8/18/2019 SPEr Conducting COR Lab Study
1/12
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est Praawaz M. Al-assi F. Al-Q
opyright 2012, Societ
his paper was prepare
his paper was selecteviewed by the Societ
fficers, or members.produce in print is res
bstractEnergy delimate changeerfect storm f
f this green h
or EOR or se
ery efficient
To designeservoir/fluid
ome thought
omprehensiveThe essenti
teractions. Fl
roperties of
ock interactioermeability, c
light of their
ntroductionEOR (tertia
re many appl
articular reser hermal EOR
OR methods
The best
equestration,welling, and l
e reservoir pterface and h
rocess of enh
The term “ixed in any
riginal fluids.
immiscible.”iscible fluids
ith the reser
ultiple-conta
termediate cy condensing
26
tices fotaibi, SPE,
htani, SPE,
of Petroleum Engine
d for presentation at t
d for presentation byy of Petroleum Enginelectronic reproductiotricted to an abstract
and has been
has the worlor the use of c
use gas. Each
uestration. T
echanism for
CO2-EOR orsystem. Wher
nd effort. A s
experimentalal components
uid-fluid stud
O2-oil or CO
studies typiritical gas satu
best practice.
ry recovery) ied EOR tech
voir dependsmethods invol
nd it involves
as for injecti
nd higher oilwering oil vi
ressure, displence the inter
nced oil reco
iscibility” isroportion. A
If an interfa
n petroleum r . They form a
oir oil can be
t or dynamic
mponents frothe intermedia
Conducaad M. Al-Maudi Aramc
ers
he SPE EOR Confere
n SPE program comers and are subject to, distribution, or storaf not more than 300 w
escalating an
abuzz on tharbon dioxide
oil company (
e injection of
increasing oil
CO2 sequestr does one sta
earch of the lit
design for con of a laborator
es include mi
-brine mixtur
ally include cration, gas tra
The ultimate g
s a process toiques includi
n a number ove the injectio
the injection
on is CO2 fo
recoveries. Ccosity. The in
cing the oil,facial forces, i
ery by gas inj
referred to the important co
ce is formed
eservoirs, CO2single phase
made miscib
iscibility. Th
reservoir oiltes from the in
ting CO2utairi, SPE,
ce at Oil and Gas We
ittee following reviewcorrection by the aut
ge of any part of thisords; illustrations ma
is predicted
primary greefor enhanced
and others) ha
CO2 into a re
recovery.
tion project, ot? Even if the
erature reveal
ducting a CO2 study for C
scible displac
s including v
oreflooding te ping and wett
oal is to establ
recover the oilg thermal, g
f factors. Then of heat and
f gases such a
r several rea
O2 increasescrease in reco
and by elimint is possible t
ction, it is firs
ability of twosideration in
at some prop
that is miscibith the reserv
e (for certain
is process can
) or the conde jected solvent
EOR Launil L. Kokal
st Asia held in Muscat
of information containhor(s). The material d paper without the w not be copied. The a
to increase fu
n house gas,oil recovery.
s therefore ste
servoir is not
ne requires adata have to
no best pract
laboratory stu
2 injection inc
ment tests,
scosity and d
sts for determability change
ish a procedu
left behind as injection, c
screening critare the most
s CO2, N2 or h
ons: lower
il recovery tery by CO2 in
ating the inteo theoretically
t necessary to
or more fluidmiscible proc
ortion of one
le with the reoir fluid. An i
compositions
be either the
nsing gas drivinto the oil).
Studyl, SPE, Jame
, Oman, 16–18 April 2
ed in an abstract suboes not necessarily r ritten consent of thestract must contain c
rther in the co
carbon dioxidhe petroleum
ped up its eff
new. Indeed
arge set of ap be generated i
ices for gener
dy.lude measurin
easurement o
ensity, asphal
ining the oils. Each of the
e for generati
ter primary ahemical, etc.
eria is mostlycommon. Gas
ydrocarbons.
iscibility pre
rough its fav jection is also
rface between recover most
understand th
s (CO2 and oiesses is the el
fluid in the
ervoir fluid i jection gas (
only) with th
aporizing gas
e (the reservoi
s J. Funk, S
012.
mitted by the author(sflect any position of t
Society of Petroleumonspicuous acknowled
ming decades
. Both of theindustry is id
orts in carbon
O2 injection
propriate expen a service la
ating this data
g fluid-fluid i
f minimum m
ene precipitat
ecovery potee sets of expe
g a reliable a
d secondary r Selecting an a
based on theinjection is o
ssures, better
rable propertiattained by m
the oil andof the oil in
concepts of
) to form a siimination of t
other, then t
any proportiO2) which is
e reservoir oil
drive (CO2 c
r oil at the mi
E and
. Contents of the paphe Society of PetroleuEngineers is prohibitegment of SPE copyrig
. The dialogu
e factors havally suited fo
dioxide utiliza
as established
rimental data, a good desi
et. This paper
teractions and
scibility pres
on, and swell
tial, three-phiments will b
d accurate dat
ecovery meth ppropriate m
luid and rocke of the most
solvent prop
es includingaintaining (or
O2. By elimilace. To und
iscibility.
