Geoservices
Services Catalog
2016
Surface Logging
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
Surface Logging Services
Drilling and Formation Monitoring. . . . . . . . . . . . . . . . . . . . . . . . . . . . 7
Surface Logging Units. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8
Acquisition System. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10
Sensors. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11
Advanced Monitoring Options. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12
Advance Drilling Pack. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16
Gas Portfolio. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20
InterACT Visualization* Modular Real-Time Data Display . . . . . . . . 23
Geological Operations Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25
Drilling Services
Wellbore Quality
CLEAR* Hole Cleaning and Wellbore Risk Reduction Service . . . . . . 27
FLAG* Fluid Loss and Gain Detection Service. . . . . . . . . . . . . . . . . . 32
PreVue* Pore Pressure Analysis Service. . . . . . . . . . . . . . . . . . . . . . . 35
Drilling Geomechanics Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37
Drilling Performance
Thema* Drilling Operations Support and Analysis Service. . . . . . . . 41
Drilling Analyst. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 45
Surface Formation
Evaluation Services
FLAIR* Real-Time Fluid Logging and Analysis Service . . . . . . . . . . 48
Rig Operations
Surveillance Services
SENSU* Rig Operations Surveillance and
Instrumentation System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 63
Surface Logging
Isotope Logging Service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 52
GeoFlex* Quantitative Cuttings Analysis and Imaging Service. . . . . . . 56
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
2016 GEOSERVICES SERVICES CATALOG | 1
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About Geoservices
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Products and Services
Geoservices provides services that support oilfield drilling performance and formation
evaluation. Since its foundation in 1958, it has built an unrivaled base of expertise and
specialist technologies in a range of essential areas
that help optimize field exploration and development.
Surface logging services
Drilling services
Surface formation evaluation services
As the recognized industry leader in surface
logging services, Geoservices has developed
unique measurement technologies, data
acquisition platforms, and analysis and
reporting systems.
The direct alignment of our comprehensive
offering of drilling-related products and services
with the full range of our customers’ drilling
functions and requirements reduces risk
and improves performance across all drilling
environments.
Fluid logging and analysis services at the
surface provide the first insight into reservoir
fluid composition. Advanced real-time
quantitative mineralogical and petrophysical
analyses of cuttings and isotope logging help
identify lithology for formation evaluation,
geosteering, and well placement.
Accurate and timely monitoring of the lithology
and pore fluid composition of the formations being
drilled supports critical decisions that help drill
wells more efficiently into potential pay zones.
People
Technology
Since its founding, Geoservices has recognized
the importance of a highly trained, highly
motivated, and culturally diverse workforce.
Engineers are recruited from the best
universities worldwide to build a workforce
of different nationalities and a healthy gender
balance. The structured career development
program includes fixed-step training and
relevant competence certifications.
In addition to having access to the world-leading
technologies of Schlumberger, Geoservices
benefits from the specialized products and
techniques delivered by its dedicated research
and engineering facilities in Roissy-en-France,
Paris. These facilities also enable experiments to
be conducted on a range of upstream oil and
gas activities. Key laboratories include
■■
Health, safety, and environment (HSE)
Geoservices has a long-standing commitment to
the highest standards for the health and safety
of employees, customers, and contractors as
well as to the protection of the environment and
the communities in which it works.
The global Schlumberger HSE Management
System defines the principles by which
operations are performed worldwide.
Surface Logging
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2016 GEOSERVICES SERVICES CATALOG
■■
■■
Gas Systems Laboratory
Design and prototyping of gas analyzers used
either for compositional or isotopic analysis
of hydrocarbons flowing up the well with the
drilling fluid. Analysis techniques include gas
chromatography, mass spectroscopy, and
laser absorption spectroscopy (isotopes).
Advanced Cuttings Characterization
Laboratory
Evaluation of advanced analytical techniques
such as X-ray diffraction (XRD), X-ray
fluorescence (XRF), and diffuse reflectance
infrared spectroscopy to characterize
cuttings while drilling. This is primarily
used to characterize mineralogy, elemental
composition, and total organic carbon
(TOC) content to predict zones of interest in
unconventional reservoirs.
Our specialized surface-located sensors
measure mechanical, hydraulic, and engineering
data while drilling, providing the basis for
calculating parameters such as mud pit
volumes, mud flow rate, mud weight in the
shale shaker area, mud-gas level, and return
flow rate.
This information helps detect unbalanced
formation fluid pressures, optimize the drilling
process, and maintain a safer operating
environment.
Drilling performance
A key part of drilling is managing risk in ways
that make it possible to achieve high performance in wells and borehole sections where
drilling efficiency is the priority. Drillers benefit
from recommendations to improve downhole
performance in real time based on measurement and analysis of surface parameters.
Wellbore quality
A range of drilling parameters related to pore
pressure, hole cleaning, and wellbore stability
are provided through 24/7 real-time surface
monitoring and data analysis combined with
predictive models. These help identify drilling
risks and operational issues early, minimize
NPT and invisible lost time (ILT), and increase
drilling efficiency—with minimal reservoir
interference and maximum returns.
Rig operations surveillance services
Geoservices offers the latest in digital
surveillance technology. We provide a
superior digital alternative to traditional
analog instrumentation and driller’s consoles
(primary instrumentation systems) that also
functions as an advanced electronic drilling
recorder with multiple built-in capabilities.
Our system enables drillers and their crews to
increase the efficiency of daily rig operations
by reducing NPT, lowering costs, and increasing
operational safety. Built specifically as an
automated system, it connects rig and onshore
personnel, enabling the sharing of wellsite
information such as real-time drilling data
and reports in a variety of formats.
Mud Laboratory
Development of techniques to maximize
hydrocarbon extraction from the drilling
fluid. This enables real-time monitoring of
hydrocarbons flowing through the reservoir.
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
Surface Logging
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
2016 GEOSERVICES SERVICES CATALOG
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Geoservices: A History of Innovation
Geoservices transformed the mud logging industry from the mere provision of geological
technicians into a range of specialist services delivered by highly trained expert engineers.
The company was among the first to introduce computers to the wellsite for mud logging
and was one of the first oilfield service companies to have a role in the entire life of a well.
1964
Gasmap surface
geochemistry launched to
detect microleaks above
hydrocarbon reservoirs
1975
Total Drilling Control (TDC)
service introduced
1964
Speedograph (depth
and drilling rate
recorder) introduced
1958
Geoservices
founded by
Gaston Rebilly
in France
1958–1960
1974
Geoservices Hydrologie,
later Geotherma
Groundwater and
Geothermal Engineering
(1981), launched
1961–1970
1963
R&D started for
first Geoservicesmanufactured
gas equipment
1968
Photogeology (aerial
photography) introduced
to create topographic
maps of lesser-known
areas
1971
Well logging
(mud logging)
represented 78%
of Geoservices
turnover
1975
Flame ionization
detector (FID)
pyrography used to
identify the type and
maturity of organic
matter and to detect
petroleum potential
in sediments
1984
Geoservices
early production
facilities started
1981
Demeter, one of the
first electronic gauges
for downhole pressure
and temperature
measurements,
launched
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2016 GEOSERVICES SERVICES CATALOG
Drilling
Surface Formation Evaluation
1996
Geodex, a joint venture
between Ipedex
and Geoservices,
founded to provide
integrated field
management services
Rig Operations Surveillance
2010
Geoservices acquired by Schlumberger,
adding mud logging technology to the existing
Schlumberger portfolio—an important step in
the development of higher-performance drilling
systems
2001
PreVue* pore
pressure analysis
service introduced
1991–2000
1985
Electromagnetic
MWD introduced,
an industry first
1986
First commercial
directional drilling
contract secured
1988
Gas chain with
gaslogger and
volumetric
degasser launched
Surface Logging
2009
GEM-Valve*
retrievable wireless
subsurface safety
valve system
launched
1995
Drilling campaign
in Argentina set a new
extended-reach drilling
record greatly facilitated
by the cuttings
flowmeter (CFM)
2004
FLAIR* real-time fluid
logging and analysis
service and advanced
GeoNEXT* mud logging
system launched
1998
BEST* buildup
evaluation shut-in
tool launched,
broadening the
timeframe for
analysis
2012
FLAG* fluid loss
and gain detection
service launched
2010
Isotope Logging
launched
2009
GEM-Line real-time
monitoring of the
downhole pressure
launched
1997
United GoCom, a Computalog
and Geoservices JV, formed
2003
Mobile multiphase
flowmeter (MPFM)
service created using
third-party equipment
Drilling
2014
SENSU* rig operations
surveillance and
instrumentation system
launched
2011–Today
2001–2010
1991
Geotop (with backing of
CGG), a multidisciplinary team
to optimize evaluation and
exploitation of hydrocarbon
reserves, launched
1980
“Fifth-wheel” surface
logging in the US
(left) and running
reports by hand (right)
Surface Logging
1987
Advanced Logging System
(ALS), a PC-base online
mud logging system,
launched
1981–1990
1984
Drilling Fluids Department
launched
1960
R&D and training set up in France
1995
Reserval* quantitative C1–C5 gas
measurement service introduced, a
revolutionary complete “gas chain” using the
constant-volume, constant-flow degasser and
fast chromatograph
1981
Drawworks sensor
commercialized
(measurement of bit
position, depth, and ROP)
1977
Production Business
(well testing and well
intervention) introduced
1971–1980
Today, Geoservices provides essential support from exploration to production at a time
when drilling technologies are constantly pushing back the limits of developing resources
in deep water and other challenging environments.
2008
Thema* drilling
operations support and
analysis service launched
2009
Geoservices MPFM service
(mobile and permanent
equipment) launched
Surface Formation Evaluation
2015
GeoFlex* quantitative
cuttings analysis and
imaging service launched
2016
FlairFlex* advanced real-time
fluid logging and analysis
service launched
Rig Operations Surveillance
2016 GEOSERVICES SERVICES CATALOG
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Surface Logging Services
Surface Logging
Services
Drilling and Formation Monitoring
Surface Logging Units
Acquisition System
Sensors
DRILLING AND FORMATION MONITORING
Geoservices Surface Logging Services (SLS) comprise an acquisition system and
geological laboratory to illuminate well stratigraphy and to monitor all events during
the well construction phase for wellsite safety. Integrated with enhanced workflows,
the surface logging service delivers accurate gas ratio, detection of string issues, and
process performance assessment with a secured real-time transmission that enables
data access from any location.
Geoservices Surface Logging Workflow
Advanced Monitoring Options
Sensors
& Measurements
Sensors and
Measurements
Advanced Drilling Pack
Geoservices Mud Logging
Acquisition,
Analysisand
& Reporting
Acquisitions,Alarms,
Alarms, Analysis,
Reporting
Data
DataTransmission
Transmission
Gas Portfolio
Alarms
InterACT Visualization Modular Real-Time Data Display
Geological Operations Services
Sampleanalysis
analysis
Sample
Gasanalysis
analysis
Gas
Data acquisition
monitoring
Data acquisition
and &monitoring
Processing
reporting
Processing
and&reporting
Surface Logging
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Drilling
Surface Formation Evaluation
Rig Operations Surveillance
Drilling monitoring
Formation monitoring
Wellsite surveillance is performed by monitoring drilling parameters,
mud properties, and toxic gases. Surface drilling data monitored includes
mechanical, hydraulic, and engineering parameters; downhole drilling
data monitored includes parameters imported from other sources such
as downhole pressure and gamma ray.
Geological data is obtained by physical examination of drilled cuttings.
Hydrocarbon data is obtained by the analysis of mud hydrocarbon content.
Surface Logging
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
2016 GEOSERVICES SERVICES CATALOG
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Surface Logging Units
Geoservices surface logging units provide purpose-built, climate-controlled environments
for onshore and offshore operations. The units house personnel, instruments, and data
acquisition systems, irrespective of external climate conditions. Fully equipped, they serve
as centers for collating and analyzing drilling parameters and geological data acquired
while drilling. The standard unit can accommodate up to four people full time, and the
combined services unit can accommodate up to six people full time. Both have room for
temporary visitors.
Standard Surface Logging Unit Specifications
Ratings
Fire
Structural
Electrical and shutdown
systems
Dimensions (L × W × H)
ST2
A60
DNV 2.7.1
ST3
A60
DNV 2.7.1
DNV 2.7.2
DNV 2.7.2
7.30 m × 2.59 m × 2.75 m
[23.95 ft × 8.50 ft × 9.02 ft]
7.70 m × 2.90 m × 2.75 m
[26.26 ft × 9.51 ft × 9.02 ft]
Three-phase 380 V, 480 V, 600 V, 690 V,
50 or 60 Hz
220 to 240 V
Three-phase 380 V, 415 V, 440 V, 480 V, 600 V, 690 V,
50 or 60 Hz
220 to 240 V and 110 V
18 kV A
36 kV A (with enhanced gas analyzer)
18 kV A (three-phase power required)
36 kV A (with enhanced gas analyzer)
0.6 MPa [87 psi]
0.6 MPa [87 psi]
Standard
(Worldwide)
13,500 kg [29,762 lbm]
2,500 kg [5,512 lbm]
11,000 kg [24,251 lbm]
Xcold
(Europe only)
14,000 kg [30,865 lbm]
2,500 kg [5,512 lbm]
11,500 kg [25,353 lbm]
–20 to 50 degC
[–4 to 122 degF]
–40 to 50 degC
[–40 to 122 degF]
–20 to 50 degC
[–4 to 122 degF]
–40 to 50 degC
[–40 to 122 degF]
Zone 1
Zone 1
CE, Zone 2
CE, Zone 2, NORSOK
Standard
10.0 m × 2.90 m × 2.85 m
[32.81 ft × 9.51 ft × 9.35 ft]
Xcold
10.0 m × 2.90 m × 2.80 m
[32.81 ft × 9.51 ft × 9.19 ft]
NORSOK
10.0 m × 2.90 m × 2.80 m
[32.81 ft × 9.51 ft × 9.19 ft]
18,000 kg [39,683 lbm]
3,000 kg [6,614 lbm]
15,000 kg [33,069 lbm]
Zone 1
19,000 kg [41,888 lbm]
3,000 kg [6,614 lbm]
16,000 kg [35,274 lbm]
Zone 2
20,000 kg [44,092 lbm]
3,000 kg [6,614 lbm]
17,000 kg [37,479 lbm]
CE, Zone 2
Power Supply
Input
Output
Power Consumption
Standard
Water Supply
Weight
Maximum gross weight
Payload
Tare weight
Working Temperature
Standard
Optional
Certification Level
The standard unit in a rig environment.
