MDT_Client.ppt wireline testers MDT Modular Formation Dynamics Tester

Worldwide, wireline test tools have a diverse range of applications. These include fluid recovery for identifying the presence of hydrocarbons and providing samples for analysis. Also included are reservoir pressure measurements for precise mapping—over hundreds of points in a single well. The monitoring of pressure interferences between wells and the determination of fluid mobility are other important uses. The MDT tool employs a modular construction design to address such a range of applications. Currently, the standard tool includes electrical power, hydraulic power, single-probe and sample modules. Optional modules include multiprobe, multisample, flow control, pumpout, Optical Fluid Analyzer and dual-packer modules. The modular design allows the optimum configuration of the tool for each operation to meet specific client needs.

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FT
Formation
Tester
RFT
Repeat
Formation Tester
MDT Modular
Formation Dynamics
Tester
1955 - 1975 New Generation1975 - Present
Dual
Packer
Electrical Power
Hydraulic Power
Probe
Pumpout
Dual-probe
Flow control
Optical Fluid Analyzer
Multisample
Sample
Sample
Wireline Testers

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MDT Modular Formation Dynamics Tester

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Applications
Modular Formation dynamics TesterModular Formation dynamics Tester
Reservoir pressure
Sampling
Uncontaminated Sampling
Sampling at Reservoir Conditions
Isotropic Permeability
Anisotropic Permeability
Vertical Permeability
Interference Testing
New Applications










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MDT Modular Design
Standard tool modules
 Electrical power
 Hydraulic power
 Single-probe
 Sample chamber
Optional modules
 Multiprobe
 Flow-control
 Dual-packer
 Multisample
 Pumpout
 Optical Fluid Analyzer

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Hole Size Maximum
Rating
Max
Min Max with Kit
Single-probe5 in. 6
1/4
in.14
1/4
in.19 in. 20 kpsi
†
400°F
†
(12.7 cm)(15.9 cm)(36.2 cm)(48.3 cm)(138 mPa)(205°C)
Multiprobe 6.3 in.7
5/8
in.13
1/4
in.15 in. 20 kpsi
†
400°F
†
(16 cm)(19.4 cm)(33.7 cm)(38.1 cm)(138 mPa)(205°C)
Dual-packer5

in. 6 in. 12 in.
§
— 20 kpsi
†
275°F
‡
(12.7 cm)(15.2 cm)(30.5 cm)— (138 mPa)(150°C)
†
350°F (175°C) and 15 kpsi with the CQG* quartz gauge and/or the Optical Fluid Analyzer module
‡
260°F and 225 °F (127°C and 107°C ) in oil-base mud
§
Maximum hole size depends on the packer installed. Larger packers are available for larger hole sizes.
For HPHT jobs, a WTSR-A gauge in memory mode can be used.
There is a basic MDT (350 °F) for 25 kpsi with 25 kpsi CQG.
MDT tool specifications

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Standard MDT Tool
Electrical power
module
Hydraulic power
module
Probe module
Sample modules

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Probe flowline system
CQG
Isolation
Valve
Equalising
Valve
Strain
Gauge
Pretest
Resistivity/
Temperature
Cell
Articulated
Flowline
Filter
Valve
Front
Shoe
Probe
Pistons
Packer
Back-up
Telescoping
Pistons
Throttle/
Seal
Valve
Sample
Chamber
Sample
Module
(MRSC)
Single
Probe
(MRPS)
F
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B
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MRPS BLOCK
Filter

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Normal and Volumetric Pretests

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Volumetric Pretest

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Drawdown Pressure Limited Pretest

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Fluid Resistivity Measurement
13,000
12,000
11,000
10,000
9000
8000
32
24
16
8
0
1264 1272 1280 1288 1296 1304
Time (sec)
Sampling starts
Hydrocarbon
flowing
Fluid resistivity
Sample
chamber
full
Reservoir
pressure
Resistivity
(ohm-m)
Pressure
(psi)
2
3
/4-gal sample

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Single-Probe Data
Depth
(ft)
X500
X600
X700
X450 X550 X650
Gas
Oil
Water

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Pressure Gauges
Specification Strain Gauge CQG* Quartz Gauge
Accuracy 0.10% full scale† 2.0 psi + 0.01% of reading
Repeatability 0.06% full scale† 1.0 psi
Resolution 0.001% full scale at 0.003 psi at 1-sec
0.14-sec sampling sampling
(0.1 psi for a 10-kpsi gauge)
Temperature rating 400°F (205°C) 350°F (175°C)
†90% confidence limit

