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INTRODUCTION TO RESERVOIR
ENGINEERING
LECTURE 1
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Pressure-Temperature Diagram
!igure "#" shows a typical pressure#temperaturediagram o a multicomponent system with a specifcoverall composition. $lthough a dierenthydrocarbon system would have a dierent phasediagram% the general confguration is similar.
These multicomponent pressure#temperature diagramsare essentially
used to:
• &lassiy reservoirs
• &lassiy the naturally occurring hydrocarbon systems• 'escribe the phase behavior o the reservoir (uid
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Petroleum Geology
LECTURE 2
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1 How is petroleum formed?
Petroleum is result of the deposition of plant or animal
matter in areas whih are slowly su!siding"These areas are
usually in the sea or along its margins in oastal lagoons or
marshes#oasionally in la$es or inland swamps"%ediments
are deposited along with that at least part of the organimatter is preser&ed !y !urial !efore !eing destroyed !y
deay"'s time goes on and the areas ontinue to sin$
slowly#the organi material is !uried deeper an hene is
e(posed to higher temperatures and pressures"E&entually
hemial hanges result in the generation of petroleum#a
omple(#highly &aria!le mi(ture lf hydroar!ons"
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2 what is )trap* ?
The term )trap* was first applied to a hydroar!on
aumulation !y +rton, )-sto$s of oil and gas might !e
reapped in the summits of folds or arhes found along
their wat to higher ground "*' detailed historial aount of
the su!se.uent e&olution of the onept and etymology of
the term trap is found in /ott and Reyonlds013"
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6asi Conepts of +rigin# 'umulation and
Reo&ery of Hydroar!ons
LECTURE 4
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型
游
梁
式
抽
油
机
异
型
游
梁
式
抽
油
机
旋
转
驴
头
游
梁
式
抽
油
机
调
径
变
矩
游
梁
式
抽
油
机
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链传式抽油机 天轮式抽油机 直线往复式抽油机
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链条式抽油机 皮带式抽油机
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Elements of Petroleum Reser&oir
777fluid ontent of the reser&oir
LECTURE 8
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Porosity and Effeti&e Porosity
LECTURE 9
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P+R+%:T;
< =or ro$ to ontain petroleum and later allow petroleum toflow#it must ha&e ertain physial harateristis" +!&ilusly#
there must !e some spaes in the ro$ in whih the
petroleum an !e stored"
< :f ro$ has openings#&oids#and spaes in whih li.uid and
gas may !e stored#it is said to !e porous "=or a gi&en
&olume of ro$# the ratio of the open spae to the total
&olume of the ro$ is alled porosity#the porosity may !e
e(pressed a deimal fration !ut is most often e(pressed
as a perentage"=or e(ample#if 1>> u!i feet of ro$
ontains many tiny pores and spaes whih together ha&e
a &olume of 1> u!i feet# the porosity of the ro$ is 1>"
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P+R+%:T; The porosity o a roc) is a measure o the storage capacity
*pore volume+that is capable o holding (uids.
,uantitatively% the porosity is the ratio o the porevolume to the total volume *bul) volume+. Thisimportant roc) property is determined mathematicallyby the ollowing generali-ed
relationship:
where φ = porosity
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$s the sediments were deposited and the roc)swere being ormed during past geological times%some void spaces that developed becameisolated rom the other void spaces by excessive
cementation. Thus% many o the void spaces areinterconnected while some o the pore spacesarecompletely isolated. This leads to two distincttypes o porosity% namely:
• $bsolute porosity• ective porosity
P+R+%:T;
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Absolute porosity
The absolute porosity is defned as the ratio o the total porespace in
the roc) to that o the bul) volume. $ roc) may haveconsiderable
absolute porosity and yet have no conductivity to (uid or lac) opore
interconnection. The absolute porosity is generally expressed
mathematically by the ollowing relationships:
or
where φa = absolute porosity.
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Ee!ti"e porosity
The eective porosity is the percentage o
interconnected pore space with respect to thebul) volume% or
where φ = eective porosity.
