Carbonate

Carbonate Reservoir Stimulation

Understanding and addressing the specific challenges and technical risks that carbonates present has put Schlumberger at the forefront of technology development to meet the challenges presented by carbonate reservoirs and to help our customers optimize productivity. Because of the complex nature of carbonate reservoirs, Schlumberger has a variety of solutions for optimum stimulation.
Fracturing and Completion Services

Maximize reservoir contact by applying the most efficient and effective services for each well.
Conventional | Intervention | Permanent | Dynamic
Deep-Penetrating, High-Temperature Acid

Use SuperX emulsified acid, a highly retarded HCl system, to overcome acid penetration problems in stimulating reservoirs above 250 degF [121 degC].
Viscoelastic Diverting Acid

Increase zonal coverage in carbonate reservoirs.
Technology Innovations
Degradable Diversion Acid

Incorporate dissolvable fiber and nondamaging acid in a single-step, self-diverting stimulation system, using MaxCO3 Acid.

Scale Control Services

Remove and prevent scale within wellbores and the reservoir.

Deep-Penetrating, High-Temperature Acid

Improve Your Reservoir Acidizing and Acid Fracturing Treatments

SuperX emulsion fluid for high temperatures improves your reservoir acidizing and acid fracturing treatments in high-temperature reservoirs. SuperX fluid is a viscous, highly retarded HCl system designed to overcome acid penetration problems in stimulating reservoirs above 250 degF [121 degC].

Standard hydrochloric acid reacts very quickly in carbonate formations. The reaction is so rapid in high temperatures that it is impossible for acid to penetrate, or wormhole, more than a few inches into the formation. In such cases, the acid is rendered ineffective in stimulating the well. Deep, live-acid penetration can be achieved if the acid reaction rate is retarded — a feat accomplished with SuperX emulsion high-temperature system. This oil-external emulsion is formed with a 70:30 HCl-to-oil ratio, stabilized with an emulsifier. HCl concentrations ranging from 7.5 to 28% may be used in either a batch or continuous mix system.

Reaction retardation

SuperX high-temperature emulsion is significantly retarded with respect to HCl. The retardation depends on temperature, acid concentration, flow regime (laminar, transitional or turbulent) and type of rock (dolomite or limestone). Between 250 degF and 350 degF [121 degC and 177 degC] the HCl-limestone and the HCl-dolomite reactions are mass-transfer controlled.

Emulsion stability

The stability of SuperX fluid is temperature dependent. Quality of oil phase and mixing time also affect the emulsion stability.

Viscoelastic Diverting Acid

Damage-free carbonate stimulation

VDA viscoelastic diverting acid, a self-diverting, polymer-free acidizing fluid, can be used alone or with other treating acids for total zonal coverage in carbonate reservoirs. It viscosifies as it stimulates in carbonate formations, diverting the remaining acid treatment fluid into zones of lower injectivity for

• improved zonal coverage across long intervals and high permeability contrasts
• extremely efficient wormholing behavior in a wide range of conditions
• significantly better leakoff control than straight hydrochloric and noncrosslinked gelled acid
• high fluid efficiency during acid fracturing treatments
• simple mixing for a smaller equipment footprint

VES fluid technology for total zonal coverage

Diverters can cause formation damage in carbonate formations. VES viscoelastic polymer-free surfactant does not damage the formation and can be bullheaded. It is self-diverting without incurring residual damage.

Enhanced, drag-reducing properties significantly lower friction pressure to reduce pumping requirements and treat deeper zones. VES-based fluids include VDA viscoelastic diverting acid, ClearFRAC polymer-free hydraulic fracturing fluid, and ClearPAC fluid system for gravel packing.

Ideal consistency

The fluid rapidly develops viscosity in situ upon acid spending and becomes self-diverting. The viscosity reduces dominating wormholes and allows the fluid to stimulate other zones.

Reduced cleanup costs

Recovery and well cleanup are easy after treatment. The barrier is broken down by production or dilution with formation fluids. Only low pressures are required for a smoother process.

Degradable Diversion Acid

MaxCO3 Acid degradable diversion acid is an effective single-step, self-diverting stimulation system that incorporates dissolvable fiber and nondamaging acid. The hydrochloric acid (HCl)-based system offers stimulation and then flow restriction for diversion. The interlocking fiber network blocks fluid during the stimulation job, yet dissolves completely with time, allowing poststimulated production contribution from diverted areas. Able to be bullheaded or deployed with coiled tubing (CT), the MaxCO3 Acid system can be used in openhole or cased hole completions for many applications.

