marine em, the past, the present, and the future · natural-source magnetotelluric fields grounded...
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Marine EM, the Past, the Present, and the Future
Steven Constable
Scripps Institution of Oceanography
Acknowledgements
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Marine EM, the Past, the Present, and the Future
Steven Constable
Scripps Institution of Oceanography
On Tuesday 17th August, 2004 the front page of the Wall Street Journal had a lead article about a new geophysical technique. Marine CSEM was suddenly in the news…
On Tuesday 17th August, 2004 the front page of the Wall Street Journal had a lead article about a new geophysical technique. Marine CSEM was suddenly in the news…
… except is wasn’t new. Over 23 years earlier an oceanographer called Charles Cox had suggested marine CSEM for hydrocarbon exploration…
On Tuesday 17th August, 2004 the front page of the Wall Street Journal had a lead article about a new geophysical technique. Marine CSEM was suddenly in the news…
… except is wasn’t new. Over 23 years earlier an oceanographer called Charles Cox had proposed using marine CSEM for hydrocarbon exploration…
… to Exxon.
Outline:• Basics of the EM methods• Early history of marine EM• Commercialization• 10 things you need to know• The future
grounded wire (E)
horizontal loop (B) Ex
By
Bz
Bx
Ey
Transmitters Receivers
I
V
V
I
Controlled Source ElectroMagnetic sounding has been used since the 1930’s to map sub-surface geology through the proxy of electrical conductivity. On land it is mainly used for mining exploration (shallower, conductive ore bodies), but has been used for map geological structure for oil exploration.
What is CSEM?
Natural-source Magnetotelluric fields
grounded wire (E)
horizontal loop (B) Ex
By
Bz
Bx
Ey
Transmitters Receivers
I
V
V
I
CSEM is related to another EM technique called MagnetoTelluric (MT) sounding, which uses similar receivers to measure Earth’s natural magnetic field variations and the induced electric currents. MT signals are either part of a useful complementary method or a source of noise for CSEM.
What is MT?
Both can be used in the marine environment:
100-300 m dipole,100-1000 amps
25-100 m
CSEM Transmitter
Oil, Gas (resistive)
Seawater (very conductive)
Air (resistive)
Salt, carbonate,volcanics (resistive)
Natural-source Magnetotelluric fields
Electric and magnetic field recorders
Seafloor (variable conductivity)
Marine CSEMmore sensitive to
resistive rocks
Marine MTmore sensitive toconductive rocks
But both methods can detect contrasts
Both MT and CSEM sounding use electromagnetic induction, which describes what happens around a time-varying primary magnetic field: primary magnetic
field
Faraday’s Law says that a time varying (or moving) magnetic field will induce electric fields:
( is magnetic flux).
CE · dl = d
dt
primary magnetic field
electric field
Faraday’s Law says that a time varying (or moving) magnetic field will induce electric fields:
( is magnetic flux).
Ohm’s Law says that E will generate a current J in a conductor:
CE · dl = d
dt
J = E
primary magnetic field
electric field and current
Faraday’s Law says that a time varying (or moving) magnetic field will induce electric fields:
( is magnetic flux). Ohm’s Law says that E will generate a current J in a conductor:
Ampere’s Law says that the current will generate a secondary magnetic field:
CE · dl = d
dt
CB · dl = µI
J = E
primary magnetic field
electric field and current
secondary
magnetic
field
The secondary field opposes the changes in the primary field. The consequence of this is that conductive rocks absorb variations in EM fields more than resistive rocks.
Half-space
Depth —
>
The secondary field opposes the changes in the primary field. The consequence of this is that conductive rocks absorb variations in EM fields more than resistive rocks.
This absorption is exponential:
The rate of absorption is given by the skin depth, which depends on rock resistivity and period:
High resistivity, long periods = large skin depths, greater penetration.
Low resistivity, short periods = small skin depths, greater attenuation.
E(z) = Eoez/zs
Half-space
Depth —
>
Secondary fields are different in amplitude, phase, and direction than the primary magnetic and electric fields. Electric fields can also be distorted galvanically, as in DC resistivity methods.
