Reservoir Management: Fundamentals and Applications in ...€¦ · Reservoir Management: Fundamentals and Applications in Mature Oilfields MSc. Victor A. Huerta Quiñones PETROPERU

Reservoir Management: Fundamentals

and Applications in Mature Oilfields

MSc. Victor A. Huerta Quiñones

PETROPERU S.A / UNI / SPE

OUTLINE

• Introduction

• Background

• Mature Field Redevelopment

• SWOT Assessment

• Technology Innovation: Inflow Control Devices (ICDs)

• Field Cases

• Conclusions

Introduction

• Mature fields in Talara and Marañón Basins offers opportunities for production optimization.

• Most of the fields in Talara Basin are very depleted with less than 30% of the original reservoir pressure.

• Talara fields are good candidates for selective secondary recovery and new approaches in hydraulic fracturing.

• Most of the oilfields in Marañón Basin have an active aquifer; delaying water encroachment is a key issue to improve recovery in heavy oilfields.

• Technology advances in well completion address both water management and productivity improvement objectives.

• The more accurate technology screening, the better field performance.

Background: What is Reservoir Management?

Field Optimization is a process by which the right technology matches with the

reservoir description

Depositional

Environment Phase

Behavior

Drive

Mechanism

Field

Optimization

Innovation &

Technology

Petrophysics

Field Optimization in Mature Oilfields

Type of Oil Density (gr/cc) API Primary (% of oil in situ)

Extra Heavy > 1.0 8 – 10 1 - 5

Heavy 1.0 – 0.92 10.0 – 22.3 1 - 10

Medium 0.92 – 0.87 22.3 – 31.1 5 – 30

Light 0.87 – 0.83 31.1 - 39 10 - 40

Superlight < 0.83 > 39 10 - 45

Subandean Basin

Subandean Basin

Mature Field Redevelopment: Field Performance

Well Engineering

Reservoir Engineering

13001

13002

13004

13006

13009

13014

13018

13041D

13047

13048

13058D

13059D13062

13065

13068D

13077D

13084D

13096D

13098D

13099D13101D

13102D

13103D

13104D

13108D

13114D

13119D

13136D

13138D

13141

13146

13151D

13157D

13162D

13163D

13164D

13169D

13172D-ST

4590

4612

4616

4621

4628

4637

4699

47024703

4708 4712

4714

471747184753

4754

47574757R4758

48314839

4842

4853

5122

5242

52515254

5281

5306

5507

5526

55525553 5558

5559

5920

5975

6207

6361

6362

6391

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6404

6433

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8021

8022

8023

8024

8025

8026

8027

8028

8029

8030

8031

8032

8033

8034

Date:01/03/2035

EUR (MMBbls)

10.00 255.00 500.00

Ubic. PND

Ubic. Prob.

Ubic. Pos.

Multilateral Drilling

EOR

Infill Drilling

Smart Wells & Real Time Monitoring

Total System Analysis

Mature Field Redevelopment: Elements

Horizontal wells allows delaying water encroachment while increasing oil production and

recovery

Mature Field Redevelopment: Why Horizontal Wells??

SWOT Assessment for Mature Oilfields in Peru

Strengths • The asset: Proved reserves, infrastructure

and surface facilities. • Experienced engineers and technicians with

local knowledge. • Current transportation, processing and

marketing contracts. • Mostly still under primary recovery. • Exploratory potential in deeper reservoirs

and unexplored leads.

Weaknesses • Mostly depleted fields or areas with high

water cuts. • Old facilities and infrastructure. • Limited data and lack of data management. • Improper ratio of engineers to the number of

fields. • Commingled production

Opportunities • Rejuvenation/Revitalizing. • Developing gas business. • Acquisition of new data and improved data

management. • Applying EOR processes and new technology. • Fostering Innovation and R&D. • Implementing production optimization

techniques • Exploring “upside potential”

Threats • New investment. • Low crude oil prices. • Very sensitive environmental and social issues • Inappropriate high royalties (the highest ones

for south America) • Lack of a clear government policy for

hydrocarbons sector.