The MaxCO3 Acid system is part of the Schlumberger carbonate stimulation offering, which includes the Contact family of stage fracturing and completion services for efficiently maximizing reservoir contact, Deep-Penetrating, High-Temperature Acid for overcoming acidizing challenges above 250 degF, and Viscoelastic Diverting Acid for increasing zonal coverage.
Damage-prone formation in North Dakota

To stimulate a 4,800-ft lateral in the Bluell formation (prone to damage from drilling mud leakoff), the MaxCO3 Acid system was implemented for superior diversion. It improved leakoff control such that after-treatment production increased 500%—to more than 300 bbl/d from just 50.
Thick carbonate in Qatar

Uniformly stimulating the thick, heterogenic Khuff formation proved challenging for an operator. The company used MaxCO3 Acid degradable diversion for 11 treatments in the North field and consistently stimulated each zone. Treatment volumes were reduced by up to 50%, and rig and operational time were reduced by 30%.
Naturally fractured carbonate in the Caspian region

The MaxCO3 Acid system was used to optimize stimulation for a horizontal openhole lateral. The technique created and diverted multiple fractures and controlled fluid loss, resulting in a production increase twice what the operator anticipated.

Degradable Diversion Acid

MaxCO3 Acid degradable diversion acid is an effective single-step, self-diverting stimulation system that incorporates dissolvable fiber and nondamaging acid. The hydrochloric acid (HCl)-based system offers stimulation and then flow restriction for diversion. The interlocking fiber network blocks fluid during the stimulation job, yet dissolves completely with time, allowing poststimulated production contribution from diverted areas. Able to be bullheaded or deployed with coiled tubing (CT), the MaxCO3 Acid system can be used in openhole or cased hole completions for many applications.

The MaxCO3 Acid system is part of the Schlumberger carbonate stimulation offering, which includes the Contact family of stage fracturing and completion services for efficiently maximizing reservoir contact, Deep-Penetrating, High-Temperature Acid for overcoming acidizing challenges above 250 degF, and Viscoelastic Diverting Acid for increasing zonal coverage.
Damage-prone formation in North Dakota

To stimulate a 4,800-ft lateral in the Bluell formation (prone to damage from drilling mud leakoff), the MaxCO3 Acid system was implemented for superior diversion. It improved leakoff control such that after-treatment production increased 500%—to more than 300 bbl/d from just 50.
Thick carbonate in Qatar

Uniformly stimulating the thick, heterogenic Khuff formation proved challenging for an operator. The company used MaxCO3 Acid degradable diversion for 11 treatments in the North field and consistently stimulated each zone. Treatment volumes were reduced by up to 50%, and rig and operational time were reduced by 30%
Naturally fractured carbonate in the Caspian region

The MaxCO3 Acid system was used to optimize stimulation for a horizontal openhole lateral. The technique created and diverted multiple fractures and controlled fluid loss, resulting in a production increase twice what the operator anticipated.

Scale Control
Remove and Control Scale Buildup

Scale control challenges are the leading cause of declining production worldwide. They cost the petroleum industry millions of dollars each year in scale control and removal costs and in deferred production. Scale control through chemical inhibition is preferred for maintaining well productivity, but when scale forms on the wellbore, more advanced scale control techniques must be applied.

Schlumberger scale control services are not only effective at removing scale and preventing repricipitation, they are quick and nondamaging to the wellbore, tubing, or formation environment.
Jet Blaster Scale Removal

Jetting scale removal service for effective one-trip wellbore cleaning.
ScaleFRAC Scale Inhibitor

Scale inhibitor service that protects wellbores and propped fractures from scale damage and related production declines.
ScaleMAT Acid-Compatible Scale Inhibitor

Acid-compatible scale inhibitor that enables scale inhibition at the same time as matrix stimulation.
ScalePROP Scale Inhibitor Proppant

Scale-inhibitor-impregnated proppant for long-term protection for fracturing proppant packs.
ScaleSOLV Carbonate Scale Dissolver

Carbonate scale dissolver to remove scale chemically without corrosion.

Fracturing and Completion Services con't

Fracturing and Completion Services

More choices. More reservoir contact.

