Abstract The study area is located towards the North of the Caribbean

Deformation Front; specifically where the structures of

Sipororo, La Yuca and Barrancas oils fields are located, near

the Barinas Traditional oil Fields. From a structural point of

view, the area of interest is bounded by the following

structural features: Bocono Fault Northward, Arco de El Baul

East, Caribbean Deformation Front to the North and Arco de

Merida to the South and have been studied with the aim build

3D/2D basin model using 3D Temis and some 2D lines (2D

Temis), with the purpose of determining the different elements

(crude oils /source rock, reservoirs, seals and traps) and

processes (maturity, migration, transformation ratio, generated

and expelled hydrocarbon volume) by the source rocks and

their contribution with charge of the proposed exploration

opportunities in the area, in order to integrate and update

previous studies in the Barinas Basin.

The methodology developed was first to evaluate the

geochemical characteristics of the crude oils and rocks. Then,

from geological-structural model proposed in the area, was

built a geochemical modeling 2D and 3D as a result of the

interpretation performed on 2D (15.520 km) and 3D (1.350

km2) surveys. The results model 2D/3D suggest two possible

intervals for generation and expelling potential hydrocarbons

of Cretaceous age: the Quevedo and La Morita Members of

Navay Formation were identified in the Northwest of the study

area, which were active in the Miocene and currently at levels

equivalent to maturity phase of maximum generation of liquid

hydrocarbons (1.3% Ro).These hydrocarbons have migrated

vectors a Northwest-Southeast direction, towards the Barinas

Basin. Thus, according to the result of this model and Mass

Balance the opportunities displayed on the study area, have

received enough volume of oil from these Cretaceous source

rocks (Miocene generation) (5035.31 MMBLS) and its lateral

equivalent La Luna Formation (generation in the Eocene),

directly or through remigration oil that was accumulated in the

Barinas fields. Molecular parameters have allowed

corroborating the crude oils Northem Barinas and traditional

Barinas areas have mainly marine origin with some

contribution of terrestrial organic matter and different levels of

maturity and biodegradation.

Keywords: oil, generation, expulsion, migration, entrapment,

geochemical, structural.

Introduction The study area, is located towards the North of the Caribbean

Deformation Front; specifically where the structures of

Sipororo, La Yuca and Barrancas oils fields are located, near

the Barinas Traditional oil Fields. The UTM area coordinates

boundaries are: Xmax = 410000, Xmin = 335,000, Ymin =

910,000 and Ymax = 990,000. From a structural point of view,

the area of interest is bounded by the following structural

features: Bocono Fault Northward, Arco de El Baul East,

Caribbean Deformation Front to the North and Arco de

Merida to the South (Figure 1).

Figure 1. Location map of the studied area showing the main

structural elements.

The sedimentary column covers ages from

Cretaceous to Recent age. It includes mainly: Basamento,

Aguardiente, Escandalosa (reservoir), Navay (source rock),

Burguita, Gobernador (reservoir), Masparrito, Paguey (seal),

Parangula and Rio Yuca formations. Four major tectonic

events led to the current basin: Pre-rift during Paleozoic, rift

and drifting during Jurassic and early Cretaceous, Passive

margin during the Cretaceous and active margin from

Cenozoic to the recent with the development of a flexural

Basin and the foreland basin (Figura 2).

Figure 2. Stratigraphic column type of the Barinas sub-basin

and the main elements of the petroleum system (Reproduced

and modified from Lisbeth Meza, 1995).

Petroleum System Of The Barinas Basin: A 2D/3D Basin Modeling Approach Rojas Iliana (PDVSA-INTEVEP) Copyright 2012, ALAGO. This paper was selected for presentation by an ALAGO Technical Committee following review of information contained in an abstract submitted by the author(s).