CRIP
PS I N
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ITUTION OF OCEANOGRA
PHY
UCSD
Primary fields
Secondary fields
Induced magneticfields
Galvanic distortion of electric currents
water
sediments
mantle
basaltic melt
ice, hydrate
hydrocarbons
basalt, salt,carbonates
marine
lower mantle
0.1 1
110 0.1 0.01 10-3 10-4
10Resistivity, Ωm
Conductivity, S/m
100 1,000 10,000
10%
0°C20°C
1%3%
peridotite
partial melt
land14
00°C
1200
°C110
0°C
seawater fresh water
MT and CSEM are methods to measure electrical conductivity. Conductivity varies over 5 orders of magnitude in common Earth materials, and provides the ideal mechanism for studying fluids, water, and geology, including hydrocarbons.
The Past
GEOPHYSICS, VOL 18, NO. 3 (JULY 1953), P. 605-635.
Interestingly, Cagniard proposed adaption to the marine environment in the 1953 paper that first presented the MT method.
Tucson mag
seafloor mag
seafloor E
Charles (Chip) Cox and Jean Filloux of Scripps Institution of Oceanography made the first marine MT measurements in 1965, in 4300 m water offshore California.
Cox, Filloux, and Larsen, 1968
Charles Cox
Jean Filloux
Tucson mag
Theory pre-dates practice, but even so marine CSEM is a young field. The earliest marine CSEM work was carried out by the British and US navies. This 1968 paper out of the US Navy Underwater Sound Lab appears to be the first proposal for marine CSEM as we now know it.
The same Chip Cox (1922-2015) developed practical deepwater CSEM in the early 1980’s, partly under funding by DARPA to improve understanding of seafloor communications, and ONR for submarine noise studies.
In 1979 Chip carried out an experiment in nearly 3,000m water with transmissions of 80 amps on an 800 m antenna. Frequencies of 0.25 - 2.25 Hz were detected 19 km away. His target was a mid-ocean ridge.
Young and Cox, 1981
Transmitter
Tow cable
Receiver
Cox et al, 1981
Electrodes
Antenna
Remarkably, within 2 years, in March 1981, Chip proposed the CSEM method for oil exploration to Exxon:
In the proposal, Chip explicitly described the direct detection of a hydrocarbon reservoir.
Fields measured 2500 m from a 104 Am CSEM transmitter
I checked Chip’s calculations and they are basically correct. However, the proposal was declined - Chip was too far ahead of the times.
Fields measured 2500 m from a 104 Am CSEM transmitter
10−1
100
101
10210
−1
100
101
102
Hz
Am
plitu
de (
nV
/m)
Meanwhile, in the late 1980’s Martin Sinha of Cambridge (later Southampton) developed a UK CSEM capability based on Scripps’, but with an “flown” transmitter capable of working over mid-ocean ridges.
(From Sinha et al, 1990)
Current industry funding for marine EM started in 1995 in order to develop MT imaging of salt in the Gulf of Mexico. Clearly, the price of oil was not a factor (adjusted for inflation, 1998 was the lowest price in history).
What drove interest in such an expensive, non-seismic method?NW
SW
Conductive (0.3 Ohm-m)
Resistive (4 Ohm-m)
4 k
m6 k
m
2 km
1 km
thin resistive layerthin resistive layer overhangoverhang
NW
SW
Conductive (0.3 Ohm-m)
Resistive (4 Ohm-m)
4 k
m6 k
m
2 km
1 km
thin resistive layerthin resistive layer overhangoverhang
First, the seismic method was having great difficultly imaging beneath salt…
Current industry funding for marine EM started in 1995 in order to develop MT imaging of salt in the Gulf of Mexico. Clearly, the price of oil was not a factor (adjusted for inflation, 1998 was the lowest price in history).
What drove interest in such an expensive, non-seismic method?
