Saturn 3D radial probe
Enabling, efficient, derisking, and flexible
Saturn
Formation
testing where
not previously
possible
Applications
■
Formation pressure measurement
■
■
Downhole fluid analysis (DFA)
■
■
Formation fluid sampling
■
Fluid-gradient determination
■
Far-field permeability measurement
and anisotropy determination
Well testing design optimization
Enabling: pressure measurement,
DFA, and fluid sampling
– Wide permeability range, extending
down to 0.01 mD
– Heavy oil
– Near-critical fluids
– Unconsolidated formations
– Thinly laminated formations
– Rugose and unstable boreholes
■
■
01
Benefits
■
Efficient: significant rig-time savings
Derisking: reduced station time and
assured retraction
Flexible: deployable across a wide
range of hole sizes, temperatures, and
pressures on all conveyance options,
from wireline to TLC* tough logging
conditions system to openhole tractors
Features
■
■
■
■
■
■
■
The industry’s largest total surface
flow area: 79.44 in2
8,000-psi differential pressure rating
qualified between flowline and
hydrostatic pressures
■
■
Fast setting and retracting time
No sump and low storage effect
to eliminate mixing of fluids with
stationary mud
Quantified contamination monitoring
algorithm for ensuring representative
sampling in oil-base mud
4-ft spacing from monitoring probe
above for vertical interference testing
■
■
Self-sealing drain assembly for excellent
seal maintenance during sampling in anyquality borehole
Improved mud bypass system to provide
superior pressure maintenance
in unstable wellbores
Combinable with all MDT Forte*,
MDT Forte-HT*, MDT* tester modules,
and the InSitu Fluid Analyzer* real-time
downhole fluid analysis system
Conveyance on wireline cable, TLC tough
logging conditions system, and UltraTRAC*
all-terrain wireline tractor
Four elliptical ports with fieldreplaceable, customizable filters
to prevent flowline plugging
02
Setting a new standard in downhole formation testing
The Saturn* 3D radial probe establishes
and maintains true 3D circumferential
flow in the formation around the borehole, enabling highly accurate pressure
measurement, downhole fluid analysis
(DFA), sampling, and permeability estimation in what were previously challenging
conditions for conventional wireline
formation testing:
Reducing stationary time and assuring
retraction every time significantly derisks
operations. Flexible deployment is supported
by wide borehole-size coverage, HPHT rating,
and qualification for up to 20 sequential
operational cycles in a single descent.
- rugose or unstable boreholes
- extremely low-permeability
or unconsolidated formations
- heavy oil or near-critical fluid types.
The Saturn probe’s fast setting and
retracting times, zero sump for a low
storage effect and elimination of
stationary mud mixing, and largest
flow area in the industry of 79.44 in2
facilitate efficient operations across
a wide permeability range in a single trip.
q
k A dP
uL
Flow from the formation to a conventional formation
tester is narrowed to the intake of the single probe,
not from the entire circumference of the borehole wall.
03
Back to basics
Successful wireline fluid sampling and
DFA begin with accessing a representative
sample of the virgin reservoir fluid, ideally in a
minimum amount of time. Formation pressure
testing similarly requires fluid withdrawal.
The fluid extraction is typically conducted
with a probe module that includes a packer,
telescoping backup pistons, and a flowline.
The pistons extend the probe and packer
assembly against the borehole wall to
provide a sealed fluid path from the reservoir
to the flowline. The governing principle
behind flowing any fluid from a reservoir for
formation testing is Darcy’s law, in which
flow (q) is a function of permeability (k),
drawdown pressure (dP), surface area open
to flow (A), fluid viscosity (u), and the length
(L) over which the drawdown is applied.
Different probe surface flow areas and
the maximum pressure drawdowns that
the formation tester can manage are used
depending on the formation permeability
and fluid viscosity. Typically, the larger the
surface area and the higher the maximum
drawdown pressure, the higher the flow rate
of fluid from the formation that can be
achieved for a formation testing operation.