Strengths Existing Facilities & Cumulative Production

Weaknesses

High Water Cuts due to Coning

Opportunities IOR

Threats Crude Oil Volatility -20.00%

-15.00%

-10.00%

-5.00%

0.00%

5.00%

10.00%

15.00%

20.00%

28/10/1995 24/07/1998 19/04/2001 14/01/2004 10/10/2006 06/07/2009 01/04/2012 27/12/2014 22/09/2017

WTI

13.5%:

PrimaryRecovery

3.4%:

Infill Drilling

5.4%:

Waterflooding

0

10

20

30

40

100

1000

10000

100000

1000000

01/1

975

02/1

976

03/1

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04/1

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05/1

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06/1

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07/1

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No

. de

Po

zos

Pro

du

cció

n (

bo

d)

Historia de Producción - Lote 1AB

Pozos de Desarrollo Pozos Exploratorios Oil Rate (Cal. Day) bbl/d

26 Pozos Exploratorios213 Pozos de Desarrollo

723 MMBbls

Tasa de Declinación: 5.18%Tasa de

Declinación: 8.58%

0.01

0.10

1.00

10.00

100.00

1000.00

10000.00

10

100

1000

10000

100000

1000000

10000000

01/1

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01/1

976

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Cum

mul

ativ

e O

il Pr

oduc

tion

(MM

bbl)

Oil

Rat

e (b

bl/d

) and

Wat

er R

ate

(bbl

/d)

Oil Rate "A" & "B" (bbl/d) Water Rate (bbl/d) Cummulative Oil Production (MMbbl)

SWOT Assessment for Mature Oilfields in Peru

Inflow Control Devices (ICDs)

Slotted/pre-drilled liner

Standalone Screens

ICD AICD

ICDs and AICDs balance inflow which delays water/gas breakthrough

Inflow Control Devices (ICDs)

• Obtain a uniform inflow profile along the well, restricting the flow in areas of high

mobility.

• Simultaneously stimulate production areas of low to moderate productivity by

slowing water breakthrough.

• Adjust dynamic pressure profile along the entire section of the well (by controlling

pressure drop).

ICD/ Multinode

Analytical Model

Laboratory Tests

– Geometry

– Fluids Properties

2qbqadP fp

g

dm

P4

L

Q, P1

wc

h

FLOW PATH

CROSS-SECTION

HELICAL FLOW PATH

KoutK

in

Pressure

taps

P2

P3

Regression AnalysisRegression Analysis

Can vary the number, width, and length of channels to

achieve the desired pressure drop

Analytical Model

Laboratory Tests

– Geometry

– Fluids Properties

2qbqadP fp

g

dm

P4

L

Q, P1

wc

h

FLOW PATH

CROSS-SECTION

HELICAL FLOW PATH

KoutK

in

Pressure

taps

P2

P3

Regression AnalysisRegression Analysis

Can vary the number, width, and length of channels to

achieve the desired pressure drop

Inflow Control Devices (ICD) Flow Path

Horizontal Well Completion Heel Conning

Oil Bypassed Fluid Equalizer Technology

Inflow Control Devices (ICD) Horizontal Well Productive Performance

Field Cases – Subandean Basin

Open Hole Log and Layer Selection

Reservoir Model

• Case: Isolating Heel and Comparing Screen 5 ½” Vs Equalizer 3 ½”



G Field

G main features

• Production since 1996

• Mature heavy oil – 16.6°API,

60cP

• High permeability sandstone

• Very active aquifer support

• Expected high water cuts >90%

• Delicate environment –

Amazonic jungle

• Produced water is treated then

re-injected


4 zonal isolation packers

creating 5 zones

ZoneQuantity of AICD Joints

1 3

2 4

3 4

4 5

5 4

Completion Design


Days on Production

Water

Cut %

Neighbor SAS

AICD Completion

Reduced

Water Cut

0 40 80 120

100

80

60

40

20

0

Swellable

packers

activate

1800

1500

1200

900

600

300

0

0 40 80 120

Days on Production

Oil

Flow

BBD

Neighbor SAS

Completion

AICD Completion

Increased

Oil Flow

0

200

400

600

800

1000

1200

1400

1600

1800

1

11

21

31

41

51

61

71

81

91

10

1

11

1

12

1

13

1

14

1

15

1

16

1

17

1

18

1

19

1

20

1

21

1

22

1

23

1

24

1

25

1

26

1

27

1

28

1

29

1

30

1

BOPD

Base Case (Real) Case 1 Case 2

AICD Completion

SAS Case 1

SAS Case 2

Caso ICD Stand Alone Screen (SAS 2)

Incremento

Reducción Petróleo (MBbl) 156 135 21 Agua (Mbbl) 862 1310 -448 Corte de Agua (%) 84.68 90.65 -6.48


YA Field

main features

Formación Vivian

Tope 10500 pies Base 10700 pies

Presión del reservorio: 4200 psia Temperatura: 244° F

Porosidad 15-22 % Permeabilidad horizontal Kh 200-1500 mD

Anisotropía Kv/Kh 0.15

Gravedad API: 19°

Factor de Volumen de Formación:

1.05 bl/stb @ pb

Viscosidad del petróleo: 7 cp

Gravedad del Gas: 0.7 s.grav.

