RESERVORIOS DIAPOSITIVAS

7/31/2019 RESERVORIOS DIAPOSITIVAS

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RESERVOIRI

PP-324 A


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rocks

Rocks continental Rocks marine

sediments

Sediments water

sweet

transport and

sedimentation

of particles

transport in

solution and

precipitation


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Igneous RocksAn igneous rock is a

rock that had melted(derriti) but it later

cooled and hardened

(endureci)

Metamorphic

Rocks Is an igneous o

sedimentary rock thahas been changed(alterada) by heat andpressure.


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Source Rock-A rock with abundant hydrocarbon-rone organic matter

Reservoir Rock -A rock in which oil and gasccumulates:

Porosity - space between rock grains in which oilaccumulates

Permeability - passage-ways between pores throughwhich oil and gas moves

Seal Rock -A rock through which oil and gas cannotmove effectively (such as mudstone and claystone)

Trap- The structural and stratigraphic configuration thatfocuses oil and gas into an accumulation

Migration Route - Avenues in rock through which oil andgas moves from source rock to trap

Petroleum System Elements


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Salt

Dome

Fault

Unconformi

ty

Pinchou

t

Anticline


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Porosity

i. Define: Porosity = Total pore volume in the rock sampleTotal rock sample volume (solid+pore)

ii. Mathematically:

iii. Range of porosity: 0.1 to 0.3

iv. Use reservoir core to measure porosity

v. Limitations

a. Rock sample must be large enough to obtain many sandgrains and many pores to be representative

b. Features sample has a different type of pore spacefrom sandstone

lV

V

Fluid Saturation

i. Water saturation, Sw = Volume filled by waterTotal pore volume

Oil saturation, So = Volume filled by oilTotal pore volume

ii. If oil and water is the only fluid present, Sw + So = 1

iii. In most oil fields Sw tends to increase as porosity decrease

iv. Typical value of Sw 0.1 to 0.5

v. Free gas also present in oil pools,

Free gas saturation, Sg = Volume filled by free gasTotal pore volume

vi. 3 factors should always be remembered conceiving fluidsaturation

a. It vary from place to place in reservoir rock; Sw highein less porous sections due to gravity segregation of thgas, oil and water


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Example

One of the most important determinations for anoil accumulation is the volume of oil in place.Suppose that in geological evidence is known thatthe area extent of an oil reservoir is 2 millionsqft and that the thickness of the bay zone is30 ft. If the sand porosity and water saturationare 0.2 and 0.3, respectively, how much oil ispresent?

Solution:

Volume of bay = 2,000,000 ft3 x 30 ft = 6x107ft3

Total pore volume = 0.2 x 6x107 = 12x106 ft3

Then Sw+So=1; So = 1 - 0.3 = 0.7

Total oil volume = 0.7 x 12x106 = 8.4x106 ft3


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b. Vary with cumulative withdrawal; oil producedreplace by water or gas

c. Oil and gas saturation frequently expressed interms of HC-filled pore space.

Pore space = V

HC-filled pore space: SoV + SgV = (1-Sw)V

Therefore,Oil saturations, Gas saturations,

w

o

w

oS

SVS

VSS

1)1(

0'

w

g

w

g

g S

S

VS

VSS

1)1(

'


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- MER (Most Efficient Recovery)i. MER rate: based on most oil and gas that

can extracted for a sustained period oftime without harming the formation

ii. Generally, most well cannot work 24 hrs, 7

days a week could damage formation

- Multiple Completions

i. Drilling single well at several differentdepth in formation

ii. Reason: increase production from a singlewell


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INJECTION GAS

PRODUCED FLUID

PRESSURE (PSI)

DEPTH(

FT

TVD)

1000

2000

3000

4000

5000

6000

7000

0

1000 20000

OPERATING GAS LIFT V

CASING PRESSURE WHEWELL IS BEING GAS LIFT

FBH

CONSTANT FLOW GAS LIF


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DISSOLVED GAS DRIVEDISSOLVED GAS DRIVE

GAS CAP DRIVEGAS CAP DRIVE

WATER DRIVE


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Sistema cerrado (un pozo)


