water weakening!of!chalk!– insight! … ww... · subsidence due to fluid withdrawal, developments...
TRANSCRIPT
Water Weakening of Chalk – insight from lab experiments and numerical
modelling
Aksel Hiorth [email protected]/[email protected]
25. April 2016 University of Stavanger
Work supported by
• Ekofisk & Valhall license – BP Norge AS and the Valhall co-‐venturer; Amerada Hess
Norge AS, AND ConocoPhillips and the Ekofisk co-‐venturers, including TOTAL, ENI, StatoilHydro and Petoro
• Norwegian research council • IOR Centre of Norway ( www.uis.no/ior )
Research Team • Rock mechanics
– Merete V. Madland (UiS), Reidar I. Korsnes (UiS), Anders Nermoen, Kim Andre N. Vorland (UiS) MegawaX MegawaX (UiS, now Statoil) , Ola KeXl Siqveland et al.
• La=ce Boltzman-‐ reacAve flow modelling – Espen Je[estuen, Jan Ludvig, Janne Pedersen, Olav Aursjø, Aksel Hiorth et al.
• SEM-‐Sub micron – Mona Minde (UiS-‐IRIS), Tania Hildebrand-‐Habel (IRIS, now at the Norgwegian
Petroleum department), Udo Zimmermann, Wenxia Wang (UiS) • Field Scale simulaAon (IORSim)
– Jan Sagen(IFE), Jarle Haukås(Schlumberger), Arild Lohne(IRIS), Jan Nossen(IFE), Jan Ludvig Vinningland(IRIS), Terje Sira (IFE), Aksel Hiorth et al.
Ekofisk compacAon IniXal: T=130C
σv =62 MPa pres=48 MPa ⇒𝜎↓𝑒𝑓𝑓 ≃14MPa
During primary depleXon: p↓res ≃24MPa⇒𝜎↓𝑒𝑓𝑓 ≃38MPa
ProducAon History(*)
Autumn 2006 57
inelastic deformation and substantial strain. The onset of inelastic behavior occurs at theendcap, a surface in stress space that connects tothe shear-failure line at high shear stresses.However, inelastic compaction alters the chalk,moving the endcap location to the highereffective-stress condition.
As a result of compaction, the subsidencerate in the mid- and late-1980s was about30 cm/yr [1 ft/yr]. The resulting loss of air gapand potential impacts on platform safety becamea major concern. The 6-m increase in platformheight in 1987 was performed to increase the airgap between the lower decks and the expectedmaximum wave height.
In 1980, waterflooding was not initiallyconsidered a viable option in the Ekofisk fieldbecause tests indicated that the chalk was atbest intermediate-wet and at worst oil-wet,reducing the water imbibition that aids water -flood efficiency. Nonetheless, the Ekofiskpartnership felt the potential production gainswarranted a small waterflood pilot, which wasinitiated in 1981.23 The results from the pilotwaterflood suggested good oil displacement andlimited early water breakthrough.
Operator Phillips, now ConocoPhillips, beganstaging a full-field waterflood in 1987. It wasdesigned as a production enhancement mech -anism, with voidage balance achieved in 1994.Despite this, the subsidence rate remainednearly constant as waterflooding continuedunder voidage balancing, reaching a maximumrate of 42 cm/yr [16.5 in./yr] in 1998 (above right).
A new complex of platforms was installed,both to withstand the continuing subsidence andto provide more facilities for an expansion offield activities.24 During the changeover from theold platform complex to the new Ekofisk IIcomplex in late 1998, water injection continuedwhile production was halted for several weeks.During this period, and continuing since then,the subsidence rate decreased dramatically to acurrent rate of 15 cm/yr [5.9 in./yr] (right). Whilea reduction in subsidence rate such as this hadbeen considered by the operator as a possibility,
its magnitude was unexpected, based on the fieldsubsidence history.
The voidage balancing condition achievedduring the mid-1990s should have slowed themechanical compaction, because the effectivestress was no longer increasing. With voidagebalancing, and later repressurization, companyscientists expected the formations to stop
compacting in that time period, and perhapsrebound slightly, but this did not happen.Although creep in the overburden can cause adelayed reaction between compaction andsubsidence, the time delay would not be years, asseen with the subsidence-rate decrease thatfinally began in 1998.