Over the years, Schlumberger innovation
has increased the maximum allowable
differential pressure from 4,596 psi with
the standard pumpout displacement unit to
11,760 psi with a high-pressure displacement
unit. Concurrently, the available surface area
of the probes has increased by nearly 40 times,
from the standard probe’s 0.15 in2 to the 6.03-in2
elliptical probe. This technical progression
enables successfully performing formation
testing in a wider range of environments.
However, as operators attempt to tap
into hydrocarbons previously thought
to be unproducible—low-permeability
or unconsolidated reservoirs, highviscosity formation fluids—or where
reduced drawdown is necessary to
test reservoirs in which the saturation
pressure of the fluid is close to the
reservoir pressure, formation testing
is technologically challenged.
The Saturn 3D radial probe meets
these challenges with a radical
redesign of the fluid-extraction module
to deploy multiple self-sealing ports
around the borehole. With a total
surface flow area of 79.44 in2, Saturn
probe technology expands the operating
envelope of formation testing for both
fluid flow and reservoir environments.
The self-sealing drain assembly
incorporating the four ports
circumferentially extracts fluid from
the formation instead localizing
flow at a single probe.
04
x4
The Saturn 3D radial probe
increases the probe surface area by more than 500 times.
Probes not to scale.
79.44
6.03
Surface flow
area, in2
Surface flow
area, in2
Saturn 3D
radial probe
Eliptical
probe
Extralargediameter probe
Surface flow
area, in2
05
2.01
1.01
0.85
0.15
Surface flow
area, in2
Surface flow
area, in2
Surface flow
area, in2
Quicksilver Probe*
focused extraction
Large-diameter
probe
Standard
probe
Unlike the packer incorporated in a
conventional probe assembly or operations
using a dual straddle packer in the testing
string, the four ports of the Saturn probe
self-seal with suction to the borehole wall
to receive direct flow from the formation
with faster cleanup.
Complete pressure surveys
in low-mobility formations
The technology that makes the Saturn 3D
radial probe excel at fluid extraction also
delivers a step change in formation pressure
testing. Conventional formation tester probes
with the largest surface flow area currently
available are limited to pressure testing formations with mobilities no lower than about
1 mD/cP. Pretesting-only service is the current
benchmark for excellent performance in lowpermeability formations, but the mobility limit
for those pressure tests is about 0.1 mD/cP.
Direct rig-time savings in lowpermeability formations
As the permeability of a formation decreases,
the performance improvement of the Saturn 3D
radial probe over conventional probes
widens significantly.
As shown in comparison with the extralargediameter probe for achieving 5% contamination,
the Saturn 3D radial probe improves sampling
efficiency beginning at formation mobilities of
500 mD/cP, with the performance gap greatly
expanding as the mobility decreases.
Once mobility approaches 10 mD/cP, the
extralarge-diameter probe cannot move the
formation fluid, whereas the Saturn 3D radial
probe is an enabling technology.
4-in invasion, 300-psi drawdown, kv/kh = 1
25
Sample enabling in low mobility
Time to reach 5% contamination, h
Sealing with confidence
Sample efficiency
20
15
Saturn 3D radial probe
Extralarge-diameter probe
10
5
0
1
10
100
Mobility, mD/cP
Modeled cleanup times for the Saturn 3D radial probe and a conventional extralarge-diameter probe
show the increase in sampling efficiency possible. The Saturn 3D radial probe is an enabling technology
for sampling at mobilities less than 10 mD/cP, at which the conventional probe cannot perform.
06
Flow fluid in three dimensions
The Saturn 3D radial probe comprises
four elliptical suction ports, distributed
at 90° intervals around the circumference
of the tool. This placement pulls fluid
circumferentially from around the borehole,
instead of the conventional probe
arrangement of one port as the sole fluid
access point. Each of the four Saturn ports
has a surface flow area of 19.86 in2, which
is more than 3 times larger than the surface
area of an elliptical probe, which is the
largest conventional probe. Together, the
four Saturn ports total 79.44 in2 of surface
flow area, an increase of more than
500 times over the area of the standard
conventional probe.
