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.,
SPESPE 20095
Saturation Evaluationof Secondary Recovered ReservoirsMN. Hashem, StanfordU.
SPE Member
Cepyfeht lSW, Soclatyof PetmfeumEnginssraho.
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ASSTRACT over the zone and from one well to another for thesame
Consider the case of a eand atone reservoir thatzone, depending .n tha posit ionof the well
has been under a water or steam flooding program,from the flood profile ) .
that was not efficient. A lot of effort is cur- This fact was real izedby the indus tryand ratherrently being done to evaluateand recover the oilthat was left in the ground, As the flood flutd
expensivemethods are followed,such as extensive
has now been introducedto the Reservoir element,coring,NuclearMagnetism tests, and EPT logs, etc.
i t becomes very difficult to find the value of thejust to detarmt~e the oil saturation over thoseunswept zones.
water saturation as the salinity of the floodwater is different frorsthe original formationwater, and involves a lot of coring and other rhispaper.offersa solution to this problem thatexpensive operations to come up with the value of could save substantial expenses to answer thatSw; water saturation. particular queetion. The results of this studyThe technique suggested in this paper finds the were compared to other saturationvalues obtainedvalue of the maturation using logs, both old and by core analysis, E PT and GST logs. The resultsnew, that are available for that field ,theoldbeing the original r esistivity l ogs and the new
were agreeable,and will be discussed later.
being the logs of the new well drilled and record- The real data tested is a case in the Wilmingtoned after the flood. field,CA.This techniqueagrees very well wi th the satura-
~is fiald is a typical c ase of a longproducer that underwent waterflooding and the
tion obtained by other methods including otherlogs
chances of bypassed oil are very much there.such as the EPT log, and the core analysis Fig.(1) shows what the problem would look like on
results ,within a tolerance of ~ 7%. a resistivity log,where a new water zone hasformed within or above the oil zone. That watim
INTRODUCTION zone has the characteristicthat its SP curve
In many fields that use water or steam flooding,full deflection d oes not reach the SSP value of
the problem of fingering and bypassing some of thethe clean thick adjacent w et zone that was notmixed with the flood water. Yet, the resistivity
oil zones frequentlyhappen. As a rasult, programs log shows low resistanceindicatingwater in the
are made to recover the oil that ia left behind in formation.fhisndicatesthat those two waters arathese secondary recoveredreservoir, The questionbecomes; Howmuch oi l is lef t behind ? .
different;the newer being fraaher.
The problam now is that the pay zone is partly The solutionsuggestedin this paper will uti lizeflooded, that leaves the old oil zone split by a the conventional Archies (Pickett) crossplot ,new water zone or any other shape that might formdue to tha new presence o f the flood water. The
with some importantmodificationsto suit the newsituation. From there we will arrive at a new
new water zone, however, does not have the same defined 100Q water line ( Ro-Line )which containssalinity as the flood watar or the original format-ion water, but rather somte sa linity inbatweeq,
the new water regardlessof ites mixture, and that
that makes the saturationevaluationfrom resiswill be our base line for evaluating t he satura-
tivity curvas a cotspltcatedroblem. (Rwwill varytions of the adjacent oil zones, ( in this casecould be above or below it, as shown in the
...----.-....e..........-.--References and +llustrationnat end of paper.
figuresattached of walls lB&2B).
-.am
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2 S ATU RATI ON E VALU ATI ON OF S ~ ~ ARy R~ ~ ~ ~ .RE D R~ = Rvo~ s SPE 2(X)95-. .-. .. - -- .-. -- --.- .Statementof TheorY and Definitions where there is compaction ,or steam flooda that ~
Our fundamentalequation %s Arcnies eq,:-could desolve some of the grains of the formation,the value of m w ill change and a solution to
Swn - Ro/Rt-~w/Rt . . . . . . ... 1that is also proposed in this study.Shel l proposed for m an equat ionwhich dependa
m on poros ity :Where F- Formation Factor = a/ l . . . . (2) m- 1.87 + 0.019/fJ . . . .(8)
aleo F Ro/RW . . . (3) B/ a : FormationFactor Constant :-
substituting(2) in (3) we getm
1- Surface conductanceand ionic mobflity in wateti
Ro-aRw/fl . . . . . ...(4)films: * Cations Exchange Capacity (CEC).
that leads to* @sntity of water absorbed to clay
particles.
logRo - log (sRw) - m log(~) . . . . . (5)2- Salinityof the formationwater.3- Wettabtlityrelationsbetween particular solid
lhis is a straight l ine on a leg log plot ofsurfaces and the Hydrocarbon.