gle phase whhe interface b
e fluids are
n are called finot first-conta
by a process
n extract or v
xing front is
r have not beenm Engineers, itsd. Permission toht.
on global
e created adisposing
tion, either
itself as a
for a givenn requires
presents a
fluid-rock
ures, fluid
ing. Fluid-
se relativedescribed
aset.
ds. Therethod for a
properties. promising
rties, CO2
iscibility,ncreasing)
nating thiserstand the
en they areetween the
considered
rst-contactct miscible
known as
aporize the
ade richer
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2 SPE 151126
CO2-EOR is a well-known method that has been applied in the field extensively. The initial pilots were conducted in the
US in the late 1940s. The first full scale immiscible carbon dioxide flooding process was conducted in Bartlesville in
Oklahoma in 1958 (Dyer and Farouq, 1989). The first pure carbon dioxide gas injection was conducted in the Ritchie field ofsouthern Arkansas in 1969 (Khatib and Earlougher, 1981). Today, most of the CO2-EOR commercial projects are located in
the Permian Basin of west Texas. CO2-EOR has added increasing amounts of oil production capacity in the US (Jarrell et al.,
2002). The American Petroleum Institute stated that the oil and gas industry has over 35 years of continuously developing
experience in transporting and injecting CO2 for enhanced oil recovery (EOR). CO2-EOR is now being commercially
exploited in the rest of the world including Canada, Europe, Asia, Middle East and the Far East. Immiscible carbon dioxideflooding has been conducted in the Bati Raman in Turkey in 1980 (Khatib and Earlougher 1981, Karaoguz et al. 1989, Sahin
et al. 2007). This project is considered one of the most successful EOR applications in the history for heavy oil fracturedcarbonate reservoirs. In recent years, a lot of interest in CO2 injection is stemming from the CO2 sequestration in reservoirs.
Due to the recent interest in CO2 from environmental issues, the interest in CO2-EOR has grown substantially. CO2-EOR
is being field tested around the world. There are numerous pilots and commercial field projects either in the implementation
phase or on the drawing board. Many other companies are contemplating CO2-EOR. Before a further decision can be madeon whether to apply it in field or not, generally some laboratory experiments are needed to be done. The lab experiments or
studies generally cover fluid-fluid and fluid-rock interactions. To generate a reliable and accurate CO2-EOR dataset we have
to establish a procedure for conducting such lab studies. A complete set of data for a CO2-EOR lab study includes MMP
measurements, fluid properties of CO2-oil mixtures, asphaltene precipitation, swelling, oil recovery potential, three-phase
relative permeability, critical gas saturation, gas trapping and wettability changes. These data are critical input for anyreservoir simulation that follows the initial laboratory study to evaluate the feasibility of the process for a given reservoir.
Experimental StudiesTwo sets of experimental studies need to be conducted for any given CO2-EOR prospect: fluid-fluid and fluid-rock
interactions. Fluid-fluid studies involve the oil and CO2 interactions while fluid-rock studies involve reservoir fluids and rock
samples. The first and perhaps the most important step towards getting accurate and reliable experimental data is acquiring
representative samples. The representative fluid sample for a CO2-EOR study is generally a recombined sample of the pressurized separator gas and liquid samples targeting the average fluid composition of the original well stream. The other
important parameters in the experimental study are procedures, and calibrated and reliable instruments. These will be
discussed under each laboratory experiment. Specific experiments that are generally conducted in any CO2-EOR studies
involve minimum miscibility pressure (MMP) measurements, fluid properties of CO2-oil mixtures, asphaltene precipitation,swelling, oil recovery potential, three-phase relative permeabilities, critical gas saturation, gas trapping and wettability
changes. These will be discussed in the following sections.
Fluid-Fluid Interactions
An understanding of reservoir oil and CO2 interactions is perhaps the most important for any CO2-EOR project. Itinvolves the measurement of miscibility of CO2 with the reservoir oil, PVT phase behavior, swelling, enrichment, reduction
in viscosity and mixing. Another important aspect of these interactions is the precipitation of asphaltenes from live crude oil
when it comes in contact with CO2. Fluid-fluid interactions should also include reservoir brine and CO2 behaviors. Thesemeasurements and procedures to measure them are outlined below, and should constitute an important part of any CO2-EOR
laboratory study.
MMP Measurements:
MMP is an important parameter for the design of gas injection-EOR processes and is defined as the lowest pressure at
which a gas can develop miscibility, through a multicontact process, with reservoir oil at reservoir conditions. When theMMP is above the reservoir pressure, the gas injection flood will be immiscible with generally lower ultimate oil recoveries.
Conversely, when the MMP is below the reservoir pressure, the gas flood will be miscible with higher oil recoveries.