Contact fracturing and completion services maximize reservoir contact by offering the most efficient and effective reservoir stimulation service for each well. This portfolio of services offers a wide variety of proven reservoir stimulation technologies; each choice can be enhanced with real-time measurement options.

Conventional

Wells completed through the conventional Contact category require separate trips into the well to fracture stimulate and isolate each stage. Conventional solutions can be divided into two techniques: cased hole and openhole completions.

Cased hole completions

Various methods can be used to access the reservoir, including wireline perforating, abrasive jetting, or shifting a sliding sleeve with the workstring. Fracture stimulation of each stage is performed by pumping down the casing or reservoir string. When multiple intervals are open in one stage, diversion can be attempted through various methods including limited entry (perforation friction pressure), ball sealers, or chemical diversion. The stage is then isolated using various techniques including setting composite bridge plugs, setting sand plugs, or natural isolation (induced stress diversion). This entire process is then repeated for remaining stages. A separate trip into the well is required for the next stage.

Openhole completions

In unconsolidated formations, a completion string may be deployed to ensure wellbore integrity. Typical completion strings include slotted liners or preperforated liners. The entire well may be fracture stimulated by pumping down the casing or reservoir string. Diversion can be attempted through various methods including limited entry (perforation friction pressure), ball sealers, or traditional chemical diversion.
Intervention

Wells completed through the intervention Contact category fracture stimulate and isolate multiple stages per intervention. The following services are used.
Abrasive Perforating & Fracturing

AbrasiFRAC abrasive perforating and reservoir services cut perforations, fracture stimulate, and isolate each interval separately-all in a single field operation.
Fracturing through Coiled Tubing

Fracturing through stimulation of preperforated intervals through CT or work string involves a straddle tool to isolate each interval during stimulation treatment. This technique is used both for new completions and to access bypassed intervals.
Wireline-enabled Perforating & Fracturing

PerfFRAC technique involves high-rate fracture stimulation treatments down the casing with a perforating gun assembly in the wellbore. The perforating guns selectively perforate the zones, which are fracture stimulated one zone at a time. Isolation between stimulated zones is accomplished by pumping ball sealers. Technology licensed from ExxonMobil Upstream Research Company.
Permanent

Wells completed through the permanent Contact category fracture stimulate and isolate multiple stages in one pumping operation using components installed as a part of the permanent completion. Services include the following.
Multistage Stimulation

RapidSTIM stimulation and completions services enable multiple stimulations of an uncemented completion in one pumping treatment with mechanical isolation.
Multistage Fracturing

StageFRAC multistage reservoir and completion services enable multiple fracture stimulations of an uncemented completion in one pumping treatment with mechanical isolation.

Dynamic

The dynamic Contact category offers fluid-enabled tool-free reservoir of multiple stages in one continuous operation.

Shale Gas Dynamic Fluid Diversion

StimMORE Fluid-Based, Tool-Free Diversion Technology

StimMORE shale diversion service combines fluid-based, tool-free fracture diversion technology with StimMAP LIVE real-time microseismic monitoring. Microseismic data delivered while the fracture treatment is pumped allows real-time optimization of fracture treatments. The service is suited to horizontal well multiple-frac completions, both cased hole and open hole.

The StimMORE service has been developed for use primarily in the Barnett Shale formation in North America, where the temperature range is between 160 and 250 degF and where narrow fracture widths less than 4 mm are expected.

Because it is fluid-based, StimMORE diversion slurries can be pumped on the fly as part of the main treating fluid, diverting the fracture as needed. By using a multicomponent blend of degradable materials, StimMORE slurries temporarily block fractures, diverting fluid flow and inducing the creation of additional fractures along the wellbore. The slurries degrade completely after the fracturing treatment has been completed and leave no residual formation damage.

In refracturing treatments, where wells have existing perforations in place, StimMORE provides an innovative solution for fracture diversion when traditional methods such as bridge plug placement are no longer possible.

Tight Gas

Stimulation This unconventional energy source is a fast-growing market; however, effective development of low-permeability tight gas reser

FiberFRAC Proppant Distribution

Proppant settling can reduce the deliverability of the fracture, causing a significant negative impact on productivity. FiberFRAC proppant distribution technology

• decouples proppant transport from fluid viscosity to reduce settling
• creates a fiber-based network within the fracturing fluid, providing a mechanical means to transport, suspend, and place the proppant
• can be tailored to reservoir conditions to optimize fracture geometry
• maintains good proppant transport, even at high temperatures, using a low-viscosity fluid.