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Field Production

.Primary Recovery (NaturalMethods)

i. 1st method of producing oil from awell

ii. Solution gas drive

a. pressure inside reservoir relievedwhen well punctures and gastrapped in oil forms bubbles

b. Bubbles grow, exert pressurepush oil to well and up to surface(20-30%)

iii. Gas cap drive

a. If contain gas cap, drill welldirectly into oil layer gas capexpand

b. Expanding gas pushes oil into well(40%)

iv. Water drive scenario

a. Water layer press against oil layer

b. Water pushes oil towards surfaceand replace it within the pores ofthe reservoir rock

c. Highest recovery: up to 75%


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2.Secondary Recovery

i. Used to enhance orreplace primary

techniquesii. Water flooding

a. Additional injectionwell is drilled into thereservoir

b. Pressure waterinjected

c. Water displaces the oilin reservoir

iii. Mechanical Lift

a. Reciprocating orplunger pumping calledhorsehead

b. Pump barrel loweredinto well on 6 inch

string steel rod(sucker rods)

c. Up and down movementforce oil up to tubing


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3. Tertiary Recovery

i. When 2nd recovery no longereffective

ii. Thermal Process

a. Steam Flooding steam injected,heats oil to flow readily

b. in-situ combustion (fire flooding) air injected, a portion if oilignited , combustion front moves

away from air injection welltoward production well

iii. CO2 injection

a. CO2 injected, mix with oil reduces forces that hold oil to

pores, allows easily displace byinjected water

iv. Chemical recovery

i. Inject polymer into water phaseof reservoir trap, large molecule

add bulk to water, waterthicken, wash oil from pores

ii. Sometimes surfactant added toreduce force water to solid


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4. Improvement of formationcharacteristic

i. To aid 3rd

recovery becauseproduction drop

ii. Acidizing

a. Injecting acid into a solubleformation (exp: carbonate) to

dissolve rocksb. Enlarge the existing voids and

increase permeability

iii. Hydraulic Fracturing

a. Inject a fluid into formation

under significant pressure toenlarge existing fracture andcreate new fracture

b. This fracture extend outwardfrom well bore into formationtherefore increasepermeability


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Petroleum ProductionSystem

. Petroleum hydrocarbon production

involve 2 districtsi. Reservoir a porous medium with a unique

storage and flow characteristic

ii. Artificial structures includes well, bottomhole, surface gathering, separation and

storage facilities

2. Production Engineering - attempts to maximizeproduction in a cost effective way

3. Appropriate production technology and methodrelated directly with other major area ofpetroleum engineering such as formulationevaluation, drilling and reservoir engineering

4. Petroleum Hydrocarbon

i. Mixture of many compounds petroleum

and natural gasii. Mixture depending on its composition and

conditions of P and T occur as liquid or gasor mixture of 2 phase


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4. Oil Gravity

i. Commonly expressed in degree API

ii. The terms heavy, medium and light crudecover approximately the ranges 10 to 20o, 20to 30o and over 30o API, respectively

5. Instantaneous Water/Oil Ratio (WOR)i. Homogeneous formation produce only oil and

water (no free gas) then

ii. The pressure drop in oil may differ slightlyfrom that in the water owing to effect ofcapillary forces, so dividing the equationsabove, results in

5.131

5.141

60

F

o

oSGAPI

dl

dPkq

o

oo

dl

dPkq

w

ww

wo

ow

o

w

k

k

q

q


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iii. At the surface

iv. Or from above equation

(surface)

Where Bo is oil formation volume factor:

v. Bo is defined as ratio of the volume of oil(plus the gas in solution) at reservoir T and Pto the volume of oil at standard conditions(so-called stock-tank oil)

o

wo

oo

w

q

qB

Bq

q

wo

owo

k

kBWOR


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6. Instantaneous Gas/Oil Ratio (GOR)

i. Homogeneous formation producing only oil andgas (no water production, although water maybe present in the formation)

ii. Where the pressure drop across the distancedl is the same for both fluid, if capillaryforces are neglected. Dividing

iii. Stock-tank oil rate will be qo/Bo, and surfacefree gas rate qg/Bg. In addition to free gasproduced from the formation, each barrel of

stock-tank oil will release a volume Rs of gas,then the total surface gas/oil ratio is

dl

dPkq

o

oo

dl

dPkq

g

g

g

go

og

o

g

k

k

q

q


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iv. At the surface

v. Therefore

(surface)