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CQG* Quartz Conventional Quartz
Gauge Gauge w/o Clock
Pressure range Atm-15 kpsi Atm-12 kpsi
Temperature range -10 to 175°C 25 to 175°C
Accuracy (over all) ±(0.01% reading +2 psi)±(0.01% reading +2psi)
Long term stability (7 days at 150°C and 10 kpsi
Better than 0.1 psi 0.5 psi
Resolution over 1 sec 0.003 psi 0.01 psi
over 0.1 sec 0.03 psi —
Pressure shock response time (return within 1 psi)
 w/o dynamic correction
– 500 psi a few sec (avg) 3 min
– 5000 psi 2 min (avg) 10 min
 with dynamic correctiona few sec (avg) N.A.
Temperature response time to a 10°C step (return within 1 psi)
 w/o dynamic correction 18 min (avg) 20 min
 with dynamic correctionalways within 1 psi N.A.
†All measurements achieved with a shock gradient around 100 ms.
Paramete
r

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Stabilization Characteristics
8010
7995
7980
0 24 48
Time (min)
Conventional quartz gauge
Pressure
(psi)
Strain gauge
+1 psi
-1 psi
CQG gauge

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Bottomhole Testing Dual-Probe System
Electrical power
module
Hydraulic power
module
Probe module
Sample modules
Electrical power
module
Hydraulic power
module
Probe module
Probe module
Sample module
Sample module

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MDT Sample Modules
Module electronics
Electrical bus
Recycling valve
Drain valve
Throttle valve
Transport valve

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Multiprobe System

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Multiprobe Operation
Sink
probe Observation
probes
Pressure
Change
(psi)
Quartz
gauge
Strain
gauge
5
0
–5
–10
–15
–1,000
–1,500
–2000
–2500
–250 255075100125150
Time (sec)
Vertical observation probe
Horizontal observation probe
Flowing probe

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Flow-Control Module PVT-Quality Samples
Electrical power
module
Hydraulic power
module
Probe module
Pumpout
module
Sample module
Dual-probe
module
Electrical power
module
Probe
module
Flow-control
module
Hydraulic power
module
Multisample
module

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Pumpout Modes
MRPO / MRMS 3-4 MRPO Theory
This information is C ONFID ENTIAL and m ust not b e copied in whole or in a ny part, and should b e filed acco rdin gly by th e ad dressee.
It must not be shown to or discussed with anyone ou tside the SCHLU MBERG ER organization.
T he MRPO can be set up at surface to be eith er in the P UMP-OU T/IN modes orthe PUMP-
UP/DOWN modes. This mea n s th at o n ce th e co rrect valves are set a t the su rface a n d the tool is
dow n ho le you can p ump INa nd OUT ofthe flow line but no t U P or D OWN. If the mod u le is set up
at surfa ce to be in th e P UMP-UP/DOWN modes, when dow nhole you can pump U P a nd DOWN
the flowline but not IN or OUT of the flowline.
PUMP-IN MODEPUMP-OUT MODE PUMP-UP MODE PUMP-DOWN MODE
*Caution: Refer to caution note in Section 3.2.3.
*CAUTION
Figure 3-2 Pumpout Module - Modes of Operation
3.2.2.Pump-Out mode
In order to obtain u n con taminate d samples of reservoir fluids itis necessarytoremove mud filtrate
from the invaded zone, before opening a sample chamb ertothe reservoir.Traditionally,mud
filtratehas been removed by taking segregated samples using the RFT. The process of
segregated sa mpling involves committing one sample chamber as a dump chambe r for mud
filtrate, w h ile a se con d ch amber is committed to take reservoir connate fluid.The limitation ofthis
m e th od is the fixe d u p p er lim it on th e vo lu m e o f filtrate th at the d ump ch a m b e r ca n h old .
R efertoFigure 3-3, MDT U nconta minated Sampling Equipme nt Combination. The main
application of th e MRPO is to remove mud filtratefromthe inva d ed zone,so thatuncontaminated
samples can be retrie ved. By using a downhole p ump,w e remove th e upperlimitrestriction on
the volume of filtrate one can flush out of the formation.