South America

Venezuela

Barinas Basin

C= Continental NI= Neritic Internal NE= External NeriticBS= BatialT= Transitional NM= Medium Neritic

Modified from: Meza M. (2000)

Erosion

Passive Margin(During theCretaceous)

MIOCENOMIOCENO PARANGULA

PAGUEYTARDIOTARDIO

MEDIOMEDIOMASPARRITO

GOBERNADOR

OLIGOCENOOLIGOCENO

TEMPRANOTEMPRANO

PALEOCENOPALEOCENO

EO

CE

NO

EO

CE

NO

T E

R C

I A

R I

OT

E R

C I

A R

I O

C R

E T

ÁC

E O

C R

E T

ÁC

E O

CUATERNARIOCUATERNARIO ALUVIONES

PLIOCENO PLIOCENO RIO YUCA

QUEVEDO

CONIACIENSEA

TURON.TARDIO

CENOM.TEMPRANOCENOM.TEMPRANOAA

ALBIENSE TARDIOALBIENSE TARDIO

ESCANDALOSA

BASAMENTOPRE-CRETACEOPRE-CRETACEO

CONIACIENSECONIACIENSEAA

TURON.TARDIOTURON.TARDIO

TURON. MEDIOTURON. MEDIOAA

CENOM.TEMPRANOCENOM.TEMPRANO

CAMPANIENSECAMPANIENSE

TEMPRANOTEMPRANO

AA

CONIACIENSECONIACIENSE NAVAY

BURGUITAMAASTRICHTIENSEMAASTRICHTIENSE

LA MORITA

AGUARDIENTE

ALBIENSE TEMP.ALBIENSE TEMP.AA

NEOCOMIENSENEOCOMIENSE

P

S

= Erosi

AGEFORMATION / MERBER

NAMEOPER PALEOENVIRONMENTS

A

BC

D

EF

GHI

JK

LM

N

O

R

T

C T NI NM NE BS

.

MIOCENE PARANGULA

PAGUEYLATE

MIDDLEMASPARRITO

GOBERNADOR

OLIGOCENE

EARLY

PALEOGENE

EO

CE

NE

TE

RT

IAR

Y

QUATERNARY ALUVIONES

PLIOCENE RIO YUCA

QUEVEDO

CONIACIENSEA

TURON.TARDIO

ESCANDALOSA

BASAMENTPRE-CRETACEOUS

LOWER CAMPANIAN

TO CONIACIAN NAVAY

BURGUITAMAASTRICHTIAN

LA MORITA

AGUARDIENTE

LOWER ALBIAN

Upl

ift

And

ean

Caribbean, Napas de Lara, Merida Arc

Post “Rift” (EarlyCretaceous)

Flexural Basin, Foreland type

“Rift” (During Jurassic)

Deepeding of the passivemargin during

ofseparation of South and North America

Beginning of the Uplift

GEODYNAMICPERIOD/EPOC

CONIACIAN TO UPPER TURONIAN

MIDDLE TURONIAN TO LOWER

CENOMANIANLOWER

CENOMANIAN TO UPPER ALBIAN

CR

ET

AC

EO

US

PETROLEUM SYSTEM

ELEMENTS

S

R

R

SR

Basin Foreland

Active margin (Cenozoic tothe recent)

Passive Margin(During theCretaceous)

