module b: in situ stresses
DESCRIPTION
Module B: In Situ Stresses. Earth 437 Maurice B. Dusseault University of Waterloo. Common Symbols in Earth Stresses. s v , s hmin , s HMAX : Vertical, minor and major horizontal stresses (usually s v to surface) S v ,S h ,S H : Same as above, different symbols - PowerPoint PPT PresentationTRANSCRIPT
Module B: Module B: In Situ StressesIn Situ Stresses
Earth 437
Maurice B. DusseaultUniversity of Waterloo
Common Symbols in Earth Common Symbols in Earth StressesStresses
v,hmin,HMAX: Vertical, minor and major horizontal stresses (usually v to surface)
Sv,Sh,SH: Same as above, different symbols 1,2,3: Major, intermediate, minor stress
1,2,3: Effective or matrix (solid) stress E, : Young’s modulus, Poisson’s ratio : Porosity (e.g. 0.25, or 25%) po Density, unit weight, pore pressure
k: Permeability (kv, kh…) These are the most common symbols used in
discussing stresses in the earth
Stresses in the Earth: Intro IStresses in the Earth: Intro I In situ stresses: a vital initial condition for
all geomechanics issues, not just drilling!To carry out any quantitative analysis, it is
necessary to start from the initial stress stateFor example, deep reservoir depletion can lead to
a Δp of perhaps -75 MPa, so that Δ‛v = +75 MPa. The stress change is what is important; it is
defined as Δ‛ = ‛ final - ‛ initial
This Δ‛ value is used to compute subsidence, rock behavior (shearing, collapse), and so on
In hard rocks (mining), []ij can be calculated from direct strain measurements – []ij
Stresses in the Earth: Intro IIStresses in the Earth: Intro II
In sedimentary rocks (oil and gas applications), it is far more difficultThe locations are deep, hard to get toAnd, the strains are small, hard to measureThe rocks are porous, poor strain response
So… hydraulic fracture-based methods are widely used - Minifrac™, LOT, XLOT
+Core-based methods (DSCA, vP(), …) +Geophysical logging based methods +Geological inference (burial and
tectonic histories of the basin give excellent clues)
Stress DefinitionsStress Definitions
hmin
HMAX
v
HMAX > hmin
a
rr = 3
a = 1
max planesslip
planes
TriaxialTest
Stresses
In SituStresses
11
2
2
3
1 > 2 > 3
3
PrincipalStresses
Borehole Stresses
r
r
ri
z
x
yWe usually
assume v is a principal stress
Local, Reservoir and Regional Local, Reservoir and Regional Scales Scales Regional Scale Stresses
Basin scale: 50 km to 1000 kmOften called “far-field stresses”
Reservoir Scale StressesA reservoir, or part of a reservoirScale from 500 m to several kmSalt dome region: 5-20 km affected zone
Local Scale StressesBorehole region: 1-5 mDrawdown zone (well scale) 100-1000 m
Small Scale Stresses (less than 10-20 cm)
~200 km
~4 km
~400 m
Common Stress RegimesCommon Stress Regimes
The most common stress regimes are:Relaxed, or non-tectonic (no faulting, flat-lying):
vertical stress, v, is = 1 (major stress)
Normal fault regime: v is 1
Thrust fault regime: v is 3 (least stress)
Strike-slip regime: v is 2 (intermediate stress)Listric (growth, down-to-sea or GoM) fault
regime: v changes from 1 to 3 at depth, then back to 1
Most sedimentary basins with O&G have relatively simple stress regimes
But, there are local complications, such as multiple faults, salt domes, uplift, etc.
Faults and Plate TectonicsFaults and Plate Tectonics
The Big Picture!
Regions of crustal extension
Compression region
Where Are Tectonics Important?Where Are Tectonics Important?
Near active plates (eg: California, Sumatra, Colombia), tectonics governs stresses
Near mountains, tectonic forces dominate Away from plate margins and mountains
(eg: Williston Basin, Kalimantan, GoM), other factors are important
In continental margin basins salt tectonics (domes and tongues) can be very important
In non-tectonic intracontinental basins (Michigan, Williston, Permian…), the shape and burial/erosion history are more important than tectonics
Basins: Major Examples in USABasins: Major Examples in USA
PE
RM
IAN
B
AS
INS
C
OM
PLE
X
WILLISTON BASIN
MICHIGAN BASIN
APP
ALA
CH
IAN
BA
SIN
Gulf Coast
Basin – G
oM,
passive or
relaxed b
asin
Paradox B.