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ne important application o the eective porosityis its use in determining the original hydrocarbonvolume in place. &onsider a reservoir with an arealextent o $ acres and an average thic)ness o heet. The total bul) volume o the reservoir can bedetermined rom the ollowing expressions:
/ul) volume = 01%234 $h% t1
or
/ul) volume = 5%526 $h% bblwhere $ = areal extent% acres
h = average thic)ness
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Permea!ility and /ary@s Law
LECTURE
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PER#EA$ILIT%
Permeability is a property o the porous medium that
measures the capacity and ability o the ormation totransmit (uids. The roc) permeability% )% is a very importantroc) property because it controls the directional movement
and the (ow rate o the reservoir (uids in the ormation. This roc) characteri-ation was frst defned mathematicallyby 7enry 'arcy in "623. In act% the e8uation that defnes
permeability in terms o measurable 8uantities is calledDar!y&s La'(
'arcy developed a (uid (ow e8uation that has since becomeone o
the standard mathematical tools o the petroleum engineer. Ia hori-ontal linear (ow o an incompressible (uid isestablished through a core sample o length 9 and a cross#section o area $% then the governing (uid(ow e8uation is
defned as
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where ν = apparent (uid (owing velocity% cmsec) = proportionality constant% or permeability% 'arcys
µ = viscosity o the (owing (uid% cp
dpd9 = pressure drop per unit length% atmcm
The apparent velocity determined by dividing the (ow rateby the cross#sectional area across which (uid is (owing.;ubstituting the relationship% 8$% in place o ν in8uation 1#<" and solving or 8 results in
where 8 = (ow rate through the porous medium% cm1sec
$ = cross#sectional area across which (ow occurs% cm<
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ne 'arcy is a relatively high permeability as thepermeabilities o
most reservoir roc)s are less than one 'arcy. In order toavoid the use o ractions in describing permeabilities%
the term millidarcy is used. $s the term indicates% onemillidarcy% i.e.% " md% is e8ual to one#thousandth o one'arcy or%
" 'arcy = "444 md
The negative sign in 8uation is necessary as the pressure
increases in one direction while the length increases inthe opposite direction.
Integrate the above e8uation
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Linear flow model
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where 9 = length o core% cm
$ = cross#sectional area% cm<
The ollowing conditions must exist during themeasurement o permeability:
• 9aminar *viscous+ (ow• =o reaction between (uid and roc)
• nly single phase present at "44> pore spacesaturation
This measured permeability at "44> saturation oa single phase is
called the absolute permeability o the roc).
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!or a radial (ow% 'arcy?s e8uation in a dierential orm canbe written as:
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:ntergrating /ary’s e.uation gi&es,
The term d9 has been replaced by dr as the length term
has now become a radius term.
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%aturation
LECTURE A
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SATURATION
;aturation is defned as that raction% or percent% o the pore
volume
occupied by a particular (uid *oil% gas% or water+. This property is
expressed mathematically by the ollowing relationship:
$pplying the above mathematical concept o saturation to eachreservoir
(uid gives
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where
;o = oil saturation
;g = gas saturation;w = water saturation
;g + ;o + ;w = ".4
Criti!al oil saturatio)* So!
!or the oil phase to (ow% the saturation o the
oil must exceed a certain value which is
termed critical oil saturation. $t this particular
saturation% the oil remains in the pores and%
or all practical purposes% will not (ow.
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Residual oil saturation, Sor
/uring the displaing proess of the rude oil system
from the porous media !y water or gas inBetion 0or
enroahment3 there will !e some remaining oil left that
is .uantitati&ely harateried !y a saturation &alue
that is larger than the critical oil saturation. This
saturation &alue is alled the residual oil saturation, Sor.
The term residual saturation is usually assoiated with
the nonwetting phase when it is !eing displaed !y a
wetting phase"
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#o"able oil saturatio)* Som
@ovable oil saturation ;om is another saturation o
interest and is defned as the raction o pore
volume occupied by movable oil as expressed by
the ollowing e8uation:
;om = " − ;wc − ;oc
where
;wc = connate water saturation
;oc = critical oil saturation
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Criti!al gas saturatio)* Sg!
$s the reservoir pressure declines below the bubble#point
pressure% gas evolves rom the oil phase and
conse8uently the saturation o the gas increases as the
reservoir pressure declines. The gas phase remains
immobile until its saturation exceeds a certain saturation%
called critical gas saturation, above which gas begins to
move.
Criti!al 'ater saturatio)* S'!