7. Productivity Index

i. Bottom hole flowing pressure - producingpressure (Pwf) at the bottom of the well

ii. The difference bettwen this and the well stati

pressure (Ps) is

og

os

oo

gg

sqB

qgBR

Bq

BqR

gog

ogo

skB

kBRGOR

wfs PPDrawdown


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iii. Ratio of producing rate of the well to itsdraw down is called Producing Index.

iv. If the rate q (bbl/day) of stock-tank liquidand draw down (psi), the productivity index

(J) is defined as

(bbl/day/psi)

iii. Productivity index is based on the gross liquidrate (oil rate + water rate)

iv. Specific productivity index, Js is the numberof barrel (gross) of stock-tank liquidproduced/day/psi/ft net thickness

wfs PP

qJ

)(wfs

sPPh

qhJJ


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Rock Permeability

i. Measurement of the fluid ability toflow through the connected pores ofthe reservoir.

ii. A function of a degree of

interconnection between pores in therock

iii. The concept was introduced by Darcyin a classical experimental work fromboth petroleum engineering and groundwater hydrology. Is expressed inmilidarcies or Darcies.

iv. The flow rate can be measured againstpressure (head) for different porousmedia

v. The flow rate of fluid thru specificporous medium is linearly proportionaltop head difference betwen the inlet

and outlet and characteristic propertyof the medium, thus u = kDP

Where k = permeability and is acharacteristic property of the porousmedium

vi. The rock permeability is measured from

core samples (plugs or whoke core) inthe laboratory or it could also becalculated from well testing


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a. Suppose a cylindrical sample (core) of a porousrock is fully saturated with liquid of viscosity.

b. Experimentally for a particular rock samplethe expression

DarcyEquation

where k is constant

c. Q will increase a k increases, the higher thevalue of k the more readily will liquid flowthrough the core

l

A

Q

P

1P

2

)(21PPA

lQ

k


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d. If in flow rate contain two fluid (oil andwater), free gas is not present then,

d. If Q (cm3/s), (cp), l (cm) A (cm2), and P1 andP2 (atm), the value of k in Darcy is

1 Darcy = 10-8 cm2

)(21PPAlQk ooo

)(21PPA

lQk www


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NUCLEOS PRESERVADOS


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PERFIL DE RADIACION

GAMMA

Objetivo: Puesta enprofundidad.

Gamma Total

Gamma espectral


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Equipo de Gamma


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Equipode

Gamma


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Equipo de Gamma


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Puesta en Profundidad

0

20

40

60

80

100

120

140

160

180

200

940 945 950 955 960 965 970 975 980

Profundidad (mbbp)

Gamma(API)

GR Pozo Gamma Corona


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PLAN DE TRABAJO

Considerar:

Objetivo del trabajo

Recuperacin y estado del

ncleo

Urgencia de datos

En ncleos preservados ver

estado de preservacin y estado

de la muestra (necesidad defreezar el ncleo)


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MANIPULEO DE NUCLEOS

EN LABORATORIO

Marcar encastres

Marcar techo y base general, ytecho y base de cada metro

Marcar lnea que una puntos de

mayor inclinacin de las capas,lnea azul o verde. Marcar lnea

roja a la derecha

Numerar trozos


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MANIPULEO DE NUCLEOS

EN LABORATORIO

Estimacin y localizacin de

tramos de mala recuperacin Marcar profundidad cada 50 cm

Marcar ubicacin de plugs y

numerar. Duplicacin de nmeros de

trozos y encastres.

Planilla de pozo


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Marcado de lneas de

orientacin


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Marcado de lneas de

orientacin


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Numeracin de trozos


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LABORATO

RIO


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PLANILLA DE CONTROL


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EXTRACCION DE PLUGS

De acuerdo al plan de trabajo:

Seleccionar plenos dimetros

Seleccionar intervalo de

muestreo

Duplicacin de plugs

Preservacin de plugs


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PLENO DIAMETRO


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PLENO DIAMETRO


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EXTRACCION DE PLUGS

DE PLENO DIAMETRO

Con isopar

Con agua de formacin

Con nitrgeno lquido

Con aire

Dimetro: 38 mm 25 mm

Longitud: 1.5 cm-6cm Ideal:

6cm.


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EXTRACC

ION DE

PLUGS


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EXTRACCI

ON DEPLUGS


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EXTRACCI

ON DE

PLUGS


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EXTRACCIO

N DE PLUGS


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FRENTEADO DEL PLUG


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FRENTEADO DE PLUG


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FRENTEADO DE PLUG


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FRENTEA

DO DEPLUG


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CORTE Y PULIDO

Remarcar lneas de orientacin

y nmero de trozo si esnecesario.