NW
SW
Conductive (0.3 Ohm-m)
Resistive (4 Ohm-m)
4 k
m6 k
m
2 km
1 km
thin resistive layerthin resistive layer overhangoverhang
But probably the biggest factor was the development of the tension leg platform, which enabled production of oil and gas from deepwater prospects…
… but deepwater drilling is very expensive.
Current industry funding for marine EM started in 1995 in order to develop MT imaging of salt in the Gulf of Mexico. Clearly, the price of oil was not a factor (adjusted for inflation, 1998 was the lowest price in history).
What drove interest in such an expensive, non-seismic method?
Commercial marine MT was offered starting in 1996. The first oilfield CSEM tests were done in late 2000 - early 2002, by Statoil and ExxonMobil. They both used Scripps receivers and the Southampton transmitter.
Again, the driver was the high cost of drilling combined with limitations in the seismic method.
First oilfield CSEM surveys, Angola
1970 1975 1980 1985 1990 1995 2000 2005 2010 2015
20
40
60
80
100
120
140
160
180
Year
We
lls;
Oil p
rice
Gulf of Mexico, wells >1,000 m water depth and oil price
Wells drilled
Oil price, nominal $
First Scripps industry funding
starts
First Scrippsindustry funding
stops
Current industryfunding starts
0 0.10.4
0.8
1.2
1.6
0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1Gas saturation
P-w
ave
velo
city
, km
/s
Seawater/gas in 50% porous sandstone
Velocity
Fizz-gas
Archie’s with fizz-gas
The seismic method has the problem that small gas saturations produce big velocity changes.
0 0.10.4
0.8
1.2
1.6
0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1100
101
102
103
104
Gas saturation
Res
istiv
ity, Ω
m, l
og s
cale
P-w
ave
velo
city
, km
/s
Seawater/gas in 50% porous sandstone
HS lower bound
Arc
hie
’sVelo
city
Fizz-gas
Least resistivity contrast easily
detected with EM
Archie’s with fizz-gas
However, electrical resistivity does not change until the gas saturation gets large. This means that marine CSEM can be used to assess targets prior to drilling.
Air
Sea
Sediment
movie © Kerry Key, SIO.
Oil and gas reservoirs are too thin to be sensed with MT - now we need to use a man-made source of energy. Again, EM energy propagates best through the more resistive rocks.
In this movie, the electric fields are absorbed more rapidly in seawater:
Air
Sea
Sediment
Oil layer
If we add a thin resistive layer to the model (an oil or gas reservoir?), then energy propagates even better through this layer than the surrounding sediments.
Then we add a transmitter and receivers to actually collect these data.
CRIP
PS IN
ST
ITUTION OF OCEANOGRAPHY
UCSD
movie © Kerry Key, SIO.
The effect can be up to an order of magnitude for a large oil or gas reservoir. This is what I call the “canonical model”, and is similar to the target chosen by Statoil for the first test of the marine CSEM method, and very similar to the model that Chip used in his proposal.
0 2 4 6 8 10
10 -14
10 -12
10 -10
10 -8
Source-receiver offset, km
In-li
ne e
lect
ric fi
eld,
V/m
/(Am
)
oil, gas
no oil, gas
1000 m, 0.3 Ωm
1000 m, 1 Ωm
100 m, 100 Ωm
E-field amplitudes larger overhydrocarbon reservoirs
Statoil’s tests were made in November 2000 over the Girasoll oil field off Angola:
-6000 -4000 -2000 0 2000 4000 6000 N 10
-15
10-14
10-13
10-12
10-11
10-10
Radia
l E
lectr
ic F
ield
, (V
/m)/
(sourc
e d
ipole
mom
ent)
Source-Receiver Offset, m
InfiniteReservoir
No Reservoir
Terminating Reservoir
Oil Reservoir
V
10
5
15
20
25
30
35
50 10 15 20 21
tow A
approximate extent of reservoir
Distance East (km)
Dis
tanc
e N
orth
, (km
)
http://www.oilpro.com/
Constable and Srnka, 2007
Over a known discovery
Prior to drilling
Constable and Srnka, 2007
Similar studies were carried out by ExxonMobil in Jan 2002, also off Angola.