In addition to fracture height containment, the retained proppant pack permeability can be significantly increased because of the lower polymer loading required. When less polymer is used, more of the propped fracture contributes to production, yielding a longer effective fracture half-length.

ThermaFOAM High Temperature CO₂ Fracturing Fluid

The future of high-temperature brownfield CO2 fracturing

The ThermaFOAM CO₂ foam system for high-temperature wells is a unique chemical system specifically designed for fracture applications in wells with bottomhole static temperatures (BHSTs) between 200 and 300 degF [93 and 149 degC]. The ThermaFOAM system is a CO₂-compatible product that uses the CO₂-polymer interaction to create stable and robust foam systems that allow polymer-loading reductions of up to 50%.

The reduction in polymer loading, combined with improved well performance and the elimination of the need for a crosslinking gel, has resulted in a fluid system that maximizes cleanup of the proppant pack within the fracture.

Significant reductions in time to sales can typically be expected for wells fractured using the ThermaFOAM CO₂ foam system compared with wells stimulated using conventional fracturing technology.

Fracturing and Completion Services
More choices. More reservoir contact.

Contact fracturing and completion services maximize reservoir contact by offering the most efficient and effective reservoir stimulation service for each well. This portfolio of services offers a wide variety of proven reservoir stimulation technologies; each choice can be enhanced with real-time measurement options.
Conventional

Wells completed conventionally require separate trips into the well to fracture stimulate and isolate each stage. Conventional solutions can be divided into two techniques: cased hole completions and openhole completions.
Intervention

Wells completed through the intervention Contact category fracture stimulate and isolate multiple stages per intervention. The following services are used.
Abrasive Perforating & Fracturing | Fracturing through Coiled Tubing | Wireline-enabled Perforating & Fracturing
Permanent

Wells completed through the permanent Contact category fracture stimulate and isolate multiple stages in one pumping operation using components installed as a part of the permanent completion. Services include the following.
Multistage Stimulation | Multistage Fracturing
Dynamic

The dynamic Contact category offers fluid-enabled tool-free reservoir of multiple stages in one continuous operation.
Shale Gas Dynamic Fluid Diversion

Microseismic Hydraulic Fracture Monitoring

StimMAP services for hydraulic fracturing monitoring record microseismic activity in real time during the fracturing process. A full range of software provides modeling, survey design, microseismic detection and location, uncertainty analysis, data integration, and visualization for interpretation, wherever and whenever decisions must be made. Computer imagery is used to monitor the activity in 3D space relative to the location of the fracturing treatment. Then the monitored activities are animated to show progressive fracture growth and the subsurface response to pumping variations.

The StimMAP service uses Petrel seismic-to-simulation software to provide accurate characterization of the locations, geometry, and dimensions of a hydraulic fracture system. Advanced processing techniques provide fracture characterization that enhances fracture models and reservoir characterization for production simulation.

Microseismic monitoring, which delivers information about the changing stress of a reservoir can be used to enhance reservoir development in tight gas completions, fault mapping, reservoir imaging, waterflood monitoring, drilling waste disposal, and thermal recovery.

Introduction in Stimulation

Treatment by Environment

Hydraulic fracturing and matrix stimulation treatments to restore or enhance well productivity are performed in all types of formations and reservoir environments. You can maximize production by creating highly conductive reservoir flow paths, but selecting the appropriate treatment for each environment is critical to well economics.

Tight Gas

Effective development of low-permeability tight gas reservoir resources requires operational efficiency to improve performance.
Proppant Distribution | High Temperature CO2 Fracturing Fluid
Carbonate

Understanding and addressing the specific challenges and technical risks that carbonates present has put Schlumberger at the forefront of technology development to help optimize productivity.
Viscoelastic Diverting Acid | Degradable Diversion Acid | Deep-Penetrating, High-Temperature Acid | Fracturing and Completion Services
Conventional Sandstone

Matrix stimulation and hydraulic fracturing techniques are designed to repair and improve the natural connection of the wellbore with the reservoir.
HiWAY Channel Fracturing | Scale Control | CO2 Polymer-Free Fracturing Fluid | Organic Clay Acid Stimulation Fluid | High-Water-Cut Acidizing Diverter | Simplified Sandstone Acidizing System | Proppant Flowback Control
High-Permeability