Cortar longitudinalmente un

tercio del dimetro total porlnea azul/verde.

Corte: con agua, isopar,

nitrgeno lquido, aire.


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CORTE DE

NUCLEO


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CORTAD

ORA


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CARACTERISTICAS DE

ROCAS RESERVORIO

-Porosidad-Permeabilidad


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POROSIDAD

-Es una medida que indica la relacin entre elespacio poral de la roca reservorio y elvolumen total de la roca reservorio.-Se expresa en porcentaje.


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Arenas consolidadas


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PERMEABILIDAD

Es una medida que indica la facilidad deun fluido a fluir en una roca porosa.

La unidad que la representa es elDarcy.


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FLUIDOS DELRESERVORIO


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Fluidos

en el reservorio

Gas

PetrleoAgua


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Petrleo

Densidad (API)

Gradiente (psi / ft)

Viscosidad (cp)

Factor de volmen de formacin(Bo)

Temperatura (F)


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Agua de formacin

Corte de agua (%)

Salinidad (ppm Cl)


Viscosidad (cp)Factor de volmen de formacin

(Bw)

Temperatura (F)


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Gas Natural

Composicin

Relacin Gas Petrleo (GOR)


Factor de volmen de formacin(Bg)

Temperatura (F)


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Formacion productiva

-Son aquellas rocas reservorio

que mantienen fludos

hidrocarburos entrampados ensu interior.


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Trampa para petrleo y

gas

Condiciones.-

Roca fuente.

Porosidad y permeabilidad.

Tope y fondo con roca impermeable.


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Tipos de reservorio

-Reservorio de arenisca

-Reservorio de caliza


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Porosity Determination from Logs Porosity Determination from LogsMost log interpretation techniques in use todayuse a bulk volume rock approachQuantitative rock data must be input into equations toderive values of phi and Sw. For example:Db = x Df + (1 - ) Dm

Porosity is then derived: = (Dma - Db)/(Dma - Df)

Values of matrix density are normally assumed:Dma = 2.65 for clean sand

= 2.68 for limy sands or sandy limes

= 2.71 for limestone

= 2.87 for dolomite

Fluid density is that of the mud filtrate:

Df = 1.0 (fresh)= 1.0 = 0.73N (salt)

Where: N = NaCl concentration, ppm x 10-6

Accurate knowledgeof grain density isessential


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Porosity at Net Overburden (NOB)

Increase in NOB can reduce porosity. Generallythe reduction is 3.0gm/cc dolomite2.32gm/cc -- gypsum2.96gm/cc -- anhydrite3.89gm/cc -- siderite

Accurate values of grain density are importantbecause grain density is used to correct wirelinelogs for potential sources of error

Fluid Saturations from CoresThrough knowledge of porosity, permeability

and residual fluid saturations (oil, water and

gas), it is possible to predict with a highdegree of accuracy the probable type of fluid

which will be produced from a given interval.

Review of the core fluorescence can also be

an indicator of oil gravity and should be

factored when type of production is predicted.

DATA USE


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se of Routine Core Data of Routine Core Dataaboratory measurements of routine coreoperties (phi, k, saturation) are commonly usedr the following purposes:

to define pay,

to interpret gas/oil and oil/water contacts,to estimate rate of production,to determine storage capacity and evaluate verticalsweep efficiency by secondary and tertiary recoverymethods

Wettability : Definitions :Water Wet the water phase is preferentially attracted to

the surfaces of the grains and water occupies most of thesmall pores. Common in sandstones, especially those thatcontain some shale

Oil Wet the oil phase is preferentially attracted to the grainsurfaces and the oil occupies most of the small pores. Canoccur in carbonates (particularly those with abundant smallpores) and in some very clean (shale-free) sandstones

Neutral Wet no preference for either water or oilFractional Wettability certain areas of the rock are oil wet,

others are water wet due to mineralogical changes or tochanges in adsorption of the oil

Mixed Wettability the larger pores contain oil (oil wet) andthe smaller pores contain water (water wet). Common in

carbonate reservoirs with heterogeneous pore geometryFormations generally increase in their degree of water

wetness above 200C


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Capillary Pressure (1)Capillary pressure exists in a hydrocarbon reservoirfundamentally because of differences in the density ofvarious fluids that affect the pressure gradients:

Pressure gradient of water = 0.44 psi/ft (density =1gm/cc)Pressure gradient of oil = 0.33 psi/ft (density =0.8gm/cc)*Pressure gradient of gas = 0.09 psi/ft (density =0.2gm/cc)*** 30O API** 5000psi

As hydrocarbons accumulate in a trap, the difference indensity between the fluids results in a vertical segregationof the fluids: gas on oil, oil on waterFor example, at 10,000ft, oil pressure = 3300 psi andwater pressure = 4400 psi


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Capillary Pressure

Capillary pressure in reservoirs can be defined asthe difference between the force actingdownwards (hydrostatic head, related to density

contrasts) and the force acting upwards(buoyancy, related to pore throat size, interfacialtension and contact angle)

Capillary pressure is measured in the laboratorygenerally using plug samples or rotary sidewallcores. Occasionally cuttings samples are usedIn the most common type of test, a non-wetting

phase fluid (e.g. mercury) is injected into the rockat slowly increasing values of pressure. Theamount of fluid injected at each increment ofpressure is recorded and is presented as acapillary curve


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Capillary Pressure andWater Saturation (2)Reservoir Sw decreases with increasing heightabove the free water level (the level at which thereservoir produces only water)Zones that are at irreducible water saturation

(Swirr) produce only hydrocarbons. Swirr occurswhere sufficient closure and hydrocarbon columnexistThe transition zone occurs between the free waterlevel and the Swirr level. Formations in this zoneproduce water and hydrocarbonsThe magnitude of the Swirr and the thickness ofthe transition zone are a function of the pore size

distributionSmall pore throats = low permeability = high Swirr


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Initial Reservoir Fluid Distribution

The amount of Sw at any height in the reservoir isa function of:Pore throat size, wettability, interfacial tension,saturation history and differences in fluid densitiesThese variables control capillary pressure,therefore there is a relationship between Sw, h,Pc and pore throat sizeLaboratory measurements of capillary pressure

are used to relate Sw to height above the freewater level as long as appropriate values oflaboratory and reservoir interfacial tension andcontact angle are usedLaboratory tests can be made with different fluidsoil, brine, mercury


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Capillary Pressure: :

Static MeasurementStatic Method Mercury injectionWidely used, rapid, economic and simple. Mercury isthe non-wetting phase and is injected into a cleaned andevacuated core plug at successively increasingpressures from 0 to 60,000psiThe core plug cannot be used for further testingbecause of residual Hg saturation

Hg capillary pressure data must be scaled to reservoirconditions using the following formula:

. Conversion factor= Mercury Pc = Sm Cos mWater-Air Pc Sw Cos wWhere:

Sm = surface tension of mercury

Sw = surface tension of water

m = contact angle of mercury against a solid (140 degrees)

w = contact angle of water against a solid (0 degrees)


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Capillary Pressure:Dynamic MeasurementDynamic Method -- CentrifugeGenerally uses oil-brine fluid system but actualreservoir fluids can also be usedRapid, more complicated and more expensive than

mercury Pc measurementsRequires preserved or restored-state core plugsLarge (2 inch) plugs are required. These can be used forfurther analysisBrine saturated samples are centrifuged at everincreasing speeds under oil to obtain a relationshipbetween capillary pressure and saturation

Capillary Pressure: Rock ControlsPore geometry is a fundamental control oncapillary pressure, in particular the size of thepore throats: the capillary pressurecharacteristics change with changes in RockType (pore geometry)In heterogeneous reservoirs, it is essential to

collect capillary pressure data for each RockType that is present in the reservoirAll other factors being equal, the lower thepermeability the smaller the pore throats thehigher the Pce and the higher the SwirrCapillary pressure data is used to determine theheight above free water (column height) for eachRock Type and to improve the prediction of the

type of fluid produced (hydrocarbon/water)


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Use of Pc in Reservoir Simulationand Reservoir CharacterizationFor purposes of simulation and characterization, it isnecessary to know the Free Water Level (FWL)When FWL is known it is possible to predict Sw at anyheight in the reservoir even in areas that lack wellpenetrationsThis is particularly important in the following cases:Areas with long transition zones and no obvious FWLAreas with misidentified or unknown FWLAreas with unknown or incorrect Rw

Areas where a, m and/or n are incorrect or unknownAreas with multiple Rock Types (where a, m,n and Swvary as a function of Rock Type)In these situations, it is possible to solve for Sw usingeither the Pc curves or the Leverett J Function.