22. Colazas XC and Strehle RW: “Subsidence in theWilmington Oil Field, Long Beach, California, USA,” in Chilingarian GV, Donaldson EC and Yen TF (eds):Subsidence Due to Fluid Withdrawal, Developments inPetroleum Science 41. Amsterdam: Elsevier Science(1995): 285–335.
23. Thomas LK, Dixon TN, Evans CE and Vienot ME: “Ekofisk Waterflood Pilot,” Journal of PetroleumTechnology 39, no. 2 (February 1987): 221–232. Originallypaper SPE 13120, presented at the SPE Annual Technical Conference and Exhibition, Houston,September 16–19, 1984.
24. For more on the Ekofisk platform complex upgrade:“Ekofisk Phase II Looks to the Future,” Journal ofOffshore Technology 5, no. 4 (November 1997): 27–29.
> Ekofisk field production history. The oil rate (green) declined until large-scale water injection (blue)began in the late 1980s. The average reservoir pressure (dashed curve) also decreased until thewater-injection rate increased in 1995. However, the subsidence rate (red) at the hotel, or quarters,platform did not decrease until production was shut in during the transition to the Ekofisk II complexin 1998.
Prod
uctio
n an
d in
ject
ion,
thou
sand
bbl
/d
500
400
700
600
900
800
100
01971 1975 1979 1983 1987 1991 1995 1999 2003 2007
300
200
Subs
iden
ce ra
te, c
m/y
rPr
essu
re, h
undr
ed p
si
50
40
70
60
90
80
10
Average reservoir pressure
Water injection
OilOil
0
30
20
Year
Subsidencerate
> Subsidence and pressures in the Ekofisk field crestal area. Pressure measurements in wells in thecrestal area follow a trend (blue) with a rapid increase in mid-1998 that corresponds closely to theslowing of the subsidence rate (red).
Pres
sure
, psi
7,500
7,000
6,500
6,000
5,500
5,000
4,500
4,000
3,500
3,0001974 1978 1982 1986 1990
Year
Subsidence rate
Pressure
1994 1998 2002 2006
Subs
iden
ce ra
te, c
m/y
r
45
40
35
30
25
20
15
10
5
0
59100schD07R1.qxp:59100schD07R1 11/20/06 10:01 PM Page 57
(*)Doornhof D., KrisXansen T. G., Nagel N., Pakllo P., Sayers S. “CompacXon and Subsidence”, Oilfield Review (2006)
Field observaAons of Water Weakening(*)
(*) Doornhof D., KrisXansen T. G., Nagel N., Pakllo P., Sayers S. “CompacXon and Subsidence”, Oilfield Review (2006)
6yrs CumulaAve CompacAon before water front
2yrs CumulaAve CompacAon aSer water front
CompacAon in lab experiments
Isotropic pressure
L
Stress
Water injecXon
0
0
L LL
ε−
=
Strain
σ↓𝑟
𝑑𝑃
σ↓𝑎
HydrostaXc tests 1. Saturate with injecXon
fluid 2. p=0.8,𝜎↓𝐴 , 𝜎↓𝑟
=1.3MPa 3. Heat to 130C 4. Raise 𝜎↓𝐴 , 𝜎↓𝑟 to
~10MPa 5. Observe creep at const.