These studies used 30 new instruments designed and built by Scripps for ExxonMobil, operated by AOA Geophysics.
Brine Filled
Distance East (km)
noise level
00
3
6
9
12
15
3 6 9 12 15 Distance (km)0 3 6 9 12 15
10-15
10-14
10-13
10-12
10-11
10-10
Radi
al E
lect
ric F
ield
, (V/
(Am
2 ))
Oligocene HC FilledMio + Olig HC Filled0.25 Hz Data
Rotated Inline E FieldReceiver 21, Tow Line 3Oligocene
Miocene
Salt
Salt
tow 3
well
receiver 21
Dist
ance
Nor
th (k
m)
Distance along line (km)
noise level
0 3 6 9
Distance (km)
0
0
3
3
6
6
9
9
12 1512 15
10-15
10-14
10-13
10-12
10-11
10-10
No
rma
lize
d f
ield
(V
/(A
m2
) )
Backgound
With Reservoir
2 min. Stacked Data
Inline E Field, 0.25 Hz
Receiver 21, Tow Line 2
Salt
tow 2Well B
Well A
receiver 21
seismic O/W
contact
reservoir limits
Dis
tan
ce
(km
)
At least 3 main contractors offering marine EM data collection and interpretationservices
Then things got interesting...
By the end of 2002 three contractors were formed to offer marine MT/CSEM as a commercial product.
Several special-purpose ships have been built since then.
Much based on early academic science and technology.
Since then more companies have joined the party…
The Present10 things you should know about marine CSEM
that are not likely to change
1. EM does not map oil or gas, or even rock type. We cannot tell the difference between an evaporite, a basalt, or an oil sand based on resistivity alone.
-5 -4 -3 -2 -1 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14
pyrrhotite
graphite
groundwater
clays
evaporites
drywet
drywet
intrusive igneous rocks
basalts/lavas
quartz
limestones
sandstones, quartzites
seaw
ate
r
OIL SANDS
Log 10 (Resistivity, Ωm)
Resistivity of Rocks and Minerals (Data from Telford et al.)
Thus, to manage false positives you need additional data - seismics, geology, magnetics, gravity, … Integration with other data sets is perhaps the only safe way to use marine EM data.
2E = µEt
+ µ2Et2
2E = 0
Radar
DC Resistivity
High frequency(megahertz)
Mid frequency(0.001 - 1000 Hz)
Zero frequency
2. The resolution of EM induction is between wave propagation and potential fields:
2E = µEt
r2U = 0
r2u = @u
@t+
1c2
@2u
@t2
Wave equation: Resolution ~ wavelength
Diffusion equation: Resolution ~ size/depth
Laplace equation: Resolution ~ bounds only
µ
= electrical conductivity ~
= magnetic permeability ~ = electric permittivity ~ 109 1011
104 106
3 106 S/mH/m
F/m
Inductive EM
Seismics
Gravity/Magnetism
E(z) = Eoez/zs+i(tz/zs)
zs =
2/µ
3. Frequency is too low for wave propagation in rocks, but does constrain length scale through skin depth :zs
2E = µEt
At a single frequency becomes 2E = iµE
which for uniform fields has solutions of the form
where we have defined a skin depth
For every skin depth the fields decay by 1/e (~37%) and phase lags by one radian (~57°).