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Clculo de Reservas de

Petrleo y Gas


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Definicin de Reservas

Petrleo crudo

Gas: Gas Natural, Gas

condensado

Lquidos del Gas Natural

Sustancias asociadas


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Estimacin de Reservas

Basados en:

Interpretacin de Datos de

Ingeniera y/o Geologa

disponibles a la fecha. Condiciones econmicas

existentes como precios , costos

y mercado.


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RESERVAS FACTIBLES DE

RECUPERAR

ENERGIA NATURAL(RECUPERACION PRIMARIA)

METODOS DE RECUPERACION

MEJORADA


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Los Clculos de Reservas se pueden

realizar:

Mtodos Volumtricos

Balance de materiales

Anlisis de Curva deDeclinacin

Simulacin de Reservorios


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Mtodo Volumetrico

Mapa de curvas de nivel de

la zona productiva (arena net

productiva).

Se emplean dos mtodos para

determinar el volumen bruto:

Trapezoidal V = h*( 0.5*A0 + A1+A2+A3+0.5*A4

Piramidal V = h (A0 + 4*A1+2*A2+4*A3+A4)3


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Mtodo Volumtrico - Reservorios

de Petrleo

Para el clculo de petrleo insitu:

N = 7758*V**(1-Swi) / Boi

STBPara el petrleo remanente:

Nf = 7758*V**(1-Swg) /

Bo

Nf = 7758*V**(1-Sw -

Sg) / BoEl Factor de recobro F.R. :F.R. = Np/N = 1 - Nf/N

V = Volumen bruto en Acres*ft

= Porosidad en fraccin

Swi = Saturacin inicial de agua FraccinBoi= Factor de volumen de formacin de petrleo inicial

Bo = factor de volumen de formacin de petrleo final


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Mtodo Volumtrico -

Reservorios de Gas

Para el clculo de gas insitu:G = 43560*V**(1-Swi) / BgiSCF

Para el gas remanente:

Ga = 43560*V**(Sgr) / Bga

El Factor de recobro F.R. :

F.R. = Gp/G =(Bga-Bgi)/Bgi


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Mtodo Volumtrico - Reservorios de Gas

Condensado

Mtodo 1.o = 141.5 / (131.5 + API)

Mo= 6084/(API-5.9)

mw = R g 28.97 + 350 o

379

nw = R + 350 o

379 MoMw = 0.07636 Rg + 350 o

0.002636 R + 350 o

Mo

w = Mw/28.97=Rg + 4584 o

R + 132800o

Mo

Encontramos la Tr y Pr yluego el valor de Z luego

determinamos:

Gw = 379 PV/ ZRT

V = 43560 AH (1-Swi)

R = 10.73 Psia-ft3 / lb-mol R

Fraccin de gas:

fg = R /(R + 132800o/Mo

Cantidad de gas:

G = Gw* fg

Cantidad de lquidos

N = Gw fg/R


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Mtodo Volumtrico - Reservorios de Gas

Condensado

Mtodo 2.avg gas prod. = gt ;

gt = qpsps + qstst

qps +qstConociendo STB

ond./MMSCF y

tilizando una grfica

esarrollada por Standing

odemos determinar una

elacin (R)= u/gt ymediante la correlacin

mprica desarrollada por

tanding podemos

ncontrar Bo para

eservorio deondensado.

Existe una grfica de Bo esfuncin de:

R SCF/STB, gt , st ,

Temperatura reserv.

P reservorio ,

a altas relaciones gas/petrCantidad de lquidos

N = 7758Ah (1-Swi)/ B

Cantidad de gas :

G = Rsi* N


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Anlisis de Curvas de declinacin

Aplicaciones Mecanismo PLOT

Hiperblico Gas Solucin log (Np) vs log (q)

Exponencial Gas Solucin Np vs q

Intrusion agua con

corte agua = 0Np vs q

2

Lineal Intrusion agua con

corte agua 0Np vs corte (petroleo/agua)

Exponencial Intrusion agua, donde

produccion de fluido

total permanece cte.