stress 6. Pass fluid through core
Chalk strength depends on pore fluid
0
5
10
15
20
0 5 10 15 20
Average effective stress, p' (MPa)
Gen
eral
ized
she
ar s
tres
s, q
(MP
a)
W ater
Methanol
Oil & Glycol
"Dry" chalk
Glycol and water are fully m iscible fluids
σ↓𝑟
σ↓𝑎
𝑞= 𝜎↓𝑎 − 𝜎↓𝑟 (→0 hydrostatic)
𝑝↑′ = 1/3 (𝜎↓𝑎 + 2𝜎↓𝑟 )− 𝑝↓𝑝 (→𝜎↓𝑣 − 𝑝↓𝑝 ℎ𝑦𝑑𝑟𝑜𝑠𝑡𝑎𝑡𝑖𝑐 ) R. Risnes “Deforma)on and Yield in High Porosity Outcrop Chalk”, Vol. 26, No. 1-‐2, pp. 53-‐57, 2001
HydrostaXc test
Why are the cores weaker in water? • The principal mechanism causing the water
weakening effect is apparently related to the added pressure on the grains caused by a[racXon of water molecules to the chalk surface. The adsorpXon pressure acts like an increase in pore pressure, and thus decreasing the cohesion of the chalk R. Risnes, M. Madland et al. J. Pet. Sci Eng (2005) Water weakening of chalk— Mechanical effects of water–glycol mixtures
AdsorpAon pressure & surface tension • Pore collapse à creaXng new surfaces
A. Røyne, J. Bisschop, D. Dysthe, “Experimental investigation of surface energy and subcritical crack growth in calcite”, J. Geophys. Res. 116 (2011)
⇒𝑌𝑖𝑒𝑙𝑑 ~ 𝛾↓𝑐𝑐
(𝑌𝑖𝑒𝑙𝑑↓𝑑𝑟𝑦 /𝑌𝑖𝑒𝑙𝑑↓𝑤𝑒𝑡 )= 18𝑀𝑃𝑎/10𝑀𝑃𝑎 =1.8
(𝛾↓𝑑𝑟𝑦 /𝛾↓𝑤𝑒𝑡 )= 0.32𝐽/ 𝑚↑2 /0.15𝐽/ 𝑚↑2 =2.1
ExplanaAon for field water weakening?
0
5
10
15
20
0 5 10 15 20
Average effective stress, p' (MPa)
Gen
eral
ized
she
ar s
tres
s, q
(MP
a)
W ater
Methanol
Oil & Glycol
"Dry" chalk
Glycol and water are fully m iscible fluids
0
2
4
6
8
10
12
0,0 0,2 0,4 0,6 0,8 1,0 1,2 1,4
Axial stress [MPa
]
Axial strain [%]
L15, NaCl unaged 20C
L27, NaCl unaged 20C
L39, NaCl unaged 130C
L38, NaCl unaged 130C
L20, NaCl aged 20C
L22, NaCl aged 20C
L14, NaCl aged 130C
L33, NaCl aged 130C
Seawater weakens at high T
0
2
4
6
8
10
12
0,0 0,5 1,0 1,5 2,0 2,5 3,0
Axial stress [MPa
]
Axial strain [%]
L19, SSW unaged 20C
L25, SSW unaged 20C
L34, SSW unaged 130C
L35, SSW unaged 130C
L31, SSW aged 20C
L32, SSW aged 20C
L6, SSW aged 130C
L13, SSW aged 130C
~25% reducXon in Yield
and weaker than NaCl
Seawater affects creep
0,0
0,2
0,4
0,6
0,8
1,0
1,2
1,4
1,6
1,8
0,0 5,0 10,0 15,0 20,0 25,0
Seawater
DW
PV
Axial Strain (%
)
What can we learn from geochemical modelling?
• HKF EOS(*) makes it possible to predict logK, Gibbs free energy, Enthalpy, heat capacity … at high P & T
• Seawater in equilibrium with calcite @ 25C and 130C
(*)Johnson et al. SUPCRT92: A soxware package for calculaXng the standard molal thermodynamic properXes of minerals, gases, aqueous species, and reacXons from 1 to 5000 bar and 0 to 1000 C, Comp. Geo. Sci., 1992
Seawater chemistry
Ion Molality
Na+ 0.48
Mg2+ 0.054