The critical water saturation% connate water saturation% and
irreducible water saturation are extensively used
interchangeably to defne the maximum water saturation
at which the water phase will remain immobile.
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Capillary Pressure and :ts Cur&e
LECTURE D
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&apillary pressureI a glass capillary tube is placed in a large open vessel
containing
water% the combination o surace tension and wettabilityo tube to water will cause water to rise in the tubeabove the water level in the container outside the tubeas shown in !igure 1.
The water will rise in the tube until the total orce acting to
pull theli8uid upward is balanced by the weight o the column o
li8uid being supported in the tube.
!igure 1
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CAPILLAR% PRESSURE
The capillary orces in a petroleum reservoir are the result o thecombined eect o the surace and interacial tensions o the roc)and (uids% the pore si-e and geometry% and the wetting
characteristics o the system.$ny curved surace between two immiscible (uids has the tendency
to
contract into the smallest possible area per unit volume. This is true
whether the (uids are oil and water% water and gas *even air+% or oiland gas. Ahen two immiscible (uids are in contact% a discontinuity
in pressure exists between the two (uids% which depends uponthe curvature o the interace separating the (uids. Ae call thispressure dierence the capillary pressure and it is reerred to bypc.
&apillary pressure = *pressure o the nonwetting phase+ − *pressure o the wetting phase+
pc = pnw − pw
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=igure8
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Tra)sitio) +o)e
The fgure indicates that the saturations are graduallychanging rom "44> water in the water -one to
irreducible water saturation some vertical distance
above the water -one. This vertical area is reerred
to as the transition zone, which must exist in any
reservoir where there is a bottom water table. The
transition -one is then defned as the vertical
thic)ness over which the water saturation ranges
rom "44> saturation to irreducible water saturation
;wc.
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,ater Oil Co)ta!t The A& is defned as the Buppermost depth in the
reservoir where a "44> water saturation exists.C
as Oil Co)ta!t The D& is defned as the Bminimum depth at
which a "44> li8uid% i.e.% oil + water% saturation
exists in the reservoir.C
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=igure 9
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It should be noted that there is a dierence
between the ree water level *!A9+ and the depth
at which "44> water saturation exists. !rom a
reservoir engineering standpoint% the ree water
level is defned by zero capillary pressure.
bviously% i the largest pore is so large thatthere is no capillary rise in this si-e pore% then
the ree water level and "44> water saturation
level% i.e.% A&% will be the same.
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etta!iloity and /istri!ution of Reser&oir
=luids
LECTURE
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,ETTA$ILIT%
Aettability is defned as the tendency o one (uid to
spread on or adhere to a solid surace in the
presence o other immiscible (uids. The concept o
wettability is illustrated in !igure". ;mall drops o
three li8uids#mercury% oil% and waterEare placed on
a clean glass plate.
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The three droplets are then observed rom one sideas illustrated in !igure 1#". It is noted that the mercuryretains a spherical shape% the oil droplet develops anapproximately hemispherical shape% but the watertends to spread over the glass surace.
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The tendency o a li8uid to spread over the surace
o a solid is an indication o the wettingcharacteristics o the li8uid or the solid. This
spreading tendency can be expressed more
conveniently by measuring the angle o contact
at the liquid-solid surace. This angle% which is
always measured through the li8uid to the solid%
is called the contact angle θ.
The contact angle θ has achieved signifcance as a
measure o wettability.
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$s shown in !igure "% as the contact angle decreases% the wetting
characteristics o the li8uid increase. &omplete wettability would be
evidenced by a -ero contact angle% and complete nonwetting would beevidenced by a contact angle o "64F. There have been various
defnitions o intermediate wettability but% in much o the published
literature% contact angles o 34F to G4F will tend to repel the li8uid.
The wettability o reservoir roc)s to the (uids is important in that the
distribution o the (uids in the porous media is a unction o wettability.
/ecause o the attractive orces% the wetting phase tends to occupy the
smaller pores o the roc) and the nonwetting phase occupies the more
open channels.
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Properties of Fatural Gas
LECTURE 1>
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PT 6eha&iour
LECTURE 11
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Classifiation of Hydroar!on
Reser&oir
LECTURE 12
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CLASSIFICATION OF RESERVOIRSAND RESERVOIR FLUIDS
Petroleum reservoirs are broadly classifed as oilor gas reservoirs.