MIOCENOMIOCENO PARANGULA

PAGUEYTARDIOTARDIO

MEDIOMEDIOMASPARRITO

GOBERNADOR

OLIGOCENOOLIGOCENO

TEMPRANOTEMPRANO

PALEOCENOPALEOCENO

EO

CE

NO

EO

CE

NO

T E

R C

I A

R I

OT

E R

C I

A R

I O

C R

E T

ÁC

E O

C R

E T

ÁC

E O

CUATERNARIOCUATERNARIO ALUVIONES

PLIOCENO PLIOCENO RIO YUCA

QUEVEDO

CONIACIENSEA

TURON.TARDIO

CENOM.TEMPRANOCENOM.TEMPRANOAA

ALBIENSE TARDIOALBIENSE TARDIO

ESCANDALOSA

BASAMENTOPRE-CRETACEOPRE-CRETACEO

CONIACIENSECONIACIENSEAA

TURON.TARDIOTURON.TARDIO

TURON. MEDIOTURON. MEDIOAA

CENOM.TEMPRANOCENOM.TEMPRANO

CAMPANIENSECAMPANIENSE

TEMPRANOTEMPRANO

AA

CONIACIENSECONIACIENSE NAVAY

BURGUITAMAASTRICHTIENSEMAASTRICHTIENSE

LA MORITA

AGUARDIENTE

ALBIENSE TEMP.ALBIENSE TEMP.AA

NEOCOMIENSENEOCOMIENSE

P

S

= Erosi

AGEFORMATION / MERBER

NAMEOPER PALEOENVIRONMENTS

A

BC

D

EF

GHI

JK

LM

N

O

R

T

C T NI NM NE BS

.

MIOCENE PARANGULA

PAGUEYLATE

MIDDLEMASPARRITO

GOBERNADOR

OLIGOCENE

EARLY

PALEOGENE

EO

CE

NE

TE

RT

IAR

Y

QUATERNARY ALUVIONES

PLIOCENE RIO YUCA

QUEVEDO

CONIACIENSEA

TURON.TARDIO

ESCANDALOSA

BASAMENTPRE-CRETACEOUS

LOWER CAMPANIAN

TO CONIACIAN NAVAY

BURGUITAMAASTRICHTIAN

LA MORITA

AGUARDIENTE

LOWER ALBIAN

Upl

ift

And

ean

Caribbean, Napas de Lara, Merida Arc

Post “Rift” (EarlyCretaceous)

Flexural Basin, Foreland type

“Rift” (During Jurassic)

Deepeding of the passivemargin during

ofseparation of South and North America

Beginning of the Uplift

GEODYNAMICPERIOD/EPOC

CONIACIAN TO UPPER TURONIAN

MIDDLE TURONIAN TO LOWER

CENOMANIANLOWER

CENOMANIAN TO UPPER ALBIAN

CR

ET

AC

EO

US

PETROLEUM SYSTEM

ELEMENTS

SS

RR

RR

SRSR

Basin Foreland

Active margin (Cenozoic tothe recent)

2 ROJAS ILIANA

The development of the model presented was in this

paper done mainly from the 2D/3D seismic data (seismic

transects and map in depth), key wells available and the

interpreted stratigraphic framework interpreted from this data.

Key tops formations were identified, as well as eroded

thicknesses, formation ages, lithology of each interpreted

sequence and geochemical parameters of the source rock such:

total organic richness, effective thickness and type of kerogen.

Objective Building a 3D/2D basin model using 3D Temis and some 2D

lines (2D Temis), with the purpose of determining maturity,

migration, transformation ratio, generated and expelled

hydrocarbon volume by the source rocks and their

contribution with charge of the proposed exploration

opportunities in the area, in order to integrate and update

previous studies in the Barinas Basin.

Methodology The methodology developed was first to evaluate the

geochemical characteristics of the crude oils and rocks. Then,

from geological-structural model proposed in the area, was

built a geochemical modeling 2D and 3D as a result of the

interpretation performed on 2D (15,520 km) and 3D (1,350

km2) surveys (figure 3,4).

Figure 3. Methodology used for the petroleum system

analysis of the Barinas Basin using a 2D-3D Basin Modeling.

Figure 4. Location map of the available seismic data (2D and

3D).

Results and Discussion The results were divided in two ways: The Petroleum System

Elements and the Petroleum System Processes.

Petroleum System Elements

Crude Oils / Source Rock

The crude oils Northem Barinas and traditional Barinas areas

have mainly marine origin (carbonate and/ or shale) with some

contribution of terrestrial organic matter and different levels of

maturity to increase from Southwest to Northeast in the study

area. The biodegradation can be interpreted in different levels,

ranging from high in the seeps studied, to moderate and low,

in some cases as presented of the Barinas fields (figure 5).

