL Experts Level Meeting (RANE) “Management of Reservoirs“ – October 6-7 – Buenos Aires, Argentina

CORRELATION BRIEF DESCRIPTION

Begs & BrillPrimarily used for pipelines, over-predict pressure

drop in vertical and deviated wells.

Fancher BrownNo-slip Hold-up correlation, use as a quality

control.

Hagerdon BrownUsed for oil wells under moderate slug flow rates

(well loading poorly predicted), not suitable for

mist flow neither condensates.

Wallis & GriffithDeveloped Flow Regime boundaries, Suitable for

Bubble flow.

Duns & RosSuitable for mist flow and high GOR oil and

condensate wells.

Petroleum Experts

Bubble Flow: Wallis and Griffith

Slug Flow: Hagerdon Brown

Transition flow: Duns & Ros

Annular Mist Flow: Duns & Ros

PE2 PE + low rate VLP

PE3 PE2 + Features for viscous, volatile and foamy oils.

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WELL MODEL

Petroleum Experts 2 & 3

86th ARPEL Experts Level Meeting (RANE) “Management of Reservoirs“ – October 6-7 – Buenos Aires, Argentina 8

NETWORK MODEL

LOCATIONGAS RATE

(MMSCFD)

Real

Pressure

(psig)

Model

Pressure

(psig)

error

PAD A 130 2052 2060 0.4%

PAD M 160 1964 1982 0.9%

LOGISTIC

BASE290 1905 1922 0.9%

SPLITING

POINT160 1412 1420 0.6%

FIELD P 360 1280 1270 -0.8%

HPS 160 1320 1320 0%

INLET PLANT

PRESSURE CONTROL

CHOKE %

RATE CONTROL

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86th ARPEL Experts Level Meeting (RANE) “Management of Reservoirs“ – October 6-7 – Buenos Aires, Argentina 9

COMPRESSION

Input data

Calculated values

86th ARPEL Experts Level Meeting (RANE) “Management of Reservoirs“ – October 6-7 – Buenos Aires, Argentina

RESULTS

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GU

0

250

500

750

1000

1250

1500

1750

2000

2250

2014

2016

2018

2020

2022

2024

2026

2028

2030

2032

2034

2036

2038

2040

2042

PR

ES

SU

RE

(p

sig

)

Date

COMPRESSION PRESSURE

DISCHARGE

B-AA INLET

FIELD M INLET

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86th ARPEL Experts Level Meeting (RANE) “Management of Reservoirs“ – October 6-7 – Buenos Aires, Argentina

RESULTSG

U

0

250

500

750

1000

1250

1500

1750

2000

2250

2014

2016

2018

2020

2022

2024

2026

2028

2030

2032

2034

2036

2038

2040

2042

PR

ES

SU

RE

(p

sig

)

Date

COMPRESSION PRESSURE

DISCHARGE

B-AA INLET

FIELD M INLET

86th ARPEL Experts Level Meeting (RANE) “Management of Reservoirs“ – October 6-7 – Buenos Aires, Argentina

CONCLUSIONS

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And integrated Model which can represent the complete production system was built and

validated to estimate compression power demand.

The compression demand start on Q3-2016.

The first scenario evaluated, where the production from field M and Block AA go to the same Slug

catcher, is identified not the most efficient scenario, because both fields have to reach different

committed production plateaus, then the pressure controlled in the chokes, to reach the desired

production rates, needs to be restored by the compression; therefore, increasing power demand.

To overcome this disadvantage, it was evaluated the use of separated slug catchers, then

controlling the production of each field properly at chokes and reducing operating cost. This

represent 10% less power consumption compared to the first scenario. Another advantage of this

scenario is that the compressors released from Field M can be further utilized by Block AA, which at

the beginning has low compression power demand.

The total compression power demand lies between 20-25 Khp.

Taking into account economical analysis, around 30 % of capital investment can be saved if joint

compression is given.

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