13,000 kg [28,661 lbm]
2,500 kg [5,512 lbm]
10,500 kg [23,149 lbm]
NORSOK
(Norway standards)
14,500 kg [31,967 lbm]
2,500 kg [5,512 lbm]
13,000 kg [28,661 lbm]
–20 to 50 degC
[–4 to 122 degF]
The combined services unit (surface logging, directional drilling, and MWD).
Combined Services Surface Logging Unit Specifications
Applications
■■
■■
Purpose-built, climate-controlled
environment, onshore or offshore
Built to the highest standards and
certified for hazardous oilfield
operations
Benefits
■■
■■
■■
■■
Features
The surface logging units are
fully equipped to serve as offices,
laboratories, and data processing
centers
■■
■■
Construction may be adapted to
specific local conditions, such as
extreme cold, heliportable rigs,
tropical forests, and deserts
■■
Cabins are pressurized, enabling
operations in hazardous
environments
■■
■■
Pressurization and shutdown control
system are included
High-quality, secured electrical
circuit
Separate workstations and
laboratory equipment
Independent air-conditioning
systems included (two for the
standard unit, three for the
combined services unit)
Sample-processing equipment
and heating modules
Secured chemical storage
To find out more, visit the Surface Logging Units web page.
Surface Logging
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2016 GEOSERVICES SERVICES CATALOG
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
Fire
Structural
Electrical and shutdown
systems
Power Supply
Input
Output
Power Consumption
Standard
Optional
Water Supply
Working Temperature
Standard
Optional
Ratings
Dimensions (L × W × H)
A60
DNV 2.7.1
DNV 2.7.2
Three-phase 380 V, 480 V, 600 V, 690 V, and 50 or 60 Hz
Three-phase and single-phase 220 to 240 V
18 kV A
36 kV A (with enhanced gas analyzer)
0.6 MPa [87 psi]
–20 to 50 degC
–40 to 50 degC
Weight
Maximum gross weight
Payload
Tare weight
Certification Level
Surface Logging
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
2016 GEOSERVICES SERVICES CATALOG
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Acquisition System
Sensors
The Geoservices acquisition system enhances drilling operations and decision making
through high-frequency and accurate data acquisition. With a dynamic, flexible design, the
system can be easily customized to meet individual challenges.
The acquisition system can connect and process data from up to 250 sensors at 1-Hz
acquisition frequency, allowing full flexibility to connect different sensor types and to import
and record parameters of any kind in a customizable database. This also allows acquisition
at high frequency (up to 50 Hz) for a maximum of 8 sensors, selectable by the user.
Accurate rig data—such as torque, standpipe pressure, cement unit
pressure, and weight on hook—is vital to efficient and safe drilling
operations. The acquisition system features contextual panels that provide
information at a glance, enabling anomalies to be identified in
a fast and accurate manner. This allows corrective action to be taken
at the earliest opportunity, improving safety and minimizing downtime.
Featuring a modern, intuitive interface, the acquisition system is fast
and easy to set up. Because of its flexible design, the system can be
customized for the specific and unique challenges that each well presents.
When required, additional services or sensors can be easily plugged in to
the platform and removed from the system when no longer required. This
plug-and-play design lets you swiftly adjust the acquisition to meet your
needs, reducing NPT and saving costs.
Analog signals are digitized directly by the field boxes located in key areas on the rig
site, enabling connection to the system network with a reduced number of cables.
Each field box is capable of connecting up to 12 sensors, allowing quick and noninvasive
rigsite installations.
The following key capabilities are provided by the acquisition system:
■■
well architecture creation and 3D cross-section view
■■
trajectory computation and follow-up
■■
bottomhole assembly (BHA) reporting
■■
mud reporting
■■
prekick sheets
■■
hydraulics reporting
■■
alarm management, including parameter values and process
and hardware failure.
The information hub.
Applications
■■
Monitoring of all well construction
operations, onshore and offshore
Benefits
■■
■■
■■
Features
Enhanced safety through quality
assurance monitoring and alarms
Reduced rig-up time with simplified
sensor connection
Reduced NPT with plug-and-play
capabilities and full integration
within a common database
■■
■■
■■
■■
High-frequency acquisition
(up to 50 Hz)
Automatic detection of system
activity
Linear and multipoint calibration
Flexibility for engineering application
plug-ins and hardware add-ons
Example of sensor layout on a land rig.
Surface Logging
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2016 GEOSERVICES SERVICES CATALOG
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
Surface Logging
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
2016 GEOSERVICES SERVICES CATALOG
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Advanced Monitoring Options
Using our well monitoring expertise, Geoservices tailors surface logging services
to specific drilling challenges. Through early abnormal event detection and quick
intervention, we can help minimize your recovery costs.
Easy Integration of Geoservices Advance Monitoring Options with the Core Acquisition System
Real-time monitoring for pressure tests
■■
Charts pumped volume versus time
■■
Replay and superimposing method
Advanced Drilling Pack
The Automatic Flowback application is fully automatic and
enables close monitoring of potential well imbalance during
critical operations when potential losses and influxes are likely
to occur. This application is especially valuable for deepwater
and high-pressure, high-temperature environments in which
narrow mud-weight windows may be encountered.
Benefits
Pressure Integrity Monitoring
■■
Automatic Flowback
■■
Provides faster detection of abnormal well balance events
■■
Minimizes potential influx volume and recovery costs
■■
Enables faster decision making
Automatic flowback identification enables faster detection of well balance events.
Automatic Flowback
■■
Vibrations
■■
■■
KPIs
■■
■■
Dual mast management
■■
Mechanical specific energy
■■
At-bit data tracking
Pop-up window
Automatic fingerprinting
alarm
Torque and Drag
The Torque and Drag (T&D) application plots the pickup
and slack-off points that are automatically recorded
and detected depending on operation status. These records
can be compared with a model established beforehand
(T&D trend estimation) as a function of wellbore geometry,
fluid, and downhole string characteristics.
Benefits
■■
Optimizes wiper trips and pill frequency
■■
Detects abnormal wellbore conditions
■■
Enhances reaming programs and reduces ILT
D-Exponent
Torque and Drag
■■
Pickup slack-off (PUSO)
modeling
Acquisition System
■■
■■
Real-time D-Exponent
Plot of pickup and slack-off points.
Overburden and fracture
gradient model
■■
Automatic PUSO
■■
Pore pressure estimation
■■
Measurements versus model
■■
Fracture pressure estimation
Fluid Displacement Monitoring
■■
■■
Surface Logging
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2016 GEOSERVICES SERVICES CATALOG
Real-time view on 2D well schematic
Pills monitoring and cement
job simulation
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
Surface Logging
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
2016 GEOSERVICES SERVICES CATALOG
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Advanced Monitoring Options
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Tech Report
D-Exponent
The D-Exponent application provides overpressure evaluation and
compaction trend estimation, interpreted by our engineers using
drilling parameters acquired by the surface logging unit.
TECH REPORT
OFFSHORE
DEEP WATER
Benefits
■■
■■
Ensures that mud-weight selection is appropriate for the
formation being drilled
Depth
Monitors for warning signs that indicate overpressure
Background
15,970 ft
When a pump shut-off event occurs, a volume
of drilling fluid flows back to the active mud pit
system driven by several hydraulics factors.
During a drilling program, analysts compared
different flowbacks in real time to quickly
determine if an unwanted wellbore event
had occurred.
Overpressure evaluation using the D-Exponent method.
Pressure Integrity Monitoring
This application closely monitors all pressure tests, including
formation integrity, leakoff, and BOP tests.
Benefits
■■
■■
■■
Determines fracture pressure and equivalent mud weight (EMW)
in real time
The Acquisition System Flowback Feature Enables
Fast Detection of Abnormal Mud Volume Return
Decision-ready information detects unwanted wellbore event
and reduces NPT
The advanced flowback feature of the latest
data acquisition system provided the following:
■
Fingerprinting mud return baseline
■
Automatic flowback screen pop-up
■
Real-time visualization of mud volume return
■
Synchronized and superimposed events
■
Internal and external alarm management
Technology
■
Avoids unnecessary overpressuring during tests
Advanced flowback feature of the data
acquisition system
Using the data acquisition system, Geoservices analysts observed the red profile was trending above the
fingerprinted baseline for the same flow shut-off procedure. Having such a plot in real time enabled quicker
detection of abnormal well balance events, facilitated faster decision making, minimized potential influx volumes,
and reduced recovery time and costs. The influx was suspected only three minutes after shutoff (10-bbl increase),
and confirmation was received after five minutes (20-bbl increase).
Provides accurate monitoring and recording of BOP stack tests
in real time
slb.com/drilling
© 2014 Schlumberger. All rights reserved. 13-GS-0020
Accurate real-time monitoring tool for pressure tests.
Fluid Displacement Monitoring
The Fluid Displacement Monitoring application is used either to simulate
a cement job or to evaluate the position of pills, lost circulation material
(LCM), and cement plugs in real time.
Benefits
■■
Enables onsite premodeling of cement jobs in planning phases
■■
Minimizes the risk of incorrect positioning of pumped pills and plugs
Onsite premodeling of cement jobs.
Surface Logging
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2016 GEOSERVICES SERVICES CATALOG
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
Surface Logging
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
2016 GEOSERVICES SERVICES CATALOG
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Advanced Drilling Pack
The Advanced Drilling Pack provides a suite of tools and processes to monitor drilling
parameters and process performance, enabling rig NPT to be minimized.
At-Bit Data Tracking
At-Bit Data Tracking uses a unique synchronization process in which
lagged data measured at surface is projected to when it was at the bit.
The data can be compared in real time with surface events or activities.
Benefits
Mechanical Specific Energy
■■
This monitoring process provides the ability to detect changes
in drilling efficiency or lithological drillability variation. Generally,
mechanical specific energy (MSE) increases when drillability and the
efficiency of the drilling process decrease. MSE is always measured from
surface, but it can also be computed on bottom to eliminate all friction
effects from the borehole.
■■
■■
Enables immediate gas peak characterization
Provides direct synchronization of “in” and “out” data
for lag-time accuracy
Enhances and speeds up the decision-making process,
avoiding imbalance events and associated recovery costs
Benefits
■■
Enables cost savings through bit-replacement optimization
■■
Enhances bit efficiency with optimized drilling parameters
Synchronization of lag and drilling data through the at-bit process.
KPIs
Using the automatic detection of rig activity, the duration of each
operation (such as slip-to-slip time) is logged and made available for
time analysis, enabling the tracking and monitoring of KPIs.
Benefits
Assessment of drilling efficiency changes.
■■
■■
Vibrations
The Vibrations application provides severity assessment of axial
and torsional vibrations based on high-frequency surface data.
Enables ILT to be quantified to detect efficiency-improvement
opportunities
Provides metrics for postwell evaluations, enabling processoptimization analysis to consistently and cost-effectively
improve performance
Benefits
■■
■■
■■
Quantify ILT using real-time KPIs.
Optimizes drilling parameters to avoid harmful drillstring
resonance effects during drilling and coring operations
Maximizes opportunities for integral core recovery
Avoids mechanical failures and reduces cost of delivery caused
by potential tool replacement and extended operations time
Dual Mast Monitoring
The Dual Mast Monitoring application provides a dedicated process to
monitor and log all operations occurring simultaneously on a rig equipped
with two-derrick systems.
Benefits
■■
Vibration detection from surface measurements.
Surface Logging
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Drilling
Surface Formation Evaluation
Rig Operations Surveillance
Enables simultaneous and flexible monitoring of all operations
occurring on both masts
Surface Logging
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
2016 GEOSERVICES SERVICES CATALOG
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17
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Tech Report
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Tech Report
TECH REPORT
TECH REPORT
ONSHORE
MIDDLE EAST
OFFSHORE
Background
During core sampling, drillstring vibrations
were adversely affecting the efficiency
and quality of core recovery.
WEST AFRICA
Vibrations Monitoring Maximizes Core Integrity
Real-time analysis and control of drilling parameters prevents
breaks and fractures in core samples
Using high-frequency acquisition and dedicated
processes within the vibrations monitoring
service of the GN4 acquisition system,
vibrations were monitored from the surface.
This enabled the operator to manage
drilling parameters and minimize drillstring
vibrations, ensuring the recovery of a clean
and undamaged core.
2,510 m
Background
While drilling a well in West Africa,
the client needed to ensure lag time
was accurately calculated without
interrupting operations.
At-Bit Data Enhances Geological Interpretation
Combined real-time technologies help correctly assess the volume
of mud system, detecting deviations from theoretical calculations
Accurate lag-time calculation is vital since
it provides the native depth for all data
conveyed to the surface, such as hydrocarbons
and cuttings. Incorrect lag-time calculation
may lead to geological misinterpretation
and increased well costs.
Technology
■
DEPTH
MW Out
Tandem pill
out of hole
Technologies
Vibrations monitoring service
of the GN4 data acquisition system
■
■
The real-time vibrations monitoring service of the GN4
acquisition system highlighted the severe torsional
vibrations that caused the broken and fractured core.
3Tandem
minutespill
out of hole
Pump tandem pill
Real-time At-Bit Data Tracking service
of the GN4 data acquisition system
Tandem pill
passing at bit
Coriolis mud weight sensor
A tandem pill was pumped, resulting in a specific response in the standpipe pressure. Using the highly accurate
Coriolis mud weight sensor, the tandem pill was observed on the surface one lag time later. The pill was also
automatically projected when it was at the bit. Both sets of data were then superimposed and synchronized, allowing
actual versus theoretical lag time to be compared. A lag-time calculation error of 3 minutes was detected, which if left
unnoticed could have resulted in inaccurate well stratigraphy.
For the second core, the data from the vibrations monitoring
service was used to adjust drilling parameters, reducing
vibrations and resulting in a clean and unbroken core.
slb.com/geoservices
slb.com/geoservices
© 2015 Schlumberger. All rights reserved. 14-gs-0057
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Drilling
Surface Formation Evaluation
Rig Operations Surveillance
© 2015 Schlumberger. All rights reserved. 14-gs-0058
Surface Logging
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
2016 GEOSERVICES SERVICES CATALOG
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19
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Gas Portfolio
PIONEERING THE STANDARDIZATION OF GAS SAMPLING
Today’s challenging drilling environments, coupled with the increased complexity
of reservoirs, introduce factors that affect mud-gas measurements at the surface.
In deepwater operations, the low mud temperature out (caused by
the riser-cooling effect) does not allow efficient gas extraction. Such
conditions affect gas measurements and can mislead interpretation.