Powder River B.
Rockies Foreland Basins, compressive stresses controlled by mountain thrust
San Joachim, a rift valley
Southern CA basin complex, strike-slip and normal faulting
Atlantic coastal plain and offshore basin complexes, passive margins
MIDCONTINENT BASINS
Thrust basins
Non-Tectonic RegimesNon-Tectonic Regimes
On stable continental plates, far from active plate boundaries. Some examples Mid-continent basins: Williston, Michigan,
Permian age basins, East Texas, Songliao Basin (richest Chinese basin), interior Russia…
On passive continental plate oceanic margins such as GoM, Kalimantan, Nova Scotia, NW Norway coast, Angola, etc.
Basin geometry, history of sedimentation, compaction, burial, erosion, diagenesis, salt dissolution features…, salt tectonics affect stress states locally & substantially
Stresses and Basin ShapeStresses and Basin Shape
Yuc
utan
Houston
New Orleans
Florida
Gulf of Mexico
USA
Mexico
Edge of continental shelf
Regional3 directions
Cross-section
shoreline
GoM example: regional stress directions are dominated by the continental slope, except locally near salt domes and a few structures such as the Mississippi canyon
listric faults
Normal Fault RegimeNormal Fault Regime
v = 1
hmin = 3
HMAX
=
The normal fault regime is also called the extensional regime. It is characteristic of shallow rocks in all non-tectonic sedimentary basins without large erosion.
The San Joachim Valley in California, the Rhine Valley between France and Germany, the Gulf of Thailand are all normal fault grabens
Horst-graben structure
extension
horstgraben
Some Classic Normal Fault AreasSome Classic Normal Fault Areas
Red Sea Around UK, Ireland
Normal Fault Zones (Pull-Apart)Normal Fault Zones (Pull-Apart)
Mid-ocean rifts East African Rift Upper zones, GoM Gulf of Thailand Upper Cook Inlet On flanks of thrust
faults, etc.
Normal Faulting RegimesNormal Faulting Regimes High angle faults at surface (60°-70° dip) This indicates that v = 1 when faulting
occurred. (But, is the fault old or active?)
Also, HMAX = 2 and hmin = 3
Characteristic of extensional strain Also, typical of non-tectonic basins Hydraulic fractures are vertical, to hmin
However, high angle surface faults may “flatten” at greater depth (as in the GoM)
Many continental margins, passive basins, regions of crustal “pull-apart” …
Strike-Slip or Wrench FaultStrike-Slip or Wrench Fault
Surfaceview
v = 2
hmin = 3
HMAX
= acuteangle
~vertical fault plane
hmin
Associated normal faults
HMAX
Block diagram
Strike-Slip Stress RegimeStrike-Slip Stress Regime
Very high angle faults (>80° usually) Indicates v = 2 (HMAX = 1, hmin = 3)
when the fault formed Characteristic of plate margins Common at depth in eroded basins Common some distance from
compression Usually, normal faults are found nearby at
the surface, away from the main fault trace, to accommodate strata movements
Hydraulic fractures vertical, to hmin
Small Window BasinsSmall Window Basins
Small “window” basins between strike-slip faults have complex stress conditions Small basin opened up
between parallel strike-slip faults. Locally, stresses can vary from normal to thrust regimes, very complex
Southern CA basin complex
San Joachim Valley Basin
Graben basin
15 km
Small basin
Thrust Fault Regime and Thrust Fault Regime and StructuresStructures
static basal sheet
overthrust sheet
brittle quartz-illite shale
hinge points
highly fractured zone
largely unfractured shale
AB C
The shale bed in zone A has gone throughone hinge point, through two in zone B, and through three hinge bends in zone C.