• The composition o the reservoir hydrocarbonmixture
• Initial reservoir pressure and temperature
pressure-temperature diagram
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Pressure-Temperature Diagram
!igure "#" shows a typical pressure#temperature diagram o amulticomponent system with a specifc overall composition.$lthough a dierent hydrocarbon system would have adierent phase diagram% the general confguration issimilar.
These multicomponent pressure#temperature diagrams areessentially used to:
• &lassiy reservoirs
• &lassiy the naturally occurring hydrocarbon systems• 'escribe the phase behavior o the reservoir (uid
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. Criti!al poi)t/ The critical point or a multicomponentmixture is reerred to as the state o pressure and
temperature at which all intensive properties o the gas andli8uid phases are e8ual *point &+. $t the critical point% thecorresponding pressure and temperature are called thecritical pressure pc and critical temperature Tc o themixture.
Pressure-Temperature Diagram
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. $ubble-poi)t !ur"e/ The bubble#point curve *line /&+
is defned as the line separating the li8uid#phase regionrom the two#phase region.
. De'-poi)t !ur"e/ The dew#point curve *line $&+ isdefned as the line separating the vapor#phase regionrom the two#phase region.
Pressure-Temperature Diagram
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• Oil reser"oirs/I the reservoir temperature Tis less than the critical temperature Tc o thereservoir (uid% the reservoir is classifed as an oilreservoir.
. as reser"oirs/I the reservoir temperature isgreater than the critical temperature o the
hydrocarbon (uid% the reservoir is considered agas reservoir.
Pressure7Temperature /iagram
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Lo'-s0ri)1age oil
• il ormation volumeactor less than ".<bbl;T/
• Das#oil ratio less than <44sc;T/
• il gravity less than 12F$PI
• /lac) or deeply colored
Types of Crude Oil
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Gas Reservoirs
In general% i the reservoir temperature is abovethe critical temperature o the hydrocarbonsystem% the reservoir is classifed as a natural
gas reservoir. n the basis o their phasediagrams and the prevailing reservoirconditions% natural gases can be classifed into1 categories:
• Hetrograde gas#condensate
• Aet gas• 'ry gas
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I the reservoir temperature T liesbetween the critical temperature
Tc and cricondentherm Tct o the
reservoir (uid% the reservoir isclassifed as a retrograde gas#
condensate reservoir.
• the gas#oil ratio or a condensatesystem increases with time due to
the li8uid dropout and the loss oheavy components in the li8uid.
• &ondensate gravity above 24F $PI
• ;toc)#tan) li8uid is usually water#white or slightly colored.
Retrogra2e gas-!o)2e)sate reser"oi
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Temperature o wet#gas reservoir
is above the cricondentherm o
the hydrocarbon mixture.
/ecause the reservoir
temperature exceeds the
cricondentherm o the
hydrocarbon system% the
reservoir (uid will always remain
in the vapor phase region as the
reservoir is depleted
isothermally% along the vertical
line $#/.
,et-gas reser"oir
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Aet#gas reservoirs are characteri-ed by the ollowing
properties:
• Das oil ratios between 34%444 to "44%444 sc;T/
• ;toc)#tan) oil gravity above 34F $PI
• 9i8uid is water#white in color
• ;eparator conditions% i.e.% separator pressure and
temperature% lie within the two#phase region
,et-gas reser"oir
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The hydrocarbon mixture
exists as a gas both in
the reservoir and in thesurace acilities.
sually a system having a
gas#oil ratio greater
than "44%444 sc;T/ isconsidered to be a dry
gas.
Dry-gas reser"oir
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/ri&es in the Reser&oir0water dri&e and
ompation dri&e3
LECTURE 18
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The Aater#'rive @echanism
@any reservoirs are bounded on a portion or all o theirperipheries by water bearing roc)s called a8uiers. Thea8uiers may be so large compared to the reservoir they adJoinas to appear infnite or all practical purposes% and they mayrange down to those so small as to be negligible in theireects on the reservoir perormance.
Heservoir havea water drive
Charateristis Trend
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Reser&oir pressure /elines &ery slowly 0remains
&ery high3
Gas oil ratio Little hange during the life ofthe reser&oir 0remains low3
ater prodution Early e(ess water prodution
ell !eha&ior !low until water productiongets excessive.