Matrix acidization treatments are used to mitigate the effects of formation damage, the biggest hindrance to productivity in highly permeable reservoirs.
High-Permeability, Polymer-Free Fracturing Fluid | Polymer Free Gravel Pack Fluid | Filtercake Removal Service | Combined Fracturing & Gravel Packing Service | Scale Control
Unconventional Gas

Better reservoir knowledge and increasingly sensitive technologies are making production of unconventional gas economically viable and more efficient. This efficiency is bringing tight gas, coalbed methane, and gas hydrates into the reach of more companies around the world.
Microseismic Hydraulic Fracture Monitoring

Measure hydraulic fracture geometry in real time.
StimMAP LIVE Microseismic Fracture Monitoring Service
Treatment Execution

Schlumberger develops innovative methods and provides the right equipment to perform stimulation treatments in any well environment.
Candidate Recognition | Offshore vessels | Monitoring Stimulation Treatments | Well Optimization Service

Detecting boundary of salt dome in seismic data with edge detection technique

Abstract
In dealing with the issue of poor seismic imaging in
boundary of salt dome in study area, the sensitivity of
several attributes (amplitude, coherence and edge detection)
to the dome boundary are tested, With the use of a chosen
edge detection technique, The salt dome boundary is
achieved.
Geological setting
The study area is located in a region with abundant
petroleum resources, and potential structure position, In
this area, there are several salt domes of great thickness
ranging from 1000-3000 m, developed in Permian
overlying the target zone of Carboniferous. VSP data show
the velocity of salt varies from 4000 to 6000 m/s, which is
obviously higher than that of surrounding rock. Sub-salt
reflections are pulled up intensely due to the great velocity
difference between salt and surrounding rock and the
thickness variation of salt layer. The thicker the salt is, the
greater sub-salt reflection is pulled up. which makes the
sub-salt events appear as pseudo-structural configuration
so iso-chrone maps of Carboniferous are not able to reflect
its true shape. Therefore, the key to sub-salt structure
interpretation is determine the thickness and boundary of
salt dome .
Different shooting patterns resulted in seismic data with
the character of nonuniform distribution of dominant
frequency band and amplitude strength, low S/N ratio of
horizons related to Permian, and poor imaging quality of
reflection at the top and bottom of salt body. As the result,
it is difficult to define the salt dome boundary in the
seismic data .
Principle
Edge detection is one of common imaging processing
technique to find the position of pixels with intense
variation which can be express the useful information in
the data.
Edge detection is a basic method in image processing, that
detects the position of pixels that vary greatly in the image,
which can express a useful that value to the central sample.
In practice, this amounts to weighting the central sample
based on how similar it is to surrounding traces. If the
surrounding traces are consistently similar, the central
sample will be given a value near zero. If the surrounding
traces show marked variation, the central sample will be
given a non-zero value. Edge detection can thus give you a
clearer image of lateral dissimilarities caused by such
conditions as faulting or stratigraphic changes.
This technique can be applied to conventional seismic data
or to a dataset of similarity attributes. If the input is
conventional seismic data, edge detection preserves
amplitudes but weights them (as opposed to ESP
processing which replaces amplitudes with Manhattan
distance values). If the input is ESP data, edge
detection accentuates the differences you uncovered in
the Manhattan distance values generated from the
original seismic data. For the salt application
LandMark, the Sobel method which uses the first
derivative is used.
Sobel Edge Detection
In Sobel edge detection, the first derivative is
calculated in both the inline and crossline directions
for a 9-trace plane. The average of these two
orthogonal measurements is then assigned to the
center sample
In practice, the Sobel algorithm is implemented by
applying two sets of sample weights and then
combining the weighted samples. The first weighting
mask detects dissimilarity in one direction (at 90° to
the row of zeros).The second weighting mask detects
dissimilarity in the other direction (at 90° to the row
of zeros).By combining all of the weighted samples,
dissimilarity can be detected along any orientation.
Applied effect
Constrained by the plane dip, Sobel method is applied
to detect salt dome boundary in post stack seismic
data, and the time slices through edge detection cut
from shallow to deep level are used to delineate salt
dome boundary.
Conlusions
Not only can the boundaries of salt domes and faults
(especially high angle fault) be identified with the use of
edge detection technique, but the variation of lithological
property also can be detected. With the results of edge
detection interpretation, boundaries of salt domes are tracked,
and the thickness of salt layer is achieved by which the
velocity field built up.True structural configuration
of sub-salt target zone is achieved after time-depth
conversion.
Acknowledgment
We are grateful to Professor Huang Zhong fan for reviewing
this paper and giving many constructive suggestions;thanks
to wang ya lin for her supported.