HMAX = 1
v = 3
overthrust sheet
compression
high-p shale
strong lateral thrust
RAMP
Thrust and Reverse FaultsThrust and Reverse Faults
Less than 45° angle on fault plane If less than 20-25°, it is almost always
called a thrust fault rather than a reverse fault
This angle is always less than 45°, usually less than 30°
Sometimes, thrust faults can take on very complex, stacked structures
Thrust Faults and MountainsThrust Faults and Mountains
AlbertaSyncline
Basinedge Canadian Shield
Williston Basin
The Western Canadian Sedimentary Basin
USA
ALTA SASK MAN
NWT Nunavut
BC
Canadian Shield
(Precambrian)
Ro
ckies
Athabasca Basin
EdmontonTectonic
stressBreakouts to HMAX
Alberta is the “classic” compressional (thrust fault) regime
Compressional Basin SectionCompressional Basin Section
Massive heavy oil deposits
+
++ +++
+++ ++ ++
+
+ ++
+ +
+
++
++
++
+
++
++ +
+
+
++ +
++ +
+
++ +
+
+
+
+ ++ +
+
Cretaceoussands, shales
Jurassic andolder carbonates,
sandstones, shales
Prairie Evaporites (halite)
Alberta SynclineRockies
Edmonton
Precambrian rocks
SW NE
not toscale
Schematic cross-sectionthrough Edmonton, Alberta
RegionalCretaceous
unconformity
Thrust faults
Salt solution andcollapse features
Devonian reefs
Thrust FaultsThrust Faults Low angle faults (dip of 0° to 30° usually) Indicates v = 3 (HMAX = 1) when the
fault formed (or if it is still active) Characteristic of compression regions,
associated with thrust mountain ranges Same stress condition can often be found
at shallow depths in eroded basins Usually, thrust fault “sheets” are bounded
by systems of normal and strike-slip faults Hydraulic fractures will be horizontal (in
fact, usually they propagate gently upward)
Cross Section: Stress & Cross Section: Stress & StructureStructure
Sing07.024
Mountains Distant plainsGolden Colorado Eastern ColoradoBanff Alberta Calgary Alberta
Near mountains:•Very high HMAX
•For great depth, v = 3 •Thrusts, folds…•Fractured strata•Low to modest po
Distant from mountains:•Moderate to high HMAX
•For some depth, v = 3 •Flat-lying, no faults•Strata are relatively intact•Low pressures
HMAX HMAX
Generally very high pore pressures are not found in thrust regimes and their forebasins, as rocks are somewhat fractured, pressures dissipate
forebasin
Real Thrust Faulting StructuresReal Thrust Faulting Structures
Sing07.024
High stresses near the tectonic compression front
Lower stresses far from the tectonic compression front
Folded belt in front of last thrust
Rocks are permeable because of fractures and folds, po is rarely overpressured
Folding Thrust sheets Thrust fault planes Undeformed sediments
Moderate deep overpressure may remain in the deepest part of the foreland basin (po ~ 1.3-1.4 w·z)
Thrusting Aided by High pThrusting Aided by High poo
Sing07.025
0 10 20 3030 20 10
MILES
Axis of geosyncline
Eroded
Zone of abnormal fluid pressure
Normal faultsThrust fault
Undeformed
Undeformed strata
This is a massive gravitational “landslide” (Wyoming), similar to listric faults. This could not be possible without high local pore pressures in shales, which allowed the fault block to virtually “float” along the fault plane
Listric Faulting and StressesListric Faulting and Stresses
“down-to-the-sea” faults
zone where faults coalesce(detachment or décollement zone)
sea
slip planes
steepat top
v
h
stress
depth
Stresses change with z!
Listric faults on continental marginslead to unusual stress regimes wherethe major stress changes from vertical
to near-horizontal at depthgrabens
Listric FaultsListric Faults
Characteristic of passive continental margin basins that are “open-to-the-sea” (GoM)
Look like normal faults at the surface At depth, the faults flatten to become
thrust faults Stress regimes change with depth! Often associated with overpressured
zones These faults are like massive landslides
India and Tibet ExamplesIndia and Tibet Examples
Passive basins
Active basins
Bay of Bengal Region and NorthBay of Bengal Region and North
A continental margin basin exists offshore south of Dacca and Calcutta, we will expect a relaxed stress condition, GoM features
A strong thrust basin to the north, along the Himalaya front, fractures, no oil
Strike-slip to the east (Sagaing zone) Shan-Thai Plateau is partly a zone of
extension, some N-S faults are normal Sichuan Basin, relatively undeformed,
but under strong compression Etc.
Tectonic Structure Map of
the Region
Tectonics Give Stress State Tectonics Give Stress State CluesCluesThis NASA image of Ganymede shows complex tectonism, giving
clues about the stresses and dynamics which caused the structures
Shear zones
Normal faulting
Extraterrestrial Geomechanics!