Resistivity (Ro) vs Porosity , with a slope (-m)4- Presence and distributionof electrical
and intersects $-1 at (eRw).conductive solid minerals.
Ro points are the lowast NE values of the RtHere we can see that a could possiblychange and
points in the original formationwater setup.for tha t reason this paper works wi th the value ofSRw. If an accuratevalue of Rw-new could be
In the case whera there is no sufficientvariationdetermined, then the value of a couldbe calcu-lated. Values of a vary bemieen [0.6 - 2.0]
of porosi ty to const ruct such a plot, then eq. (5)mostly considered-1.0could be rewritten as:
LogRo- -mLog (RHO -RHO )+Log(aRw) . .(6)C/ n: Saturation exponent
ma log 1- Volume percentageof oil.or
Log Ro = -mLog (Dt - Dt )+1.og(aRw) . . .(7)2- Distributionof oil.
log ma3- nettability to 011,4- Degree of interconnectedbodies through pores.
Conventionally this wouldbe a way to determine5- Interracialtensionbetween brine and oil.
the values of the Cementation Factor (m),6- Degree of electricalisolationdue to wetting
and by Oi~.knowingRw, then the constant (a) couldbe deter-mined. nvalues normal ly range between 1.2 - 2.2 taken
This Ro-line would represents100% Sw line, satu-mostly as 2, however this method will allow forvarying the value of n .
rat ion of any point could be calculateds imply by A widely used formula isreading its resistivityRt value, and project i t 2.15vertically (constant~) to the Ro line to get Ro, F-O.62/$fthen the water saturation of this point is the 2value givan by equation (1). or F .81/~
The limitationsof such techniqueare:-called Humble equation for sands.
Other aquations used;2
1- For use in clean reservoirs rock, as shaly F- l/@ for compacted f ormations androcks wil l cause sw to be predicted too high. chalky rocks,
2- Format ionmust have the same minera logy, for The presence of oil and gas produces n valueacomplex ltthology m will vary from one type ofrock and porosity to another.
which vary with saturationand nettability. Inwater wet systems containingwater and oil , when
Figure (2) shows the conventionalArchies cross-oil saturation f s below critical, o il exists inInsular globules.
plot.Theapherity of the globules
Factors Effecting the Values m,a,nwill depend on its size with respect to the size
of the pore, and the inter racial tens ion betwaenA/ m:Cementation,Tortuousity,or Shape Factor:- the reservoirwater and the crude oil . Aa spherity
decreases, the saturat ionexponent n wi ll in-1 . pore Geo~try: ~ surfacearea, vohlme Of ~raill- crease. n increaseefurthetwhen oil saturation
angularity - spherity. is above critical nd insular g lobules of oil ce~nt.ation- compaction. become intcrconnactedthroughouttha porous meclia.* ~ifomity of mtneral mixture. As oil saturation increases,the electrical fnter-
2- Anisotropy ference producedby the oil increases, that causes
3- Degrae of electric isolationby cemantat$on. n to ksep increasinguntil the water volume has4- Occurrence of an open fracture. been reduced to irreduciblefiha.
m valuee will range from 1.3 for fracturedrocks Looking t the factors ffecting m ad m wto 3. nom the factors bove we can see that it find that we could asstwa that m would stay thewould be reasonable assumption for thie paper to same, nd a would clmWe ali@tlY~
conai&r ths value of m to be constant. Xn casee*-
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SP E 2009s M OH AM E D N . H AW I E M 3
tioweverto account for the disturbance in the clay is the porosity corrected for wet clay.Mstr ibut ion or content of the porous media that If the new point falls on the water line, thiscould influence these parameters, this study will is the EffectivePorositydaal wfth the effective p orosity ($e), and dealwith (sRw) as a term, and leave the value of (n) 8* If the new point crosses the water &_ne, someto the different u sers to apply their imperical Hydrocarboncorrec tion fs then needed . Forvalues. that determine tho Hydrocarboneffect direct-
ion and that is ganerally in the NE direction,TECHNICALAPPROACH so its corracti.onis in the opposite direction
to bring our new point dotinto the water l ine.This paper s approachwill differ from the origi- That is the Effective Porosity corrected fornal Pickett work in the followtngways:- Hydrocarbonand shale effect.