Ca2+ 0.010
K+ 0.010
Cl- 0.56
SO42- 0.028
HCO3- 0.0024
CO32- 0.00027 4
4
4
4
4
4
4
4
4
4
4
4
,
,
,
,
24
04
24
204
244
244
CaSO
SOCaCaSO
MgSO
SOMgMgSO
KSO
SOKKSO
NaSO
SONaNaSO
aaa
KSOCaCaSO
aaa
KSOMgMgSO
aaa
KSOKKSO
aaa
KSONaNaSO
=+→
=+→
=+→
=+→
−+
−+
−+−
−+−
Sulphate species, similar equaXons for other species
Result, 25˚C and 1 bar Ion Molality
(Total) Free Ion (percent)
Me-SO4 Pair (percent)
Me-HCO3 Pair (percent)
Me-CO3 Pair (percent)
Na+ 0.48 99 1 0.04 0.006 Mg2+ 0.054 86 13 0.6 0.4 Ca2+ 0.010 90 9 0.6 0.1 K+ 0.010 98 12 - -
Ion Molality (Total)
Free Ion (percent)
Ca-anion Pair (percent)
Mg-anion Pair (percent)
Na-anion Pair (percent)
K-anion Pair (percent)
SO42- 0.028 52 3 26 19 0.6
HCO3- 0.0024 76 3 14 8 -
CO32- 0.00027 9 7 72 12 -
Cl- 0.56 100 - - - -
Result, 130˚C and 8 bar Ion Molality
(Total) Free Ion (percent) Me-SO4
Pair (percent)
Me-HCO3 Pair (percent)
Me-CO3 Pair (percent)
Me-Cl Pair (percent)
Na+ 0.45 86 2.6 0 0 11.4 Mg2+ 0.045 72 23 0.03 0.02 5 Ca2+ 0.011551 82 15 0.02 0.07 3 K+ 0.01 99.96 0.04 - - -
Ion Molality (Total) Free Ion
(percent) Ca-‐anion Pair
(percent) Mg-‐anion
Pair (percent)
Na-‐anion Pair
(percent)
K-‐anion Pair
(percent)
SO42-‐ 0.024 0.7 7 43 49 0.002
HCO3-‐ 5.13E-‐05 69.6 5 25 0 -‐
CO32-‐ 1.73E-‐05 5 47 48 0 -‐
Cl-‐ 0.525 90 0.08 0.4 9 -‐
Mg, SO4 in seawater alter mineralogy in core Mineral SSW
Q/K SSW wo/SO42-
Q/K SSW wo/SO42-,Mg2+
Q/K SSW wo/Mg2+ Q/K
Dolomite CaMg(CO3)2
2.16 2.2 - -
Dolomite(ordered) CaMg(CO3)2
2.17 2.2 - -
Dolomite(disord.) CaMg(CO3)2
1.18 1.22 - -
Huntite CaMg3(CO3)4
1.98 2.09 - -
Brucite Mg(OH)2
1.37 1.41 - -
Magnesite MgCO3
1 1.04 - -
Anhydrite CaSO4
0.22 - - 0.35
Calcite CaCO3
0 0 0 0
”A Chemical Model for the seawater-‐CO2-‐carbonate system-‐aqueous and surface chemistry”, Hiorth, Cathles et al. SCA, Abu Dhabi, 2008
Seawater flooding dissolves calcite and precipitate Mg-‐carbonates & CaSO4
0
0.02
0.04
0.06
0.08
0.1
0.12
0.14
0 2 4 6 8 10 12
Con
cent
ratio
n [m
ol/L
]
Time [days]
CaCl
MgSO4SO4
MgCaCl
-0.02
-0.015
-0.01
-0.005
0
0.005
0.01
0.015
0.02
0 0.01 0.02 0.03 0.04 0.05 0.06Distance[m]
wt_calcitewt_dolomite
wt_anhydrite
-0.008
-0.006
-0.004
-0.002
0
0.002
0.004
0.006
0.008
0.01
0 0.01 0.02 0.03 0.04 0.05 0.06Distance[m]
dpor_totdpor_calcite
dpor_dolomitedpor_anhydrite
0.08%/PV dissolve & 0.07%/PV precipitates 0.01%/PV net change
Hiorth, A., Je[estuen, E., Cathles L. M., Madland M. “PrecipitaXon, dissoluXon, and ion exchange processes coupled with a lakce Boltzmann advecXon diffusion solver” GCA, 104 (2013)
Hypothesis: InjecAon water induces chemical alteraAon and affects Yield and Creep
