Artificial Lift in Mature Fields Case Study of the Golfo

Artificial Lift in Mature Fields

By Marcelo Hirschfeldt

OilProduction Consulting & Training

Patagonia Argentina

Golfo San Jorge BasinCase Study of the

Argentina

Artificial Lift in Mature Fields

By Marcelo Hirschfeldt

OilProduction Consulting & Training

Patagonia Argentina

Golfo San Jorge BasinCase Study of the

Argentina

ARTIFICIAL LIFT CONFERENCES ARTIFICIAL LIFT CONFERENCES

2121--22 22 FebruaryFebruary 2006 2006 –– JakartaJakarta, Indonesia, Indonesia

OutlineOutline

OilProduction Consulting & TrainingOilProduction Consulting & Training

••Lifting cost consideration & evolutionLifting cost consideration & evolution

•• ConclusionsConclusions

•• Argentina Argentina –– Regional contextRegional context

-- Oil & gas production history and distributionOil & gas production history and distribution

•• GolfoGolfo San Jorge Basin (GSJB) San Jorge Basin (GSJB) –– IntroductionIntroduction

-- Reservoir characteristicsReservoir characteristics

-- Oil & water production trendsOil & water production trends

••GSJB GSJB -- Artificial Lift SystemsArtificial Lift Systems

-- Sucker rod / Sucker rod / PCPumpPCPump / / ESPumpESPump & others & others

-- Artificial lift evolution Artificial lift evolution –– Typical exampleTypical example

Argentina Argentina –– Regional contextRegional context

SouthSouthAmericaAmerica

ArgentinaArgentina

Buenos AiresBuenos Aires

GOLFO SAN JORGE GOLFO SAN JORGE BASINBASIN


ArgentinaArgentina-- Regional contextRegional context

General InformationGeneral InformationFive productive basinsFive productive basins

Oil Oil [bpd][bpd]: : 649,240649,240Gas Gas [[MMcfpdMMcfpd]] 4,8664,866Water Water [M bpd][M bpd]: : 5,0155,015Water %: Water %: 9090Active Oil Wells: Active Oil Wells: 18,20018,200

35.5 35.5 bopdbopd / well/ wellActive Gas Wells: Active Gas Wells: 1,3201,320


Basins Basins –– Production distributionProduction distribution

Oil production Oil production -- MbpdMbpd

5050

100100

150150

200200

250250

300300

G. San JorgeG. San Jorge

43.4 %

CuyanaCuyana

6 %

NeuquinaNeuquina

42.8 %

AustralAustral

5.8 %

NorthNorth--WestWest

2.2 %


Oil well distributionOil well distribution

Oil wells : 18,200Oil wells : 18,200

GolfoGolfo San San JorgeJorgeNeuquinaNeuquina

CuyanaCuyana

AustralAustral NoroesteNoroeste

63 %63 %30 %30 %

5 %5 %

1.7 %1.7 % 0.3 %0.3 %


Argentina Argentina -- Production HistoryProduction History

19001900 19201920 19401940 19601960 2000200019801980 20202020

Oil & Gas Production History (average per year)Oil & Gas Production History (average per year)