North Sea Stress TrajectoriesNorth Sea Stress Trajectories
From the World Stress Map Project
In the central part, complex of grabens and wrench faults
Many “blocks”, each with a stress pattern
Farther north, the Continental Shelf is “open to the sea”
Breakouts, LOT, HF tests…
North America (World Stress Map)North America (World Stress Map)
(available online at www.world-stress-map.org)
Stress Map of EuropeStress Map of Europe
Many solutions for earthquake focal mechanisms in southern Europe give the dense stress coverage
In the hard-rock areas – strain relief methods
In quiescent basins, data from breakouts, hydraulic fracturing, LOT
Geological History!!Geological History!!
This basin opened, filled, was compressed (thrusts and folds), uplifted and eroded
Later, it subsided with new sediment fill The different lithologies compacted
differently, leading to normal faults
gravelsclays and silts
20 – 100 km
3-10 km
Thrust condition
Relaxed stresses
Normal faults
Folds and closed structures
Conclusions on Tectonics and Conclusions on Tectonics and FaultsFaults The tectonic condition and the nature and
orientation of faults give important clues:The principal stress directionsThe relative magnitude of the stressesWhether stresses are intense or relaxed
To be confident of the stress conditions, the faults must be shown to be “active”
Geological history can be complex, giving different stress fields at different depth
The first task in a new area is to study the stresses and tectonic features
Burial and Diagenetic HistoryBurial and Diagenetic History
What controls stresses during burial? How do stresses change with diagenesis? What happens during uplift and erosion? Do all rocks behave the same? What happens if pore pressures change? When there is tectonic loading or
unloading, how are stress changes partitioned in strata?
Hydrocarbon generation effect? Etc, etc… (it gets complicated…)
Stresses at DepthStresses at Depth
σv from density logs, σhmin, σHMAX from various methods (geological estimation, HF…)
We often use the “K” coefficient.
Ratio of least horizontal effective stress to the vertical effective stress (in situ)
<1 – vertical fracturing >1 – “horizontal” fracturing
v
minh
ov
ominh
p
pK
Friction Angle Control of Friction Angle Control of StressesStresses If soft sediment is in a state of plastic yield
during sedimentation and burial: K’]min = (1 - sin )/(1 + sin ) (soft seds)
is the Mohr-Coulomb friction angle For loose sand: = 30°, thus K’]min = 0.33 For shales, much lower friction angles = 10°: this gives K’ = 0.70 We observe that horizontal stresses in soft
shale are much higher than in sands during burial, until sediments are indurated
Upper GoM, Gulf of Thailand…
Burial Stresses, Friction ControlBurial Stresses, Friction Control
Ka = 0.33
Ka = 0.70
Ka = 0.33
Ka = 1.0
po
Note: = - po
(Terzaghi’s law)
UC sand
shale
salt
sandstone E
0.5E
0.75E
salt is viscoplastic
These values are the limits, not actual values in situ
E = stiffness
Frictional Control of StressesFrictional Control of Stresses
In fact, the strata we encounter are rarely purely frictional materials
They also have cohesion The frictional stress control “model” is
only intended to give the theoretical lower bound of hmin for high porosity strata
If rocks are strongly cemented, it is possible to have stresses lower than this
In exceptional cases, open fractures!Shallow, above flanks of salt domes In mountainous areas
Stresses In and Around SaltStresses In and Around Salt
Salt is a very special material:Highly solubleLow density (2.16 g/cm3 or 18 ppg equivalent)Viscoplastic, so all stresses are the same
Drilling long sections of salt is a challenge Drilling near salt structures such as
diapirs and sand tongues is challenging Therefore, a special Module on salt
drilling is included, and not treated here…
See Module G for a full discussion…
Deep Salt Diapir ExampleDeep Salt Diapir Example
Gas Pull Down
Mid-Miocene regional pressure boundary
Top BalderTop Chalk
Intra Hod/Salt
Sands and Shales, Sands and Shales, hh vs. Depth vs. Depth
0 0.5 1.0
hsand
~ 0.45
stress, units of density (/z)
depth
h
shalehyd
rost
at
= g
wz
mud
clay
mud-stone
shale
v, vertical stress
Ko - effective stress ratio
h/v h/v
depth
sands &sandstones
clays &shales
This modelapplies only to
upper 2000 m of soft sediments and
no tectonics!