• CalculaXons: If Mg and SO4 is removed from seawater à no(very li[le) chemical alteraXon
• 0.219M MgCl2 flooding à ~0.07 wt% alteraXon per PV à 100/0.07= 1429 PV replace all calcite w Mg-‐carbonates
Seawater (Io=0.657)
0.219M MgCl2 (Io=0.657)
0.219M Na2SO4 (Io=0.657)
Dolomite, hunXte, magnesite , … precipitaXon
Some dissoluXon of calcite (comparable with NaCl brine)
MgCl2 flooding of Liege chalk @130
Flood sequence: – 0.657 M NaCl brine 1-‐7 days – 0.219 M MgCl2 7-‐58 days – DisXlled water (DW) 58-‐65 days – 0.219 M MgCl2 65-‐1072 days
1-‐3PV /day à ~1880PV
Data: Nermoen, A. , Korsnes, R. I., Hiorth, A. ,Madland M. V. “Porosity and permeability development in compacXng chalks during flooding of nonequilibrium brines: Insights from long-‐term experiment” J. Geo. Res. Solid Earth , 120 (2015) Pore Scale Modelling: Pedersen, J., Je[estuen E., Madland, M. V., Hildebrand-‐Habel, Korsnes, R., Vinningland J. L., Hiorth A. “A dissoluXon model that accounts for coverage of mineral surfaces by precipitaXon in core floods” Adw. Wat. Res. 87 (2016)
Mg loss and Ca gain during flooding
Mg2+
Cl-‐
Ca2+
• Modelling highlight (Pedersen et al.):
• Literature dissoluXon rates too high – only match first week
• Explained by dynamic reacXve surface area
• Precipitated minerals partly covers primary minerals
𝜑(𝑡)= 𝜑↓𝜀 (𝑡)+ 𝜑↓𝑐 (𝑡)
𝑘↓𝐶𝐾 (𝑡)= 𝜑(𝑡)↑3 /2𝜏(1−𝜙(𝑡))↑2 𝑆(𝑡)↑2
10% deformaAon
Perm
Strain
compacAon = dissoluAon
compacAon
and permeability = f(φ, diss.)
• Increase in specific surface area explains drop in perm
• DissoluXon explains increase in porosity
• Measured: 𝝓(𝒕↓𝒇 )≃𝝓(𝟎)∼𝟒𝟎%
Specific surface area increases ! explains perm behavior
• 𝑘↓𝐶𝐾 (𝑡)= 𝜑(𝑡)↑3 /2𝜏(1−𝜙(𝑡))↑2 𝑆(𝑡)↑2
• (𝑘(𝑡↓𝑓 )/𝑘(0) )= 1.05𝑚𝐷/0.15𝑚𝐷 ≃6.7
• (𝑆(𝑡↓𝑓 )𝜌(𝑡↓𝑓 )/𝑆(0)𝜌(0) )↑2 = (9.4⋅2.9/3.7⋅2.7 )↑2 ≃7.4
3.56 m2/g
3.84 m2/g
8.85 m2/g
9.92 m2/g
𝜌(0)≃2.69g/cm↑3
𝜌(𝑡)≃2.9g/cm↑3
Pore scale simulaAon of alteraAon
5003 voxels @ 12.5 nm = (6.25 μm)3 350 voxels = 4.4 μm
Currently working with Sandia NaXonal Lab to obtain high resoluXon of chalk
Adding Ca stops creep and perm decline
0,00
0,05
0,10
0,15
0,20
0,25
0,30
4,0
4,5
5,0
5,5
6,0
6,5
7,0
7,5
8,0
8,5
60 110 160 210 260
Ion concen
tration [m
ol/l]
Axial creep
strain [%
]
Creep time [days]
0.219 M MgCl2 pH=5.80
0.219 M MgCl2 + 0.130 M CaCl2 + NaOH pH=8.9
0.219 M MgCl2 + NaOH pH=9.02
Calcium concentration
Original Ca2+ in 0.219 M + 0.13 M CaCl2 + NaOH
Magnesium concntration
Original magnesium concentration
Ca2+
Mg2+
permeability
Can Mg-‐alteraAon explain field water weakening?
• AlteraXon propagaXon is slow at high T • Temperature gradients in field will slow down kineXcs
• What about SO4?