+il reo&ery 49 to A9
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Ro!1 a)2 Li3ui2 E4pa)sio)
Ahen an oil reservoir initially exists at a pressurehigher than its bubble#point pressure% the reservoir iscalled an undersaturated oil reservoir.
$t pressures above the bubble#point pressure% crudeoil% connate water% and roc) are the only materials
present. $s the reservoir pressure declines% the roc) and(uids expand due to their individual compressibilities.
The reservoir roc) compressibility is the result o twoactors:
• xpansion o the individual roc) grains
• !ormation compaction
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Hoc) and 9i8uid xpansion
6oth of the a!o&e two fators are the results of a
derease of fluid pressure within the pore spaes#
and !oth tend to redue the pore &olume through
the redution of the porosity"
This dri&ing mehanism is onsidered the least
effiient dri&ing fore and usually results in the
reo&ery of only a small perentage of the total
oil in plae"
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%olution7gas /ri&e#Gas7ap
/ri&e#Gra&ity /ri&e
LECTURE 19
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The 'epletion 'rive @echanism
This driving orm may also be reerred to by the ollowing various
terms:
• ;olution gas drive
• 'issolved gas drive
• Internal gas drive
In this type o reservoir% the principal source o energy is a result
o gas liberation rom the crude oil and the subse8uent
expansion o the solution gas as the reservoir pressure is
reduced. $s pressure alls below the bubble#point pressure%
gas bubbles are liberated within the microscopic pore spaces.
These bubbles expand and orce the crude oil out o the pore
space as shown conceptually in !igure "
=igure 1 %olution gas dri&e reser&oir
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g g
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as Cap Dri"e
Das#cap#drive reservoirs can be identifed by the
presence o a gas cap with little or no water driveas shown in !igure <.
'ue to the ability o the gas cap to expand% thesereservoirs are
characteri-ed by a slow decline in the reservoir
pressure. The natural energy available to producethe crude oil comes rom the ollowing two sources:
• xpansion o the gas#cap gas
• xpansion o the solution gas as it is liberated
=igure 2 Gas7ap dri&e reser&oir
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T0e ra"ity-Drai)age-Dri"e #e!0a)ism
The mechanism o gravity drainage occurs in
petroleum reservoirs as a result o dierences in
densities o the reservoir (uids. The eects o
gravitational orces can be simply illustrated by
placing a 8uantity o crude oil and a 8uantity o
water in a Jar and agitating the contents. $ter
agitation% the Jar is placed at rest% and the more
denser (uid *normally water+ will settle to the
bottom o the Jar% while the less dense (uid
*normally oil+ will rest on top o the denser (uid.
The (uids have separated as a result o thegravitational orces acting on them.
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Charateristis Trend
Reser&oir pressure Kariable rates o pressuredecline% dependingprincipally upon the amounto gas conservation.
Gas oil ratio 9ow gas#oil ratio
ater prodution 9ittle or no waterproduction.
ell !eha&ior
+il reo&ery Fear to D>
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T0e Combi)atio)-Dri"e #e!0a)ism
The driving mechanism most commonly encountered is one in
which both water and ree gas are available in some degreeto displace the oil toward the producing wells. The most
common type o drive encountered%
thereore% is a combination#drive mechanism as illustrated in
!igure
0. Two combinations o driving orces can be present incombinationdrive reservoirs. These are *"+ depletion drive
and a wea) water drive andL *<+ depletion drive with a small
gas cap and a wea) water drive.
Then% o course% gravity segregation can play an important
role in any o the aorementioned drives.