The constant-volume heated degasser from Geoservices enables better
extraction in the traditional surface logging gas spectrum (C1–C5) in cold
mud, mitigating incorrect interpretation. The constant-volume heated
degasser can be used in all geological, drilling, and mud environments.
The Geoservices portfolio covers surface logging challenges in
alignment with well complexity, providing answers in high vertical
resolution to enable efficient and rapid onsite extraction and analysis
of hydrocarbons.
Data standardization in any environment
Flexible and fully adaptable to meet your needs, modern gas analysis
chains from basic safety gas monitoring to highly advanced solutions
provide data standardization—even in harsh environments.
Geoservices industry-leading fast gas analyzers, such as the Reserval
qualitative C1–C5 gas measurement service, and solid quality-control
processes help to ensure data quality at all times.
Following gas data on the Reserval measurement service.
Gas sampling under constant conditions
The gas extractor is characterized by constant
gas-air volume in the degassing chamber,
constant mud flow through the system, and
constant agitator speed. The gas sample is
therefore taken under constant conditions,
delivering the same gas sample extraction
efficiency and enhancing comparability of
the data measured. The gas measurement
results can be easily standardized versus
the drilling parameters, providing a powerful
interpretation tool for comparing different
sections of the wellbore or comparing with
a reference well.
Conventional degasser
Constant-volume degasser
Contamination-free chromatography
Gas quantity, ppm
The polar components in standard analyzers can affect C4 and C5 measurement, resulting in
standard chromatographic analysis gas readings that may be biased by contaminants. Complex
drilling fluids can also affect the quality of mud-gas data by introducing contaminants such as
complex amines or alcohols in the extracted gas.
Additionally, the heat that is generated at the bit when drilling in hard and abrasive formations
can induce thermal cracking of the hydrocarbons downhole and produce artificial components
that directly contaminate the C2 measurement—especially on fast-response chromatographs.
Geoservices technologies prevent gas data from being contaminated, providing reliable gas
results that are unaffected by synthetic chemical components and bit metamorphism effects.
Gas quantity, ppm
The constant-volume gas extractor enables
mud to be sampled very close to the
wellhead. This minimizes the degassing
effect on the light components (C1–C2) of the
gas into the atmosphere. The conventional
positioning of gas traps in the shaker enables
the degassing effect to adversely alter the
gas ratios between components when using
standard methods of sampling.
Better extraction in cold mud (right) in comparison with a standard degasser's extraction performance (left).
The effect of contaminants on gas readings.
Time
Time
Spurious peak due to mud level fluctuations
and gas trap starvation effect.
No spurious peak—measurements consistent
with fluid reservoir composition.
Total gas
C1
C2
C3
i-C4 and n-C4 (dashed)
i-C5 and n-C5 (dashed)
Effect of contaminants on standard fast-response
chromatographs.
A chromatogram showing that the contamination
has been removed from the data.
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Surface Formation Evaluation
Rig Operations Surveillance
Surface Logging
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Surface Formation Evaluation
Rig Operations Surveillance
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Gas Portfolio
InterACT Visualization
PIONEERING THE STANDARDIZATION OF GAS SAMPLING
MODULAR REAL-TIME DATA DISPLAY
Recycling Indication Options
The InterACT Visualization display provides globally accessible and fully integrated
drilling-parameter visualization. It incorporates an interactive Geoservices viewer, which
displays cuttings descriptions, interpreted lithology, gas data, a driller’s console, MWD
and LWD measurements, and recorded events through specific screens. Information is
displayed as a function of time or depth, or in numerical format, with real-time comments.
Gas in
The InterACT Visualization display enables secure, two-way
communication of drilling and gas parameters, geological data, and
comments and recommendations in real time, worldwide.
No special software or dedicated communication infrastructure is
required, enabling users to securely monitor multiple rig operations
simultaneously through a web browser whenever they are connected
to the Internet, intranet, or a mininum 3G network.
Users can monitor multiple wells simultaneously in a single viewer,
using the real-time data displays in the InterACT Visualization display
to compare data, including key indicators, depth data, and surveys.
Gas out
Applications
■■
■■
■■
Real-time drilling-parameter
visualization
Rig-to-office file exchange
Secure data sharing and
collaboration between the entire
team, including the rig crew
Benefits
■■
■■
■■
Enables informed and timely drilling
decisions
Reduces risk and costs
Monitors multiple rig operations
simultaneously
Correction for recycled gas at bit
■■
■■
■■
■■
■■
Safety indicator for gas-cut mud effect
■■
Improved control of rig degassing system efficiency
■■
Features
■■
Indication of drilling fluid capability to retain
hydrocarbons from drilling processes
Real-time access to drilling,
geological, and gas data
Secure access and file transfer from
anywhere via the Internet
Fully integrated and customizable
visualization
Simultaneous monitoring of multiple
wells
Compatible with wellsite
information transfer specifications
Real-time data display of drilling, geological, and gas data, including real-time comments.
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Surface Formation Evaluation
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Surface Logging
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Surface Formation Evaluation
Rig Operations Surveillance
2016 GEOSERVICES SERVICES CATALOG
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InterACT Visualization for Mud Logging
InterACT Visualization
A patented technique for monitoring connection status buffers
data if communication to the rig is temporarily interrupted and automatically resumes data flow—without gaps—when the connection
is restored. The InterACT Visualization service also provides
a comprehensive project work area. Team members can upload
MODULAR REAL-TIME DATA DISPLAY
and share any type of file, and files uploaded by anyone on the project
are automatically downloaded to the user’s desktop without the need
to browse the World Wide Web. The service includes an application
that will ensure synchronization of the system with the user’s
Windows® desktop.
Customizable displays and reliable data transfer
InterACT Visualization display for tablets and mobile devices
The InterACT Visualization display’s log viewer offers intuitive
customization of displayed parameters, header positions, curve positions
and formats, track properties, and scales. Users can modify displays to
suit individual preferences and then share them with others to ensure
that the information is seen consistently by all parties. Collaborative
capabilities include online chat for timely and efficient interaction. A
patented technique for monitoring connection status buffers data if
communication to the rig is temporarily interrupted and automatically
resumes data flow without gaps when the connection is restored.
Viewing logs via predefined viewing windows is as simple as clicking
a link. The fully customizable viewer enables users to
■■
modify the presentation format to view additional data
■■
change the vertical scale to see smaller features or a larger interval
■■
zoom in and out of the log
■■
display and track data values.
Viewing logs via predefined viewing windows is as simple as clicking
a link. The viewer is fully customizable, enabling you to
change or modify the presentation format to view additional data
■
change the vertical scale to see smaller features or a larger interval
■
zoom in and out of the log
■
display and track data values.
Geological Operations Services
The Geoservices wellsite geologist drives our geological operations services and is a key
contributor to the drilling process. All our wellsite geologists have advanced technical skills
and broad field experience.
With extensive activities worldwide, our wellsite geologists form a unique
pool of highly trained personnel. They work mostly onsite (offshore or
onshore) but can also work as operations geologists in customer offices.
The display also provides a comprehensive project work area. Team
To find out more, visit the InterACT Visualization data display web page.
members can upload and share any type of file, and files uploaded by
The InterACT Visualization Drilling time viewer displays drilling parameters
The InterACT Drilling Multi-Wells viewer enables simultaneous monitoring
anyone
the project are automatically downloaded to the user’s desktop.
as a function of time and shows comments.
of
multipleon
wells.
The service includes an application that ensures synchronization of the
system with the user’s Microsoft® Windows® desktop.
interACt Visualization for tablets and mobile devices
■
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Core expertise
Our wellsite geologists are competent in the following disciplines:
■■
wellsite geology
■■
geological interpretation
■■
reservoir evaluation
■■
reporting procedures
■■
supervision and quality assurance
■■
wireline logging.
As well as studying rock cuttings from oil and gas wells to determine what
rock formations are being drilled into, wellsite geologists also
■■
supervise every stage of the drilling process
■■
ensure that correct health and safety procedures are followed
■■
■■
identify critical strata from rock cuttings, sidewall core, and
conventional core sample data
compile drilling reports and logs, including a final well report.
Our wellsite geologists also liaise with drilling and petroleum engineers
during the course of projects, conveying information fluently, interpreting
and clarifying details, and explaining the rationale.
In addition, our operations geologists are experienced in tasks including
well planning, well supervision, and the provision of wellsite and
shorebase services.
From reservoir characterization to production, the InterACT global
connectivity, collaboration, and information service delivers accurate,
secure well and reservoir data directly to your Web-enabled
device—at any time, to anywhere.
Combining knowledge of logging services (surface logging, LWD, and
wireline) with an understanding of oil and gas geology, our wellsite
geologists are able to quantify and QC geological data. This enables
them to determine reservoir architecture and compartmentalization,
hydrocarbons in place, and lithology or facies distribution via a singleor multiwell dataset.
Predefined viewing windows that enable log display on tablets
and mobile devices.
The wellsite geologist following up the drilling process with the
surface logging crew.
www.slb.com/interACt
*Markoperations
of Schlumberger
The
control room.
Other company, product, and service names are the properties of their respective owners.
Copyright © 2013 Schlumberger. All rights reserved. 13-GS-0075
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Drilling
Surface Formation Evaluation
Rig Operations Surveillance
Surface Logging
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
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25
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CLEAR
Drilling Services
HOLE CLEANING AND WELLBORE RISK REDUCTION SERVICE
Wellbore Quality
The simple, reliable, and robust CLEAR service monitors hole cleaning effectiveness and
wellbore stability, providing real-time data to help the drilling team continually improve
drilling performance and reduce NPT.
CLEAR Hole Cleaning and Wellbore
Risk Reduction Service
FLAG Fluid Loss and Gain Detection Service
PreVue Pore Pressure Analysis Service
Drilling Geomechanics Services
Drilling Performance
Thema Drilling Operations Support and
Analysis Service
Drilling Analyst
Applications
■■
Extended-reach drilling and
highly deviated wells
■■
Horizontal and multilateral wells
■■
Deepwater wells
■■
■■
■■
■■
Surface Logging
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2016 GEOSERVICES SERVICES CATALOG
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
Surface Logging
Features
Benefits
Increase safety by monitoring
wellbore stability with drilling
practices based on cuttings
flowmeter (CFM) measurements
and indicators
Drill faster by ensuring good
wellbore cleaning and condition
Reduce NPT and stuck pipe risk
by optimizing monitoring, analysis,
and hole cleaning recommendations
■■
■■
Digital measurements for improved
cuttings evaluation accuracy
Real-time dashboard with a simple,
intuitive interface
■■
One-click report generation
■■
Transparency in data delivery
■■
Automatic alarm to signal when
operational integrity of the
equipment is compromised
Optimize pill program and identify
best practices for future wells
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
2016 GEOSERVICES SERVICES CATALOG
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CLEAR
HOLE CLEANING AND WELLBORE RISK REDUCTION SERVICE
Flexible service delivery
Using the CLEAR service, the weight and volume
of cuttings are continuously measured at surface
and compared with theoretical data to provide
early detection of inadequate hole cleaning and
wellbore stability issues. This helps confirm that
the mud and drilling parameters are effectively
removing and bringing cuttings to surface,
mitigating problems such as bit balling, cuttings
bed, stuck pipe, and packoff, which could lead
to formation damage or loss of circulation.
Advanced services are available in addition to the
CLEAR service dashboard and CFM equipment,
providing next-level analysis through expert-level
interpretation and evaluation of hole cleaning,
lessons learned, and best practices for future use.
Automated solutions improve data integrity and
quality control as well as reduce the workforce
required on the rig. With multiple service delivery
options, the CLEAR service provides the flexibility
to choose which services and deliverables are
most appropriate for the operation.
Multiple sensors and digital signals
A CFM located at the end of each shale shaker
incorporates a weighing tray positioned to
catch cuttings as they fall off the screen. The
tray is locked in position for a fixed interval,
and cuttings that accumulate on it are
weighed via strain gauges.
Cuttings Flowmeter Specifications
Online dashboard at the rig site or at remote offices that displays real-time cuttings flow information.
Digital outputs are sent to the acquisition
system, which performs the computations. At
the end of the adjustable preset period, the tray
swings down and discharges the wet cuttings.
The tray then returns to a horizontal position
for the next measurement. The pneumatically
controlled device is powered by the rig air supply.
The CLEAR service is compliant with the
European Union’s Atmosphères Explosives
directive as well as rated by the European
Conformance (CE) and by the International
Electrotechnical Commission Explosive Scheme.
Length
Width
Height
Minimum
Maximum
Minimum free space
required under shaker
Weight
Strain gauges
Paddle volume
Sensor nominal sensitivity
Sensor nominal load
Minimum air supply
1.85 m [6.08 ft]
0.50 m [1.64 ft]
1.04 m [3.42 ft]
1.10 m [3.62 ft]
0.11 m [0.36 ft]
CFM and weighing tray located at the end of each shale shaker to catch cuttings as they fall off the screen.
145 kg [320 lbm]
4
28 L [7.4 galUS]
2 mV/V ± 1%
100 kg [220 lbm]
0.6 MPa [87.02 psi]
To find out more, visit the CLEAR service web page.
Comprehensive, real-time data dashboard
The CLEAR service provides comprehensive, realtime cuttings flow information integrated with
drilling parameters, cuttings geology, drilling fluid
properties, and MLWD data. Results are visually
displayed through the CLEAR service dashboard,
accessible online whenever and wherever it’s
needed—at the rigsite or at remote offices for
analysis by well construction engineers. The
accessibility and ease-of-use of the dashboard
allows the drilling team to more efficiently assess
hole cleaning effectiveness and to minimize
wellbore stability risks.
Efficient assessment of hole cleaning effectiveness for minimizing wellbore instability risks.
Accumulated cuttings weighed using strain gauges.
Surface Logging
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Drilling
Surface Formation Evaluation
Rig Operations Surveillance
Surface Logging
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
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Optimized hole cleaning and pill strategy helps improve drilling performance
and minimize risk, Southeast Asia
CHALLENGE
Optimize hole cleaning strategy, minimize risk
Mitigate wellbore instability suspected during
an extended-reach drilling (ERD) operation
that poses safety concerns and threats to the
operator’s schedule and budget.
During a three-well ERD operation in Southeast Asia, an operator wanted to measure and optimize its
hole cleaning strategy to mitigate risk when drilling 12¼-in × 13½-in sections. The primary challenge
was to deliver a long horizontal section at 70° with average departure greater than 5,000 ft [1,524 m]
while minimizing the number of bit runs, avoiding overloading the annulus with cuttings, and
maintaining wellbore stability.