~ 0.25
1.0 1.5 2.0 2.5
Stress plot (density) Stress plot (ratio of h / v) 2.0 = 16.7 ppg
( = Poisson’s ratio)
Porosity-Depth RelationshipsPorosity-Depth Relationships
mud
clay
mud-stone
shale
0 0.25 0.50 0.75 1.0
clay & shale,“normal” line
sands &sandstones
effect ofoverpressures
on porosity
depth
porosity
4-8 km
The specific details ofthese relationships area function of basin age,diagenesis, heat flow ...
Diagenesis and RocksDiagenesis and Rocks
Mechanical compaction, most important in shales, drives the particles closer together
Pressure solution, important in sands but not shales, lowers porosity substantially
Cementation, usually SiO2 or CaCO3, bonds grains together, reducing porosity as well, most important in sands (sandstones)
Very deep, clay minerals change, leading to fracturing & stress changes (shales only)
Diagenesis rate and intensity is ƒ[T, (ie: depth), t, chemistry…]
Stress and DiagenesisStress and Diagenesis
line
of
v =
h, o
r K o =
1
yiel
d,
= 3
0°v
burial
diagenesis
Sand burial in a non-tectonic environment results in h < v because of friction. Diagenesis seems to reduce this stress difference slowly over long periods of time.
h
is the friction angle for sand
Stress & Diagenesis, no Stress & Diagenesis, no TectonicsTectonics If there has been no tectonic activity, h is
less than v
In sands, the ratio Ko (defined as the ratio of horizontal to vertical stress, h/v), can be as low as 0.3, usually 0.4 – 0.6
Shales have a low angle of friction, usually Ko is 0.6 – 0.8, even as high as 0.95 in muds
Thus, the fracture gradient is higher in mud or shale in non-tectonic areas (GoM)
Deep burial and diagenesis tend to reduce the stress differences
Diagenesis and StrengthDiagenesis and Strength
shear stress -
chemical cementation
densification(more interlock)
originalsediment
diageneticstrengthincrease
3
diagenesiseffects on the
strength
cohesion
a
rr = 3
a = 1 max planes
slipplanes
TriaxialTest
Stresses
normalstress - n
Principal stresses – see inset
strength increase
Diagenesis, Strength, StiffnessDiagenesis, Strength, Stiffness
Mechanical compaction in the early burial stages increases the friction angle,
Chemical effects increase cohesion, c, often cementing particles together
The sediments also become stiffer (higher Young’s modulus)
In general, rocks become stronger, ƒ() However: deep, intense shale diagenesis
often generates shrinkage fractures; they become weaker, hmin and HMAX , k, even though they are lower porosity
Erosion and StressesErosion and Stresses
K o =
1.0
line
(i.e
.: 1
= 3
)
yiel
d,
= 3
0°
’v
’h
buria
l
diagenesis
Elastic behavior governs unloading because the rock is stiff and strong; lateral stresses increase naturally
eros
ion
v
h
Effect of ErosionEffect of Erosion Once a sediment is buried and diagene-
tically indurated, it behaves elastically Direct erosion without tectonic loading
leads to the so-called “Poisson effect”:
Thus, erosion naturally leads toward the shallow condition K’o > 1.0 (except for salt, which behaves as a viscous fluid)
vh '1
'
Rocks, Stresses in an Eroded Rocks, Stresses in an Eroded BasinBasin
Erosion has created a “skin” near the surface where HMAX = 1, and v = 3
Deeper, a strike-slip regime condition HMAX = 3, v = 2 is found
I.e. fracture gradient increases with depth
Rocks are stronger, stiffer
High pore pressures (po > 1.3 v) are rare in eroded basins
, po
Z
v
hv = 3
v = 2
Assuming that both horizontal stresses are equal
thrust stress state
strike-slip stress state
Eroded BasinEroded Basin
The “Poisson effect” during unloading generates a region at shallow depth where horizontal stresses are larger than vertical
Also, the rocks are strong Drilling underbalanced is becoming
common in such regions because of rock strength
Pore pressures in such regions are rarely in the overpressure domain
For large overpressures, there is a special module
Conclusions on ErosionConclusions on Erosion Generation of high Ko values requires
plastic deformation (incl. diagenesis) This happens naturally in sedimentary
basins, even without tectonics, during the burial phase, however, after induration…
The unloading phase is largely elastic It is unlikely that glaciation has a large
effect on previously eroded basins Any eroded basin will have a skin that is
“overstressed”, with v = 3 to some depth
Changes in StressesChanges in Stresses
Opening a hole (drilling) changes stresses massively r is now 3 at a local scale
In drilling, heating or cooling the wall can change the stresses, affecting stability
High mud pressures can cause joints to slip Stresses changed by injection or production
E.g.: Depletion of the reservoir decreases the fracture gradient (loss of horizontal stress)
Hot or cold water injection changes stresses Pressurization or depletion can result in
shearing of casing, faulting, minor seismicity
In Situ Stresses: SummaryIn Situ Stresses: Summary
Stresses are needed for casing programs, borehole stability analysis, etc. etc.