Miscibility can be achieved through a vaporizing process, a condensing process, or a combined vaporizing-condensing
process. The MMP can be obtained experimentally either by the slim tube system (Danesh, 1998), a rising bubble apparatusor through the use of correlations. The gold standard for MMP measurement in the industry is the slim tube apparatus. Aschematic representation of the slim tube apparatus is given in Fig. 1. The tubing is tightly packed with glass beads and
coiled to give a certain permeability and porosity. The specifications for slim tube are rather stringent and are provided
elsewhere (Elsharkawy, Suez, Poettmann and Christiansen, 1992).
8/18/2019 SPEr Conducting COR Lab Study
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ps
c
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r
sc
ta
a
i
pt
PE 151126
The proce
ressurized totabilization, t
epending on t
onstant flow
ensor. The ga
ell at the outlixture after
onstant flow
equiring 3-4
hrinkage factompared to th
olume of gas,
e cumulativere calculated.
ppropriate for
lass over the
These steps
miscible reg
ressure. Frome effluent str
ure for MM
the desired te slim tube i
he slim tube v
ate (6-8 cc/hr
is measured
t of the slimil passes thro
rate (10-20 c
V of toluene.
r is calculatee volumes and
oil density, s
gas injected (The ultimate
mation volum
ntire injection
Fi
Fig
are repeated
ion). The perc
this plot (Fig
am.
measuremen
est pressure.flooded with
olumes and sp
). The effluen
sing a contin
ube periodicaugh the visua
c/hr). Sufficie
The amount
d from the d density at 60o
stem pressur
PV), cumulaoil recovery
e factor. An e
history. Bubb
gure 2: Cum
re 3: Bubbl
or at least six
ent oil recover 4) the MMP
Figure 1: S
t includes the
The oven istwo pore vol
ecification).
oil is collect
ous gasomete
ly. An onlinecell. The re
nt quantities
of extracted
nsity of theF. The format
and temperat
tive oil recovet 1.2 PV inje
ample plot is
les are general
ulative CO2
es are gene
est pressures
y calculated a
s estimated as
VisualCell
im Tube Ap
following st
then heatedmes (PVs) o
fter stabilizati
d in a burett
. A digital ca
densitometeraining oil in
of toluene ar
il in toluene
live oil meason volume fa
ure are record
red (%PV), dcted gas is c
shown in Fig.
ly observed in
injected ver
ally observ
t the given re
1.2 PV of C
the point of
paratus
eps. The slim
nd set to thf live reservoi
on, the slim t
where it is c
era takes pic
continuouslythe slim tub
injected unt
s measured u
red at test ptor is also cal
ed periodicall
nsity of prodlculated from 2. The prese
an immiscibl
us oil reco
d in an imm
servoir temper
2 injected at
iscontinuity,
tube is first
desired reser oil at a cons
be is flooded
ontinuously
ures of the oil
easures theis extracted
l the effluent
sing UV spect
essure and r culated accord
during gas f
ced oil and c the measure
ce of bubbles
case (Fig. 3).
ery (%PV)
iscible case
ature (three in
ach pressure i
s well as the
filled with t
voir temperatant flow rate
ith 1.2 PVs
easured using
passing throu
ensity of the by flooding t
becomes cle
roscopy techn
servoir tempeingly. The vol
ooding. From
mulative GO oil collected
is monitored i
miscible and
s plotted as a
bservation of
3
luene and
ure. After(2-4 cc/hr
f CO2 at a
an optical
gh a visual
ffluent oilluene at a
ar, usually
iques. The
rature andume of oil,
these data
producedand using
n the sight
hree in the
function of
bubbles in
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4
i
b
p
c
a
t
c
r
t
t
pi
s
p
t
t
s
s mentioned
eveloped in ts a flat glass t
etter viewing
aporizing anreparation ti
ompletely plu
nd Christians
welling and
Slim tube tning an equa
ells at differe
eservoir oil a
ests is general
e change in oiscosity, oil s
erformed in ato a cell at 5
ample is mea
ressure, relati
e volume at
o target a desiolume, gas-oi
ixtures (usua
welling data i
before, the M
e early 1980s. be mounted v
of bubbles ri
condensinge), while the
g slim tubes,
n, 1992). The
luid Propert
sts do not proion of state.
t injected gas
d the swellin
y referred as t
il propertieswelling in th
high pressure00 psig (shou
sured at thes
e volume, an
ach step is re
ed mole% ofl-ratio, and li
ly 10, 20, 40
plotted in Fi
Figure 4: Ult
P can be als
A partial floertically in a h
ing in opaque
systems thanslim tube ta
hereas such p
e is no recove
Figure 5:
es of CO2-Oi
vide phase beo generate the
reservoir oil
of the oil, de
he swelling or
hen it is mixe reservoir, c
-high temperald be higher t
conditions.
liquid densit
orded. The fi
injected gas inuid density f
and 60 mole. 7.
imate oil re
o obtained ex
sheet for theigh pressure s
oils. The RB
the slim tubekes one to t
recipitation is
y data or flui
chematic o
Mixtures:
avior and fluise data experi
ixture ratios.