Use the CLEAR* hole cleaning and wellbore
risk reduction service to monitor cuttings
removal from the hole and to analyze the
efficiency of the hole cleaning strategy.
RESULTS
Obtained continuous measurement of hole
cleaning and stability, allowing the drilling
team to adjust the drilling parameters, equipment, mud rheology, and pills.
150,000
15
100,000
10
50,000
5
0
ERD has proven to be an efficient solution in reservoirs with restricted production, reducing wellsite
footprint and minimizing environmental effects while dramatically improving reservoir drainage at
reduced cost. However, using this method to drill horizontal wells requires advanced technology
that can accurately describe downhole conditions to identify the causes of harmful vibrations, BHA
damage, poor performance, and inadequate hole cleaning.
Use CLEAR service to maintain wellbore stability
The CLEAR hole cleaning and wellbore risk reduction service was used by the operator to monitor
cuttings removal from the hole and to analyze the efficiency of the hole cleaning strategy. The
weight of cuttings reaching the surface is continuously measured and analyzed as they come off
the shale shakers. By comparing measured and theoretical volumes, the service provides early
detection of inadequate hole cleaning and of excess returns caused by wellbore instability (caving)
or formation damage.
Time directly saved, h
Operator Saves 16 Rig Hours and USD 194,000
Using CLEAR Service
Cost saving, USD
CASE STUDY: Operator saves 16 rig hours and USD 194,000 using CLEAR service
CASE STUDY
SOLUTION
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0
Well 1
Cost saved
Well 2 #1
Well 2 #St1
Well 3
Time saved
The hole cleaning strategy using CLEAR service saved USD 194,000.
Improved drilling performance, saved time and expenditures
Using the CLEAR service, the hole cleaning and pill strategy was successfully optimized. The frequency
of the pills used was decreased without detrimental effect on the hole cleaning, improving the net
ROP and decreasing hidden time spent on mud treatment.
Through correlation and systematic benchmarking on the impact of cutting lifting of the pills, the
size, frequency, and type of pills used were revised according to the data to optimize efficiency and
control time dedicated for a secondary hole cleaning. These results decreased the invisible lost time.
High-viscosity pills were maintained for the larger-OD slant hole, and tandem pills were assessed and
measured as having optimal performance in smaller ODs.
The solution led to an overall improvement in drilling performance. The average time spent per stand
for circulating and pumping pills decreased by 11 minutes compared with previous wellbores. Due to
a more systematic approach, the operator saved 16 hours of rig time and USD 194,000 in direct costs.
Information provided by the CLEAR service showed that the drilling fluid rheology was ineffective
and, because of insufficient hole cleaning, the well was degrading further. Acting on this information,
the drilling team adjusted the approach by raising the low-end fluid rheology, improving hole cleaning
and avoiding the need for unplanned circulation.
250
Operation time, min
200
150
100
50
0
Well 1
Time per stand
Well 2 #1
Drilling time per stand
Well 2 #St1
Well 3
Wellbore treatment time per stand
The operator saved 16 rig hours using CLEAR service.
slb.com/CLEAR
Wellbore Quality Services
Surface Logging
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2016 GEOSERVICES SERVICES CATALOG
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
*Mark of Schlumberger
Other company, product, and service names
are the properties of their respective owners.
Copyright © 2015 Schlumberger. All rights reserved. 15-GS-0017
Surface Logging
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
2016 GEOSERVICES SERVICES CATALOG
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FLAG
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Winner of the Offshore
Technology Conference
(OTC) 2014 Spotlight on
New Technology Award
FLUID LOSS AND GAIN DETECTION SERVICE
The FLAG service, delivered by Geoservices analysts, detects influx or loss in the well
faster than sensors monitoring the mud pits.
Significant reduction in risk
Fluid influx or loss is a potential hazard that can lead to loss of control
of a well, with potential loss of life and damage to property and the
environment. As deepwater and other increasingly complex drilling
programs multiply, the magnitude of the possible risks continues to grow.
The FLAG service aims to meet these challenges with an essential early
warning system that is highly sensitive to fluctuations but sufficiently
intelligent to help prevent false alarms, making it an ideal primary well
control device.
The FLAG service provided on a rig
using an electromagnetic flowmeter.
Applications
Benefits
Features
■■
Rapid kick and loss detection
■■
Improves well safety
■■
Flowback fingerprinting
■■
Reduces NPT
■■
Pump efficiency measurement
■■
Lowers environmental risk
■■
Optimizes drilling procedures
■■
■■
Drilling fluid displacement
monitoring
Cement displacement and free-fall
monitoring
■■
Wellbore ballooning characterization
■■
Tripping and casing run monitoring
■■
■■
■■
■■
■■
■■
■■
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Drilling
Accurate differential flowout under
various operating conditions
Reliable differential flowout alarm
corrected for heave, flowline effect,
mud compressibility,
and reciprocation
True assessment of flow from
the wellbore
Accurate monitoring under various
operating conditions—drilling,
circulating, pipe connection, tripping,
or cementing
Intuitive visual displays, alarms,
and quality controls
Suitable for deepwater, HPHT,
slimhole, and conventional wells
on any type of rig
The FLAG service is calibrated for the rig
circulating system to compute the theoretical
return flow from the well in real time.
The streamlined interface minimizes user
dependence. A Coriolis flowmeter† installed in the
return flowline continuously measures the actual
return flow. By comparing the measured and
theoretical values, the FLAG service can detect
an influx or loss almost as soon as it occurs,
even under conditions that may make detection
difficult by conventional means. Monitoring
losses and gains in the flowline instead of the
mud pit ensures faster detection and gives a
true picture of downhole conditions, unaffected
by surface actions such as the addition of
chemicals to the mud pit or mud transfers.
Dedicated support technician for
supervision of design, installation,
and commissioning
Stand-alone capability
Surface Formation Evaluation
Rig Operations Surveillance
The algorithm is accurate under a number
of operating conditions such as drilling,
tripping, circulating, and cementing. The
system automatically compensates for mud
compressibility and disturbances that could
mask the true flow, such as pipe movement
or heave on a floating rig. Transitional flow
regimes, such as those created by starting
or stopping of the pumps, can also be
accommodated.
In addition to visual and audible alarms
activated by preset thresholds, computed
and measured data and the alarm status are
continually displayed in log format on the
Schlumberger monitors. When used as part
of the Thema drilling operations support and
analysis service, depth- and time-base data
from the FLAG service and a number of other
sensors are used to display decision-ready
information on drilling performance and safety
via customizable screens in real time.
FLAG service provided on a drillship
using a Coriolis flowmeter.
An electromagnetic flowmeter is used when space
constraints do not permit installation of a Coriolis
flowmeter and a water-base mud is in use.
†
Surface Logging
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
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FLAG
PreVue
FLUID LOSS AND GAIN DETECTION SERVICE
PORE PRESSURE ANALYSIS SERVICE
Rapid system response
The PreVue service provides real-time monitoring and prediction of pore pressure and
fracture gradients at the wellsite using LWD (gamma ray, resistivity, and sonic), MWD
(annular pressure), drilling (ROP and torque), gas (C1–C5), and other surface logging data,
including cutting and caving morphology diagnosis.
Quick and reliable detection of fluid influx
or loss in the well is crucial, especially when
drilling a slim hole or when drilling under
high-pressure, high-temperature conditions.
The FLAG fluid loss and gain detection
service, delivered by Geoservices analysts,
detects gains and losses 5 to 10 minutes
faster than conventional systems. This
provides significantly earlier warning of any
abnormalities, thus allowing more time for
remedial action. In addition, this automated
early kick detection system gives a valuable
advantage during drilling operations by
accurately indicating influx or loss at very low
volumes and by reducing the number of false
alarms that result in time-consuming
flow checks.
Abnormal pressure events—such as kicks, mud losses, and other well control problems—
can lead to the loss of the entire well, life, and property. The PreVue service can play a
decisive role in minimizing these risks and improving drilling performance.
Applications
■■
To find out more, visit the FLAG service web page.
Estimation and monitoring of pore
pressure and fracture gradients
in any environment:
■■
The FLAG service detecting an influx substantially earlier than was possible using
a conventional flow paddle method.
■■
■■
Benefits
■■
Exploration wells
Deepwater wells with narrow
mud-weight windows
High-pressure, high-temperature
environments
■■
Presalt
■■
Complex geologic environments
■■
Features
Safer well trajectory and better
well control through proactive
and actionable pore pressure
recommendations
Enhanced drilling efficiency and
reduced NPT through informed
selection of drilling parameters
such as mud weight
■■
■■
■■
Real-time evaluation of normal
hydrostatic pressure, overburden,
pore pressure, and fracture gradients
Discrete pressure compartment
analysis to better understand pore
pressure envelope shifts at bedding
interfaces (e.g., sand and shale)
Corrected D-Exponent analysis for
evaluation of pore pressure gradient
Resistivity used as porosity-dependent curve
used by experts to estimate pore pressure.
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PreVue
Drilling Geomechanics Service
PORE PRESSURE ANALYSIS SERVICE
EXPERT SERVICES TO REDUCE DRILLING RISK, COST, AND UNCERTAINTY
Predrill planning
Our drilling geomechanics services help reduce risks, costs, and uncertainty in complex
drilling environments worldwide. Wellbore stability and pore pressure analysis is conducted
while drilling using a variety of wellsite monitoring and data measurements—such as
sonic, resistivity, density, pressure, and seismic—in real time to ensure better anticipation
of potential risks.
Before drilling starts, pore pressure experts at the Geopressure Technical
Center analyze offset data such as results from leakoff tests (LOTs),
engineering and geological reports, well logs, and mud weights. The
experts use this information to model the pore pressures likely to be
encountered along the proposed wellbore trajectory. Potential hazards
are identified and analyzed, and contingency plans are recommended.
Real-time monitoring
During drilling, two Geoservices analysts specialized in the PreVue
pore pressure analysis service provide 24-hour service at the wellsite,
using real-time pressure monitoring software, evaluating data, and
adjusting the predrill model for accurate estimation of pore pressure,
fracture gradient, and overburden. Interpretations and recommendations
are communicated to key decision makers both at the wellsite and in
the office. Interpretation experts based at the Geopressure Technical
Center provide additional support to the wellsite and customer teams as
required, through in-depth analysis of the daily reports submitted by the
wellsite analysts.
Applications
■■
■■
Deepwater and HPHT reservoirs
■■
Drilling in and around salt structures
■■
Event analysis
Extended-reach and challenging
well trajectories
Drilling in depleted zones and faulted
or fractured reservoirs
The PreVue service captures particular events during the drilling phase.
All observations are recorded, including the type and time of the event
and the recommendations made. The result is a cogent and immediate
review of pore pressure issues.
Special emphasis is placed on examining the following events:
Flowback events
Abnormal flowback is recognized through connection fingerprinting and
provides valuable insight into the relationship between the mud density
and formation pressures.
■■
■■
■■
■■
■■
■■
Pore pressure and fracture gradient log versus depth.
Features
Benefits
■■
Improve well placement and design
Identify and reduce exposure
to drilling hazards
Monitor and update pore pressure
predictions ahead of the bit
■■
■■
Predrill pore pressure prediction
■■
Safer mud-weight window planning
■■
Update wellbore stability forecasts
while drilling
Reduce NPT and well costs
■■
Increase well integrity
and cementing success
Enhance operational decision making
■■
Mud events and torque and drag
Accurate control of mud weight can have a positive effect on the outcome
of a well influenced by pore pressure. A record of pickup, slack-off, and
free-rotating weights is a valuable indicator of hole cleaning effectiveness
and also helps to analyze the origin of cavings.
■■
■■
Drilling events
Variations in ROP are used to estimate formation competency at the bit.
Drilling breaks can signal the beginning of a pore pressure ramp.
Gas events
All gas events and their contexts are recorded. Accurate monitoring of
lag time and identification of connection gas origins and propagation
mechanisms can help detect the onset of abnormal pressure.
Caving events
Observations at the shale shakers provide a digital record of the quantity,
size, shape, and mechanism of the origins of cavings. The information is
included in a caving report.
Predrill screening for well design
and drilling engineering
Operational monitoring and
interpretation of pore pressure
and wellbore stability
Geomechanics roadmap for well
trajectory using DrillMAP* drilling
engineering and operations plan,
updated during drilling
24-hour forecast of geomechanics
risks for current drilling operations
using DrillCAST* drilling operations
look-ahead
Multidisciplinary expertise for
wellsite and office support
End-of-well review including
an updated DrillMAP plan and
geomechanics roadmap identifying
all risks and events encountered
To find out more, visit thePreVue service web page.
1D or 3D mechanical earth model can be used to create a planned drilling program.
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Drilling Geomechanics Service
BACK TO TABLE OF CONTENTS
CaSe StuDy
EXPERT SERVICES TO REDUCE DRILLING RISK, COST, AND UNCERTAINTY
Reduce NPT and risk while optimizing drilling performance
Mitigate risk with operational monitoring and interpretation
Geomechanical problems are associated with an estimated 40% of drillingrelated NPT in challenging environments. Rapid changes in pore pressure
and fracture gradient along a well track can lead to lost circulation,
washouts, stuck pipe, loss of tools and equipment, additional casing
strings, and unplanned sidetracks.
Schlumberger has the industry’s largest pool of pore pressure and
wellbore stability experts. For every drilling geomechanics operation, we
provide experienced engineers to meet specific needs—at the wellsite, in
the customer office, or through our worldwide network of PetroTechnical
Engineering Centers (PTECs).
The move to more hostile environments and complex geometries has
often resulted in narrower mud-weight windows. For efficient well
engineering in these conditions, it is critical to know the precise wellbore
stability boundaries. Offset well data does not give the accuracy that is
now required to optimize casing points and adjust mud weights. Using
MWD provides more accurate input to predict fracture gradient and pore
pressure ahead of the bit.
This dedicated team combines advanced processes, workflows, and
technologies to offer continuous support and minimize the risk of costly
wellbore hazards during drilling.
At the wellsite or at the office, Schlumberger pore pressure analysts and
geomechanics engineers provide continuous monitoring and interpretation
of well data, communicating any changes to the safe mud-weight window
while drilling. This enables operational decisions to be made with the
most accurate information available, reducing exposure to drilling risk and
mitigating the impact of geomechanical problems for optimal
drilling performance.
Based on available field and offset-well information, our geomechanics
experts collaborate with the customer’s drilling and well-design team to
build a predrill mechanical earth model. This provides a safe mud-weight
window, including the wellbore stability, pore pressure, and fracture
gradients, with uncertainty determination for optimal well planning.