I . Model assumed is the Dual Water Model, 9* If the new point stops before the water line ,~ (3-3a-4) shows the distributionof the then heavymineral correction is needed tofree and bound water, and it couldbe summed bring it up to the water line and that willup in the following form:- give you the effective porosity, corrected for
shale and heavy mineral effect.$lt= ~e +$ne
10* To find the total porosity, one must first11.Porosityused is the Effective porosity (Oe) determine the clay density,thatwould inters-
which is the HydrodynamicallyEffective Poros- ect the extension of the lime connectingthaity. water point(l,l),withthe wet clay point (WCP)
at the Dry Clav Point. Any line drawn paralle lNote in Fig-3A, that the irreduciblewater satura- to the line connectingthe matrix point to thet ion is par t of the free water, while the bound dry clay point, f~om a given originalpoint,water is part of the bound water saturation. will intersectthe water l ine at the
Total Porosityof that point.Fig-4 shows the increaseof shaliness,ina model.
Figure (6) shows actual log values plotted beforecorrection, and figure (7) the same points aftercorrection,on the water line, giving the EFFEC
To determina Pe there are numerous methods, one TIVE POROSITYvalues used in this study.of tha ways could be obtained through computerprograms in the logging unit, provided a dual III. Rt: True FormationResistivitywater modal is used for clay correction.A graphi-cal method will be introducednext. This term is obtained from the DUS1A graphical way to get $e ie :- Water Model, where :-
1* Plot (~ ) or Bulk Density Vs (p ), Rt - f(~e,fie), but @ -$e +flneD N then
and construct the graph shown In Fig.(5),. Rt - f(~t) , and
include in the plot points .:romclean wet Total Water Saturation; Swt- f (Rt,@).zonesa as well as some shaly zo..ws. As we are seeking tha effectiveSw, for bette r
Hydrocarbon saturationdetermination,2* From the origin ,0 draw a ta~gent line to then
to the cluste r of poin ts to touch them at thai r Swe-f(Rt,~e) . . . . . . . . ..(9)lowest point.Point(O,O)is the [matrixpoint].That line is the [Shalinessline]. The material Balance for hydrocarbon volume in
water wet rock:-3* Froa the point(l,l) [Waterpoint] draw two
l ines; one to point (0 ,0) -that will be the ( l-Swt)jZt- (1-Swe)j%e. . . . . . . . (10)effective porosity or clean matrix lina. thenThe second line is a tangent to the cluster of Swe - l-[@(l-Swt)/~e] . . . . . . (11)pofnts to touch them at the most southwest wherepoin t. That is the [Wetness Line]. Swe ~ Swt
A* The intersectionbetween both tangents,thewetnass and the shaliness,will give the
JWET CLAY POINTI.PROCEDIJRBOF SW DETBRHINATION
5* Scale the Shaliness line linearly from ZeroIf old logs, of a near by well that were recordedbefore the flooding took place, are available,
at the (0,0) point, to 100* at the wet clay - then construct the [Resistivity- Porosity] plotpoint. disczsviearlier. If both density and neutron
6* calculate the shale volume Q by any method,logs wede recorded, then follow the proceduredescribed above to coma up with the effective
preferably by the neutron-densitymethod, andapply it to the shale-l inescale, and
porosity, nd evaluate the value of m and (sRw)
measure the equivalentlength on that scale.old. Then follow the following steps from step l.Wa will discuss both situations,but first;
7* maw fr~ eve~ Qoint a parallel ltne to theshale line , and mark the measured length ofstep 6, start ingfrom the point Itself. that
H
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4 SATURATIO N 13VALUAIfONOF SIKCXQ13ARY R~VRl?l?D RI? W?RVOIRS S P E 2 9s.. --- .... . -- . - -.-
If the old 10KS are not available,using new re- The S@xration determinedby thi method greedcorded logs. the most with the cores with a difference of ~ h
and by -10% to GST Saturation, and =6* to the UPTSaturations. The differencewith the SPT and the
1* Pick a wet zone, on the new log, that would GST Saturations is influenced by the fact thatsti ll show the old formationwater, in the example they investigate in the inva&d zone, and as theshown in Fig.(l) that was the upper water zone, as oil in this case is quit heavy the dffferance isthe most llkely explanation shows that the upper not much. Results were also compared with comput-portion of the otl zone wae sweptby the flood. arized packages of ~gging Service c~aniee and
it agreed with around the seas tolerance.CONCLUSIONS
Cautisn should be noted , in excluding the zonethat the higher resietive wet zone ie not due to * The saturation values can be &termined withless porosity. Read several points in both old reasonable accuracy from the Resistivi.ty Veand new wet zones, as wall as the oil zone to be EffectivePorosity Croesplot.That could raault inevalua ted,p lot them on the Log-Log plot of Rt vs huge savinge due to less cortng needed.~e obtainedby the method explainedbafore.