200200

400400

600600

800800

1,01,0

2,02,0

3,03,0

4,04,0

0000

Oil

Oil

--M

bo

pd

M b

op

d

Ga

s G

as

--M

M c

fpd

MM

cfp

d


Cumulative oil Production

9,070 MM BO9,070 MM BO

2005200519991999 20002000 20012001 20022002 20032003 20042004

1,0001,000

2,0002,000

4,0004,000

5,0005,000

6,0006,000

400400

800800

1,2001,200

6006003,0003,000

1,0001,000

200200

Wa

ter

Wa

ter

--M

bp

dM

bp

d

Oil

Oil

--M

bo

pd

M b

op

d

Golfo San JorgeGolfo San Jorge

Argentina Argentina –– Oil ProductionOil Production


Artificial Lift distributionArtificial Lift distribution

Total oil wells : 18,200Total oil wells : 18,200

SRPSRP

70.9 %70.9 %

12,90112,901

ESPESP

15.3 %15.3 %

2,7872,787

PCPPCP

10 % 10 %

1,8241,824

Gas liftGas lift

1 % 1 %

176176

Plunger liftPlunger lift

0.8 % 0.8 %

141141

Natural Natural flowingflowing

1.9 %1.9 %

351351


Golfo San Jorge BasinGolfo San Jorge Basin

Atla

ntic

Oce

an

General InformationGeneral InformationArea Area [M Acre]: 28,00028,000Oil Oil [bpd]: 281,500281,500Gas Gas [MM cfpd]: 447447* Water * Water [M bpd]: 2,6862,686Water Water %: : 9090Active Active oil wells: : 11,46711,467

24.5 24.5 bopdbopd / well/ well°° API API (Type Escalante) 2424

* All the water is injected* All the water is injected

Drilling : Drilling : 3030WokoversWokovers: : 6565

Golfo San Jorge Basin (GSJB)Golfo San Jorge Basin (GSJB)

Comodoro Rivadavia

2005 RIG Count2005 RIG Count


First oil well drilled in First oil well drilled in Comodoro Rivadavia in 1907Comodoro Rivadavia in 1907

Comodoro Rivadavia

Caleta Olivia

Cañadón Seco

Pico Truncado

Las Heras

Sarmiento

145 miles 9

4 m

iles


Cities

Oil Oil fieldsfields distributiondistribution

Golfo San Jorge Basin (GSJB)Golfo San Jorge Basin (GSJB)

Comodoro Rivadavia

Caleta Olivia

Cañadón Seco

Pico Truncado

Las Heras

Sarmiento


Cities

GSJBGSJB-- Reservoir characteristicsReservoir characteristics

•• Enviroment of depositionEnviroment of deposition

•• Fluvial and alluvial braided stream.Fluvial and alluvial braided stream.

••TrapsTraps

••Tilted horst blocks, faulted anticlines, Tilted horst blocks, faulted anticlines, combination structural/combination structural/stratigraphicstratigraphic

•• StratigraphicStratigraphic pinchoutspinchouts

•• Reservoir rocksReservoir rocks

•• SandstonesSandstones

•• Multi layers (lens)Multi layers (lens)

•• Since 30 Individual Reservoir in some Since 30 Individual Reservoir in some wellswells


GSJB GSJB -- Reservoir characteristicsReservoir characteristics

NorthNorthSouthSouth

WestWest EastEast


GSJB GSJB -- Reservoir characteristicsReservoir characteristics

NorthNorthSouthSouth

10,000 ft

3,000 ft

65 miles65 miles


Water Oil

GSJB GSJB -- Oil and Water ProductionOil and Water Production

500500

2,0002,000

1,0001,000

3,0003,000

1,5001,500

2,5002,500

5050

100100

150150

200200

250250

300300

350350

400400

450450

500500

Wa

ter

Wa

ter

--M

bp

dM

bp

d

Oil

Oil

--M

bo

pd

M b

op

d

20002000 20012001 20022002 20032003 20042004 2005200519991999


0%

10%

20%

30%

40%

50%

60%

Oil produced from WaterfloodingOil produced from Waterflooding

40 % of oil production is from secondary recovery

(waterflooding)

20002000 20012001 20022002 20032003 20042004 2005200519991999


Water % evolutionWater % evolution

80%

82%

84%

86%

88%

90%

92%

94%

96%

98%

100%

Wa

ter

Wa

ter

--%%

20002000 20012001 20022002 20032003 20042004 2005200519991999


Typical oilfield in Typical oilfield in GolfoGolfo San JorgeSan Jorge

•• Finishing of primary stage (natural declination) and Finishing of primary stage (natural declination) and beginning of secondary recovery projects (water beginning of secondary recovery projects (water flooding)flooding)