Pore pressures are a vital aspect as well Often stress directions and relative
magnitudes can be estimated from the tectonic and burial history of the sedimentary basin, or its structure
The most recent fault patterns often reflect the stress regime
Features such as salt domes, etc., invariably indicate locally altered stresses
Lessons LearnedLessons Learned
Stresses in the earth arise from:Gravity effects (rock bulk density – v)Tectonic effects (compression, salt tectonics…)
Recent faults indicate stress patterns Basin shape is a stress pattern indicator Geology and history allow us to estimate
relative stress magnitudes and orientations Stress is involved in many basin processes
Basin fabric, diagenesis, overpressure, oil migration, gas and oil valving…
RecommendationsRecommendations
Offshore or inshore, it pays to have some stress information for drilling, hydraulic fracturing, reservoir modeling…
The first step is to use geological history to build a regional stress model
The pore pressure conditions should be inferred as well, (also offset well data…)
Then, examine reservoir & local scale factors Faults, salt features, reefs and drapes,
hydrothermalism, and other featuresThese may “perturb” regional stresses
Extra MaterialsExtra Materials
Breakouts and Natural StressesBreakouts and Natural Stresses
HMAX
hmin
principalstresses,1 > 3
Vertical borehole
breakoutsdamage,ravelling
high
Breakouts are evidence of stress anisotropy and are caused by shear rupture of the borehole wall
However, care must be taken in assessing breakouts, as other factors can “interfere”
Use only vertical wells (10) to get good stress orientations
Some “Confusing” EffectsSome “Confusing” Effects
HMAX
hmin
jointedlaminated
shale
slabbing,ravelling
HMAX
ravelling
materialanisotropy
1
3
ravelling
bedding planes
Material anisotropy means the mechanical properties are different in different directions, as in a fissile shale
3
Borehole Features: Wall ScanBorehole Features: Wall Scan
HMAX
axialfractures
Stress directions
0 90 180 270 360
largewashout
hmin
higher angleof intersection(joint plane)
low intersection angle (bedding?)
breakouts
Geometry of joint plane intersection
Sinusoidal fracture traces
“en-echelon” axial fractures
if hole is slightly inclined
Reconstructed breakout data from Schlumberger borehole scanner logs
Axial fractures and breakouts are stress direction indicators. If the stress difference is large, breakouts are also larger (deeper and wider).