nsity and visc
solubility test
d with the injange in satur
ure PVT winan the reserv
constant co
for the origi
st oil-injected
the mixture.r the oil-inje
injected gas)
overy at dif
erimentally b
BA appears iight gage in a
A is a consid
. The RBA to weeks per
only a minor
samples avail
f the Rising-
d property datental simula
During these t
osity of the m
s. The objecti
cted gas in teation pressure
owed cell. Air pressure) a
position exp
al oil. In the
gas mixture i
gain a CCE icted gas mixt
. A typical C
erent test p
y using a risi
n (Fig. 5). Thtemperature c
rably faster
kes 1-2 hour MMP deter
indrance in t
able during a
Bubble App
a needed for cion is often c
ests, a fixed a
ixture, and co
e of conducti
rms of reducti and change
known volumd heated to r
ansion (CCE)
CCE experim
prepared by
s performed tore. This test
E plot for di
ressures
g bubble app
most essentiantrolled bath.
eans of meas
s per MMPination. Asp
e RBA. (Elsh
RBA test.
aratus
ompositionalnducted in a
ount of the i
mpositions ar
g these tests i
on in reservoiin GOR. A s
e of reservoirservoir tempe
is performed
nt, the pressu
dding a certai
determine satis repeated se
ferent mixture
ratus, or RB
l feature of th The glass tub
uring the MM
eterminationaltene precip
rkawy, Suez,
imulation, esatch mode in
jected gas is
measured. T
s to observe a
oil density, r elling test i
fluid (~40 cc)rature. The de
to determine
e is reduced i
n amount of i
uration pressuveral times f
s is shown in
PE 151126
, that was
apparatuse is flat for
P for both
(excludingtation can
Poettmann
ecially forstatic PVT
ixed with
is suite of
d measure
duction ingenerally
is chargednsity of oil
saturation
steps and
jected gas
re, relativer differentFig. 6 and
8/18/2019 SPEr Conducting COR Lab Study
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p
(
ss
i
t
p
o
PE 151126
CO2 injecti
ore volume in
nset of Asph
Whenever
Kokal and Sa
ystem (SDS)ystem is give
to the PVT c
e received laounted insid
ermits visual
f the fluid in
Fig
on reduces th
ected. A typi
altene Precip
a gas is inject
egh, 1995). T
Hammami, C in Fig. 9. Th
ll, the actual
ser light froma temperatur
observation o
ide the cell.
re 6: Swelli
Figure 7: S
oil viscosity.
al viscosity pl
Figure 8:
tation:
ed into an oil
he onset of as
ang-Yen, Ni SDS apparat
VT cell conta
the PVT cell,-controlled ov
the oil inside
he PVT cell
g test sum
ollen volu
Using PVT a
ot for differen
il viscosity
reservoir, esp
haltene preci
hswander ands consists of
ining the crud
and a poweren and has an
the cell. A va
lso has a spe
ary (Satura
e versus a
pparatus we c
mixtures is s
versus am
ecially CO2,
itation can be
Strange, 199a laser power
at pressure a
eter that meeffective volu
iable volume
cially designe
tion Pressu
ount of CO
an find the vi
own in Fig. 8.
unt of CO2
potential exi
measured fro
). A schematisource, a fiber
d temperatur
asures the amme of 110 cm
displacement
d magneticall
re and GOR)
added.
scosity reducti
.
dded.
sts for the pre
m live crude o
c representati optic bundle
, another fibe
unt of light r . The PVT ce
ump controls
coupled imp
on of oil in e
cipitation of
ils using solid
n of the solidhat carries the
optic bundle
ceived. Thel is a window
the volume a
eller mixer th
5
ch step of
sphaltenes
s detection
s detectionlaser light
hat carries
VT cell ised cell that
d pressure
t provides
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6
p1
t
t
o
r
a
p
ct
t
at
t
owerful mixi0,000 psig an
certain volu
he procedure
en, Nighswa
ansmittance i
). This is theansmittance
easurable (P
r a re-dissolu
eached (Point
ulk Depositi
The experi
sphaltenes pr
ressure filtrat
onnected to aansferred int
emperature re
t the end of thotal oil charge
e trend plotte
g and mainta temperatures
Figure 9: So
e of reservoi
for detecting
der and Stra
creases initial
point of asphaeclines mono
int B). As mo
ion effect (Po
D).
n:
ents describ
cipitated. Th
on apparatus
pump. Thethe second e
resenting res
e experimentd. The experi
d (Fig. 12).
ns equilibriu up to 360°F.