=igure 8 Com!ination dri&e reser&oir
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/eri&ation of aterial 6alane E.uation
LECTURE 1
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< hen an oil and gas reser&oir is trapped with wells#
oil and gas# and fre.uently some water# areprodued# there!y reduing the reser&oir pressureand ausing the remaining oil and gas to e(pand tofill the spae &a&ated !y the fluids remo&ed" henthe oil7and gas7!earing strata are hydraulially
onneted with water7!earing strata# or a.uifers#water enroahes into the reser&oir as the pressuredrops owing to prodution "This water enroahmentdereases the e(tent to whih the remaining oil andgas e(pand and aordingly retards the deline in
reser&oir pressure"
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< :n as muh as the temperature in oil and gas
reser&oir remains su!stantially onstant duringthe ourse of prodution# the degree to whihthe remaining oil and gas e(pand depends onlyon the pressure "6y ta$ing !ottom7hole samples
of the reser&oir fluids under pressure andmeasuring their relati&e &olumes in thela!oratory at reser&oir temperature and under&arious pressures #it is possi!le to predit how
these fluids !eha&e in the reser&oir as reser&oirpressure delines"
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< The general material !alane e.uation is simply
a &olumetri !alane# hih states that sine the
&olume of a reser&oir 0as defined !y its initial
limits3is a onstant # the alge!rai sum of the
&olume hanges of the oil # free gas # water # and
ro$ &olumes in the reser&oir &olumes dereases
# the sum of these two dereases must !e!alaned !y hanges of e.ual magnitude in the
water and ro$ &olumes "
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< :f the assumption is made that omplete
e.uili!rium is attained at all times in thereser&oir !etween the oil and its solution gas #it is possi!le to write a generalied material!alane e(pression relating the .uantities of
oil # gas and water produed # the a&eragereser&oir pressure # the .uantity of water thatmay ha&e enroahed from the a.uifer # andfinally the initial oil and gas ontent of the
reser&oir"
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%teady7state and Pseudo %teady7state
=low
LECTURE 1A
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The area o concern in this lectureincludes:
• Types o (uids in the reservoir
• !low regimes
• Heservoir geometry
• =umber o (owing (uids in thereservoir
T;PE% += =LU:/%
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In general% reservoir (uids are classifed intothree groups:
• Incompressible (uids• ;lightly compressible (uids
• &ompressible (uids
Incompressible (uids
$n incompressible (uid is defned as the (uidwhose volume *or density+ does not changewith pressure. Incompressible (uids do notexistL this behavior% however% may be assumed
in some cases to simpliy the derivation andthe fnal orm o many (ow e8uations.
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;lightly compressible (uids
These BslightlyC compressible (uids exhibit smallchanges in volumeor density% with changes in pressure.
It should be pointed out that crude oil and water systemsft into this category.
&ompressible !luids
These are (uids that experience large changes in volumeas a unction o pressure. $ll gases are consideredcompressible (uids.
=L+ REG:E%
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There are three (ow regimes:
• ;teady#state (ow
• nsteady#state (ow
• Pseudosteady#state (ow
;teady#;tate !low
The (ow regime is identifed as a steady#state(ow i the pressure at every location in thereservoir remains constant% i.e.% does notchange with time. @athematically% thiscondition is expressed as:
*0#"+
The above e8uation states that the rate o change opressure p with respect to time t at any location i is
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pressure p with respect to time t at any location i is-ero. In reservoirs% the steady#state (ow condition canonly occur when the reservoir is completely rechargedand supported by strong a8uier or pressuremaintenance operations.
nsteady#;tate !low
The unsteady#state (ow *re8uently called transient fow+is defned as the (uid (owing condition at which therate o change o pressure with respect to time at anyposition in the reservoir is not -ero or constant.
This defnition suggests that the pressure derivative withrespect to time is essentially a unction o both position iand time t% thus
*0#<+
Pseu2ostea2y-State Flo'
Ahen the pressure at dierent locations in the reservoir is
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Ahen the pressure at dierent locations in the reservoir isdeclining
linearly as a unction o time% i.e.% at a constant declining
rate% the (owing condition is characteri-ed as thepseudosteady#state (ow. @athematically% this defnitionstates that the rate o change o pressure with respectto time at every position is constant% or
*0#1+
It should be pointed out that the pseudosteady#state (owis commonly reerred to as semisteady#state (ow and8uasisteady#state (ow.
!igure shows a schematic comparison o the pressuredeclines as a unction o time o the three (ow regimes.
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RE%ER+:R GE+ETR;
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!or many engineering purposes% however% the actual (owgeometry may be represented by one o the ollowing(ow geometries:
• Hadial (ow
• 9inear (ow
• ;pherical and hemispherical (ow
/ecause (uids move toward the well rom all directions and
coverage at the wellbore% the term radial fow is given tocharacteri-e the (ow o (uid
into the wellbore. !igure 0#" shows ideali-ed (ow lines andiso#potential lines or a radial (ow system.