The information is consolidated to generate a wellbore stability and
pore pressure roadmap.
During drilling operations, pore pressure and geomechanics experts
analyze all available drilling, log, mud, seismic, and geological data to
visualize current downhole conditions. In close collaboration with the
customer team, our experts validate the safe mud-weight window and
deliver actionable recommendations to avoid potential hazards using
the DrillCAST drilling operations look-ahead.
To find out more, visit the Geomechanics web page.
Real-time Drilling geomechanics
Reduces nPt
Wellbore stability prediction reduces risk in Gulf of Mexico well
Challenge
Reduce NPT caused by wellbore stability
issues in a Gulf of Mexico field.
Solution
Implemented real-time drilling
geomechanics services to monitor,
update, and recalibrate the predrill
pore pressure model; used daily
updates to modify the drilling
program as needed.
a history of wellbore instability
The operator of a Gulf of Mexico field had a history of NPT related to wellbore stability problems.
The most recent well had experienced losses, influx, stuck pipe, and cementing challenges.
As the team prepared for the next well, it focused on completing operations within the AFE
and dealing with an expected pore pressure increase.
ReSult
Provided predictions that reduced NPT,
enabled revised casing set point decisions,
and eliminated a casing string.
Real-time drilling geomechanics
workflows and modeling predicted
and mitigated wellbore stability
issues during drilling operations.
The real-time drilling geomechanics workflows and modeling predicted and mitigated wellbore stability issues.
Actionable information to avoid potential hazards ahead of the bit.
Capitalizing on real-time data
The operator decided to utilize Schlumberger real-time drilling geomechanics services
to make more-informed decisions during drilling operations.
Schlumberger experts used offset well information to build a temperature-dependent
predrill pore pressure model. Engineers in Petrotechnical Engineering Centers (PTEC*)
continued real-time monitoring of drilling operations to update and recalibrate the pressure
model using all available data, including
■
gas information
■
leakoff tests
■
formation integrity tests
■
logging-while-drilling resistivity and gamma ray data.
geomechanics
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Surface Formation Evaluation
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Thema
CaSe StuDy: Wellbore stability prediction reduces risk in Gulf of Mexico well
CaSe Wellbore
StuDy: Wellbore
prediction
reduces
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key for successful drilling.
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the operator’s
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substantially reducing the time required.
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substantially reducing the time required.
Real-time drilling geomechanics helped exceed the operator’s expected technical limit,
substantially reducing the time required.
Pore pressure engineers at the rig supported by a Geomechanics expert at the PTEC
Pore pressure engineers at the rig supported by a Geomechanics expert at the PTEC
160
160
BACK TO TABLE OF CONTENTS
modeling predicted and mitigated wellbore
The real-time
geomechanics
workflowwellbore
and
modeling
predicted
mitigated
stability
issues
duringand
drilling
operations.
modeling
predicted
and
mitigated
wellbore
stability
issues
during
drilling
operations.
This process calculated a pore pressure
stability
issues
during
drillingand
This
process
calculated
aoperations.
pore
pressure
ramp
that
was
shallower
of greater
ramp that
was shallower
of from
greater
This process
calculated
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magnitude
than
was aanticipated
magnitude
than
was
anticipated
from
and
of
greater
rampoffset
that
was
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well information.
offsetthan
well was
information.
magnitude
anticipated from
offsetThis
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information.
in an informed decision to
This
in an informed
decision
set
theresulted
117⁄87-in casing
early. The
9 5⁄58-into
set thewas
11
8-in casing early. The 9 ⁄8-in
This resulted
in ⁄an
informed
to
casing
then
pushed decision
1,700 ft deeper
casing
then
pushed
1,700
5 ft deeper
set the
117planned
⁄8-inwas
casing
early.
The
9 real-time
⁄8-in
than
because
further
than
because
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real-time
casing
wasplanned
then
pushed
ft deeper
modeling
indicated
no1,700
stability
issues would
modeling indicated no stability issues would
encountered.
The
operator
therefore had
than be
planned
because
further
real-time
be encountered. The operator therefore had
the flexibility
to no
save
a liner issues
string or
finish
modeling
indicated
stability
would
the flexibility to save a liner string or finish
the well in a 7½-in
hole. therefore had
be encountered.
The operator
the well in a 7½-in hole.
the flexibility to save a liner string or finish
As the
97⁄87-in hole
was drilled below the
the well
in
hole.
As
thea 97½-in
⁄8-in hole
was drilled below the
5
9 ⁄85-in casing, real-time geomechanics
9 ⁄8-in casing, real-time geomechanics
modeling
predicted
a severe
tightening
As the
97⁄8-in hole
was drilled
below
the
modeling
predicted
a severe
tightening
the mudreal-time
weight window,
requiring an
9 5⁄8-inofof
casing,
geomechanics
the mud weight
window,
requiring
an
unplanned
7 3⁄43-ina casing
string. Although
modeling
predicted
unplanned
7 ⁄4-insevere
casing tightening
string. Although
well
was landed
using
a 6½-inan
× 7½-in
of thethe
mud
weight
window,
requiring
the
well
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using
a 6½-in × 7½-in
bit, a slimhole
section was avoided because
3
unplanned
7 ⁄4-in casing
string.
bit, a slimhole
section
was Although
avoided because
the 9 5⁄85-in casing had been pushed much
the well
landed
a 6½-in
× 7½-in
thewas
9 ⁄8-in
casingusing
had been
pushed
much
deeper than expected.
deeper than
expected.
bit, a slimhole
section
was avoided because
the 9 5⁄8-in casing had been pushed much
High-quality real-time data and timely
High-quality
real-time data and timely
deeper
than expected.
predictions
enabled each hole section to
predictions enabled each hole section to
be completed ahead of schedule with no
be completed
ahead ofand
schedule with no
High-quality
real-time
losses, stuck
pipe data
instances,timely
or influx—
losses,enabled
stuck pipe
instances,
or influx—
predictions
each
hole
section
to
reducing the risk of NPT. Additionally,
reducing
the
risk
of
NPT.
Additionally,
be completed
ahead
of schedule
with no
the improved
drilling
process helped
the improved drilling process helped
losses,
stuck pipe
instances,
or influx—
eliminate
remedial
cementing
work.
eliminate remedial cementing work.
reducing the risk of NPT. Additionally,
the improved
drilling
process helped
Contact
Contactyour
yourlocal
localSchlumberger
Schlumberger
eliminate
remedial cementing
work.
representative
to
representative tolearn
learnmore.
more.
DRILLING OPERATIONS SUPPORT AND ANALYSIS SERVICE
The unique Thema service workflow connects information from rigsite resources and data
with our experts and knowledge. The service supports, analyzes, and maximizes performance
of all elements in a drilling project, both at the rig and in the office.
Through data replication, all data produced at
the rig site, together with contextual information
such as well architecture, mud details, and
string data, is sent to our customer’s offices.
A dedicated Thema service analyst (based
at the customer’s office) then integrates
all downhole and surface data, delivering
detailed reports directly to the customer
as well as finalizing objectives and making
recommendations for effective decision making.
The Thema service analyst communicates
these conclusions, models, best practice
recommendations, and detailed analyses both
to the customer and the rig-base team—
ensuring that information reaches the right
people at the right time.
Recommendations for effective decision making.
Applications
Benefits
■■
Exploration
■■
■■
HPHT
■■
■■
Deep water
■■
Extended-reach drilling
Contact your local Schlumberger
representative to learn more.
■■
■■
Pore pressure engineers at the rig supported by a geomechanics expert at the PTEC
*Mark of Schlumberger
*Mark
of Schlumberger
Other
company,
product, and service names
Other company, product, and service names
are the properties of their respective owners.
are the properties of their respective owners.
Copyright © 2010 Schlumberger. All rights reserved. 10-DC-0042
Copyright © 2010 Schlumberger. All rights reserved. 10-DC-0042
www.slb.com/Drillgeo
www.slb.com/Drillgeo
Features
Enhanced communication
■■
Enhanced data quality
■■
Advanced hardware
■■
High-quality measurement
■■
Data frequency up to 50 Hz
■■
Information available earlier
Better integration of information
■■
Intelligent processes
Correlation and integration of
information using the latest in
information technology
■■
Enhanced visual interpretation
■■
Faster information delivery
Methodical stream of up-to-theminute data by receiving, analyzing
and distributing information primed
by the right people, with the right
expertise
www.slb.com/Drillgeo
*Mark of Schlumberger
Other company, product, and service names
are the properties of their respective owners.
Copyright © 2010 Schlumberger. All rights reserved. 10-DC-0042
Surface Logging
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Thema
DRILLING OPERATIONS SUPPORT AND ANALYSIS SERVICE
Our customers receive wellsite support in the form of a comprehensively
equipped Geoservices surface logging unit (with mud logger and data
engineer in situ) and a dedicated Geoservices engineer based in the
customer’s office.
Thema service analyst profile
■■
■■
Experienced in well operations
High-level communication skills
■■
Supported by a team of experts
■■
Coordinates rig activity and objectives
Drilling Efficiency and Optimization
Thema service deliverables
Deliverables and reports within the Thema service come from
both the rig and the customer office with specific focuses.
Rigsite deliverables include
■■
semiautomated daily activity report (DAR)
■■
master log
■■
flowback log.
In addition, the Thema service analyst produces the following reports:
The Thema analyst has real-time access to time and depth data from the
Geoservices surface logging unit. Using this data, the engineer integrates,
enriches, and combines surface and downhole information from the Thema
service’s vast database, acquisition, and processing facility. This helps our
customers reach the best possible decision in a timely and cost-effective
way. The analyst conveys the analysis and recommendations back to the rig
to complete the workflow loop.
■■
■■
Drilling efficiency (DE) panel
The DE panel takes real-time drillstring analysis further and
contributes to the assessment of the wear and behavior of the
drill bit. Add-on applications can be aligned with the DE panel
to provide a comprehensive drilling efficiency and optimization
service—including vibration mitigation, MSE management, bitwear interpretation, avoidance of low ROP, prevention of tools lost
in hole, and monitoring of downhole conditions—entirely from the
surface. Results are equivalent to those provided from downhole.
DE panel capabilities include
daily Thema service report (with optional KPIs and fluid displacement
monitoring)
■■
bit-run report focusing on well balance, hole cleaning status,
and drilling efficiency
■■
■■
event report with real-time and postrun analysis
■■
final well report review and synthesis.
■■
Metier and technical support
Our analyst works closely with the local drilling performance domain
champion, who supports our personnel in optimizing operations. Technical
support is also available to our Thema service analyst from the worldwide
Geoservices Quality and Operations Support team.
Information
value
Real-Time Applications
High-frequency data
Vibration monitoring and alarms
Imported third-party time data
Enhanced
communication
Hole Cleaning
monitoring and analysis of MSE through parameter correlation
and various easily accessible crossplots
analysis of combined surface and downhole measurements
(when available), which is particularly valuable in complex well
conditions, in extended-reach drilling, and while performing
coring operations.
Hole condition monitoring (HCM) panel
Integration of data collected from the hole cleaning applications
provides real-time information about the status of the well,
addressing challenges that affect highly deviated wells and horizontal
wells, such as stuck pipe, borehole integrity, and possible packoff.
Better
integration of
information
Better
data
quality
assessing the BHA’s efficiency response to drilling parameter
adjustments
HCM panel capabilities include
Conventional
mud logging
■■
Processing time
■■
■■
Time
■■
Added information that improves the decision-making process.
lithology information for correlation of torque increase and
excessive drag with the formation
torque and drag modeling
real-time drilling parameters correlated with information from
the torque and drag model
real-time acquisition of torque and drag data through
activity filtering
■■
real-time rheology parameters display
■■
display and correlation of dogleg severity and LWD data
■■
monitoring and follow-up of backreaming and wiper trips.
Real-Time Applications
Cuttings flowmeter (additional equipment)
Pickup and slack-off models
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Surface Formation Evaluation
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Thema
Drilling Analyst
DRILLING OPERATIONS SUPPORT AND ANALYSIS SERVICE
ENGINEERING INTEGRATION AND DRILLING OPTIMIZATION
Well Balance Monitoring and Analysis
Geoservices drilling analysts provide an advantage in drilling performance services.
Combined with the knowledge and expertise of Schlumberger, overall drilling performance
is optimized, reducing time to TD through integrated engineering, execution, and evaluation
work processes.
Well surveillance panel
Primary well control is the foundation of all drilling operations.
The Thema service well balance monitoring and analysis service
applications are dedicated to the real-time monitoring and
presentation of data pertaining to well equilibrium.
Well surveillance panel capabilities include
■■
■■
■■
time-base log including display of hole gain and losses
computations (from the optional FLAG service), and graphic
pit trend follow-up (with alarms)
performance indicators that are aligned with the project objectives and
anticipated challenges. The geomechanics and pore pressure models can
also be integrated into the execution plan, depending on the identified
project challenges.
Our drilling analysts, who are specifically trained and have the relevant
experience in drilling optimization and risk management, drive our
drilling performance services. Their primary objective is to work with the
customer’s drilling team, Schlumberger experts, and third-party service
providers to ensure a seamless execution of the well construction plan.
The drilling analyst integrates the engineering and modeling outputs from
well design, BHA and bit design, fluids system, geomechanics, and pore
pressure to create an integrated well execution plan with the customer
while also supporting the individual teams to execute the plan.
follow-up of pumpoff gas magnitude and composition, with
the ability to overlap and compare the causes of gas peaks
active, real-time monitoring and recording of trip speed and
trip tank volumes and variations.
To find out more, visit the Thema service web page.
Drilling analysts are an integral part of the Schlumberger team, leading
the integration of surface and downhole measurements with performance
models that optimize the well construction process, reduce NPT, and
mitigate risk. The drilling analysts are assigned to a project early during
its planning stage to work with the customer drilling teams and other
Schlumberger experts in our PTECs, helping to define key drilling
Real-Time Applications
Flowback monitoring
Synchronized event display
Fluid displacement monitoring
Synchronized data at bit
FLAG service (additional service)
Real-time display
During the planning stage, the development of a multidisciplinary
performance drilling plan (PDP) takes place as part of the well design
deliverables. Based on the project and well objectives and anticipated
challenges, the PDP includes risk assessments to prevent and mitigate
different hazards, reduce unplanned flat time, and improve the drilling
performance strategy.
Depending on availability of data and the timing of the project, a detailed
offset well analysis can also be performed. The different historical drilling
events and problematic zones are identified, and a detailed NPT analysis
is performed in geological context.