lids Detecti
oil is charged
the onset of a
ge, 1995). A
ly as the CO2
ltene onset. Atonically. Aft
re CO2 is add
int C). After
Fi
d previously
precipitation
and it consis
ample is take pty cylinder
rvoir conditio
nd weighted.ent is conduc
in the fluid
n System (
into the PVT
phaltene preci
n example pl
dilutes the cru
more CO2 isr 3.7 cm3 of
d the light tra
5.0 cm3 of C
10: Titratio
rovide the on
quantity can
s of two floa
n in one of tthrough a filt
s. The deposi
The amount oted at differen
system. The P
DS) (Courte
cell at a relati
pitation from
t of a titrati
de and then st
added the amoCO2 addition
smittance sta
O2 addition th
of reservo
set of asphalt
be measured
ting piston p
he cylindersr assembly.
ted asphaltene
asphaltenes pt gas-reservoi
VT cell is de
sy Oi lphase
ely high pres
crude oils is d
g experiment
rts to decline
unt of asphaltthe amount o
ts to increase
e transmittanc
ir oil with C
ne precipitati
using a separ
mps as show
nd equilibrathe experimen
s are trapped
recipitated isoil ratios an
signed for ope
/DBR-Sc h lu
ure. It is then
escribed elsew
is shown in
after ~0.75 cm
ene precipitatif light passin
(~4.2 cm3) in
e declines aga
2.
n; they do no
ate PVT cell.
n in Fig. 11.
d for ~48 hot is conducted
on the filter as
calculated in p the amount p
ration at pres
berger)
titrated slowly
here (HammaFig. 10. The
3 of CO2 injec
n increases a through the
dicating a dilu
in as the bub
t quantify the
It is essentia
One of the c
urs. The samat constant p
sembly that a
pm or as a perecipitated me
PE 151126
ures up to
with CO2.
i, Chang-
laser light
tion (Point
d the lightcell is not
tion effect,
le point is
amount of
ly a high-
ylinders is
le is thenessure and
e removed
cent of theasured and
8/18/2019 SPEr Conducting COR Lab Study
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t
(
i
a
f
i
p
PE 151126
luid-Rock IFluid-rock
pical, but we
ater-gas) rela
Another co
issolution of plugging of p
teraction bet
cid (H2CO3):
he weak carb
ollowed by se
he deposition
ifferent CO2-
jection of C
AppropriatO2 injection
O2/rock inte
ublications (I
Fig
teractionsinteractions a
l thought out
ive permeabil
cern during
rock can havres, scale pre
een CO2/bri
nic acid react
ondary precip
of interactio
OR operatio
2 in limestone
studies shoulCO2-EOR). It
actions. This
sever et al. 19
re 11: Bulk
Figure 12:
e equally imp
oreflooding e
ity, critical gas
O2 injection is
e both positivcipitation). Be
e and carbon
s with carbona
itation of calci
CaMg(
products of
s. According
cores, while n
d be conducteshould invest
aspect of flu
93, Stalkup 19
Asphaltene
ulk Asphal
ortant in a C
periments. O
saturation me
its interactio
e (increase isides the pote
te rock is cru
CO2 +
H2CO3 + H2
HCO3- + H
te rocks releas
um carbonate
aCO3 + H2
O3)2 + H2C
O2/brine/rock
to Grigg and
o deposition
d that addressgate factors (
id-rock intera
78, Simon an
Precipitatio
ene Precipi
2-EOR proje
her experime
asurements, a
with reservoi
injectivity, r tial benefits
cial. Carbon d
2O ↔ H2
O↔ H3O+
O ↔ H3O+
ing calcium a
due to increas
O3 ↔ Ca2+
3 ↔ Ca2+ +
has been fou
vec (2003), s
as observed i
the impact of.g., pressure,
ctions is not
Graue 1965,
Apparatus
ation Data (
t. The oil rec
ts that need to
d wettability
r rock and the
educed pressut of the CO
ioxide dissolv
O3
HCO3-
CO32-
d magnesium
e in pH value:
2HCO3-
Mg2+ + 2H
nd to cause a
ignificant calc
dolomite cor
CO2 on carboflow rate, wat
covered and
Mungan 1991,
(Schematic)
typical)
overy potentia
be conducted
alteration mea
subsequent di
re for injecti flooding in t
es in water to
ions. This ini
O3-
decrease in t
ium carbonate
es.
nate (or sandser saturation,
the reader is
Hadlow 1992
l should be si
include three-
urements.
solution of th
n) and negaterms of oil re
form the wea
tial dissolutio
e well injecti
was noted du
tone) rocks asand other) tha
referred to t
).