Figure 5. General Characteristics of the crude oils and seep

oils of Barinas area: the origin, maturity and biodegradation.

From previous studies, the main hydrocarbon source

rock is represented by Navay Formation, which is constituted

by La Morita and Quevedo Members, for Barinas Basin.

The figures 6 show the TOC variation and Ro for the

Quevedo and La Morita Members. The general trends for both

of them increase from Southeast to Northwest.

6.- Building the lithologymaps and the lithology

index maps

3.- Building of structuralmaps (depth)

2.- Building of structuralmaps (time ms)

1.- Evaluation of thegeochemical

characteristicsof crudeoils and rocks

4 and 5.- Exporting, reviewing andediting the depth structural maps

in the Map Editor

7.- Constructions ofthematic maps (TOC,

kerogen index and thermalmodel)

Geological Model8.- 3D block building (mapsloading in the Block Build)

9. - Extraction of 2D sectionto validate geometry, 2D-3D

geometry model run andthermal calibration

6.- Building the lithologymaps and the lithology

index maps

3.- Building of structuralmaps (depth)

2.- Building of structuralmaps (time ms)

1.- Evaluation of thegeochemical

characteristicsof crudeoils and rocks

Exporting, reviewing andediting the depth structural maps

in the Map EditorBasin Modeling

- 3D block building (mapsloading in the Block Build)

- Extraction of 2D sectionto validate geometry, 2D-3D

geometry model run andthermal calibration

10 Km10 Km

Study area

10.534 Km 2

G

H

IJ

DL K

MN

OÑ

P

10 Km10 Km

Study area

10.534 Km 2

G

H

IJ

DL K

MN

OÑ

P

LEGEND

3D Block

Study area

2D Seismic

3D Merged

O

AA

K

MA

BT AB

AC F

Z Y

D

H

3

2

1

O

AA

K

MA

BT AB

AC F

Z Y

D

H

3

2

1

AKAL

Q

AMW

XAN

R

AKAL

Q

AMW

XAN

R

G

HAD

I

JÑ

O

D K A

NAK

ALQ AC

F

P

AE

WAM

AN XAF

AGZ Y

AH

AI AJ

R

G

HAD

I

JÑ

O

D K A

NAK

ALQ AC

F

P

AE

WAM

AN XAF

AGZ Y

AH

AI AJ

R

Ro (%)Ro (%)

Quevedo MemberTOC Original Maturity

TOC (%)TOC (%)

PETROLEUM SYSTEM OF THE BARINAS BASIN: A 2D/3D BASI N MODELING APPROACH 3

Figure 6 .TOC and maturity trends in the Quevedo and Morita

Member.

Reservoirs

The gobernador and Escandalosa Formations have been

identified as the main reservoirs in the Barinas Traditional

Field. In the Gobernador Formation sandstones of Middle

Eocene age, have porosities between 9 to 18 % and Escadalosa

Formation between 2 and 10% in areas already drilled.

The figures 7 show the general trend of the thickness

reservoir, for the Gobernador and Escandalosa formations, the

higher thickness are observed in the central part of the study

area and the lower to the North.

Figure 7. Total thickness variation for the Gobernador (A)

and Escandalosa Formations (B) (From Re-Exploration

Barinas 2009 Project).

Seals

The regional seal characterized by shales intervals of the

Paguey Formation of Late Eocene age which is responsible of

the retention of hydrocarbons in the area is represented mainly

by with thicknesses varying from 1100´, in the Barinas

Traditional Area, to 5000´to the North, where Sipororo, La

Yuca and Barrancas structures are located (Figure 8)(ANKA

et al,1998).

Figure 8 Thickness variation of the Formation Paguey in the

Barinas Traditional Area to the North, where the red line

represents the depth lines, the blue one lines in time, time lines

and the different colors (yellow, medium and strong) (Taken

from ANKA et al, 1998).