Flow from the formation to a conventional formation tester is narrowed to the intake of the single probe, not from
the entire circumference of the borehole wall.
07
Circumferential flow around the wellbore
has significant benefits for both sampling
cleanup and interval pressure transient
testing (IPTT). The Saturn 3D radial probe
quickly removes the filtrate from the entire
circumference of the wellbore to draw in
uncontaminated formation fluid. In addition,
the significantly larger flow area of the 3D
radial probe can induce and sustain flow in
low-mobility formations, formations in which
the matrix is uncemented, and the viscous
fluid content of heavy oil reservoirs.
The four Saturn ports efficiently establish circumferential flow from the formation to quickly remove filtratecontaminated fluid and flow uncontaminated, representative fluid for DFA, sampling, and pressure measurements.
08
Circumferential support for
unconsolidated formations
The circumferential self-sealing technology
of the Saturn 3D radial probe mechanically
supports the borehole with the compliant rubber
seal of its drain assembly throughout the sampling
operation. Pressure drawdown is localized to
the four elliptical suction ports, which minimizes
the matrix stress while flowing fluid. If any matrix
disengages while flowing fluid, the Saturn 3D
radial probe is equipped with sandface filtering
mechanisms on each of the ports to prevent
plugging of the system.
Accurate permeability and permeability
anisotropy measurement
The Saturn 3D radial probe is designed with zero
sump, which significantly minimizes wellbore
storage. This storage reduction coupled with
spacing of the monitoring probe just 1.23 m
from the Saturn probe’s pressure gauge makes
it possible to derive formation permeability
and permeability anisotropy across a wide
permeability range in a single trip.
09
The mechanical retract mechanism of the Saturn 3D radial
probe employs heavy-duty springs to secure the drain
assembly when not deployed.
Extending sampling to large-diameter
wellbores, HPHT conditions, and
lengthy programs
Available in both 7-in and 9-in tool diameters,
the Saturn probe brings the efficiency of radial
fluid flow to boreholes sized up to 14½ in.
The high temperature rating of the 7-in Saturn
probe at 400 degF and high pressure rating
for both Saturn probe sizes at 30,000 psi
extends coverage across practically all
downhole environments.
Qualified for 20 sequential sealings of the drain
assembly at maximum differential pressure
in a single descent, the Saturn 3D radial probe
has achieved up to 60 settings in the field,
depending on environmental conditions. This
reliable downhole flexibility enables achieving
ambitious formation testing objectives.
Combinability and conveyance
flexibility
Full compatibility with the MDT Forte,
MDT Forte-HT, and MDT tester modules
along with the InSitu Fluid Analyzer realtime downhole fluid analysis system family
maximizes configuring the formation testing
string to match the wellbore and formation
conditions and the test objectives. Deployment
capabilities are similarly flexible—from
wireline to the TLC tough logging conditions
system to the UltraTRAC all-terrain tractor—
for accessing wells at any angle: vertical
to highly deviated and horizontal.
Reliably out of the hole, every time
Sixty-four individual heavy-duty springs
mounted around the edges of the Saturn probe
assembly and two large-diameter heavy-duty
springs around the mandrel ensure reliable,
consistent retraction of the elliptical suction
ports after every station. The large cumulative
closing force of the mechanical spring system
keeps operational risk to a bare minimum.
10
Case Study
High-quality samples in OBM and tests across wide
permeability range, Norwegian Sea
Benefits:
Enabling
Efficient
Derisking
Flexible
When a potential Lower Jurassic reservoir
was found to consist of unexpectedly poorer
quality, low-permeability rock in comparison
with the over- and underlying producing
beds in a deepwater field, Statoil wanted
to conduct a thorough evaluation by measuring
pressure data, collecting fluid samples, and
conducting pressure transient and vertical
interference tests. However, an initial run of
the MDT tester employing conventional single
probes could not answer these data needs in
the low-permeability zones. For example,
a hydrocarbon sample collected in 2.4-mD/cP
mobility after 5 h of pumping contained 17-wt%
oil-base mud (OBM) filtrate.