0
2
4
6
8
10
12
0,0 0,5 1,0 1,5 2,0 2,5 3,0
Axial stress [MPa
]
Axial strain [%]
L14, NaCl aged 130C
L33, NaCl aged 130C
L4, MgCl2 aged 130C
L9, MgCl2 aged 130C
L10, Na2SO4 aged 130C
L17, Na2SO4 aged 130C
L6, SSW aged 130C
L13, SSW aged 130C
SO4 affects Yield (Mg less)
Liege chalk, Porosity = 40.3 – 41.8%
Na2SO4 @ 130C
Seawater @ 130C
Sulphate adsorbes
Megawati, M., Hiorth, A., Madland, M.V., (2012), The impact of surface charge on the mechanical behaviour of high-porosity chalk, Rock Mechanics and Rock Engineering-Springer
Increasing adsorption & ionic strength SO
4
0.219M Na2S
O4
Sulphate adsorpAon ! neg surface charge • Surface complexaXon model(*)
à predict 𝜓 from adsorpXon
(*)Hiorth, A., L. M. Cathles, Madland M. V. (2010). "The Impact of Pore Water Chemistry on Carbonate Surface Charge and Oil We[ability." Transport in Porous Media 85(1): 1-‐21.
𝜉↓0 ≡ 𝑒↑𝐹𝜓/𝑅𝑇
Weakening effect by disjoining pressure
• Disjoining pressure:
• Results from(*) shows that reducXon in Yield follows formula obove
Megawati, M., Hiorth, A., Madland, M.V., (2012), The impact of surface charge on the mechanical behaviour of high-porosity chalk, Rock Mechanics and Rock Engineering-Springer
𝐼≡ 1/2 ∑ 𝑍↓𝑖↑2 𝑚↓𝑖
Summarize Water Weakening
• Pore collapse due to – Lower cohesion – Surface tension (adsorpXon pressure) – Chemical effects
• Textural changes (dissoluXon/precipitaXon) (slow) (Mg-‐carbonates)
• Surface charge (fast) (SO4-‐absorpXon)
physical
Next crucial steps
• Can chemical water weakening explain Ekofisk compacXon?
• Need to Xe chemical alteraXon to field data • IOR Center project
– Add geochemistry to reservoir simulaXon – Predict alteraXon – Compare with Ekofisk data
IORSim(*)-‐An add on tool to ECLIPSE for fast and accurate simula=on of mul= phase geochemical interac=ons at the field scale
Eclipse
Reservoir simulator
IORSim(*)
advect components
Geo-‐chemistry
Restart Files Sw, Po, Pw, qw
…
Oil Rate
Water Rate SO4
Mg
(*)Hiorth, A., Sagen J., Lohne L., Nossen J., VinninglandJ., Sira, T.IEA, Sapporo, Japan (2015)
INJ I
PRD I
INJ III
INJ II
Simulated “Ekofisk sector”
Produced water composiAon
Mg ions
Reservoir pH
SO4 Model Constant Temp
SO4 Model Temp Gradients
IORSim Backward coupling
Eclipse Reservoir simulator
Files
IORSim
Geo-‐chemistry Temp
First step use Ocean technology Schlumberger
Example – core flood Run Eclipse
𝚫𝒕 Stop Eclipse process
Run IORSim 𝚫𝒕, calc X , calc X
Update SATNUM
Summarize • Lab Water weakening can be explained by:
– Change in surface energy (lower cohesion) – Chemical dissoluXon – InteracXon energy (disjoining pressure)
• Field water weakening: – Need to couple flow and geochemistry – Predict chemical alteraXon speed & compacXon – Compare with field data (IOR Centre)
45
Monitoring CompacAon. C-11A CumulativeCompaction Rate
9600
9700
9800
9900
10000
10100
10200
10300
10400
10500
10600
10700
10800
10900
-5 5 15 25 35 45 55 65 75
Cumulative Compaction Rate (cm/year)
Dept
h (ft
)
Jun94-Jan95 Jan95-Jun95 Jun95-Nov95Nov95-Jun96 Jun96-Mar97 Mar97-Jun97Jun97-Feb98 Feb98-Oct98 Oct98-Apr99Apr99-Jan00
• Results from compacXon monitoring tool can prove to be criXcal to understanding the nature of the compacXon phenomenon
• The water weakening effect on reservoir compacXon and seabed subsidence has been verified by direct field measurements including reservoir compacXon, water saturaXon and pressure profiles in a verXcal monitoring well
N. B. Nagel 2000
Sulphate adsorbes
Megawati, M., Hiorth, A., Madland, M.V., (2012), The impact of surface charge on the mechanical behaviour of high-porosity chalk, Rock Mechanics and Rock Engineering-Springer
Increasing adsorption
SO4