Np vs q

Armnica Intrusin de agua de flanco Np vs q

Lineal Impulsin capa gas

con bajo GOR,

gas solucion = 0

Np vs 1/p

Hiperblico

Impulsin capa gas

con bajo GOR bajo

gas en solucin

log (Np) vs log (q) b = 2,0

Impulsin capa gas

despues que GOC alcance

a los pozos productores

Np vs GOR

Np vs Profundidad del GOC


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Ecuacin de Balance de Materiales -

Reservoriosde Gas

Para el clculo tenemos:masa inicial- masa final final = masa

removida

ni - nf= n producido del reservorio

iVi/ziRT - PfVf/zfRT = PscGp/RTscVf= Vi - We + WpBwGBgi -(G -Gp) Bgf= We + WpBwReservorio volumtrico, no hay

ntrusin de agua entonces Vi=Vf

f/zf= Pi/zi - Psc TGp/Tsc = b - m Gp

P/z

Gp

MMM SC

Gi

Pi/zi


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Reservoriosde Petrleo

Reservorios No saturado, produccin

erca al punto de Burbuja no hay intrusin

e agua, Compresibilidad de la formacin

agua=0

Vi = Vf ; Vi = N Boi ;

Vf = Nf Bof= (N - Np) Bof

Luego: N Boi = (N - Np) BofN = Np Bof/ (Bof- Boi )

.R. = (Bof- Boi )/ Bof

PETROLEO PETROLEO

AGUA AGUA

Pi Pb


cerca al punto de Burbuja no hay intrusinagua , si efectos compresibilidades

Cf +w = Cf+CwSwi/ (1-Swi)

N = Np Bof / (Bof - Boi (1- Cw+fDP))

F.R. = Bof - Boi (1- Cw+fDP)/ Bof


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Reservorios

de Petrleo


ebajo al punto de Burbuja no hay

ntrusin de agua

Vi = Vf= Vo + Vg;N Boi = (N - Np) Bof + GfBgf

f = Nrsi - (N-Np)Rs - NpRp siendo Rp = Gp/Np

N = Np [Bof+ Bg (Rp- Rs)]/ [Bof- Boi + Bg(Rsi-Rs)]

.R.= [Bof- Boi + Bg(Rsi-Rs)]/ [ Bof+ Bg (Rp- Rs)]i hay intrusin de agua:

Vi = Vf= Vo + Vg+ Vw

Vw = We-BwWp

N ={ Np [Bof+ Bg (Rp- Rs)]- (We-BwWp)}/ [Bof- Boi + Bg

PETROLEO PETROLEO

AGUA AGUA

Pi Pf

GAS

Pb


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Reservorios

de Petrleo


ebajo al punto de Burbuja no hay

ntrusin de agua, considerando la

xpansin del volumen poroso

N = Np [Bof+ Bg (Rp- Rs)]/ [Bof- Boi + Bg(Rsi-Rs) + Cf+w.R.= [Bof- Boi + Bg(Rsi-Rs) + Cf+w BoiDP ]/ [ Bof+ Bg

PETROLEO PETROLEO

AGUA AGUA

Pi Pf

GAS

Pb


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Reservorios

de Petrleo

Reservorios saturado, produccinebajo al punto de Burbuja , intrusin

e agua, considerando la

xpansin del volumen poroso

m= Vgli

/Voi

Vi = Vf= Vo + Vgd + Vgl + Vw;

Vgl = m N Boi [Bg - Bgi] / Bgi

= Np [Bof + Bg (Rp- Rs) - (We-BwWp) ]/ [Bof - Boi + Bg(Rsi-Rs) + m Boi [B

PETROLEO PETROLEO

AGUA AGUA

Pi Pf

GAS

Pb

Intrusin de agua.

GAS


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Simulacin de Reservorios

Fundamentalmente se basa en los principios fsicos de

conservacin de masa, flujo de fluido y la conservacin

de energa.

Contiene un juego de ecuaciones que permiten describir

el comportamiento de los fluidos en un reservorio.

Los tipos de simuladores existentes: Black Oil ,Composicional, Recuperacin Mejorada entre otros..

Es un estudio planeado y organizado para obtener

buenos resultados, teniendo en consideracin:

Geometra del reservorio

Propiedades de roca y fluido

Pruebas de presinDatos de produccin y completacin

Diseo del modelo del reservorio

Inicializacin del modelo del reservorio.

Anlisis de sensibilidad del modelo

Ajuste de historia

Performance del reservorio


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RESERVORIOS DIAPOSITIVAS

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