Gravedad del agua: 1.01 s.grav.

GOR: 124scf/STB @ Pb=883 psi


Completion Design

Capa Tope Espesor Porosidad Permeabilidad

1 10656.038 5.6 18 1250

2 10661.638 5.2 18 1250

3 10666.838 3.6 15 500

4 10670.438 5.2 21 1500

5 10675.638 3.6 16 500

6 10679.238 5.9 19 1200

7 10685.138 6.9 19 1500

8 10692.038 4.6 12 1200

9 10696.638 4.6 18 1300

10 10701.238 3.9 15 500

11 10705.138 12.1 18 1200

12 10717.238 4.3 10 200

13 10721.538 19.7 18 1500

Segmento Descripción Tamaño Tipo

1 10 packer

2 14 junta 6.4 FRR 560 Ecualizador

3 10 packer


5 10 packer


7 10 packer

8 4junta 6.4 FRR 160 Ecualizador

9 10 packer


11 10 packer


13 20 packer


Caso ICD Convencional Incremento

Reducción Petróleo (MMBbl) 1.441 1.306 0.135 Agua (MMbbl) 2.136 2.513 -0.377 Corte de Agua (%) 83.8 84.6 -0.8

Conclusions

Redevelopment of Peruvian mature fields would require an implementation of reservoir

management approach.

Innovation strategies and dissemination of new technology can be broadly group into

production optimization and improved oil recovery.

Coupling reservoir and completion modeling is critical during technology screening and design.

Flow pattern is not homogeneous along the entire borehole of a horizontal well; without

selective completion, eventually, flow will be restrictive to the “heel” section.

ICD’s delay water/gas breakthrough, increasing ultimate recovery factor and NPV.

Successful applications of ICDs in Colombia and Ecuador proved 10% to 30% increase in

cumulative oil production, and 10% to 50% decrease in water production.

Preliminary numerical simulation studies for mature heavy oilfields in Peru shows 10% increase

in cumulative oil production and 15% decrease in water production during the first two years.

GTW Peru 2015

Increasing the Recovery Factor

in Mature Oil & Gas Fields

THANKS

QUESTIONS?

Edgewater Drive Bottomwater Drive

Conning Well Production with Water Coning

1998 99 2000 01 02 03 04 05 06 07 08 09

100

101

102

103

104

105

Date

CORR-1002D

Oil Rate (Cal.Day) ( bbl/d )

Water Rate (Cal. Day) ( bbl/d )

Oil Cut ( % )

Cumulative Oil Production ( Mbbl )

PRD.DAYS ( days )

Liquid Rate (Cal. Day) ( bbl/d )

CORR-1002D

Field Performance in Heavy Oilfields Water Drive Mechanisms

Inflow Control Devices (ICD)

Helical Type: Large flow area, low velocity,

viscosity sensitive

Tube Type: Small flow area, high velocity,

viscosity sensitive

Labyrinth Type: Small flow area, low

velocity, viscosity sensitive

Nozzle/Orifice Type: Small flow area, high

velocity, viscosity insensitive

Hybrid Type: Very Large flow area, low

velocity, highly viscosity insensitive

Screen or

Debris

Barrier

Passive Inflow Control Device (PICD): Fluid flow is regulated

by the additional pressure drop through the ICD

Helical Type: Large flow area, low velocity,

viscosity sensitive

Tube Type: Small flow area, high velocity,

viscosity sensitive

Labyrinth Type: Small flow area, low

velocity, viscosity sensitive

Nozzle/Orifice Type: Small flow area, high

velocity, viscosity insensitive

Hybrid Type: Very Large flow area, low

velocity, highly viscosity insensitive

Screen or

Debris

Barrier

Passive Inflow Control Device (PICD): Fluid flow is regulated

by the additional pressure drop through the ICD

History Matching and Forecast Oil & Water Production


Scenario

• Case 1: Screen vs Equalizers results under original completion

There is little benefit in production performance if equalizers are

not used with swelling packers that provides zones isolation.


Documents

Reservoir Management: Fundamentals and Applications in ...€¦ · Reservoir Management: Fundamentals and Applications in Mature Oilfields MSc. Victor A. Huerta Quiñones PETROPERU