Traps

The main structure of the Barinas Basin occurred during the

Middle Eocene. This period of deformation generated new

inverse structures and also produced the inversion of some

previous normal faults, with subsequent recovery activity

during the Late Middle Miocene (The Venezuelan Andes

Uplifting), generated structural styles represented by highs

associated with inverse faults reactivated and Neogene age

faults. There are two (2) big groups of older alignments: (1)

The alignment direction (Northeast-Southwest), driven by the

Boconó Fault in the Andes and (2) The economic basement

heritage in the East-West direction, which left its remains well

marked in the Barinas Traditional Area with a variety of

structural traps that give rise to numerous opportunities

identified.

Figure 9. Traps Eocene (Compresion Napa de Lara) and

Oligocene- Miocene (Compresion y Transpresion).

Petroleum System Processes

To simulate the processes of maturity, generation, expulsion,

migration and entrapment of oil in the North area of Barinas

and Barinas traditional, Temis 2D and 3D (Beicip Franlab ®)

programs were used. The following results describe the

obtained products of 2D lines and 3D block to define the

location of clearly source rocks, the amount of Hc generated

BORBURATA

TORUNOS

LA YUCA

BARRANCAS

BEJUCAL

CAIPEOBISPO

MAPORAL

PAEZ

MINGO

SINCO

SMW

0 10 km

A

BORBURATA

TORUNOS

LA YUCA

BARRANCAS

BEJUCAL

CAIPEOBISPO

MAPORAL

PAEZ

MINGO

SINCO

SMW

0 10 km0 10 km0 10 km

A

BORBURATA

TORUNOS

LA YUCA

BARRANCAS

BEJUCAL

MAPORAL

MINGO

SINCO

LAS LOMAS

CAIPE

PAEZ

OBISPO

0 10 km

B

BORBURATA

TORUNOS

LA YUCA

BARRANCAS

BEJUCAL

MAPORAL

MINGO

SINCO

LAS LOMAS

CAIPE

PAEZ

OBISPO

0 10 km0 10 km0 10 km

B

LEGEND (Feet)LEGEND (Feet)LEGEND (Feet)LEGEND (Feet)

Escandalosa FormationGobernador Formation

10 Km 10 Km

G

HAD

IJ

ÑO

AK

N AKAL

Q ACF AE

AMWP

R AF AG ANX

Z Y

D

AH

AI AJ

G

HAD

IJ

ÑO

AK

N AKAL

Q ACF AE

AMWP

R AF AG ANX

Z Y

D

AH

AI AJ

TOC (%)TOC (%)

G

HAD

IJ

Ñ

OK

A

NAKALQ AC

F AEAMW

PRAFAGZ Y

AN X

AJ

AH

AI

D

Ro (%)Ro (%)

La Morita MemberTOC Original Maturity

G

HAD

IJ

ÑO

AK

N AKAL

Q ACF AE

AMWP

R AF AG ANX

Z Y

D

AH

AI AJ

G

HAD

IJ

ÑO

AK

N AKAL

Q ACF AE

AMWP

R AF AG ANX

Z Y

D

AH

AI AJ

TOC (%)TOC (%)

G

HAD

IJ

Ñ

OK

A

NAKALQ AC

F AEAMW

PRAFAGZ Y

AN X

AJ

AH

AI

D

Ro (%)Ro (%)

La Morita MemberTOC Original Maturity

4 ROJAS ILIANA

(mass balance) and the direction of migration of these

hydrocarbons toward the proposed structures in the area.

The figures 10, shows the 3D block and the location

of the 2D lines. These NW-SE direction lines were selected to

represent the structural basin evolution, which generally can

be divided into 3 areas: One located to the North of the

Caribbean Deformation Front, where the Sipororo, La Yuca

and Barrancas structures are located. Second, located between

the Deformation Front and the Caribbean Neogene Syncline

foothills where Las Lomas and Guasimitos structures were

located. Finally, the third structure is located to the South, in

the Traditional Barinas Fields.