•• High fluid flow rate extraction (in 51/2High fluid flow rate extraction (in 51/2”” casing)casing)

•• High water % and oil production from secondary High water % and oil production from secondary recoveryrecovery

•• Complex fluids: corrosive, heavy oil, gas, sand and Complex fluids: corrosive, heavy oil, gas, sand and scalescale


•• Multitphaces fluids (Oil + gas + water)Multitphaces fluids (Oil + gas + water)

•• Multilayer reservoir (from 3000 to 9000 ft) in the same Multilayer reservoir (from 3000 to 9000 ft) in the same wellwell

GSJB GSJB -- Artificial Lift OverviewArtificial Lift Overview

Artificial lift & typical well completionArtificial lift & typical well completion

SRPSRP -- 78 %78 % -- 8,9898,989

PCPPCP -- 11 %11 % -- 1,3131,313

ESPESP -- 10 %10 % -- 1,1251,125

Gas LiftGas Lift -- Plunger Lift Plunger Lift –– Jet pumpJet pump

51/251/2”” CasingCasing (9(955 %)%)

Vertical Vertical wellwell

SomeSome directionaldirectionalwellswells


Beam Pumping ESP PCP

Artificial Lift EvolutionArtificial Lift Evolution

20002000 20012001 20022002 20032003 20042004 20052005

7,0007,000

8,0008,000

9,0009,000

10,00010,000

11,00011,000

12,00012,000

192 %

135 %

17 %

Grows in the last 5 years

Nu

mb

er

of

we

llsN

um

be

r o

f w

ells

S.Rod pumping


Sucker rod pumping

Sucker rod pumpingSucker rod pumping

•• Insertable & Tubing pump : From 1 Insertable & Tubing pump : From 1 ½”½” to 3 to 3 ¼”¼” diameterdiameter

PumpsPumps

Best Best practicespractices & & InnovationsInnovations

Sucker rod Sucker rod

•• Grade D: 1Grade D: 1””--7/87/8””-- 3/43/4””

Sucker rod Sucker rod ““over size pinover size pin””

SR SR ¾”¾” -- 7/87/8”” pin / SR 7/8pin / SR 7/8”” –– 11”” pinpin

HighHigh StrengthStrength Rods Rods & & specialspecial alloyalloy

TEN

AR

IS-S

ider

ca

SurfaceSurface

LongLong-- StrokeStroke PumpingPumping UnitsUnits-- 300 300 ””

The bigest MII in Latin AmericaThe bigest MII in Latin America

Pump off controlerPump off controler

•• Conventional, MII & Air BalancedConventional, MII & Air Balanced

•• Max Torque: Max Torque: 1,280 1,280 [M in.lbs][M in.lbs] RO

TAFL

EX

LUFK

IN

MII-1824-427-216


0

2,000

4,000

6,000

8,000

10,000

12,000

0 1,000 2,000 3,000 4,000fl b d


5,400 ft5,400 ft

400 bfpd400 bfpd

Flowrate Flowrate -- bfpdbfpd

Pu

mp

de

pth

P

um

p d

ep

th --

ftft

•• Pulling Job /well / year: Pulling Job /well / year: 0.4 0.4 –– 1.21.2



SummarySummary

•• Numb of wells : Numb of wells : 8,9898,989

•• Average flowrate Average flowrate -- bpd: bpd: 400400

•• Average pump depth Average pump depth -- ft : ft : 5,4005,400


200400600800

1,0001,2001,4001,6001,800

0

2,000

4,000

6,000

8,000

10,000

12,000

0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000

Pu

mp

de

pth

Pu

mp

de

pth

--ftft

Flo

wra

te

Flo

wra

te --

bfp

db

fpd

Number of wells


Progressive Cavity Pump (PCP)Progressive Cavity Pump (PCP)

Progressive cavity pumpProgressive cavity pump

Drive headDrive head

Sucker rod stringSucker rod string

DownholeDownhole

•• Tubular & Insertable pumpsTubular & Insertable pumps•• Single lobeSingle lobe•• NBR & HNBR ElastomerNBR & HNBR Elastomer