= 2f( )
In 1 Ωm sediments:
frequency skin depth0.1Hz 1,600 m0.25 Hz 1,000 m1.0 Hz 500 m5.0 Hz 225 m
degrees
degrees
degrees
degrees
7785
7790
7795
7800
7805
7810
7815
7820
7825
7830
Nort
hin
g, km
3000m, Erad
0.25Hz
N = 623 rms = 4°
−90
−80
−70
−60
−50
−40 3000m, Erad
0.75Hz
N = 642 rms = 3°
−190
−180
−170
−160
−150
−140
710 720 730 740 750 760
7785
7790
7795
7800
7805
7810
7815
7820
7825
7830
Easting, km
Nort
hin
g, km
3000m, Erad
1.75Hz
N = 602 rms = 5°
−330
−320
−310
−300
−290
−280
710 720 730 740 750 760
Easting, km
3000m, Erad
3.25Hz
N = 348 rms = 8° −460
−450
−440
−430
−420
−410
Although you need a low enough frequency to reach your target, sensitivity can increase with frequency (Eradial, 3,000 m, phase):
0.25 Hz 0.75 Hz
1.75 Hz 3.25 Hz
(But your signal size gets smaller.) These are data over the Scarborough gas field offshore NW Australia, collected by Scripps with support from BHP Billiton.
Single frequency - 0.25 Hz
Single frequency - 0.75 Hz
Multiple frequencies
Single frequency - 1.75 Hz
4. Good inversion technology is key to getting the most out of EM data, and inversions of multiple frequencies are much better than single frequency inversions.
10−1 100 101 102
1
1.5
2
2.5
3
3.5
4
4.5
Resistivity (ohm−m)
Dep
th(km)
Truth1 Hz0.1, 1 Hz0.1, 0.3, 1, 3, 10 Hz
y transmitter
Key, 2009
Constable, Orange, and Key, 2015
With a single frequency and no phase data, a shallow resistor (say, hydrate) has an almost identical response to a deep hydrocarbon reservoir. This led to actual drilling errors.
Receiver
Shallow slab
Reservoir
Ey
1 ohm-m
0.33 ohm-m
1 ohm-m
0.33 ohm-m
Reservoir Shallow slab
Courtesy Arnold Orange
5. Transmitter fields have a dipole geometry. The radial (inline) and azimuthal (broadside) fields behave differently. The greater vertical component of the radial fields creates greater sensitivity to thin, sub-horizontal resistors (reservoirs). You can use this to tell thick from thin resistors. The modes also behave differently to anisotropy.
Transmitter
Receiver
Azimuth
Radial fieldEr
Azimuthal fieldEø
0 AzimuthField purely radial(in-line geometry)
o
90 AzimuthField purely azimuthal(broadside geometry)
o
,
log10
(V/Am2) degrees
log10
(V/Am2) degrees
7785
7790
7795
7800
7805
7810
7815
7820
7825
7830
No
rth
ing
, km
4000m, Erad
0.75Hz
N = 690 rms = 10% −13.25
−13.2
−13.15
−13.1
−13.05
−13
−12.95
−12.9
−12.85
−12.8 4000m, Erad
0.75Hz
N = 690 rms = 4°
−250
−240
−230
−220
−210
−200
710 720 730 740 750 760
7785
7790
7795
7800
7805
7810
7815
7820
7825
7830
Easting, km
No
rth
ing
, km
4000m, Eaz
0.75Hz
N = 297 rms = 9% −13.65
−13.6
−13.55
−13.5
−13.45
−13.4
−13.35
−13.3
−13.25
−13.2
710 720 730 740 750 760
Easting, km
4000m, Eaz
0.75Hz
N = 297 rms = 6°
−150
−140
−130
−120
−110
−100
0.75 Hz amplitude, 4km Tx-Rx offset
log10
(V/Am2) degrees
log10
(V/Am2) degrees
7785
7790
7795
7800
7805
7810
7815
7820
7825
7830
No
rth
ing
, km
4000m, Erad
0.75Hz
N = 690 rms = 10% −13.25
−13.2
−13.15
−13.1
−13.05
−13
−12.95
−12.9
−12.85
−12.8 4000m, Erad
0.75Hz
N = 690 rms = 4°
−250
−240
−230
−220
−210
−200
710 720 730 740 750 760
7785
7790
7795
7800
7805
7810
7815
7820
7825
7830
Easting, km
No
rth
ing
, km
4000m, Eaz
0.75Hz
N = 297 rms = 9% −13.65
−13.6
−13.55
−13.5
−13.45
−13.4
−13.35
−13.3
−13.25
−13.2
710 720 730 740 750 760
Easting, km
4000m, Eaz
0.75Hz
N = 297 rms = 6°
−150
−140
−130
−120
−110
−100At intermediate azimuths the data are a trigonometric mixture of the radial and azimuthal fields.