=igure 871 :deal radialflow into a
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flow into awell!ore
Li)ear Flo'
9inear (ow occurs when (ow paths are parallel and the
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9inear (ow occurs when (ow paths are parallel and the(uid (ows in a
single direction. In addition% the cross sectional area to
(ow must beconstant. !igure 0#< shows an ideali-ed linear (ow system.
!igure 0#< Ideal linear(ow
into vertical racture
Sp0eri!al a)2 5emisp0eri!al Flo'
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'epending upon the type o wellbore completionconfguration% it is possible to have a spherical orhemispherical (ow near the wellbore. $ well with a
limited perorated interval could result in spherical(ow in the vicinity o the perorations as illustratedin !igure 0#1. $ well that only partially penetrates thepay -one% as shown in !igure 0#0% could result inhemispherical (ow. The condition could arise where
coning o bottom water is important.!igure 0#1 ;pherical (ow due to limited entry
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=igure 878 Hemispherial flow in a partially penetrating well
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FU6ER += =L+:FG =LU:/% :F THE RE%ER+:R
There are generally three cases o (owing systems:
• ;ingle#phase (ow *oil% water% or gas+
• Two#phase (ow *oil#water% oil#gas% or gas#water+
• Three#phase (ow *oil% water% and gas+
The description o (uid (ow and subse8uent analysis o
pressure data becomes more diMcult as the number omobile (uids increases.
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Horiontal ells
LECTURE 1D
;ince "G64 hori-ontal wells began capturing an ever increasing
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;ince "G64% hori-ontal wells began capturing an ever#increasingshare o hydrocarbon production. 7ori-ontal wells oer theollowing advantages over those o vertical wells:
• 9arge volume o the reservoir can be drained by eachhori-ontal well.
• 7igher productions rom thin pay -ones.
• 7ori-ontal wells minimi-e water and gas -oning problems.
• In high permeability reservoirs% where near#wellbore gas
velocities are high in vertical wells% hori-ontal wells can beused to reduce near#wellbore velocities and turbulence.
• In secondary and enhanced oil recovery applications% longhori-ontal inJection wells provide higher inJectivity rates.
• The length o the hori-ontal well can provide contact with
multiple ractures and greatly improve productivity.
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The actual production mechanism and reservoir (ow regimesaround the hori-ontal well are considered more complicated
than those or the vertical well% especially i the hori-ontalsection o the well is o a considerable length. ;omecombination o both linear and radial (ow actually exists%and the well may behave in a manner similar to that o awell that has been extensively ractured.
$ssuming that each end o the hori-ontal well is represented bya vertical well that drains an area o a hal circle with aradius o b% Noshi *"GG"+ proposed the ollowing two methodsor calculating the drainage area o a hori-ontal well.
#et0o2 I
Noshi proposed that the drainage area is represented by
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N p p g p ytwo hal circles o radius b *e8uivalent to a radius o avertical well rev+ at each end and a rectangle% odimensions 9*<b+% in the center. The drainage area othe
hori-ontal well is given then by:
!igure 2#"
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09713
where
$ = drainage area% acres
9 = length o the hori-ontal well% t
b = hal minor axis o an ellipse% t
#et0o2 II
Noshi assumed that the hori-ontal well drainage area is an
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Noshi assumed that the hori-ontal well drainage area is anellipse and given by:
*2#<+
with
*2#1+
where a is the hal maJor axis o an ellipse.