7
mulated in
phase (oil-
rock. The
ive effectsovery, the
k carbonic
is usually
ity during
ring WAG
a result oft affect the
he several
8/18/2019 SPEr Conducting COR Lab Study
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8
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c p
p
a p
i
p
o
r i
a
e
il Recovery
There can
e enhanced
omprehensiveaboratory or
imultaneous i
ower the mini
as injection, ioday employ t
bout 40% of t
eported to be
The oil rec
oreflooding ssi, pore press
arts should b
nd CO2 are gumps. System
s equipped wi
laced inside t
ne of which is
The core fl
outine analysis to make sur
acro porosit
pparatus, all
xperiment co
1. S2. St
te
st
3. R 4. St
5. A6. T
te
7. St pr
fl
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re
K 9. F
fo
otential:
e significant
hen CO2 is
review of C pplied in the
jection of C
um miscibili
njecting LPGhe WAG met
he total US-E
n economic s
overy potenti
stem is showres up to 9,50
constructed
enerally suppl pressure can
th a three pha
e oven in a m
used for acqu
ooding proced
s, computerize that there is
distribution
accumulators
sists of the fol
turate the cor
art dead oil perature. T
bilized.
ise the tempeart live oil flo
ge the core for e composite perature and
art water floo
oduced oil in
oding until n
ection).r the continuo
covered oil wi
eep continuour WAG mod
llowed by 0.2
ifference in o
miscible wit
2 flooding unfield in the fo
2 and water, a
y pressure, inj
and CO2 mixtod (Hinderak
R production
ccess (Hadlo
l can be mea
in Fig. 13. T0 psi and temp
rom inert mat
ied from highe maintained
se separator th
ounting brack
iring level me
Figure 1
ure starts wit
d tomographyno fracture or
nd to ensure
are filled wit
lowing steps:
plugs with re
looding to me dead oil fl
ature in the oding and keep
some time (tys now fully sready for wat
ing initially a
he separator.
o more oil pr
us CO2 injecti
ll be collected
CO2 flooding CO2 injectio
PVs of wate
il recovery be
h oil under
er different illowing mode
lternating inje
ecting CH4 wi
ures, and LPr, Utseth, Hu
: most of whi
, 1992).
ured experim
pical coreflooeratures up to
rials such as
-pressure floa by a back pres
at is used to
t and operate
surements for
3: Core Flo
selecting a l
(CT) – scan a permeability
that the com
the correct
servoir brine.
easure the oriooding will
en to reservoi flooding till t
pically 10-15aturated withr flooding.
constant flo
he separator i
oduced, until
on experiment
in fraction col
until no more experiment:
injection. T
ween miscibl
eservoir con
jection scenas: CO2 stim
tion of CO2 a
th CO2 to take
followed bytad, Kvanvik
h are WAG fl
ntally by cor
ding apparatu150°C (higher
Hastelloy C-2
ing piston acsure regulator
easuring the
at reservoir p
the water-oil
ding Appar
rge number o
d nuclear ma barrier within
osite core pl
luids (dead o
ginal oil inontinue till t
temperature.he pressure di
ays).ive oil and t
rate (typicall
s at reservoir
the water cut
: Start continu
lectors at atm
fluid is produStart injecting
is cycle (0.2
e and immisci
itions. Mun
ios. Basicallylation, contin
nd water (W
advantage of
CO2. Almostand Paulsen,
oods. Most o
eflooding syst
es can operat specification
6, Viton, and
umulators th(BPR) at the
recovered oil
ressure and te
nterface posit
tus (Schem
f core plugs f
gnetic resonan the plugs. T
gs are of the
il, live oil, b
lace (OOIP).e pressure d
Inject severalference betwe
e pore pressu
1 cc/min an
onditions and
reach ~99%
ous CO2 floo
spheric condi
ced (usually 1 CO2 at const
PV CO2 and
ble gas injecti
an (Mungan,
, CO2 floodinous CO2 inje
G), injecting
gravity stabili
all the comme996). Gas inj
the WAG flo
em. A schem
at overburdeare also possib
Teflon™. La
t are driven bore outlet. Th
during waterfl
perature. Th
on that measu
atic)
r screening.
ce (NMR) mee NMR is to
same rock ty
ine and CO2)
This is nor ifference bet
pore volumesen inlet and o
re is at avera
later at 2 and
the collected
(Usually 2 –
ing at constan
tions. The coll
-2 pore volumant flow rate
0.2 PV water
on. The oil re
1991) has c
has been stuction, CO2 sl
H2S or SO2
ation, flue (c
rcial misciblection projects
od projects in
tic representa
pressures uple). All pore f
ge volumes o
y external hie core floodin
ooding. The s
separator ha
red with a tra
he screening
asurements. Tdetermine the
pe. In the co
. A typical c
ally conducteeen inlet an
of dead oil.tlet is stabiliz
e reservoir pr
4cc/min) and
oil is live oil.
pore volum
t flow rate of
ected oil here
of CO2 injectf 0.5 cc/min
) is repeated
PE 151126
overy will
ompiled a
died in theg process,
ith CO2 to
mbustion)
gas floodscontribute
the US are
tion of the
to ~10,000uid wetted
f oil, brine
h-pressureapparatus
eparator is
two bores
sducer.
consists of
e CT scanmicro and
e flooding
reflooding
d at roomoutlet is
d
essure and
collect the
eep water
s of brine
.5 cc/min,
is dead oil.