Figure 10. 3D block, the location of 2D lines (1 and 2) and

interpreted faults in the structural model of the area, showing

the deeper part of the basin to the NW (warm colors) and the

shallower to the SW (cold colors) as well as the 3 stages that

represent the structural evolution of the basin.

Thermal Calibration

This transect (figure 11) allowed to verify thermal calibrations

by comparing the trend obtained from measured data of

temperature and vitrinite reflectance of wells. So, it is possible

to say according to figures 12 that the obtained calibration was

successfully, since the measured data from wells and those

calculated by the program are very similar.

Figure 11 Thermal Maturity variation. Yellow color indicates

immature zone (0.1 to 0.6% Ro) and the green one the oil zone

(% Ro 0.7a 1.3).

Figure 12 Thermal Calibration of temperature and maturity

for B and A wells, showing a similar tendency between the

measured data from wells and those calculated by the

program.

The results model 2D/3D suggest two possible

intervals for generation and expelling potential hydrocarbons

of Cretaceous age: the Quevedo and La Morita Members of

Navay Formation were identified in the Northwest of the study

area, which were active in the Miocene and currently at levels

equivalent to maturity phase of maximum generation of liquid

hydrocarbons (1.3% Ro) , as shown in graphics (Age My Vs%

Ro) of Figures 13 and 14. In contrast, to the Southeast, is now

at the beginning of the oil generation window. This is due to

the Upper Eocene-Oligocene and Miocene have the biggest

thickness of rocks, while thickness is smaller in the Southeast

area, in the Traditional Fields of Barinas. These hydrocarbons

have migrated vectors a Northwest-Southeast direction,

towards the Barinas Basin.

Figure 13 Transect 2D (NW-SE), showing the thermal

maturity variation and the graph showing the evolution in time

(Age My Vs% Ro) for transect 1, NW-SE.

Figure 14. 3D view of maturity evolution (Quevedo Member

%Ro)

H

G

J

D

E

KM

ÑO

B S

R X

Z Y

FV

H

G

J

D

E

KM

ÑO

B S

R X

Z Y

FV

• Thermal maturity 2D section NW-SE

TOR-1X CAI-1X

1

NW SETOR-1X CAI-1X

1

TOR-1X CAI-1X

1

NW SEA B

• Thermal maturity 2D section NW-SE

TOR-1X CAI-1X

1

NW SETOR-1X CAI-1X

1

TOR-1X CAI-1X

1

NW SEA B

HG

J

DÑ

E

Q

R

KM

AB S

FT V

W

X

YZ

HG

J

DÑ

E

Q

R

KM

AB S

FT V

W

X

YZ

• Thermal maturity (Where yellow color indicates immature zones (0.1 to 0.6% Ro) and the green one the oil zones (% Ro 0.7a 1.3)).

1

NW SE

11

NW SE

~1.3% Ro

Age (Ma)

Ro

(%R

o)

Age (Ma)

Ro

(%R

o)

Age (Ma)

Ro

(%R

o)

Age (Ma)

Ro

(%R

o)

PETROLEUM SYSTEM OF THE BARINAS BASIN: A 2D/3D BASI N MODELING APPROACH 5

According to the analysis show in the 2D sections

and in the 3D block, have been identified two active source

rocks in the study area: Quevedo and La Morita member. The

figure 15, shown the productivity of these rocks in terms of

the hydrocarbons generated. Indicating that the crude oils from

Barinas Basin were generated from these two source rocks

(Miocene generation) with its lateral equivalent La Luna

Formation (generation in the Eocene), directly or through

remigration oil that was accumulated in the Barinas fields.

These results could verify the mass balance

conducted in the area, in which the rocks for the Navay

formation have a volume of hydrocarbons generated about

5035.31 MMBLS, a value greater than the amount of oil in

place (POES) calculated for the 14 oil fields in Barinas about

4027.035 MMBLS; which is the product of the ratio between

the recoverable reserves (cumulative production + remaining

reserves) and the recovery factor (FR). These results are only

considering the area of hydrocarbon generation located NW of

the study area (figure 15).