High flow rate single lobe pumps : High flow rate single lobe pumps : 500 bpd @ 100 rpm500 bpd @ 100 rpm

Downhole pressure & temperature sensorDownhole pressure & temperature sensor

•• Direct & Right angle Direct & Right angle

•• Max. power : 75 HpMax. power : 75 Hp

Grade D : 1Grade D : 1”” & 7/8& 7/8””

Hollow rods Hollow rods (PCP Rods(PCP Rods™™) )

HighHigh StrengthStrength Rods Rods & & specialspecial alloyalloy


TEN

AR

IS-S

ider

ca


0

1,000

2,000

3,000

4,000

5,000

6,000

7,000

8,000

0 500 1,000 1,500 2,000 2,500 3,000

4,000 ft4,000 ft

770 bfpd770 bfpd


Pu

mp

de

pth

P

um

p d

ep

th --

ftftProgressive cavity pumpProgressive cavity pump

•• Pulling Job /well / year: Pulling Job /well / year: 1.0 1.0 -- 1.41.4


SummarySummary

•• Num of wells : Num of wells : 1,3131,313

•• Average flowrate Average flowrate -- bfpd: bfpd: 770770


•• Pulling Job /well / year: Pulling Job /well / year: 1.0 1.0 --1.41.4

0

500

1,000

1,500

2,000

01,0002,0003,0004,0005,0006,0007,0008,000

0 200 400 600 800 1,000 1,200

Pu

mp

de

ph

t P

um

p d

ep

ht

--ftft

Flo

wra

te

Flo

wra

te --

bfp

db

fpd

Progressing cavity pumpProgressing cavity pump

Number of wells


Electric submersible pump (ESP)Electric submersible pump (ESP)



Electric submersible pumpElectric submersible pump

SurfaceSurface

•• Switchboards Switchboards

•• Variable Variable SpeedSpeed DriveDrive (VSD) (VSD)

DownholeDownhole

•• 456 series motors @ 5 1/2456 series motors @ 5 1/2”” casingcasing

Instalation under deepest perforations Instalation under deepest perforations (51/2(51/2”” casing)casing)

-- 375 Series Motors with refrigeration shrouds375 Series Motors with refrigeration shrouds

-- Recirculation systemsRecirculation systems

Rec

ircu

latio

nSy

stem

s-C

EN

TRIL

IFT

== ==

ESP

–W

ood

Gro

up


0

2.000

4.000

6.000

8.000

10.000

12.000

0 1.000 2.000 3.000 4.000 5.000

6,500 ft6,500 ft

1,300 bfpd1,300 bfpd


Pu

mp

de

pth

P

um

p d

ep

th --

ftftElectric submersible pumpElectric submersible pump



0

2,000

4,000

6,000

8,000

10,000

0 200 400 600 800 1,000

0

1,000

2,000

3,000

4,000

Electric submersible pumpElectric submersible pump

SummarySummary

•• Num of wells : Num of wells : 1,3131,313

•• Average flowrate Average flowrate -- bfpd: bfpd: 1,3001,300


•• Pulling Job /well / year: Pulling Job /well / year: 0.4 0.4 -- 0.60.6

Pu

mp

de

pth

P

um

p d

ep

th --

ftftF

low

rate

F

low

rate

--b

fpd

bfp

d

Number of wellsOilProduction Consulting & TrainingOilProduction Consulting & Training