ion).for 0.2 PV
for several
8/18/2019 SPEr Conducting COR Lab Study
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a
a
f
p
1s
s
e
p
o p
p
f a
p
2
a
p
PE 151126
cd
10. CA typical
Figure
hree-Phase
Another imll three phas
pplications. E
luid flow in p
hase while oil
982). It was aaturation and
aturations of o
Three-phasxperiments is
hase flow (O
bstacle of coermeability d
Ahmadloo
rovided guide
ound that ther ccurate prediermeability d
An alternat
002, Suicmezodels (Spiteri
Figure 1
ettability C
Wettability
lteration are oistory (Buckl
resent in the
cles. The recoad oil. Keep c
llect the data
AG type core
4: Cumulati
elative Perm
portant aspects, oil, gas a
tensive resea
rous medium
and water co
lso noted thatrelative perm
ther two phas
e relative per lengthy and e
k 1990, Main
ducting suchta.
et al. (2009) r
lines on the se
e is no singlection of isopta.
ive technique
et al., 2006)., et. al ., 2005)
: Experime
anges:
alteration is a
il compositioy et al., 1995)
crude oil ca
vered oil is continuous CO2and perform t
flooding exper
ve PV CO2 i
eability:
of CO2-EORd water sho
ch has been c
during gas inj
ld be wetting
the relative peability of the
s (Pejic, Drag
eability dataxpensive leadi
i et al., 1990,
lab experimen
viewed a wid
lection of pre
available threerms because
that overcome
The simulatioas well as a pl
tal and por
effective app
, brine chemis. The adsorpti
alter most
llected in fra flooding until
e recovery cal
iments results
jected vers
ab studies anld be consid
nducted on th
ection. The lit
or intermediat
meability of tintermediate-
an and Maini,
an be obtaineng to limited
Larsen and S
ts, predictive
e range of exp
ictive models
e-phase predithese predic
s the experim
s for both caatform for opt
network si
roach to enha
try, rock surf n of polar co
f the rock’s
tion collector no more flui
culations.
are shown in
us cumulati
experimentsered in gas i
ree-phase rela
erature revie
wetting (Lev
he wetting anetting phase
2003).
d by conductinumber of lab
auge, 1995,
odels have b
erimental res
for generation
tive model thive models
ental difficult
bonate and saimal sensitivit
ulated thr
ce oil recover
ce mineralog pounds and/
surface chem
s at atmosphe is produced.
ig. 14.
e % OOIP r
is three-phasenjection, gas
tive permeabil
shows that t
erett and Lewi
non-wettingis strongly aff
g special SC experiments
leri et al., 19
een used wid
lts reported o
of three-phas
at can be conave been de
is the use o
ndstones prov testing. An
e phase rel
y significantl
and the syster the depositi
istry. Polar c
ic conditions.
covered an
relative permcap expansio
ity to understa
e gas always
s, 1940, Core
phase is primaected by the s
L experimentreported in th
95 and Baker
ely to estimat
n three-phase
e relative per
idered reliableloped base
pore network
de quantifiablexample is sho
tive permea
. The main fa
m temperatur n of organic
mpounds co
The collected
d pressure
ability data.n and therm
nd the hydrod
ehaves as a n
et al., 1956,
rily a functionaturation histo
s. The naturee literature fo
1999). To ov
the three ph
elative perme
eability isope
e and compre on two-pha
models (Piri
e data includiwn in Fig. 15.
bility (SPE9
tors affecting
, pressure andatter that wa
tain a polar
9
oil here is
rop
he flow ofl flooding
namics of
on-wetting
araf et al.,
of its ownry and the
of such labthe three-
rcome the
se relative
ability and
ms. It was
ensive forse relative
and Blunt,
g trapping
594)
wettability
saturationoriginally
end and a
8/18/2019 SPEr Conducting COR Lab Study
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1
(
s
(
ps
1
c
c
cr
c
s
f i
c
ar
f
cc
s
t
c
I
c
r f
e
p
se
r
0
ydrocarbon eAnderson, 19
trongly affect
egatively chaettability-alte
etting prefere
Okasha et al.,
ressure and dtructure, the s
Wettability
ettability bef
975; Tiffin a
ores. The resuater injection
onducted exp
ores representelative perme
hasing the c
uggesting extr
looding. Cor termediate-w
onditions. Bo
etted the soli
lteration ofecognize the
avorable cond
rude oil and iarbonate rese
alinity increa
emperature le
Wettabilityhanges in the
n conventiona
omparison as
Figure 17:
onclusionThe design
eservoir/fluideasibility of s
ssential comp
Fluid-fluid
roperties of C
uch experimexperiments w
Fluid-rock
elative perme
d. The polar6). Brine che
the charge of
ged when thering compoun
nce is seen ne
2007). Zones
estabilize thelid surfaces
alteration du
re and after
d Yellig, 198
lts showed tha. Also, it was
riments study
ed three types bility were e
anges in rela
action of the r
experimentset. CO
2 flood
h results sho
s if the media
ettability forettability alte
tion of wettab
s brine whichvoirs to study
ed, wettabilit
ding to higher
changes duriT2 relaxation
l testing, repe
do more sophi
ater distrib
of a CO2-EO
system. Theseuch a project.