Sampling efficiency was greatly improved
by incorporating the Saturn 3D radial probe
in the tester toolstring. Three oil samples
and six water samples at mobilities as low
as 0.3 mD/cP were collected, including
11
fluid extracted from 5 m lower in the same
formation as a sample collected with a
conventional probe at 17-wt% contamination.
However, the Saturn probe reduced the
drawdown by half in a 0.6-mD/cP zone
to deliver only 5-wt% contamination after
6 h of pumping.
The toolstring also incorporated an
observation probe at a 1.23-m interval
from the Saturn probe for conducting
vertical interference tests (VITs) to evaluate
permeability and permeability anisotropy
and to estimate the flow potential. All four
VITs returned valid, interpretable reservoir
responses at the probes, with particularly
good data acquired in a zone with
120-mD/cP mobility. High-quality pretest
pressure measurements were made at all
Saturn probe stations, in mobility as low
as 0.3 mD/cP.
Water
1.0
0.5
0
Oil
Highly absorbing fluid flag
Pumped volume
440
420
9-bar drawdown
at 3 cm3/s
400
380
360
340
320
X Saturn probe
Three samples
at only 5 wt%
contamination
460
Pressure, bar
Volume, L
Quartz gauge
240
220
200
180
160
140
120
100
80
60
40
20
0
High quality
X Observation probe
Saturn probe derivative
Pressure and pressure derivative, psi
Gas/oil ratio,
m3/m3
Low quality
300
200
100
Observation probe derivative
10 –1
10 –2
10 –3
35-bar drawdown at 12 cm3/s
300
0
1
2
3
4
Elapsed time, h
5
6
The Saturn 3D radial probe sampled a zone at 0.6-mD/cP mobility with contamination
reduced to 5 wt% after only 6 h of pumping. Drawdown was 35 bar during cleanup
at 12 cm3/s and 9 bar during sampling at 3 cm3/s. A conventional probe used in a
zone 5 m higher in the same formation with 4 times the mobility required almost
twice the drawdown and still had 17-wt% OBM filtrate contamination.
10 –3
10 –2
10 –1
Elapsed time, h
A pressure transient test with vertical interference monitoring shows
well-developed pressure transient responses at both the Saturn probe
and the observation probe. The buildup interpretation yields a mobility of
120 mD/cP, for which a dual-packer configuration would be challenged
to create sufficient drawdown for conducting a valid test.
12
Case Study
Oil/water contact delineated in 12¼-in wellbore
in low-permeability presalt carbonate
An operator needed to accurately define the oil/water contact in a low-permeability
zone of a 12¼-in deepwater well offshore Brazil where conventional single probes had
returned only tight tests. The low mobility also implied longer pumping times on station,
which would increase operational risk.
Benefits:
Enabling
Efficient
Derisking
Flexible
13
The 9-in version of the Saturn 3D radial probe extends the efficiency of four-port fluid
extraction with the industry’s largest surface flow area to large-diameter wellbores.
Where a conventional probe had previously failed to define the pressure gradient in the
transition and water zones, the 9-in Saturn probe reliably sealed in the 12¼-in wellbore.
Fluid was extracted at stations with estimated mobilities of 0.03 and 0.06 mD/cP in only
3.5 and 6.5 h, respectively, to both save rig time and reduce risk. The purity of the collected
samples was confirmed with real-time downhole fluid analysis.