10−1
100
101
102
1
1.5
2
2.5
3
3.5
4
4.5
Resistivity (ohm−m)
De
pth
(km
)
TruthExBy
Bz
Ex,By,Bz
TruthBxEy
Ez
Bx,Ey,Ez
TruthBxEy
Ez
Bx,Ey,Ez
x transmitter
10−1
100
101
102
1
1.5
2
2.5
3
3.5
4
4.5
Resistivity (ohm−m)
De
pth
(km
)y transmitter
10−1
100
101
102
1
1.5
2
2.5
3
3.5
4
4.5
Resistivity (ohm−m)
De
pth
(km
)
z transmitter
y
x
E
BB
y
x
B
EE
y
x
Bx
EyEz
1D Inversions of synthetic 0.1 and 1.0 Hz data with 1% noise added:
Inline Tx Vertical TxCrossline Tx
Inverting either inline Bx or Ey provides best resolution to reservoir targets. Note Ez: don’t confuse sensitivity with resolution.
Key, 2009
6. CSEM works best in deep water, where the “air wave” is small. But, it works OK in shallow water because the air wave and target response are coupled. Don’t try to remove the air wave.
Flood from left - Water depth 1500 & 3000 m
Flood From: Orange, Key and Constable, Geophysics, 2009
'Air wave'
Seawater propagation
host rock propagation
target signal
CRIP
PS IN
ST
ITUTION OF OCEANOGRAPHY
UCSD
Orange, Key, and Constable, 2009
7. Depth sensitivity in CSEM is largely determined by geometry. Sensitivity is always greatest right below the Tx and Rx. Depth sensitivity is about half Rx-Tx spacing, and so is sensitivity to off-line structure.
inline (m)
Plan
Section0.25 Hz and perturbationof 1 Ωm halfspace
Constable, 2010
1000 2000 3000 4000 5000 6000 7000 8000 -18
-17
-16
-15
-14
-13
-12
-11
-10
-9
-8
Radial mode fields (1 Hz)
Range, m
log10(E
fie
ld m
agnit
ude, V
/m/(
Am
))
100 m, 100 Ωm
1000 m, 1 Ωm
5 km diameter
4 km
3 km
2 km
1 km
1D layer
1D halfspace
(3D calculation courtesy C. Weiss)
Targets have to be bigger than their depth of burial to be detected (note that this has nothing to do with transmitter power!).
Constable and Weiss, 2006
8. Anisotropy is important. Aligned crystals and inter-bedding can produce anisotropy on microscopic to macroscopic scales.
CSEM cannot tell micro- from macro-anisotropy until the layers get very thick.
http://www.sleepingdogstudios.com/NR O’Brien, J. Sed. Res. 1987
0 1 2 3 4 5 6 7 8 9 10-18
-17
-16
-15
-14
-13
-12
-11
-10
-9
-8
Horizontal Range (km)
AZIMUTHAL: Frequency: 0.25 Hz
0 1 2 3 4 5 6 7 8 9 10-18
-17
-16
-15
-14
-13
-12
-11
-10
-9
-8
Horizontal Range (km)
RADIAL: Frequency: 0.25 Hz
Am
plitu
de (
log
10 V
/m/(
Am
), T
/(A
m))
Am
plitu
de (
log
10 V
/m/(
Am
), T
/(A
m))
Bx: Anisotropy
Ey: Anisotropy
Bx: HS_half
Ey: HS_half
Bx: HS_one
Ey: HS_one
By: Anisotropy
Ex: Anisotropy
By: HS_half
Ex: HS_half
By: HS_one
Ex: HS_one
Radial Azimuthal
1 Ωm 0.5 Ωm
To a good approximation (10% or so), the anisotropic response follows the vertical resistivity for the radial mode, and the horizontal resistivity for the azimuthal mode.