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MRPO Performance
MRPO / MRMS 3-50 MRPO Theory
This information is CON FIDEN TIAL and must not be copied in w hole or in any part, and should be filed accordingly by the addressee. It
m ust not be shown to or discussed with anyone outside the SC HLUMB ERGER organization.
Figure 3-39 shows differential pressure plotted against hydraulic pressure, motorspeed and
flow rate (for a fixed duty cycle of 85% ). T his graph is shown only toreinforce the understanding of
the operating parameters ofthe MRPO. More hydraulic pressure is needed as differential pressure
increases. T he flowrate and m otor rpm decrease as differential pressure increases.
Figure 3-39 MRPO - Differential Pressure / Hydraulic Pressure / Motor speed

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Displacement Unit Pressures

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Pumpout Module Operations
POPV
(gal)
35
30
25
20
15
10
5
0
1.4
1.2
1.0
0.8
0.6
0.4
0.2
0.0
7000
6000
5000
4000
3000
2000
1000
0
0 20 40 60 80 100 120 140 160
BFR1
(ohm-m)
BSG1
(psi)
BSG1 (probe pressure)
BFR1 (flowline resistivity)
POPV (cumulative volume pumped
6 gal
2
3/4 gal

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Optical Fluid Analyzer
Provides
• Oil and water fractions
• Fluid color
• Gas indication
Objective
• Know when to sample
• Know whether to sample
• Maintain sampling pressures above the bubble
point

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Formation Sampling
Tool String
aa
Pumpout module
Multisample module(s)
(Six 450cc samples)
Sample chamber(s)
(1, 2 3/4, or 6 gallon)
Single probe
module
Packer module
Optical fluid
analyzer module

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Fluid Sampling Overview
•Two Main Reasons to Sample
–Confirm the presence of hydrocarbons
–Fluid Properties
•Fluid Composition is Everything
–‘recipe’ for the fluid
–determines all properties
–goal is to get the reservoir recipe to the lab
•Two Main Risks
–pressure drawdown can change composition
»gases can come out of liquids: volatile oils, wet gases
»solids can come out of liquids: asphaltenes, waxes
»liquids can come out of gases: condensates
–mud filtrate can add extra ingredients to composition
»significant WBM filtrate might be tolerable in an oil sample
»must have low OBM filtrate in an oil sample
»worst case: OBM filtrate drops out of a condensate

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What can we do to get less % filtrate?
•Try to start off with less filtrate
–low loss mud, good mudcake
–low overbalance while drilling
–sample soon after drilling
–don’t damage the mudcake prior to sampling
•Be smart about where you set the probe
–pick a permeable spot…use CMR to help
–pick an anisotropic spot
–pick a spot just below a permeability barrier
–pick a spot between two permeability barriers
–use the ‘guard probe’ technique below a permeability barrier.

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Single Probe and Filtrate
Percent Filtrate
time
t
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t
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Anisotropy Improves Percent Filtrate
Percent Filtrate
time
t
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t
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Perm Barrier Improves Percent Filtrate
Percent Filtrate
time
t
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t
o

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Two Barriers Is Ideal
Percent Filtrate
time
t
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Guard Probe Simulates Second Barrier
Percent Filtrate
time
2t
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2t
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Single Probe and Dual Probe Set Below a Permeability Barrier

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Interpretation
Example 1
Example 2

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MRFA Log Example (Water)
Water volume was almost
100%.
Formation water was coming into
the flowline.
Pumpout started
Mud filtrate was cleaned up
Each spectrometer CH
response
S0 ~ S9
Gas Indicator
Water/Oil Fraction
Fluid Color
Formation Water in OBM
MDT Data
Water Peak Channels,S6 and S9
Oil Peak Channel, S8
Coloration Channels, S0 ~ S4

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MRFA Log Example (Oil)
Formation oil was coming into
the flowline.
Pumpout started
Oil volume was almost stable
because the FCOL was stable.
Mud was cleaned up
Formation Oil in OBM
Fluid Color was going down
quickly and up again.
Fluid Color was still going up
because formation oil volume
was increasing gradually.
Water/Oil track showed only oil
because filtrate and formation
fluid were both oil.
* Fluid Color (FCOL) was a only
function to discriminate the
formation oil from OBM filtrate.
S0 ~ S9

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Dual-Packer
Module
Packer-Probe
Combination
Electrical power
module
Hydraulic power
module
Probe module
Pumpout
module
Sample module
Sample module
Dual-packer
module
Electrical power
module
Pumpout
module
Dual-packer
module
Sample module

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Power Cartridge
Pumpout (In / Out Mode)
Sample Chamber
Multi-Sample
Optical Fluid Analyzer
Hydraulic Unit
Single Probe
Traditional Sampling Tool String
Sample Chamber
Conditions:
- Firm rock
- Reservoir not critical
Pump to clean-up
Multi-Sample with water cushions
Pumpout Module removes water
or
Throttle to a Sample Chamber
Sample Chamber with air cushions
- Limited Pressure drawndown
control

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Sampling Tool with Flow Control
Low Perm
Controlled drawdown
to maintain single phase
fluid or withdraw liquid in
near critical reservoir.
Average Conditions
Single phase sampling;
Sample Validation
Power Cartridge
Pumpout (In / Out Mode)
Optical Fluid Analyzer
Sample Chamber
Flow Control
Multi-Sample
Hydraulic Unit
Single Probe
Dual Packer or
2nd Single Probe
Multiple Probes for
flexibility