Figure15. Hydrocarbons generated (kg/m2) by the Quevedo

and La Morita members of the Navay Formation, in cold

colors the lowest values and warm colors the highest, at the

same time histogram of the area of cumulative production

Barinas Traditional, remaining reserves and POES in MMBL

(Production data taken from Re-Exploration Barinas 2009

Project).

According to the estimated data obtained from the

simulations, it has been determined the migration efficiency of

about 80%, which is a very high value, considering the losses

of hydrocarbons by primary and secondary migration. This

high value is a result of the following equation: EM (%) = 100

(POES / HG) where; EM: migration efficiency, POES:

original oil in place and HG hydrocarbons generated, and can

be explained by the low estimation of hydrocarbons generated,

for this study. The hydrocarbon generation area is limited to

covered the 3D model, being necessary to consider the

volumes generated by the intervals corresponding to the La

Luna Formation located further North in the study area,

beyond the extend of the 3D model, as evidenced by the basin

modeling done by the team EFAI 2009.

The basin modeling EFAI 2009 was made through a

transect located West of the transect considered in this study,

even when it overlaps with the covered area of the 3D model,

it has the special property to extend to the North of the

outcrops area of the Santo Domingo River. Simulations show

the history of the basin structure and evolution of thermal

maturity of source rock intervals (Figure 16). It is possible to

visualize that during the Middle Eocene (46 My), the

depocente of the basin was located to the Northeast of the area

where the ranges of Cretaceous age of maturity reached levels

equivalent of thermal generation of petroleum. This situation

continued until the Middle Miocene, when subsequently, with

the “Uplift of the Andes” and the inversion of the basin, the

generation and maturity process was extended Southward

from the basin.

Figure 16. Hydrocarbons of Generation areas in the Barinas

Basin. (a) Generation of hydrocarbons area of Eocene-

Oligocene age. (b) Generation of hydrocarbons area of

Miocene age. (Taken from Schneider 2009).

Conclusions � Crude oils from Northern Barinas and Traditional

Barinas areas have mainly marine origin (carbonate

and / or shale) with some contribution of terrestrial

organic matter.

� Crude oils from the study area have different levels

of maturity and biodegradation.

� Two possible intervals for generation and expelling

potential hydrocarbons of Cretaceous age were

identified in the Northwest area, for both the

Quevedo and La Morita Members of Navay

Formation.

� The maturity evolution map in terms of rate of

transformation in the area, shows the existence of a

possible kitchen in the Northwest area, responsible

for the crude oils found in Traditional Area of

Barinas.

� The two proposed source rocks in the study area

correspond to Quevedo and La Morita of Navay

Formation facies, according to this model (Mass

(b) Generation of hydrocarbons area in Miocene age

(a) Generation of hydrocarbons area in Eocene- Oligoc ene ages

C D EF

C D EF

(b) Generation of hydrocarbons area in Miocene age

(a) Generation of hydrocarbons area in Eocene- Oligoc ene ages

C D EF

C D EF

TOTAL GENERATED LIQUID HYDROCARBONS

(MIOCENE KITCHEN)

(Fm. Navay) : 5.035,51 MMBLS

ACUMULATED PRODUCTION : 735,16 MMBLS

REMAINING RESERVES : 1.002,22 MMBLS

RECOVERABLE RESERVES : 1.737,38 MMBLS

TOTAL POES: 4.027,03 MMBLS

0

200

400

600

800

1.000

1.200

1.400

BO

RB

UR

AT

A

CA

IPE

LAS

LO

MA

S

SIN

CO

TO

RU

NO

S

BE

JUC

AL

MA

PO

RA

L

ES

TE

RO

HA

TO

VIE

JO

PA

EZ

MIN

GO

PA

LMIT

A

SIL

VA

N

SIL

VE

ST

RE

OB

ISP

O

CAMPOS

MM

BLS

PROD. ACUM (MBLS)