Drilling Analyst Integration Workflow
Well
Design
BHA and Bit
Design
Lessons
Learned
Drilling Analysts
Fluid System
Drilling Execution
(Operations)
Engineering Integration
(Customer and PTEC)
Evaluation
Geological
Challenges
Geomechanics and
Pore Pressure
Customer Initial
Well Design
Well Placement
Drill the Plan
Integration role of the drilling analyst during the engineering, execution, and evaluation phases of the well.
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Drilling
Surface Formation Evaluation
Rig Operations Surveillance
Surface Logging
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
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Drilling Analyst
Surface Formation
Evaluation Services
ENGINEERING INTEGRATION AND DRILLING OPTIMIZATION
A graphical representation of the DrillMAP drilling engineering and
operations plan includes a chart of the risk assessment, the performance
strategy, and the different models to be monitored during the execution
of the well.
Analysts located at the rig or off site
The information presented in the DrillMAP plan provides a reliable roadmap
that enables drillers to better manage operations and to respond more
effectively to anomalies in drilling behavior. The drilling analysts then define
tailored deliverables from the list of specific project and well requirements,
which are prioritized and aligned with the drilling KPIs and integrated well
execution plan.
At the customer’s real-time monitoring center, analysts participate in rig
calls and discussions with the customer’s drilling team. They can also
participate in well planning meetings if there is no monitoring required.
During the execution phase, drilling analysts monitor and assess realtime surface and downhole data using proprietary software to track
data trends and highlight any deviation from the models or precursors
of upcoming drilling problems. They also interact with our various
petrotechnical experts (geomechanics, fluids, bits, drilling, formation
evaluation, etc.) to support any necessary model updates and to
collaborate with the customer’s team.
The DrillMAP plan is continuously updated by the drilling analysts in
the form of a DrillCAST drilling operations look-ahead. The DrillCAST
look-ahead is a daily report that contains essential information about the
drilling process over the last 24 hours and provides a reliable forecast of
drilling hazards, as well as agreed recommendations to deal with them for
the following 24 hours. This allows drillers to adjust the drilling process in
order to mitigate drilling risks, prevent unscheduled events, and optimize
drilling performance.
Drilling analysts can be located at the rig site or in a real-time monitoring
center. The day-to-day activity of the drilling analysts varies depending on
where they are located.
FLAIR Real-Time Fluid Logging and Analysis Service
Isotope Logging Service
GeoFlex Quantitative Cuttings Analysis
and Imaging Service
At the rig site, in addition to rig calls, they participate in internal
preoperation meetings to help highlight the main hazards identified for
each specific operation.
In both cases, and in coordination with other petrotechnical experts,
analysts provide recommendations when the precursor of an NPT event
is observed and participate in analysis of the different drilling events until
the determination of the root cause.
To find out more, visit the GeoFlex service web page.
At the end of the well, the drilling analyst delivers a final well report and
presents an updated DrillMAP plan that details the actual results versus
the initial models and includes the lessons learned, which can be applied
to future operations.
For trip monitoring, the DrillCAST look-ahead includes a detailed
description of the hole condition observed while drilling or during
previous trips and an updated forecast of hazards in the next bit trip,
casing, or logging run.
Daily, 24-hour forecast through the DrillCAST look-ahead.
Surface Logging
46 |
2016 GEOSERVICES SERVICES CATALOG
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
Surface Logging
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
2016 GEOSERVICES SERVICES CATALOG
|
47
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FLAIR
REAL-TIME FLUID LOGGING AND ANALYSIS SERVICE
The FLAIR service provides C1–C6 reservoir fluid composition and monitors other fluid
characterization markers (e.g., light aromatics), enabling early assessment of potential pay
zone and acquisition of formation evaluation information ahead of downhole sampling and
well testing.
CnF
FLAIR Service
Pilot Hole, mol%
PVT Pilot Hole,
mol%
C1F
C2F
C3F
i-C4F
n-C4F
i-C5F
n-C5F
89.2
6.1
2.4
0.5
0.9
0.5
0.4
89.2
5.9
2.1
0.5
0.8
0.4
0.3
FLAIR Service
Sidetrack Hole,
mol%
89.5
6.0
2.5
0.5
0.8
0.4
0.3
CnF = Quantitative fluid composition provided by the FLAIR service. This composition is comparable to reservoir fluid.
†
Pilot hole:
oil-base mud
Sidetrack hole:
water-base mud
The FLAIR service applies a proprietary process from extraction to data processing,
enabling quantification of hydrocarbons for reservoir fluid characterization and
interpretation.
Data acquisition
The FLAIR service's fluid extractors continuously
sample mud from the flowline returning from
the well and in the pump suction line. Extraction
occurs at controlled constant thermodynamic
conditions and is calibrated for each mud
system. The extracted hydrocarbons are
transported to a specifically designed detector,
which provides a full chromatographic analysis
up to C8, including differentiation of several
C n isomers.
Processing of the acquired data includes
synchronization of “in” and “out” data and
filtering for potential equipment quality control
issues and drilling artifacts.
The formation fluid composition with respect
to the C1–C6 components can therefore be
quantitatively determined throughout the drilling
of the well. Accurate measurement and robust
data processing are foundations for enhanced
interpretation.
Data processing
The constant and repeatable extraction
conditions, including calibration against the mud
system in use, enable the recycling effect to be
quantified.
Data interpretation
Using the Techlog* wellbore software platform,
our experts generate a fluid facies log and
compositional analysis of various facies,
which can be integrated with other formation
evaluation data (e.g., from triaxial resistivity
induction and the MDT* modular formation
dynamics tester) to allow for enhanced
reservoir characterization. From daily quicklooks
(including facies and star diagrams) to more
in-depth analysis such as multiwell studies,
our expertise contributes to greatly enhanced
reservoir understanding.
Proven formation evaluation technology
The FLAIR service has been successfully used
worldwide in more than 1,000 exploration,
appraisal, and development wells in all
geological settings and complex operation
conditions (deepwater and shallow offshore,
onshore HPHT, and tight formations) and with
different reservoir fluids.
Graphics indicating that the fluid of the sidetrack hole had the same
composition as the fluid in the pilot hole confirmed by PVT analysis
of downhole fluid samples taken from the pilot well.
Applications
■■
■■
■■
Interwell and intrawell fluid facies
mapping
Support for geosteering and
well placement
Formation evaluation data assurance
in challenging environments
Surface Logging
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2016 GEOSERVICES SERVICES CATALOG
Features
Benefits
■■
■■
■■
Provides early insight into reservoir
structure and fluid distribution
Allows for derisking and optimization
of formation testing, sampling, and
downhole fluid analysis
Enables evaluation of hydrocarbons
in unconventional reservoirs
Drilling
■■
■■
■■
Fluid surface logging while drilling
PVT-equivalent quantitative composition of hydrocarbons in place.
PVT-comparable quantitative
hydrocarbon characterization
Proprietary calibration of extractor
efficiency and correction from
recycling and contamination
Surface Formation Evaluation
Rig Operations Surveillance
To find out more, visit the FLAIR service web page.
Surface Logging
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
2016 GEOSERVICES SERVICES CATALOG
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CASE STUDY
CASE STUDY: Continuous fluid typing while drilling enables cost-effective downhole sampling, offshore Malaysia.
Integration of FLAIR Service Enables
Cost-Effective Reservoir Characterization
Continuous fluid typing while drilling enables optimized downhole sampling
and maximizes information acquired in complex HPHT exploratory well.
CHALLENGE
Offshore, multilayered HPHT
reservoir required optimized sampling
program to reduce risk and increase
sampling recovery.
SOLUTION
Acquire reservoir fluid properties
from surface logging while drilling
using FLAIR* fluid logging and analysis
in real time.
RESULTS
■
■
Identified subtle compositional variations
in fluids across several reservoir layers
while drilling
Optimized sampling and downhole fluid
analysis program
■
Maximized value of acquired information
■
Improved planning for future wells
Hostile downhole conditions required optimized sampling program
While drilling an HPHT (16,400 psi, 327 degF) exploration well offshore Malaysia, a major
operator in Southeast Asia wanted to optimize its downhole fluid sampling and analysis program.
A continuous fluid facies log along the entire drilling interval, covering all sands of interest,
would improve selection of both the sample depths and the estimates of the likely fluid type.
Minimizing risk and cost was a priority in this challenging environment, while maximizing
the amount of information acquired while drilling was paramount for the project.
Cost-effective fluid typing while drilling
The FLAIR service was used to continuously analyze hydrocarbons extracted from drilling
mud returning to the surface, providing a quantitative C1–C5 composition of the downhole reservoir
fluid, and qualitative measurement in the C6–C8 range. Integration of the FLAIR service within
an innovative workflow—including downhole fluid analysis (DFA) and pressure-volumetemperature (PVT) data—was implemented to provide a cost-effective solution for formation
evaluation analysis.
Early identification of compositional variability improved downhole evaluation
FLAIR analysis identified subtle compositional variations with depth while drilling. Fluid families
with a characteristic signature were identified and a detailed fluid distribution was then used
to select depths for fluid sampling and DFA. The downhole data, in turn, was used to calibrate
the fluid signatures. Subsequent PVT analyses of the samples further corroborated
the results of the FLAIR analysis. The validated fluid signatures were then used to optimize
evaluation programs, enabling both time and cost to be saved in future wells within the field.
Correlation in the C1–C5 range between FLAIR analysis and PVT results
FLAIR data acquisition
Sample Fluid Type
DFA interpretation and single-phase
representative fluid samples
1
2
3
4
FLAIR data QC and processing
Detailed PVT lab sample analysis
Condensate
Condensate
Condensate
Condensate
C1mol%
PVT
85.55
85.29
85.16
86.04
FLAIR
86.62
83.78
85.13
85.73
C2mol%
PVT
6.40
6.64
7.54
7.42
FLAIR
5.89
7.07
7.79
7.92
C3mol%
PVT
4.60
4.67
4.29
3.82
FLAIR
4.17
5.37
4.08
3.73
iC4mol%
PVT
0.89
0.89
0.80
0.73
FLAIR
0.91
1.11
0.85
0.74
nC4mol%
PVT
1.44
1.43
1.24
1.11
FLAIR
1.39
1.64
1.29
1.17
iC5mol%
PVT
0.61
0.59
0.53
0.49
nC5mol%
FLAIR
0.56
0.58
0.47
0.39
PVT
0.51
0.49
0.44
0.40
FLAIR
0.46
0.47
0.38
0.33
The fluid complexity is highlighted by the fluid facies log provided by FLAIR analysis (track 2). Red circles indicate the sampling depths suggested to the operator,
based on fluid composition variations highlighted by FLAIR analysis. The table shows the close correlation in the C1–C5 range between the FLAIR analysis
and PVT results (C1f, C2f, etc. = formation fluid content; C45f = iC4f + nC4f + iC5f + nC5f).
FLAIR reservoir fluid composition
in the C1–C5 range
Establish typical fluid signatures to correlate
to future wells (from FLAIR, DFA, and PVT results)
Recommended fluid sampling based on
FLAIR analysis
Update reservoir model with validated
fluid properties
The reservoir fluid analysis workflow, comprised of FLAIR analysis, DFA, and PVT data.
slb.com/FLAIR
Drilling
Surface Logging
50 |
2016 GEOSERVICES SERVICES CATALOG
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
*Mark of Schlumberger
Copyright © 2015 Schlumberger. All rights reserved. 14-GS-0018
Surface Logging
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
2016 GEOSERVICES SERVICES CATALOG
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Isotope Logging
CONTINUOUS ISOTOPIC RATIO MEASUREMENTS IN REAL TIME
The Geoservices Isotope Logging service delivers real-time measurement logs of isotopic
ratios, opening up early access to geochemical characterization of hydrocarbons in the
formation in terms of source, generation, and processes.
Laboratory technology ruggedized for rig environments
Integrated interpretation and decision making
The Isotope Logging service is a key tool within the Geoservices
formation evaluation portfolio. With consistent accuracy, more than
300 km has been logged in more than 100 wells drilled in a variety of
basins and reservoir configurations—from unconventional reservoirs
to deepwater wildcats.
The availability of real-time isotopic ratio logs enables immediate and
accurate interpretation of geological and geochemical systems, optimizing
key decisions affecting the development of the reservoir. Our community
of geochemists and reservoir engineers works closely with customer
teams to assist in understanding their reservoir complexities.
GeoFlex
Service,
XRF,
DRIFTS,
and LWD
Fluid units Isotope Ro
LWD
Elemental
Analysis
2 FLAIR Service
Ratios
An example of the utilization of various integrated
datasets available from Schlumberger formation
evaluation tools (isotope logging, FLAIR, GeoFlex,
and LWD services) for a complete picture of the
petroleum system. The GeoFlex service provides
mineralogical and elemental composition and
kerogen content of cuttings through integration of
XRD, XRF, and diffuse reflectance infrared Fourier
transform spectroscopy (DRIFTS).
Mineralogical and elemental
composition and kerogen content of
cuttings through integration of XRD,
XRF, and DRIFTS.
Isotope
d13C–C1
GeoFlex
Service
and XRF
1 ■■
■■
■■
Complex fluids and fluid
uncertainties
Benefits
■■
Unconventional reservoirs
Assistance with downhole fluid
sampling programs, including
selection of spot-sample analysis
■■
■■
Surface Logging
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2016 GEOSERVICES SERVICES CATALOG
Drilling
Features
Assessment of fluid migration
mechanisms, such as sealing
characteristics of caprocks
and faults, connectivity, and
compartmentalization
Early identification of active and
nonactive hydrocarbon systems
■■
■■
■■
Continuous measurement for reliable
identification of small-scale features
LWD
Elemental
Analysis
Applications
GeoFlex Service,
XRD, and TOC
3 Real-time data delivery for optimized
decision making
Field-proven, robust, and reliable
logging technology with integrated
quality assurance procedures
Reduced uncertainty and risk
associated with the collection,
shipment, and analysis of samples
Surface Formation Evaluation
Rig Operations Surveillance
To find out more, visit the Isotope Logging service web page.
Surface Logging
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
2016 GEOSERVICES SERVICES CATALOG
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53
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■
Enabled optimal development of
unconventional reservoir.