* Old records of the f ield are very deeirable to2* Pace a line through the lowest NW old water determine the original formationparameter morepoints. Find the slope (ml); and the value of(al*Rwl)at the intersectionwith ~e-1,
accurately , however, if not vailable tha resultscould be still cbtained , as euggasted by thispaper, by searching for a zone that was not flocd-
Slope m - [Lcg(sRw) - Lcg(Ro)] / Log 06 ed and obtaining the originalwater parameters (m).,. (12) and (sRw).
The value of Rol is the value read on the Ro-lineof the vertical projectionof the point (Rtl,$el). * The values of (m) could be accurately deter-
mined, if the effective porosity ie used. That3* The new lowest N Ewet points should fit a will correct for the shale effect, also will leadparallel line to the old Ro-line. This parallel to Swe.line is displacad away due tls difference of6al inity between old and new waters. I f tha mate- * Applicationof such a method is scheduledto berlal balance of the formation was not tested in different lithologies, ndwith differ-maintained;(i.6. injactisn r ate is not equal to ent types of flood recoveries, co test for thethe productionrate) and subsidenceoccurred, the saturations.value of (m) could changa for the new water zone.In that case find the mean ovar the new water zone NO14SNCIATUREp o in t s a n dp a e s a parallel l ine through it , thatwill ba the new Ro-line, for t ha t c a se La t er Bou nd Wa t er : Layer of water h e r i n g to thecompare this l ine and the value of (m) to another shales, describedby Rwb,Swbnwell were the same subsidence problem did not Free Water : All water not bound, describedbyhappen. Rwf - Resistivityof free watar
includtng the irreduciblewater5* That new Ro-line becomes the basis for thenew ttaturationevaluation.Its intersection with Total Porosity :*Fractionof unit volume occupied~e-1, gives (a2Rw2) by fluMs* - ~t
Effective Porosity :Frac tion of unit volume6* Simply for any oil zone point of a value containing the free water(Rti, jlei),rop verticallyto thenew Ro line and and Hydrocarbonsa- ~,read Roi,then the EffectiveWater Saturationis :: Rt - True formationRe6istivity (oh@.
Rw -Resist ivity of FormationWater (ohm).Swen - Roi/Rtl Rwf. Resistivlty of F r ee FormationWater.
Rwb - Reeistivityof Sound Water.7* The value of tha maturation exponent (n)could be elways aesumed the old value as its Swt - Total Water Saturation.change, if ny, will change the maturation values Fractionof total porosity occupiedby
obtained very slightly .water - both bound and free
RESULTS COMPARISON Swe - EffectiveWater Saturation.aFraction of I occupied by water-.
Figures 7A and 8 show ct@ &ta points frOa 2S* . go@ Water Saturation.
di fferent wel16 that showed two different poei-Vrac t ion of ~t occupied by bound wat*rm.
tio-l~for the new water line, one was less resls-t iv~ (fig.-k), and the other more re8istive. n
- Saturation Exponent in Ar c h ie s equstton.
In both cases the Swe wa calculated t o the newm - Ce?aentatfon,Shapa, or Tortuousity Factor.
lines os shown on the ftgures . RNoma=llatrix density (gm/ce).