nents of mea
studies inclu
O2-oil or CO2nts should bell to obtain ac
nteraction stu
bility, critical
nd adsorbs oistry plays a
the rock surf
pH is increasds. In an oil-
ar the bottom
higher in the
water film, alostly retain th
ing CO2 floo
O2 flooding to
3). Schneider
t oil bypassedfound that w
ing the effects
of wettabilityamined initial
tive permeabi
ock surface ca
were conducing was perfo
ed that CO2 di
were interme
tight limestoration. The re
ility, i.e., mor
was a favorabthe effects so
y alteration d
oil recovery f
g and afterime distributi
at measureme
sticated obser
ution and in
or CO2 sequ
data are criti. A comprehe
uring fluid-flu
e miscible di
-brine mixtur
conductedcurate and rep
dies typically
gas saturation
the rock sur ajor role in
ce. The rock
ed. Also, raisiearing forma
f the transitio
structure hav
lowing surface water film (
ing process i
track any cha
nd Owens (1
by the solventater mobility
of CO2 flood
states: intermly before and
lity behaviors
used by CO2.
ted on a car rmed in glass
d not contact
iate-wet. Ze
e cores. Chaults suggeste
water-wet co
le effect. Gue of the fluid
ecreased. Als
om fractured
O2 injectionsn and calcula
ts of the Am
ations based o
ermediate
(S
stration proje
al input for ansive experim
id interactions
placement in
s including vi
ith live reser esentative dat
include corefl
, gas trapping
ace, exposingltering the we
surface beco
ng the temper tion, the wett
n zone and a
a greater ca
e-active compil and Gas Jo
s investigated
nges (Lin and
976) conducte
bank increaseas reduced
ing on the we
diate oil-wet,after CO2 flo
. The results
Chalbaud et a
bonate reserv micro-model
he solids for
ri et al. (2007
ges in relati that CO2 floo
ndition. Also,
ta and Moha properties on
o, it was fou
carbonate rese
are difficult ttion of surfac
tt our USBM
n ESEM imag
etting char
E 105114)
t requires a la
y reservoir siental design
and fluid-roc
luding the m
scosity and d
oir fluids ata that can be u
oding tests f
and wettabilit
the hydrocarbttability of the
es positively
ature and presability can va
reater oil-wet
illary pressur
onents in thernal, summer
extensively i
Huang, 1990;
d laboratory e
d the gas satuuring later pe
tability of W
intermediateding. Then, r
showed that
l. (2007) addr
oir for twos to trace the
ater-wet med
conducted a l
e permeabilitding changed
CO2 flooding
ty (2008) testwettability al
d that the
rvoirs.
o determinerelaxavity ca
before and a
es (Okasha, 2
cteristics o
rge set of exp
mulation studor conductin
interactions.
easurement o
nsity, asphalt
reservoir consed in simulat
r determining
changes. Th
on end and m rock where t
charged when
sure tends tory with depth
ing preferenc
e, which can
oil to contact2007).
the literatur
Stalkup, 197
xperiments on
ation trappedriods of wate
st Texas dolo
nd intermediaock wettabilit
the cores be
ssed the role
ettability codistribution o
ia. On the oth
aboratory stud
y due to CO2the water-wet
reduced the I
ed oil sampleseration. The t
ettability alte
uantitatively.n often be use
ter CO2 inject
07).
grains, Ara
erimental and
that may bea CO2 labor
minimum mi
ene precipitati
ditions. It isors and fluid c
the oil recov
se tests provi
aking the surf e brine’s salin
the pH is dec
romote the s where a gre
is observed n
counteract the
the solid. Lo
. Researchers
; Shelton and
more than 19
during the late injection. Po
itic cores. T
te water-wet.was monitor
came slightly
f wettability
nditions: watf fluids unde
r hand, the C
y evaluating t
injection we limestone co
T between th
obtained frost results sho
ation increas
With NMRd for wettabil
ion provide o
b-D carbona
modeled data
conducted toatory study r
scibility pres
on, and swelli
important toharacterizatio
ry potential, t
e the key co
PE 151126
ace oil wetity and pH
reased and
lubility ofter water-
ear the top
disjoining
wer in the
measured
Schneider,
preserved
r period oftter (1987)
e selected
hanges ined through
water-wet
uring CO2
r-wet andthe same
2 partially
e possible
re used toes to more
employed
fractureded that as
ed at high
echniques,ty indices.
e point of
te rocks
for a given
xplore thequires the
ures, fluid
ng. Ideally
design the.
hree-phase
ponents to
8/18/2019 SPEr Conducting COR Lab Study
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SPE 151126 11
address flow regime and displacement sensitivities. An accurate set of data is key to successfully modeling and validation
larger pilot and field scale projects.
AcknowledgementsThe authors would like to thank Saudi Aramco for permission to publish this paper. Special thanks go to Ali Al-Meshari
for his help in the development of experimental procedure.
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