Inverting the modes separately using isotropic models may give reasonable results, but joint inversion of both modes will fail without anisotropy.
Red - magnetic fieldsBlue - electric fields Anisotropic
Horizontal Vertical Constable, 2010
9. Seawater conductivity matters. Getting it wrong can introduce spurious structure into CSEM models (red = correct, black = 1-layer approximation). Expensive mistakes have been made...
Key, 200910 −1 10 0 10 1 10 2
0
0.5
1
1.5
2
2.5
3
3.5
4
4.5
Resistivit y (ohm−m)
Dep
th(km)
TruthFree sea, 1 layer, rms 3.6Fixed sea, 20 layers
10 1 10 2 10 3 10 4
10 0
101
Electrode Spacing
App
aren
t Res
istiv
ity
100 m, 1 Ωm
10 m, 100 Ωm
100 m, 1 Ωm
1 m, 1000 Ωm
VI
VI
10. Like DC resistivity, CSEM is mainly sensitive to the resistivity-thickness product of thin resistive layers. This is called T-equivalence, where “T” = transverse resistance (i.e. resistivity times thickness).
If resistivity is proportional to net pay, this may not be much of a problem.
The Future
Marine EM was almost certainly over-sold between 2002 and 2007 or so. WesternGeco pulled out of the marine EM business in 2010 and OHM was absorbed into EMGS in 2012.
The marine EM market was recently worth around $200m/year, or about 5% of the marine seismic market. Marine EM is a capital-intensive business and there is a persistent fear of patent lawsuits, so it is difficult for smaller, innovative companies to enter the market. On the other hand, there probably isn’t enough profit for the big companies to care. But there is some progress.
EM contractor share price
PGS’ surface towed streamer system is providing good data in water depths up to 400 m or so, and allows data collection co-incident with 2D seismics.
PGS website
Petromarker website
Petromarker has a novel vertical-vertical system which can operate in deep water, but has limited lateral capabilities.
However, the custom vessel, large (3D) survey model has made CSEM a relatively expensive commodity.
On the other hand, there is only one contractor offering the standard approach that works so well in deep water.
EMGS website
Hesthammer et al., First Break, 2012; Hesthammer pers. comm. 2015
Does it work? Jonny Hesthammer thinks so. False positives have been drilled (mostly lithological resistors), but false negatives are very rare. That is, without a CSEM signature the likelihood of a commercial discovery is very low - but industry just keeps drilling and providing more data for Jonny’s plot - without more confidence in the method it is difficult to realize its value.
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NAR=15%
Weak EM response (NAR<15%)Strong EM response (NAR>15%)
Discovery - ExplorationDiscovery - Calibration
Dry well - ExplorationDry well - Calibration
Recent CSEM wells
Discovery – Non-commercial
Mostly discoveries (76%) Mostly dry wells (68%)(2.9% commercial discovery rate)
Incr
easi
ng E
M s
igna
ture
350%
300%
250%
200%
150%
100%
50%
0
-50%
Norvarg – 189 mmboeSkrugard – 286 mmboe
Havis – 250 mmboe
Bønna - Dry
Wisting – 132 mmboe
Skavl – 35 mmboe
Byrkje - Dry
Hanssen – 18-56 mmboe
Goliat 238 mmboeIvory 32 mmboe
Darwin - DryWisting Alt. - Dry
Eik - Dry
Heilo - DryBreiflabb
Storbarden - Dry
Phoenix – Dry*Apollo - Dry*
Atlantis – Minor gasMercury – 6-12 mmboe
Salina – 38 mmboe
Discovery – Unknown commerciality
Much of the CSEM data is collected by the majors (ExxonMobil, Shell, Chevron, etc.) and the large NOCs (Petrobras, Pemex, etc.). These companies keep their success rate statistics fairly confidential. But they are still collecting data… I think the future lies in smaller, portable, ship-of-opportunity systems (like the ones academics must use), expanding the market to smaller client companies. This may take the passing of a few years and a rise in oil prices, but I think we can count on both of these.
Thank you!
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