Reeults were compared to differant sources ofmeasurement, uch e core Saturationvalusa, EPTand GST logs Saturations.
-
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- ..VV. LV8US lruvu lx. Ku-Aim SsaLra
RHOlog- Log density value (bulk density) - gin/cc. 5- Fricke,H. :llm Electric Conductivityand Cap-acity of Disperse Systems
Dt -Matrix transit time (u/ft). Physics,Volume 1. August 1931a
Dt = Log intervaltransit t ime, 6- Norris ,R.L.and Biggs ,W. Using Log Derivedlog Values of Water Saturationand Porosity,
Trana., SPWLA, 1967REFERENCES
7- Pirson,S. :FactorsWhich Effect True Formation1- Archie,G.E.: The ElectricalResistivityLcg Resistivity. Oil & Gas Journal Nov.-1947
es an Aid in DeterminingSome ReservoirCharacteristics.AIMME Ott.1941. 8- Porter,C. and Carothers,J.:FormationFactor -
PorosityRelation Derived from Well Log Data ,2- Ransom,R. :Tha Bulk Volume Water Concept of Trane. SPWLh 1970
ResistivityWell Log Interpretation.Lag Analyst - Jan.197& 9- Wexman,M. and Smits,L.:ElectricalConductivi-
t iee in Oil Bearing Shaly Sands. SPEJ June 683- Serra,O. :Fundamentals@fWell Log
InterpretationPart Two, ELSEVIER 10- Wyllie,M. and Gregory,A, : FormationFactorsBook Ser ies - 1989 of UnconeolidstedPorous Media: Influence of
Particle Shape and Effect of Cementation.4- Atkinson and Smith :The Sigrdficanceof Parc- Paper 223-G, AIMS, Houston,TexasOctober 19S2
icle Shape in Formation ResistivityFactor -Porosity Relationship. JPT 1961 11- Serra,O. SedimentaryEnvironmentsFrom Wire-
line Logs Schlumberger 1989
m
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SPE 20095
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Simple ARCHIES Cross PlotLog Ro Log (aRw) - m Log
100
10
1
0 w-4--- I I I I I I
I I I
. SPE 20095
0.1 I II I I 1 1 , 1
0.1 1Porosity
FIG 2
DUAL WATER MODELFREE & BOUND WATER
rs Sw I SwHC F B
ar
FIGURE -3
EFFECTIVE & TOTAL POROSITYSHALY SANDS
b TOTAL
EVOLUTION OF TOTAL POROSITYWITH SHALINESS
FIG. 4
m
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1.0
Buk
gin/ccD
NEUTRON - DENSITY CROSSPLOTEFFECTIVE POROSITY DETERMINATION
Water poin
\
gas correction ;O z
N.
2
1,1)
\o 0. 1 0. 2 3 4
d
6 6 7 8 9 1
NEUTR POROSITYeavy$~i},
/
\/DllYCLAY R?iNT
qg. s4nphkdrnbthodc+f 6@urA%th.
YHX1=KHUB (&-c3> Y} Ull=llmlt0.0 .16667 .33333 .50000 .66667 . e3333 1.0
1.0
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2.2:
.
2.6
~,:y,./
3*O ,-----------
~lE JTRON pOFiOSlry~ - -- xrUtl-l DEtlW1=I PIII (Ssfw)
PLOT OVER DCPT,HS 2666 TO t?154 fTPtm IS wtc..m=T:v= puRusITVS
Fb.-- d dbUtdm*b-h~* ~
no
00
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rlii~ a OS-MY-ES 10:03
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YAX1=RHOB (WC3> YrUH=I0.0 .16667 3
. .
PLOTPHIE
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r
67 . e3 33
ARCHIES CROSSPLOTWELL lB
sPE 2009s
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Rt10
1
0.10.1
EFFECTIVE POROSITY
Ro LINE1 + HC VALUES * new Water
R3.7a-mmm@90fRo (Ilmv)do(om
1
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wELL 2BOLD/NEW WATER
I , 1I 1 1t \\ f
1&
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I I I m= i I Im .2.0 I I I I I
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0.1EFFECTIVE
1
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ORIGINAL + NEW WATER
m. M*>RO*.
I
an