brea
kout
sno
bre
akou
ts
axia
l fra
ctur
es
Directions: Breakouts, Directions: Breakouts, FracturesFractures
Borehole wall tensile fractures
Small breakouts (90° to tensile fractures)
Natural fracture
plane
Modest breakouts, no tensile fractures
Natural fracture
plane
hmin is at 40°Az in this example
This is a LWD log trace taken during a trip, so resolution is poor
Use of Breakouts, Axial Use of Breakouts, Axial FracturesFractures For orientations, use only wells that are
vertical +/- 10° (rarely more inclined) Establish quality control on your data
(length, symmetry across hole, quality…) Grade your data (“A” “B”, “C” quality…) Breakouts: HMAX is at 90° to breakout axis
Borehole wall axial fractures: HMAX is parallel to the fractures axis
Combine with geology, v calculations from density log data, LOT data, HF data…
Build a stress map for your region & use it
More about Breakouts, FracturesMore about Breakouts, Fractures Don’t confuse breakouts with hole
enlargement (breakouts are symmetrical, and the minor axis ~ hole gauge size)
Don’t confuse breakouts with sloughing in a fissile shale when the hole dip is close to the dip of the shale fissility
Joints and planar features trace sinusoidal patterns on the borehole wall; induced axial fractures do not
4-arm dipmeter data must show ~symmetry, consistency, reasonable length, etc. (QC)
Full wall scans are easier to interpret
Log Data as Stress IndicatorsLog Data as Stress Indicators
borehole,pw
Formation, po
Anisotropically invaded zone, & stress microfissured region, giving anisotropic permeability
Pad region
a
bc
dHMAX
hmin
Conductivity response
borehole
4-arm dipmeter responseSome other log properties may give stress orientation information
Mud Weight Window PrognosisMud Weight Window Prognosis1.1 1.3 1.5 1.7 1.9 2.1 2.3
prognosisfor hmin
XLOT hmin value
shoe
depth
density, g/cm3
v
prognosisfor po
overpressuretransition zone
area indicatespossible MW
MW=1.92
shoe location for next casing string
Previouscasingstring
Convert todensity unitsby dividing
pressures andstresses by
vertical depth
strong overpressure zone
This is a conservative approach: often, we can stretch the lower limit a bit, carefully
Mud Weight PrognosesMud Weight Prognoses
Data garnered from many sources, offset wells, geology, XLOT, MWD…
The interval defined is the secure window:MW below pfrac (= hmin) at the shoe
MW above pmax, usually at or near the bit
However, the window can be pushed a bit!Drilling MW + ECD can be a bit above pfrac
If shales are strong and no high k sands, drilling may take place slightly below the pore pressure
Tricks such as high weight pills on trips Underbalanced drilling in strong shales
Pushing the Envelope in Drilling!Pushing the Envelope in Drilling!1.1 1.3 1.5 1.7 1.9 2.1 2.3
prognosisfor hmin
XLOT hmin value
shoe
depth
density, g/cm3
v
prognosisfor po
overpressuretransition zone
area indicatespossible MW
MW=1.92
deeper shoe for casing string!
Previouscasingstring
Convert todensity unitsby dividing
pressures andstresses by
vertical depth
strong overpressure zone
Using high weight trip pills and careful monitoring, the lower limit can be extended
(2.0 = 16.7 ppg)
Pore Pressure GenerationPore Pressure Generation
yiel
d,
= 3
0°
v
h
Pore pressure generation reduces effective stresses, but not in a path parallel to hydrostatic because of Poisson effect. This can lead to rock shear if po is high
faulting
Poissoneffect
Stre
ss p
ath
for +
p
h = v(/1-)
/(1-
line
of
v =
h, o
r K o =
1
Diagenesis, Burial, ErosionDiagenesis, Burial, Erosion
h - MPa
v =
h (
K o =
1)
diagenesis
sedi
men
tatio
n,
~ 3
0o
actu
al p
ath?
0 5 10 15 20 25
erosion, ~ 0.2
-2000 m-
-500 m-
h =17 MPav = 7 MPa
25
20
15
10
5
0
v - MPa
This stress pathexplains the presence of
high horizontalstresses nearthe surface
Burial to 2000 m, erosion to 500 m
Stress path
A simple calculation of the probable effect of erosion of 1500 m of rocks on the stresses. We assumed initial stress state (red star), took a reasonable Poisson’s ratio for erosion (0.2), and made the calculation. (Assume that po is always 8.33 ppg)
Fluid Flow in ShalesFluid Flow in Shales
Shales are almost always the source rocks; sands, limestones the reservoirs
Most shales are water-wet, except for the rich kerogenous shales
Gas or oil as the non-wetting phase flows only with gradients of > 500
Two-phase permeability of shales = zero Thus, HC flow must be through fissures,
fractures, or other macrodiscontinuities Shales are originally intact, so O&G
expulsion is likely through induced fractures
Stress and Petroleum MigrationStress and Petroleum Migration How are microfissures generated? When 3 normal to fissures is < po
po is the pressure in the shale pores
3 is the lateral confining stress at the scale of the microfissure
This can occur by various geological and tectonic processes:Processes which increase po
Processes which decrease 3
These are linked to shrinkage of shale, loading…
Reduction in Reduction in 33
Tectonic unloading reduces 3 (hmin)
Any shrinkage in the material reduces 3
-Clay compaction, thermal shrinkage (uplift) -Loading of anisotropic shales -Smectite to mixed-layer to illite changes
When 3 drops below po, fissures can open stably, and remain open
Fissures can be dominantly vertical (usual case), or also horizontal
Now, fluids can easily flow through the open cracks, migrate to traps & accumulate
Increase in pIncrease in poo
HC generation increases pore pressures Retarded compaction (overpressure) Smectite diagenesis releases H2O
Thermal pressuring increase po
Accumulation of a thick gas zone in a reservoir with good vertical closure
Tectonic loading (?) may increase po
Other processes (e.g. gypsum dewatering)
These processes give the driving forces for fluid flow and HC migration
clayparticle
clayparticle
gas or oil bubble
r
0.1-0.5m
water
oil orgas
p = /2r = interfacial tension r = radius of curvature p = po - pw
pw
po
Darcy flow requires huge p
Can Oil or Gas Flow in Shales?Can Oil or Gas Flow in Shales?