Free-Fluid
Volume
Capillary-Bound
Water
Tight Test
Dry Test
Dry Test
Tight Test
8,100
Washout
psi
NMR Porosity
9,100
0.3
Gamma Ray
0
gAPI
150
Bit Size
10
in
Water
20 0
in
V/V
0.2
Mud After
8,800
psi
10,000
Mud Before
Oil
1 8,800
psi
0.3
Depth,
m
Cable Tension
10,000 15,000 lbf
Dry test
X,550
Dry test
V/V
Permeability
0
Drawdown Mobility
Free-Fluid
0.01
mD/cP
1,000
Volume Using
NMR Permeability
3-ms Cutoff
0 0.3
V/V
0 0.01
mD
ohm.m 2,000
Density Standoff Correction
g/cm3
0.2
ohm.m 2,000
Array Induction 2
2-ft
Resistivity A10
1,000 0.2
0.25
Standard-Resolution Formation
Photoelectric Factor
Array Induction
20
2-ft
Resistivity A90
0
Free-Fluid
Volume
InSitu Fluid
Analyzer
Fluid Fractions
20
Caliper
10
Array Induction
2-ft
-1
Resistivity A30
Clay-Bound
Water
Formation pressure
ohm.m 2,000 0.45
0
Standard-Resolution
Formation Density
g/cm3
3
Near/Array-Corrected
Limestone Porosity
V/V
–0.15
The tight, low-quality pressure points (red) returned by
a conventional probe were so scattered that pressure gradients
and contacts across the low-permeability water zone could not
be determined. The Saturn 3D radial probe acquired multiple valid
pressure measurements (yellow) and low-contamination samples
from the zone that confirmed the presence of water and delineated
the contact to the overlying oil zone.
X,560
Dry test
Tight test
X,570
Lost seal
X,580
Dry test
Tight test
Lost seal
No seal
No seal
Lost seal
X,590
14
Case Studies
Saturn probe retrieves uncontaminated 7.5-API oil
from friable sandstone
Benefits:
Enabling
Efficient
Derisking
Flexible
Accurate fluid description and determination
of pressure differentials were needed to guide
well placement and completion in an onshore
Mexico field to avoid the development
of preferential flow along higher-mobility
intervals. However, the combination of a poorly
consolidated formation, with unconfined
compressive strength (UCS) values ranging
from 100 to 800 psi, and high-viscosity fluid
content meant that the pressure differential
generated by conventional formation testing
inevitably caused collapse of the wellbore wall and failure of the seal or sanding out of the tool.
The operator had to resort to temporarily
perforating, completing, and flowing each
sand separately to collect samples in coiled
tubing–deployed bottles on a DST string.
The complicated logistics and high costs
of this approach were not sustainable.
15
Unlike single-probe conventional formation
testers, the Saturn 3D radial probe is ideal for
flowing fluid in these challenging conditions
of an unconsolidated reservoir with low
mobility. The four self-sealing elliptical ports,
with the industry’s largest surface flow area
of more than 79 in2, quickly establish and
maintain flow from the entire circumference
of the wellbore instead of funneling fluid from
the reservoir to a single access point. The
result is quicker cleanup and the efficient
performance of pressure measurements.
In unconsolidated formations, the compliant
rubber surface of the Saturn probe’s drain
assembly mechanically supports the borehole
throughout the sampling operation. Pressure
drawdown is localized to the four elliptical
ports, which minimizes matrix stress while
fluid is flowing. If sand grains were drawn in with
the flowing fluid, the drain assembly incorporates individual port filters
to prevent flowline plugging.
The Saturn 3D radial probe was deployed
in the field to test and sample at multiple
stations in several wells, which have up
to 12% ovalization. Whereas conventional
probes commonly experienced lost seals
in the rugose holes, the Saturn probe’s selfsealing ports maintained seal integrity to
support the borehole in the unconsolidated
sandstone reservoirs. There was no
evidence of sand grains reaching the pumps.
Each self-sealing port incorporates a filter to capture
any dislodged matrix and prevent plugging.