δ13C–CH4 , 0/100 versus Peedee belemnite (PDB)
–25
Cracking of oil
Cracking of wet gas
Oil window
Condensate
wet gas
Predominantly dry gas
Early Peak
oil
oil
Processes
–40
Only dry gas
VREq
(δ13C–C1)
%
%
0.15 30
Effective
Porosity
Copper
Uranium
0
ppm 100 150 ppm 275 0
Quartz
ACC
60
60
%
10 30
Permeability Quartz DRIFTS
Nickel
25 150 ppm 375
%
150 ppm 325 0.01
TVD, ft
6,550
12,250
7,200
6,650
Overburden
Marcellus Shale
Base
Limestone
Shale Below
Base Limestone
Base
Limestone
Marcellus
Shale
Real-time measurement of δ13 of C1 from isotope logging clearly marks the entry into the Marcellus Shale from the overburden. The exit from the base limestone marked from other
data sources reveals no maturity variation from δ13 of C1.
–30
–50
Light
oil
10%
–30
Gamma Ray
0
Stratigraphy
The continuous maturity log, which measures VRE, closely matched the official Marcellus VRE maturity
map for the well’s location. The fluid typing results from the isotope logging service were also
confirmed by a detailed maturity study on gas spot samples (δ13 of C1, C2, and C3).
Cracking of kerogen
to oil and gas
MD, ft
The isotope logging service produced a thermal maturity log that showed very high stability along
the lateral, confirming homogeneity of the fluid maturity and the formation.
12,250
0
Confirmed official VRE maturity map with real-time formation property information
–20
ELAN
Effective
Porosity
1
Diffuse
Reflectance
Infrared
Fourier
Transform
Spectroscopy
(DRIFTS)
Gamma Ray, gAPI
Confirmed homogeneity of the fluid
maturity and the formation.
Kerogen
Kaolinite
Illite
Dolomite
Calcite
Quartz
TOC
Gas
Pyrite
Illite
Dolomite
Calcite
Quartz
7,200
■
Provided a thermal maturity log that
showed strong agreement with the official
Marcellus vitrinite reflectance equivalent
(VRE) map and that was confirmed by a
separate study.
Schlumberger proposed using isotope logging service to continuously measure isotopic ratios of
δ13C–CH4 from surface while drilling to produce a continuous thermal maturity log. A continuous thermal
maturity log is the first step toward determining hydrocarbon fluid type in place, and providing this
data would enable improved while-drilling reservoir management decisions. The isotope logging
service, which poses no additional operational risk, would also help in identifying vertical and lateral
discontinuities, including gradients and small-scale features. Acquiring this information is particularly
challenging in unconventional reservoirs but would provide the initial information needed to determine
hydrocarbon fluid type in place, improve geosteering, and increase the accuracy of target allocation.
Elemental
Analysis
(ELAN)
RESULTS
■
Determine hydrocarbon fluid in place with thermal maturity log
Molybdenum
In a horizontal development well targeting the Marcellus Shale, the operator needed to acquire accurate
formation data. Specifically, the operator wanted to assess lateral heterogeneity of the fluid and rock
to gain initial information for determining hydrocarbon fluid type in place.
Kerogen
Evaluate rock and fluid heterogeneity to identify the optimal landing point
Evaluate rock and fluid heterogeneity along
the lateral of a well in the Marcellus Shale.
Molybdenum
CHALLENGE
Kerogen
DRIFTS
Quartz
Advanced
Cuttings
Characterization
(ACC)
ELAN
X-Ray
Permeability
Diffraction
Brittleness
Thermal maturity calculation from isotope logging service
provides insight into hydrocarbon fluid type in place
Assess fluid and formation heterogeneity
and obtain thermal maturity proxy at
surface with isotope logging service
providing continuous measurement of the
isotopic ratio.
0
At-Surface Real-Time Isotope Logging Assesses
Lateral Heterogeneity in Marcellus Shale
Maturity
(δ13C–C1)
Immature
Early oil
Peak oil
Light oil
Condensate
Wet gas
Dry gas
2
CASE STUDY: At-surface real-time isotope logging assesses lateral heterogeneity in Marcellus Shale, USA
CASE STUDY
SOLUTION
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0.9
90%
C1 versus C2
1.0
–40
1.1
Oil
1.2
1.3
–35
1.4
1.5
+++
–40
–50
0.8
1.0
1.2
1.4
1.6
1.8
2.0
2.4
1.1
Gas
1.3
C2 versus C3
Berner and Faber, 1996
Marcellus lateral section
Marcellus lateral average
2.2
1.0
1.2
�
+
0.6
–30
Approximate well location:
VRE 1.1–1.2%
++
–45
2.0
0.9
1.4
1.5
2.0
2.6
Thermal maturity, % VREq
δ13C–C2, 0/100 versus Vienna PDB
Thermal maturity, % VREq
Comparing the isotope log thermal maturity proxy (vitrinite reflectance equivalent [VREq ]) with the VRE map
shows a perfect match within 10%–90% confidence (red arrow) ±0.09% VRE.
slb.com/IsotopeLogging
Surface Logging
Surface Logging
54 |
2016 GEOSERVICES SERVICES CATALOG
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
*Mark of Schlumberger
Other company, product, and service names
are the properties of their respective owners.
Copyright © 2016 Schlumberger. All rights reserved. 15-GS-10607
Surface Logging
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
2016 GEOSERVICES SERVICES CATALOG
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GeoFlex
QUANTITATIVE CUTTINGS ANALYSIS AND IMAGING SERVICE
The modular GeoFlex service determines the mineralogical and geochemical composition
of drilled cuttings as well as their TOC content in near-real time, supporting operational
decisions and minimizing risk.
Combining high-resolution digital microscopy, accurate mineralogical
quantification, precise elemental composition, and TOC assessment, the
GeoFlex service enables cost-effective, near-real-time formation evaluation
in all drilling environments.
This at-surface modular service is especially advantageous in operations
traditionally considered cost- or risk-prohibitive for conventional formation
evaluation techniques.
Real-time data transmission for seamless collaboration.
Accurately determine lithology and mineralogy
Enhance multidisciplinary collaboration
To optimize well placement in unconventional reservoirs, fast-field TOC
quantification precisely identifies organic-rich formations in 7 minutes.
This technique uses a patented process to directly measure TOC in cuttings
regardless of mineralogy and mud type.
Information from the GeoFlex service is transmitted in real time and can
be integrated with other available data sources for seamless collaboration
between the customer’s drilling, geology, and geophysics teams.
Integrated logs further enhance understanding of reservoir characteristics
and potential productivity, which, in turn, reduces the risks inherent to key
decision-making processes.
Define geochemical fingerprint to assess production potential
Geochemical fingerprinting is performed using XRF, which quantifies up to
50 inorganic elements to part-per-million levels. Evaluation of elemental
data to this degree enables highly accurate well-to-well correlation and
identification of preserved organic matter, which both offer insight into
production potential in unconventional reservoirs.
Minimizes NPT through early
remediation of the well path
when necessary
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2016 GEOSERVICES SERVICES CATALOG
Drilling
C1F
20 0 ppm 100,000
%
TOC
Vanadium
Molybdenum
10 0 ppm 100 0 ppm 500 0 ppm 2,000 0
%
% 100 0
55 0
Uranium
Thorium
%
C2SF
Sulfur
Trioxide
Silicon
Dioxide
Calcium
Oxide
Synthetic total and spectral gamma
ray for accurate depth matching and
well-to-well correlation
Pyrite
Total feldspar
Total clays
Quartz
Dolomite
Calcite
Anhydrite
Integration of GeoFlex with proprietary surface logging acquisition system allows automatic generation of log answer products integrating all GeoFlex data as well as
improvement of data integrity by having all data stored into a secured database.
To find out more, visit the GeoFlex service web page.
Surface Logging
5
■■
Automatic mineral recognition and
quantification technology for fast
and reliable wellsite analysis
%
Integrates with LWD, wireline,
and other available data sources
to provide a comprehensive log
Gamma ray
■■
■■
Potassium
■■
Acquires reliable and repeatable
data for near-real-time evaluation
Integrated real-time transmission
and visualization for wellsite
and remote data monitoring and
interpretation
-5
Onshore and offshore exploration
and development
■■
Portable, modular devices and
services for wellsite mobilization
TVD
■■
Characterizes lithology
independently of wellbore geometry,
temperature, and pressure
■■
100 .2
■■
Assessment of reservoir quality and
optimization of completion quality
in unconventional reservoirs
Conducts formation evaluation at
surface, adding zero operational risk
%
■■
■■
0
■■
While-drilling formation evaluation
and reservoir characterization
in conventional reservoirs
XRD minerology
■■
Features
0 gAPI 350 20 ppm -20 0
Benefits
Applications
0 ppm 50,000
Pictures
C 3F
Together, these technologies classify and quantify a wide range of minerals.
As a result, describing cuttings is made easier, faster, and virtually error
free for the wellsite geologist. The addition of synthetic total and spectral
gamma ray also ensures perfect depth matching to acquired information
from other data streams, such as LWD or wireline logs.
Near-real-time data from wellbore cuttings.
Quantify TOC to identify organic-rich formations
0 ppm 20,000
The GeoFlex service makes it possible to conduct accurate and repeatable
mineralogical evaluation from cuttings at the rig site and outside of the
critical drilling path. Using high-resolution digital microscopy (HRDM) and
XRD, the GeoFlex service enhances appraisal of rock texture, shape, and
color and quantifies mineralogy with laboratory-quality accuracy.
Surface Formation Evaluation
Rig Operations Surveillance
Surface Logging
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
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Presalt reservoirs: Reveal complex formations
Siliciclastic reservoirs: Complement mineralogy with geochemical fingerprinting
The GeoFlex service conducts geochemical fingerprinting, one of
the most advanced formation evaluation techniques available for a
sediment. By identifying feldspars, clays, and carbonates as well as
the distinction between cement and matrix, geochemical fingerprinting
helps predict producibility in siliciclastic and all other reservoirs.
This enhanced formation evaluation method improves wellsite lithology
identification and easily pinpoints intrafield formation tops. Mineral
recognition can be done in semiautomatic or automatic mode
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Further, geochemical fingerprinting from the GeoFlex service enables
you to update petrophysical models and optimize logging and coring
operations.
XRD Mineralogy
%
100
Using high-resolution digital microscopy,
X-ray diffraction, and X-ray fluorescence,
the GeoFlex service provides direct and
0 100
Anhydrite
Calcite
Dolomite
Quartz
Siderite
Total clays
Total feldspars
Interpreted Lithology
0
comprehensive measurements of lithology,
mineralogy, and elemental composition.
Near-real-time data from this service
is combined with other available data
sources to create a comprehensive log that
enables advanced modeling, including basin
reconstruction and dynamic simulation.
The cuttings-based GeoFlex service helps
to solve this challenge by clearly flagging
biogenic silica and accurately identifying
and quantifying volcanic, carbonate, and
hydrothermal minerals.
Presalt formations are among the most
difficult environments to drill and evaluate.
The presence of carbonate lithology with
complex mineralogy—pyrite, k-feldspars,
plagioclase, calcite, dolomite, clays—and
the frequency of encountering altered
volcanic rocks and hydrothermal depositions
create challenges for rock and reservoir
classification.
to simplify this task for field personnel. The limit of detection for each
mineral is established in relation to the matrix and is programmed into
software used at the wellsite that is proprietary to Schlumberger.
SiO2
0
%
TiO2
100 0
%
P2O5
2 0
%
Na2O
5 0
%
90
10
5
70
30
60
40
Zirconium, %
Cuttings are analyzed using HRDM and XRD from the
GeoFlex service to identify and quantify mineralogy. Each
plot point represents a sample, and the color of each
indicates TOC.
80
20
Carbonate with
siliciclastic input
50
50
Aluminum oxide, %
40
60
30
70
20
80
90
Magnification of cuttings for
improved characterization.
10
Altered mafic rocks
100
0
10
20
30
40
60
50
Titanium dioxide, %
70
80
90
0
100
Carbonate, %
0
Carbonate reservoirs: Unlock potential productivity
Identification and quantification of clays and
anhydrite, for example, provide significant
insight into the porosity and permeability of
XRD mineralogy
Lithology
XRF GR
0
API
150
%
100
Anhydrite
Calcite
Dolomite
Quartz
Siderite
Total clays
Total feldspars
0
CaO
0
%
MgO
55 0
%
Al2O3
SiO2
25 0
%
20 0
%
SO3
5 0
Igneous rock: Easily identify basement rock
information critical to assessing porosity and
permeability and, thus, production potential.
In carbonate reservoirs, production
potential is highly influenced by the mineral
composition of the matrix. By clearly
identifying and quantifying calcite, dolomite,
and siderite, the GeoFlex service provides
%
100
carbonate reservoirs. Accurate quantification
of pyrite can notably improve any subsequent
petrophysical log interpretation.
High-resolution digital pictures from the
GeoFlex service also aid in the recognition
of microfossils and the subsequent
characterization of biomarkers, resulting in a
more comprehensive stratigraphy and dating
of the reservoir.
The identification and characterization of igneous rock has become
increasingly important to hydrocarbon exploration and production.
While drilling, reaching the basement rock often means that the bottom
of a potentially hydrocarbon-producing interval has been reached.
Additionally, the production of hydrocarbon resources trapped in igneous
fractured formations has made significant progress in the past few
years. In both cases, identifying the presence of igneous, volcanic and
volcanoclastic rocks is of paramount importance.
The GeoFlex service optimizes geostopping by accurately detecting
basement rock. The service uses high-resolution digital microscopy
to identify the texture of igneous rock and to characterize flow
structure and crystal sizes. Magnification of up to 200 times enables
the mud logger to easily recognize altered and reworked volcanic rocks.
Sr
40 0
ppm 4,000
Zirconium/titanium dioxide ratio
5
Using HRDM and XRD, the GeoFlex service
provides objective and precise evaluation of
mineral composition.
Phonolite
1
Rhyolite
0.1
Trachyte
Ryodacite/dacite
Trachyte/andesite
0.01
Andesite
Andesite/basalt
Subalkaline basalt
0.1
0.01
0.1
Niobium/yttrium ratio
Alkaline
basalt
Basanite
nephiline
1
10
The GeoFlex service identifies all rock types, making basement rock easy to detect.
Surface Logging
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2016 GEOSERVICES SERVICES CATALOG
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
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Surface Formation Evaluation
Rig Operations Surveillance
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GeoFlex service cost-effectively provides completion optimization data
Mo
U
3
Assess rock and fluid heterogeneity in the
complex lithology of the Marcellus Shale
while drilling a lateral well.
An operator drilling a lateral well in Pennsylvania needed to evaluate rock and fluid heterogeneity
surrounding the planned trajectory of its lateral well targeting the Marcellus Shale. The well was
planned to target a section of the Marcellus Shale with a high total organic carbon (TOC)
concentration of up to 20%. The operator needed to analyze the mineralogical and geochemical
composition of the formation to precisely steer the horizontal well within the target zone and optimize
the fracturing strategy.