Noshi noted that the two methods give dierent values orthe drainage area $ and suggested assigning the
average value or the drainage o the hori-ontal well.@ost o the production rate e8uations re8uire the valueo the drainage radius o the hori-ontal well% which isgiven by:
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09783
Ahere
reh = drainage radius o the hori-ontal well% t
$ = drainage area o the hori-ontal well% acres
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Fatural =low Reo&ery
LECTURE 1
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' thorough understanding of the flowing well is
neessary prior to plaing it on artifiial lift "There are two surfae onditions under whiha flowing well is produed # that is # it may !eprodued with a ho$e at the surfae or it may!e produed with no ho$e at the surfae" ThemaBority of all flowing wells utilie surfaeho$es " %ome of the reasons for this aresafety I to maintain prodution allowa!le I tomaintain an upper flow rate limit to pre&entsand entry I to produe the reser&oir at themost effiient rate I to pre&ent water or gas
oning I and others"<
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< :n partiular # flowing wells utilie a ho$e in their
early stages of prodution " 's time progresses #the ho$e sie may ha&e to !e inreased ande&entually remo&ed ompletely in order to try tooptimie prodution "
< The seond ondition that we are onernedwith is produing the flowing well with norestritions at the surfae e(ept normalChristmas tree turn # !ends# et " E&en these may!e streamlined in order to o!tain the ma(imum
flowing rate possi!le "<
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< :n order to analye the performane of a on&entionallyompleted flowing well # in is neessary to reognie thatthere are three distint phases # whih ha&e to !e studiedseparately and then finally lin$ed together !efore ano&erall piture of a flowing well@s !eha&ior an !eo!tained " These phase are the inflow performane # the&ertial lift performane # and the ho$e 0or !ean 3performane"
< The inflow performane # that is # the flow of oil # water #and gas from the formation into the !ottom of the well # istypified # as far as gross li.uid prodution is onerned #!y the P: of well or # more generally # !y the :PR "
< The &ertial lift performane in&ol&es a study of thepressure losses in &ertial pipes arrying two7phase
mi(tures0gas and li.uid3"
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ehanial Reo&ery0rod system3
LECTURE 2>
< +il well pumping methods an !e di&ided into two
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< +il well pumping methods an !e di&ided into twomain groups,
< Rod systems"Those in whih the motion of thesu!surfae pumping e.uipment originates at thesurfae and is transmitted to the pump !y means of arod string"
< Rod less systems"Those in whih the pumping
motion of the su!surfae pump is produed !ymeans other than su$er rods"
< +f these teo groups#the first is represented !y the!eam pumping system and the seond is represented!y hydrauli and entrifugal pumping systems"
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< The !eam pumping system onsists essentially of fi&eparts,
< The su!surfae su$er rod5fri&en pump"< The su$er rod string whih transmits the surfae
pumping motion and power to the su!surfae pump"'lsoinluded is the neessary string of tu!ing andJor asingwithin whih the su$er rods operate and whihonduts the pumped fluid from the pumpto the surfae"
< The surfae pumping eauipment whih hanges therotating motion of the prime mo&er into osillatinf linearpumping motion "
< The power transmiddion unit or speed reduer"
< The prime mo&er whih furnishes the neessary powerto the system"
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=omation /amage Control
LECTURE 22
S1i) Fa!tor
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It is not unusual or materials such as
mud fltrate% cement slurry% or clay
particles to enter the ormation during
drilling% completion or wor)overoperations and reduce the permeability
around the wellbore.
Skin Factor
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This effet is ommonly referred to as a wellbore damage
and the region of altered permea!ility is alled the skin zone.
This one an e(tend from a few inhes to se&eral feet from
the well!ore" any other wells are stimulated !y aidiing or
fraturing whih in effet inrease the permea!ility near the
well!ore" Thus# the permea!ility near the well!ore is alwaysdifferent from the permea!ility away from the well where the
formation has not !een affeted !y drilling or stimulation" '
shemati illustration of the s$in one is shown in =igure 879"
Those actors that cause damage to the ormation canproduce additional locali-ed pressure drop during (ow.
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p p p g This additional pressure drop is commonly reerred to as∆ps)in. n the other hand% well stimulation techni8ues
will normally enhance the properties o the ormationand increase the permeability around the wellbore% sothat a decrease in pressure drop is observed.
!igure 0#2
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• Positi"e S1i) Fa!tor* s 6 7
Ahen a damaged -one near the wellbore exists% )#s)in is
less than ) and hence s is a positive number. Themagnitude o the s)in actor increases as )#s)indecreases and as the depth o the damage r s)inincreases.
. Negati"e S1i) Fa!tor* s 8 7
Ahen the permeability around the well )#s)in is higherthan that o the ormation )% a negative s)in actorexists. This negative actor indicates an improvedwellbore condition.
• +ero S1i) Fa!tor* s 9 7
Oero s)in actor occurs when no alternation in thepermeability around the wellbore is observed% i.e.% )#s)in
= ).
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Re&ision
LECTURE 24I28
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LECTURE 29
=:F'L TE%T