Conclusion: oil or gas cannot flow through intact shale!
Typical pore size in shale
Can Water Flow Easily in Shale?Can Water Flow Easily in Shale?
Free water, partly on ionsBound water
Bound water Much of the water in shales is not free to move easily:Adsorbed on the clay fragmentsHydrated onto cationsPore throats are “blocked” by adsorbed water
Na+
H2O molecules
Cations
Hydratedcations
Conclusion: oil or gas cannot flow through intact shale!
Fluid Generation & FracturingFluid Generation & Fracturing
semi-solidorganics, po < h < v
po = h < v,fractures
develop andgrow
fluids areexpelled through
the fracturenetwork,
po declines
shale
kerogen
micro-fissure
v
oil and gas
generation of hydrocarbon fluids
fluidflow
vT, p,
increase
high T, p,
3-20 mm
Flow in shales mustbe through fractures!
Effects of Increasing pEffects of Increasing poo
Fluid migration is a function of stress as well as pressure!
hydraulic fracturewhen po > h
gas cap, low density
oil
stress
depthhpo
gas capeffect
fault slips when > (n - po)·tan,
i.e. when > n·tan
stresses along A-AA
Aoil, density= 0.75-0.85
n = n - po
n
This is called “valving” of gas
Valving of Reservoirs & StressesValving of Reservoirs & Stresses
Gas is generated and accumulated, increasing the gas cap height
Because gas is light, it has a different gradient of pressure (0.1 instead of 0.8 for oil and ~1.04 to 1.10 for brine)
This causes po to increase at the crest
When po exceeds h, hydraulic fracture! This is like a valve that opens episodically
over geological time, releasing pressure Responsible for shallow gas in some areas
Tectonic StressingTectonic Stressing
UC sand
shale
salt
sandstone
stresslithotype stiffness
limestone
E
0.5E
0.75E
1.5E
loading
unloading
salt isviscoplastic
mud
depthassumedinitialh
stresses areisotropic
Tectonic StressingTectonic Stressing
From its “virgin state”, unloading (rifting) or loading (compression) can occur
This has a relatively larger effect in the stiffer rocks (small strains = large h)
Stress contrasts can be generated among the beds (except salt)
This was proven by measurements in the Appalachian Basin thrust zones in 1980s
This is easily simulated by numerical models, but real data need measurements
Typical Stress ConditionsTypical Stress Conditions
stress (or pressure)
depth
vertical stress. v
horizontal stress. h
pore pressure, po
4 kmmild
overpressure
b. Western Alberta, 100 km from Rockies
stress (or pressure)
depth
stronglyoverpressuredregion at depth
vertical stress, v
horizontal stress, h
pore pressure, po
4 km
a. Gulf Coast of USA
Relaxed continental margin Tectonically stressed rocks
A Well Plan, North SeaA Well Plan, North Sea• classical mud weight window is too
narrow; cannot avoid instability
• low mud weight breakouts
• high mud weight destabilized fractured zones & losses
• breakout problems are controllable by good hole cleaning; fracture zones are uncontrollable
Strategy:
• keep mud weight low
• manage breakouts with good hole cleaning before increasing mud weight
• monitor cavings and mud losses for warning of fractured zones
Stresses and DrillingStresses and Drilling
v >> HMAX > hmin
hmin
HMAX
v
HMAX >> > hmin
HMAX ~ v >> hmin
v
hmin
HMAX
v
hmin
HMAX
To increase hole stability, thebest orientation is that whichminimizes the principal stressdifference normal to the axis 60-90° cone
Drill within a 60°cone (±30°) from the mostfavored direction
Favored holeorientation