RES. REMAN. (MMBLS)

POES (MMBLS)TOTAL GENERATED LIQUID HYDROCARBONS

(MIOCENE KITCHEN)

(Fm. Navay) : 5.035,51 MMBLS

ACUMULATED PRODUCTION : 735,16 MMBLS

REMAINING RESERVES : 1.002,22 MMBLS

RECOVERABLE RESERVES : 1.737,38 MMBLS

TOTAL POES: 4.027,03 MMBLS

0

200

400

600

800

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Generated HC LiquidKg/m 2

Generated HC LiquidKg/m 2

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6 ROJAS ILIANA

Balance), have a good capacity of generation to

provide enough volumes of oil to the structures and

prospects of Barinas.

� The migration vectors have a Northwest-Southeast

direction towards Barinas Basin.

� The petroleum system proposed in this study for the

Barinas area, is considered an active and efficient

system, due to the evidence of hydrocarbon presence

during drilling and evaluation of drilled wells in the

area.

Recommendations � Since the migration model appears to be very

sensitive to changes in porosity, permeability,

capillary pressure and reservoir pressure data, it is

recommended to incorporate to this study, new

drilling data when it is available, in order to gradually

improve approaches obtained from this study.

� To improve lithologic maps and characterization of

different faults in order to have a better estimation of

migration processes in the new 3D survey in the area.

� To characterize more effectively the risk of

occurrence of hydrocarbon exploration prospects

with the use of the basin modeling tool and

subsequent calibration with the geochemical

characterization of the crude oils present in the area.

� To do better estimation of the migration efficiency in

the basin, in order to assess the prospectivity

associated with the new proposal opportunities.

References � Audemard F. y Audemard F. A. (2002). “Structure of the

Mérida Andes, Venezuela: Relations with the South America–Caribbean Geodynamic Interaction”.

Tectonophysics, Volume 345, p. 299-327.

� Anka, Z., Callegon A., Hernandez V., Gallango O.,

Gonzalez A., Loureiro D., Lacey J., Thompson K., Elrod

L., (1998). “Geoquímica del Flanco Surandino”. Sector

Barinas – Portuguesa. Petróleos de Venezuela. Informe

interno.

� Connan J., and Cassou A. M., (1980). “Properties of gases and petroleum liquids derived from terrestrial kerogen at various maturation levels”. Geochimica et Cosmochimica

Acta, 44, pp. 1-23.

� González de Juana, C., J. M. De Iturralde y X. Picard C.,

(1980), “Geología de Venezuela y de sus Cuencas Petrolíferas”. Foninves, 2.V: Intevep Caracas.

� Meza, L., (1995). “Características Estratigráficas y Estructurales del Área Tradicional de Barinas y su Relación con las Acumulaciones de Hidrocarburos”.

� Lopéz L., Lo Monaco S. y Richardson M., (1998). “Use of molecular parameters and trace elements in oil – oil correlation studies”. Barinas sub-basin, Venezuela.

Organic Geochemistry, 29, pp.613 -629.

� Parnaud, et al., (1995). “Stratigraphic Synthesis of Western Venezuela”. AAPG. Memoria.

� Proyecto Re-Exploración Barinas, 2009. Informe Final.

� Stephan, J. (1997). “El Contacto Cadena Caribe-Andes Merideños entre Carora y El Tocuyo (Edo. Lara)”.

Ponencia Presentada en el V Congreso Geológico

Venezolano, Caracas: Colegio de Ingenieros de Venezuela.

p. 789-815.

� Schneider F., (2009). “Estudio integrado de los sistemas petroliferos de Venezuela Occidental”. Sintesis Version

4.0. Petróleos de Venezuela y Beicip Fralab. Informe

interno.

� Vipa, (2000). “Visión integrada del potencial petrolífero de Venezuela”. Petróleos de Venezuela, Informe interno.

Acknowledgments First let PDVSA-INTEVEP by presenting this work and to

Mr. Frederic Schneider for their assistance in the same