Full pressure surveys were conducted in
both water- and oil-base mud environments
with only minor storage effects observed
in the pressure responses. The pressure
surveys in combination with the mobilities
determined from every pretest are being
used to design completions that will evenly
distribute injected steam among designated
intervals and avoid channeling.
Fluid sampling successfully captured
an uncontaminated sample of 7.5-API oil;
subsequent laboratory analysis reported
a viscosity of approximately 1,030 cP at
downhole conditions. Being able to use the
Saturn 3D radial probe to collect what were
previously unobtainable high-quality samples
and pressure data is providing a wealth
of information for the operator.
The Saturn 3D radial probe collected an uncontaminated
sample of 7.5-API oil from an unconsolidated sandstone
reservoir without sanding or seal failure.
16
Case Study
Saturn probe proves low-permeability laminated
pay, offshore northwest Australia
Benefits:
Enabling
Efficient
Derisking
Flexible
17
An operator identified an interval for further investigation from borehole images obtained with
the OBMI* oil-base microimager. However, a wireline formation tester with a conventional probe
was unsuccessful at evaluating the thinly laminated sands in the deepwater exploration well.
The probe’s pressure measurements were ineffective, indicating very low permeabilities, and
flow could not be established for fluid sampling.
The Saturn 3D radial probe performed well in the low-permeability laminated sands, obtaining
valid pressure measurements in submillidarcy formations for pressure transient analysis to
accurately determine the permeability. Fluid samples were collected for identification, including
a gas sample from a zone with 0.36-mD permeability. The operator’s reservoir evaluation was
greatly improved by the Saturn probe’s results to significantly increase the net pay for the well.
X,X13
X,X14
Formation contact area
of Saturn 3D probe
X,X15
X,X16
X,X17
Formation contact area
of conventional probe
Pressure measurements and fluid samples were acquired
by the Saturn radial probe with its large 79-in2 contact area
in the interval identified from images obtained by the OBMI
oil-base microimager. A conventional single probe, with its
much smaller contact area, was not able to perform in the
very low-permeability laminated sands.
18
Case Study
650% faster flow rate efficiently acquires fluids from dolomite
Benefits:
Enabling
Efficient
Derisking
Flexible
The openhole logs from a dolomitic limestone
interval drilled with saline water-base mud
in the Middle East did not indicate the
presence of hydrocarbon, but the analysis was
ambiguous because some zones had resistivity
values as low as 0.7 ohm.m. The operator
wanted to conduct DFA and collect samples to resolve the identity of the reservoir fluids,
but the time allowed at each sampling station
was limited to 4 h in consideration of mud
losses during the job.
Schlumberger deployed an advanced wireline
formation tester toolstring that included both
the Saturn 3D radial probe and an extralargediameter conventional probe to acquire fluid at multiple stations in a single trip.
19
After DFA at Station I clearly identified
60%–70% oil, Station II was selected for
determining the lowest mobile oil. The initial
sampling attempt with the extralarge-diameter
probe experienced a significant pressure drop,
with 2,000-psi drawdown and a low flow rate
of 5.2 L/h. The resulting pretest mobility was
1.5 mD/cP. After 1.5 h of pumping out, flow
was switched to the Saturn 3D radial probe,
and the rate increased 650% with only 680-psi
drawdown. The performance of the Saturn 3D
radial probe for the ratio of rate to pressure
drop was a 19-times improvement over that of
the extralarge-diameter probe for the 1.5-mD/cP
mobility. Flowline resistivity stabilization was
achieved with water identification at Station II
within the 4-h limit for the well, and the water
collected in the sample bottle confirmed the
DFA results.