Al2O3
% 20
% 55 0
CaO
0
Brittleness
Depth, ft
X,200
ft
ill a S ili c
c eo a-r
u s ic h
mu
ds t
o
ar g
Quartz and
feldspars, %
Argillaceous/
carbonate
mudstone
(marl)
s ili
c e o C lay
u s - r ic h
mu
ds t
on
e
Mixed
mudstone
0
10
Mixed
siliceous
mudstone
Mixed
carbonate
mudstone
Carbonate/
siliceous
mudstone
Carbonate-rich
siliceous mudstone
20
30
60
50
70
30
20
Carbonateddominated
lithotype
Silica-rich
carbonate mudstone
40
Marcellus Shale
XX,000
Base limestone
Shale below
limestone
Base limestone
XX,500
XX,000
XX,500
XX,000
XX,500
Through analysis of cuttings samples, the GeoFlex service identified lateral variations in mineralogy
and TOC and revealed zones of superior production potential. Logs from the GeoFlex service confirmed
that the lateral was landed in the target zone. Providing further proof that the well was landed in the
Marcellus Shale, TOC concentration exceeded 10% and the concentration of redox proxies, such as
molybdenum and uranium, increased.
80
10
0
100
90
Measurements of brittleness from the GeoFlex service identified brittle zones that the operator
can use to optimize the fracturing strategy of this well. Additionally, the GeoFlex service identified
intervals where the lateral was drilled out of zone. The changes in formation are indicated by spikes in
calcite, as shown in the logs, and provide valuable information for optimizing completion design.
ft
GR
X,750 X,200
TVD
100
Pyrite
%
Total feldspars
Quartz
Total clays
Dolomite
XX,000
XX,500
XX,000
XX,500
XX,000
XX,500
XX,000
XX,500
XX,000
XX,500
Calcite
XX,000
0
XRD Mineralogy
0 API 350
Brittleness
Depth, ft
0
% 20
Carbonate, %
TOC
Marcellus Shale
Provided information critical to optimizing fracturing design
40
e
100
XX,000
Total clays, %
50
Argillaceous/
siliceous
mudstone
Silicadominated
lithotype
60
ic h t on
y - r uds
C la t e m
na
bo
90
drilled out
of zone
Logs from the GeoFlex service provide objective measurements of cuttings to improve the operator’s understanding of
the formation. The TOC concentration (Track 4) indicates zones of superior production potential, and the formation top
changes (Track 12) show what intervals were drilled out of zone.
c ar
80
70
50
60
70
Mixed
argillaceous
mudstone
h
r ic one
te - s t
n a ud
r bo s m
C a c e ou
ill a
ar g
ne
MD, ft
30
40
XX,500
80
20
XX,000
12
XX,500
Clay90
dominated
lithotype
XX,000
10
Hamilton Shale
11
0 100
Burkett Shale
Tully Shale
TVD
X,750
GR
API 800
0
%
100
10
Rhinestreet Shale
Identified brittle zones and formation tops.
9
Depth
Located zones with optimal production.
■
Schlumberger recommended characterizing the mineralogy, elemental composition, and TOC of the
reservoir with the GeoFlex quantitative cuttings analysis and imaging service from Geoservices,
a Schlumberger company. This onsite laboratory-quality evaluation method provides accurate and
repeatable evaluation of cuttings at surface immediately after the cuttings reach surface, avoiding
conveyance issues and exposure to additional operational risk.
Formation Tops
■
Pyrite
Albite
Microcline
Quartz
Chlorote
Montmorillonite
Kaolinite
Illite
Dolomite
Calcite
Anhydrite
API 800
Provided at-surface characterization of
lithology of a lateral well in near-real time
and outside of the critical drilling path.
Accurately evaluate formation at surface from cuttings
0
■
8
XRD Mineralogy
RESULTS
7
0
Use the GeoFlex* quantitative cuttings
analysis and imaging service to conduct
formation evaluation from cuttings at surface.
6
GR
SOLUTION
0
Evaluate reservoir with significant TOC and mineralogical variations
TiO2
5
CHALLENGE
% 0.8
0
TOC
4
% 10 0
SO3
2
0 ppm 100 0
1
% 20
Marcellus Shale Operator Receives At-Surface
Formation Evaluation in Near-Real Time
ppm 500
CASE STUDY: GeoFlex service provides at-surface formation evaluation in near-real time
CASE STUDY
MD, ft
slb.com/GeoFlex
This ternary diagram from the GeoFlex service reveals the heterogeneity of the rock, and the color
of the plot points indicates the brittleness of the cuttings sample. Together, this information can
be used to improve completion design.
Geoservices
Surface Logging
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2016 GEOSERVICES SERVICES CATALOG
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
*Mark of Schlumberger
Other company, product, and service names
are the properties of their respective owners.
Copyright © 2015 Schlumberger. All rights reserved. 15-GS-10689
Surface Logging
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Surface Formation Evaluation
Rig Operations Surveillance
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SENSU
Rig Operations
Surveillance
RIG OPERATIONS SURVEILLANCE AND INSTRUMENTATION SYSTEM
SENSU Rig Operations Surveillance and
Instrumentation System
Featuring digital instrumentation and an advanced driller’s console, the SENSU* rig
operations surveillance and instrumentation system provides the granular operations
metrics and KPIs to deliver a step change in well construction efficiency. By reducing
NPT and ILT, the SENSU system enables cost reduction of daily rig operations.
Continuous decision-ready rig and drilling information for enhancing
operational efficiency.
Applications
■■
■■
■■
■■
Real-time monitoring of drilling
parameters and pit volumes,
on the rig and in the office
Uniform system independent
of rig vendors
■■
■■
Benchmarking the performance
of the rig and crew
Automated reporting for rig
maintenance and for tracking
operation metrics and drilling KPIs
■■
■■
■■
Surface Logging
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Drilling
Surface Formation Evaluation
Rig Operations Surveillance
Surface Logging
Features
Benefits
Optimize well construction
performance using daily, automated
KPI dashboard; detailed performance
benchmarking; and gap analysis
Obtain decision-ready information—
precisely where and when it is
needed
Improve critical activities through
constant, comprehensive access
to rig and drilling information
Modernize data acquisition systems
on existing rigs cost effectively
Achieve accurate, consistent, and
timely reporting through automated
IADC reports and daily drilling logs
Drilling
■■
■■
■■
■■
■■
■■
■■
Easy-to-install, reliable, and
automated system
Customizable and intuitive driller
displays (numerical and graphical)
with Live Setting console
Fast, responsive, and proactive
control of rig instrumentation
and drilling processes
Redundancy and mirroring to
minimize lost data and NPT
High-frequency data acquisition
and processing
Automatic rig-state detection
Stop and start system with
automatic loading of sensor
calibration
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Rig Operations Surveillance
2016 GEOSERVICES SERVICES CATALOG
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SENSU
RIG OPERATIONS SURVEILLANCE AND INSTRUMENTATION SYSTEM
Lean deployment at the wellsite
Enhanced data backup, security, and reporting
With a reduced footprint and automatic reloading of sensor calibrations,
the SENSU system has true start and stop functionality. Noninvasive
rig installation and quick configuration enable the rig crew to power up
the system and begin real-time monitoring immediately. Data from more
than 200 sensors can be processed at 1 Hz—with the ability to acquire
data up to 50 Hz—facilitating instantaneous event detection, while highresolution processing enables in-depth trend analysis.
Full data redundancy is assured by a second core computer running
in parallel to the primary system. Live sensor backups on critical
measurements can also be installed, while real-time monitoring
of acquired data quality and proactive detection of anomalies are
provided by the embedded diagnostic tool.
Automated reporting
The SENSU system provides automated reporting applications,
enabling the driller to spend more time focusing on operations and
optimizing rig performance, and less time on everyday reporting tasks.
Key reporting applications include automated daily logs and reports
in IADC-approved format.
Customizable interface
With its intuitive and customizable interface, the SENSU system provides
continuous decision-ready rig and drilling information. The driller can
adjust parameters, set alarms, and reset counters in the Live Setting
mode, while real-time data remains visible. Low- and high-level alarms
can be assigned to each parameter, and alarm states are indicated by
visible and audible cues.
User-friendly dashboard
displays for easy access
to all critical parameters
acquired by digital
sensors.
Automatic rig-state detection
The embedded Schlumberger rig-state engine—unique to the SENSU
system—automatically detects 17 individual rig activities and states,
enabling real-time calculation of 18 event metrics, including
■■
backreaming, on-slip, and off-bottom time
■■
maintenance measurements for critical rig component parts
■■
Real-time data via a variety of mobile devices.
operations metrics, calculating various drilling and tripping KPIs
in real time at the rig site.
Extensive networking and connectivity
The SENSU system has the unique ability to connect to the majority
of rig equipment, including all types of sensors, pit volume totalizers,
and detectors for hazardous gas. The system also connects the rig with
office-base personnel, enabling the sharing of wellsite information—
such as real-time drilling data—via the InterACT Visualization modular
real-time data display.
Identify invisible lost time
The rig-state engine enables the SENSU system to identify ILT through
real-time data analysis and statistical comparison of activities on a single
rig or across a rig fleet, enabling the setup and achievement of desired
efficiency targets.
Continuous real-time updates enable an entire rig fleet’s performance to
be benchmarked and corrective actions taken, minimizing the time and
cost of operations.
Real-time operational metrics and KPIs that empower the driller and wellsite
team to deliver consistent, superior performance—whether in conventional or
unconventional environments.
A 24-hour log automatically generated by the SENSU system, including rig states,
real-time comments, and vibrations.
Data can be viewed on a wide range of devices, including tablets and
mobiles using the WITSML industry standard (HTML5 and specific
Apple® iPhone® and iPad® applications are supported).
To find out more, visit the SENSU system web page.
Identification of ILT through real-time data analysis and statistical comparison of
activities on a single rig or across a rig fleet.
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CASE STUDY
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CASE STUDY: Real-time rig information enables improved drilling performance, rig operations, and safety in Oman.
SENSU System Logs over 3,000 Hours of Successful,
Uninterrupted Run Time for Saxon Energy Services
“The SENSU system is extremely
easy to use and helps save
the drilling crew precious time.”
Khalfan Alabir
Rig Electrician
Saxon Energy Services
Real-time critical rig information enables improved drilling performance,
rig operations, and safety.
CHALLENGE
Increase operational efficiency and reduce
NPT, while improving safety on the rig.
SOLUTION
Deploy SENSU* rig operations surveillance
and instrumentation system to enable
the following:
■
■
■
Robust and comprehensive rig monitoring
Greater, more focused rig operations
surveillance with new rig-states
Enhanced decision making by the driller
and crew, based on reliable alarms
and decision-ready information
RESULTS
■
■
■
Improved real-time decision making
by the driller, reducing rig time and costs
Automated real-time monitoring
of critical drilling parameters and KPIs
Greater operational reliability and ease
of use compared to traditional systems
Fast, accurate data streamlines monitoring
Using the rig-state engine, the SENSU system’s software capabilities provide Saxon’s
rig crew with unique, automatic rig-state detection, allowing them to carefully monitor drilling
operations. With accurate depth-measurement and calibration capabilities, confidence
is increased while drilling wells.
Saxon Energy Services also benefits from the range of applications provided by the SENSU
system, including the ability to export data, produce pipe tallies, and create automated daily logs
and reports in IADC-approved format. The advanced reporting applications of the SENSU system
have been tested extensively by the rig crews and acknowledged as effective time savers.
New system enables opportunities for time and cost savings
Opportunities for improved efficiency and reduced risk on a mature rig
Saxon Energy Services rig personnel found the new SENSU system easy to install, operate, and
configure. Between first deployment in mid-December 2013 and the end of March 2014, SENSU
systems on both rigs logged over 3,000 hours without failure and successfully withstood more
than six rig moves.
The rig instrumentation systems on two Saxon Energy Services rigs in Oman were in need
of updating to improve rig operations and well construction. The existing system required
considerable human intervention to set up, record measurements, and compute parameters.
This consumed a significant amount of time, increased the likelihood of errors, and prevented
the rig crew from improving the efficiency of daily operations.
After initial installation on the rig, the SENSU system was set up at each new well location
in less than 2½ hours due to its reduced footprint, quick-start feature, and automatic reloading
of sensor calibrations.
Integrated digital system provides efficient solution
Schlumberger proposed the SENSU rig operations surveillance and instrumentation system,
which helps improve drilling performance and safety by networking more than 200 digital
electronic sensors—located at various positions on the rig—with data processing units
and user-friendly displays to provide a complete, reliable, and real-time rig operation monitoring
system. These capabilities, combined with Geoservices’ extensive experience in surface data
acquisition, deliver improved data quality that enables enhanced decision making at all times.
The rig-state engine (which includes automatic detection of 17 rig activities) provides
the granularity that enables real-time monitoring of KPIs. Through the automatic generation
of reports and tracking of flat time via a real-time dashboard, Saxon Energy Services
rig personnel are able to improve overall well construction. All well data is stored within
an easily accessible database. Data can also be transmitted to remote offices via standard
protocols such as WITS0 and WITSML, enabling real-time monitoring and performance
benchmarking on the rig and over a rig fleet.
“The SENSU system offers
a range of solutions in one place.
It is not only an instrumentation
system—it also provides the best
reporting tool. The rig state engine
automatically detects and displays
17 rig states, helping us to easily
understand the operations.”
Umar Naved
Wellsite Drilling Engineer
Saxon Energy Services
www.slb.com/SENSU
Customizable, real-time displays provide accurate, decision-ready information.
Drilling
Surface Logging
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2016 GEOSERVICES SERVICES CATALOG
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
*Mark of Schlumberger
Other company, product, and service names
are the properties of their respective owners.
Copyright © 2014 Schlumberger. All rights reserved. 14-gs-0007
Surface Logging
Drilling
Surface Formation Evaluation
Rig Operations Surveillance
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slb.com/geoservices
*Mark of Schlumberger.
Microsoft and Windows are either registered trademarks or trademarks
of Microsoft Corporation in the United States and/or other countries.
Apple, iPad, and iPhone are trademarks of Apple Inc., registered in the U.S.
and other countries.
Other company, product, and service names are the properties of their respective owners.
Copyright © 2016 Schlumberger. All rights reserved. 15-GS-2731
Surface
Surface
Logging
Logging
Services
Drilling
Surface Formation Evaluation
Rig Operations Surveillance