Other Artificial lift experiencesOther Artificial lift experiences

Gas LiftGas Lift Plunger LiftPlunger Lift Hydraulic Jet PumpHydraulic Jet Pump

Diadema Diadema OilfieldOilfield -- CAPSACAPSA

Cerro Dragon Oilfield-PanAmerican Energy

Cerro Dragon Oilfield-PanAmerican Energy


0

1.000

2.000

3.000

4.000

5.000

6.000

7.000

8.000

9.000

10.000

11.000

12.000

0 500 1.000 1.500 2.000 2.500 3.000 3.500 4.000

Artificial lift summaryArtificial lift summaryP

um

p d

ep

th

Pu

mp

de

pth

--ftft


ESPESPPCPPCPSRPSRP


Artificial lift evolution Artificial lift evolution -- ExampleExample

•• Example of artificial lift evolution before and during a Example of artificial lift evolution before and during a waterfloodingwaterflooding projectproject

•• Maximum reservoir depth= 7,000 ft Maximum reservoir depth= 7,000 ft

•• 5 1/25 1/2”” CasingCasing

•• We consider one oil well and one water injector wellWe consider one oil well and one water injector well

WaterfllodingWaterfllodingpatternpattern

Oil wellOil well

Water injetion well Water injetion well


Artificial lift evolution Artificial lift evolution -- ExampleExample

1

10

100

1000

10000

bpd

Increase pumping speed, pumping units & pump sizeIncrease pumping speed, pumping units & pump size

Secondary recovery (waterflooding)Secondary recovery (waterflooding)

Declination First stage Second stage

SRP

ESPChange ALS for ESP – Increase pumping speed & sizeChange ALS for ESP – Increase pumping speed & size

Increase pump size & depth setting

Small pumping unit & pump sizeSmall pumping unit & pump size

PrimaryPrimaryPrimary

OilOil + water

Water injection

One year

Lifting Cost Lifting Cost

80 % 80 % forfor productionproduction

20 % 20 % WaterWater injectioinjectionn

SelfSelf ggeneratedenerated

RRentalental oror boughtbought

GasGas (owned or (owned or boughtbought))

ALS efficiencyALS efficiency

Flow rate x depth Flow rate x depth (HHP)(HHP)

Type of contractsType of contracts

Operative modelOperative model

Major artificial lift Major artificial lift sistemssistems

FailureFailure indexindex

Leas Leas oror contractcontract forforartificial artificial liftlift supplysupply

GSJB Lifting cost considerationsGSJB Lifting cost considerations

Energy (15Energy (15--30 %)30 %)

Energy distributionEnergy distribution

Surface maintenance Surface maintenance

(15(15--25 %)25 %)

SubSub--surface surface maintenance (25maintenance (25--35 %)35 %)

Oilfields with more than 85 % of water & Oil from Waterflooding Oilfields with more than 85 % of water & Oil from Waterflooding (60(60--80 %)80 %)

Fluid Fluid treatmenttreatmentPersonnelPersonnelOthersOthers

OthersOthers


Lifting cost evolutionLifting cost evolution

Effect of system efficiencyEffect of system efficiency Lifting cost model solutionLifting cost model solution

By By JohnJohn G. G. SvinosSvinos & & TerryTerry TreibergTreiberg –– Theta Theta EnterpricesEnterprices, , IncInc SPE 69559SPE 69559-- ForecastForecast TechniquesTechniques forfor LiftingLifting CostCost in Gas in Gas andandOil Oil OnshoreOnshore FieldsFields-- Ricardo E. MartRicardo E. Martííneznez--PerezPerez CompancCompanc


Lifti

ngco

st–

u$s

/ B.O

.E

Cumulative production (% of Final Recovery)

ConclusionsConclusions

To increase the productive basin lifeTo increase the productive basin life


How to achieve it ?How to achieve it ?

• Deepest reservoirs

What is our challenge ?What is our challenge ?

• Waterflooding project (improving recovery factor)

• Exploration

• Off shore development

• To continue improving our artificial lift experience

Contact information Contact information

Marcelo HirschfeldtMarcelo Hirschfeldt


Patagonia ArgentinaPatagonia Argentina

www.oilproduction.netwww.oilproduction.netInfo@[email protected]

http://www.oilproduction.net/

http://www.jakarta2006.oilproduction.net/

mailto:[email protected]

Documents

Artificial Lift in Mature Fields Case Study of the Golfo