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Fluid Sampling Overview
•Two Main Reasons to Sample
–Confirm the presence of hydrocarbons
–Fluid Properties
•Fluid Composition is Everything
–‘recipe’ for the fluid
–determines all properties
–goal is to get the reservoir recipe to the lab
•Two Main Risks
–pressure drawdown can change composition
»gases can come out of liquids: volatile oils, wet gases
»solids can come out of liquids: asphaltenes, waxes
»liquids can come out of gases: condensates
–mud filtrate can add extra ingredients to composition
»significant WBM filtrate might be tolerable in an oil sample
»must have low OBM filtrate in an oil sample
»worst case: OBM filtrate drops out of a condensate

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Fluid Composition is Everything
Component
C
3
I
-
C
4
N
-
C
4
I
-
C
5
N
-
C
5
C
6
M
C
Y
C
-
C
5
B
E
N
Z
E
N
E
C
Y
C
L
-
C
6
C
7
M
C
Y
C
L
-
C
6
T
O
L
U
E
N
E
C
8
C
2
-
B
E
N
Z
E
N
M
&
P
-
X
Y
L
E
N
O
-
X
Y
L
E
N
E
C
9
C
1
0
C
1
1
C
1
2
C
1
3
C
1
4
C
1
5
C
1
6
C
1
7
C
1
8
C
1
9
C
2
0
C
2
1
C
2
2
C
2
3
C
2
4
+
W
e
ig
h
t

P
e
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n
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0.01
0.1
1
10
100
Live Fluid 17048 Residual Liquid
Live Fluid 17049 Residual Liquid
Expected Compositional
Trend
DBR Fluid Properties Inc.

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Phase Behavior
pure ethane pure heptane 50% ethane, 50% heptane
P P P
Liquid CP
bubble O
Liquid o CP oCP point
line dew-point
Gas Liquid 25% 50% line
75%
T Gas T Gas T

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Phase Behavior Changes w/ Composition
TEMPERATURE
T
res, P
res
DRY
GAS WET
GAS
VOLATILE
OIL
GAS
CONDENSATE
BLACK
OIL

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‘Single Phase’ Sampling
•‘Single Phase’ means ‘maintain pressure on sample to surface’
•Applications
–asphaltenes
–surface transfer
•Benefits
–asphaltenes stay in solution
–rapid wellsite validation/evaluation
•Techniques
–overpressure sample (aspect of low shock)
»low temp reservoirs only
–SPMC (single phase multisample chamber)
»all reservoirs, smaller volume

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Single Phase Sampling
asphaltene precipitation
phase separation
- flowing pressure
- reservoir pressure
- hydrostatic pressure
- reservoir + 3500 psi
- preset gas cushion pressure
T
reservoir
T
surface
Temperature
Pressure
‘single phase’ pressure -
‘low shock’ pressure -
precipitation pressure -
phase sep. pressure ---
opening pressure -
(conventional)
reservoir pressure -

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Need SPMC at Higher TemperaturesNeed SPMC at Higher Temperatures
asphaltene precipitation
phase separation
- flowing pressure
- reservoir pressure
- hydrostatic pressure
- reservoir + 3500 psi
- preset gas cushion pressure
T
reservoir
T
surface
Temperature
Pressure
‘single phase’ pressure -
precipitation pressure -
phase sep. pressure ---
‘low shock’ pressure -
opening pressure -
(conventional)
reservoir pressure -

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Power Cartridge
Pumpout (Up / Down Mode)
Hydraulic Unit
Single Probe
Low Shock Sampling Tool
Multi-Sample *
Optical Fluid Analyzer
Unconsolidated
Formations
- High Perm
- Minimum Pressure Drawdown
- Over Pressured Samples
- Flow Restricted by Pump
- Sample Chambers Flooded
Sample Chamber
Sample Chamber
* Low Shock Kit for exit port

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Borehole Images
x437
x438
x439
x440

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Summary
Major benefits with standard MDT tool
Better pressure accuracy and dynamic response reduces
survey time and improves interpretation
Surface-controlled pretest rate and volume reduce survey
time
Numerous fluid samples per trip save rig time
Surface-controlled sampling pressure improves success ratio
and aids interpretation
Flowline resistivity for fluid identification improves sample
quality
Extended range of borehole sizes saves rig time
Bottomhole testing eliminates rat hole footage

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Summary
Added applications with optional modules
Vertical and horizontal permeability
Sampling at reservoir conditions
Interference testing
PVT-quality sampling
Borehole interval testing
Flowline fluid identification in oil-base mud