Thermal Neutron Porosity
V/V
Formation Density
g/cm3
530
Pretest
Mobility
mD/cP
Formation Pressure
psi
930 0.01 1,000
46
Delta-T
Compressional Slowness
us/ft
Bulk Density Correction
g/cm3
Photoelectric Factor
Resistivity
Array Induction 4-ft A60
ohm.m
Array Induction 4-ft A30
ohm.m
Array Induction 4-ft A20
ohm.m
Array Induction 4-ft A10
ohm.m
Invaded Zone Resistivity Core
Interval
ohm.m
MDT
Station
Drillstem
Test
Interval
MDT
Quality
Station III
46
30%
oil
70%
water
0.367 psi/ft (oil)
48
48
Station I
40%
water
60%
oil
49
Station II
Water
50
0.477 psi/ft (water)
± 0.021 psi/ft
50
51
51
52
52
The extralarge-diameter probe was able to collect reservoir fluid at Station I, but after 1.5 h of pumping out at Station II, flow was switched to the
Saturn 3D radial probe, which increased the flow rate by 650%.
20
Time, s
ExtralargeDiameter
Probe
16,200
7,200
5,400
6
5
4
Pressure
X,000
W,000
9,000
Flow rate,
cm3/s
3
2
Rate
W,500
1
0
1,000
2,000
3,000
4,000
5,000
6,000
7,000
0
Time, s
35 L
5,400
3,600
20
Inflation, 7 L
Y, 800
18
Y, 600
16
Y,400
3,600
Y, 200
1,800
Pressure, Y, 000
psi
X, 800
1,800
No oil was observed by the optical analyzers for the
34 L of fluid extracted at Station II by the extralargediameter probe (left) at a large drawdown and low
rate. Once flow was switched to the Saturn 3D radial
probe (right), cleanup was achieved at a rate that
was about 3.5 times faster. The insets show how the
fluid flow in the reservoir is to a single point for the
conventional probe but circumferentially for the four
self-sealing ports.
21
7
Pressure,
psi
X,500
10,800
7,200
8
Y,000
12,600
34 L
9
Z,000
Y,500
14,400
12,600
9,000
10
16,200
14,400
10,800
Time, s
Saturn 3D
Radial
Probe
14
Formation pressure
12
10 Flow rate,
8
Flow rate
X, 600
6
X,400
4
X, 200
2
0
2,000
4,000
6,000
8,000
10,000
12,000
cm3 /s
14,000
0
16,000
Time, s
Comparison of pressure and rate of the extralarge-diameter probe (left) and Saturn 3D radial probe (right) at
Station II shows that the Saturn probe increased the flow rate 650% with only 680-psi drawdown, which is
one-third of the conventional single probe’s drawdown. The resulting ratio of rate to pressure drop delivered an improvement of 19 times over the single probe’s performance.
Saturn
Specifications
Saturn 3D Radial Probe
Measurement
Output
Logging speed
Mud type or weight limitations
Combinability
Special applications
Mechanical
Temperature rating
Pressure rating
Borehole size—min.
Borehole size—max.
Max. hole ovality
Outside diameter
Length
Weight (in air)
Ultralow-contamination formation fluids, formation pressure, fluid mobility,
downhole fluid analysis, permeability anisotropy
Stationary
None
Fully integrates with MDT modular formation dynamics tester and
InSitu Family* sensors
Low-permeability formations, heavy oil, near-critical fluids, unconsolidated
formations, rugose boreholes, large-diameter boreholes, high temperatures
7- and 9-in versions: 350 degF [177 degC]
High-temperature 7-in version: 400 degF [204 degC]
20,000 psi [138 MPa]
High-pressure version: 30,000 psi [207 MPa]
7-in version: 7.875 in [20.0 cm]
9-in version: 9.875 in [25.08 cm]
7-in version: 9.5 in [24.13 cm]
9-in version: 14.5 in [36.83 cm]
20%
Tool body: 4.75 in [12.06 cm]
7-in version drain assembly: 7 in [17.78 cm]
9-in version drain assembly: 8.75 in [22.23 cm]
5.7 ft [1.74 m]
With Modular Reservoir Sonde and Electronics
(MRSE): 12.4 ft [3.78 m]
7-in version: 385 lbm [175 kg]
9-in version: 485 lbm [220 kg]
22
Saturn
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