Wellsite Connectivity for Well Testing Operations

InterACT connectivity, collaboration, and information system, secure monitoring of well testing operations via the Internet has made a significant impact on how oil and gas companies plan and execute their operations.

Well testing experts are now able to actively participate as if they were on site. This remote witnessing capability provides significant logistical savings and increased ability to deal with multiple responsibilities. Using a standard Web browser, InterACT remote witnessing and data delivery enable the operator, partners, and Schlumberger experts to collaborate on well test operations while they happen. Expertise not normally available at the wellsite can be focused on a well test, regardless of the location, and informed operations decisions can be made and implemented in a timely manner.

This remote, real-time capability can be critical when applying new technology in well testing, for example multiphase meter production testing, or wellsite PVT analysis. Remote expert collaboration is key to extracting value when the exceptional dynamic response of the PhaseTester portable multiphase periodic well testing equipment is combined with data from the Schlumberger PVT Express wellsite service.

Reservoir Sampling and Analysis-Surface Testing and Cleanup

Reservoir Sampling and Analysis

Fluid and rock sampling and analysis services optimize your production decisions with a global network of sampling operation and reservoir fluid and rock analysis centers. We have industry-leading technology for mercury-free reservoir fluid sampling, wellsite analysis, sample management, fluid phase behavior, flow assurance laboratory studies, and geomechanics testing and analysis.

Surface Testing and Cleanup

The fluids produced during a test must be handled using surface testing equipment when permanent production facilities are not available. The surface testing equipment (described below) must perform a wide range of functions:

* quickly control pressure and flow rates at the surface and shut in the well
* accurately meter the fluids and collect surface fluid samples
* separate the resulting effluent into three fluids: oil, gas, and water
* dispose of the resulting fluids in an environmentally safe manner.


Flowhead

Four gate valves used to hang test string from elevator and to control flow through master and flow valves; if fitted with a swivel, it allows test string to rotate. Compatible with slickline and electric line operations.
Surface Safety Valve

Hydraulically actuated fail-safe gate valve for testing oil and gas wells; used to quickly shut in a well upstream of the choke manifold in case of overpressure, failure, a leak in downstream equipment, or any other well emergency requiring an immediate shut-in.
Emergency Shutdown (ESD) System

Multistation system that permits closure during testing operations in response to an emergency; remotely and simultaneously controls the flowline valve on the flowhead and surface safety valve.
Data Header

Short sub connected to upstream side of choke manifold to provide additional pressure gauge, thermowell, and sampling or injection ports; allows connection of pressure and temperature monitoring equipment, as well as sampling and injection equipment.
Dual-Pot Sand Filter

Filter with two filter pots and interconnecting piping used to remove sand and other solid particles from well effluent to prevent erosion of downstream equipment.
Floor Choke Manifold

Four manual valves (five if bypass valve is included) used to control flow rate and reduce well pressure before flow enters processing equipment.
Steam-Heat Exchanger

Steam-heat exchanger used to raise the temperature of well effluents to prevent hydrate formation, reduce viscosity, and break down emulsions for efficient separation of oil and water.
Indirect-Fired Heater

Skid-mounted indirect-fired diesel heater used to raise the temperature of well effluents to prevent hydrate formation, reduce viscosity, and break down emulsions.
CleanPhase Well Test Separator

New-generation horizontal separator that can operate as a stand-alone unit or in combination with the PhaseTester multiphase flowmeter. The separator uses SmartWeir technology, which accommodates the most challenging well effluents and provides online separation for the entire job, from the beginning of cleanup until the end of the well test.
CleanSep

New-generation horizontal separator that can operate as stand-alone unit or with PhaseTester portable multiphase flowmeter with Vx technology. With Vx technology, flow measurements are unaffected by separation issues such as foaming oil, emulsions, and gas in the oil line.
Conventional Horizontal Separator

Instrumented vessel that separates well effluent into three phases for onshore and offshore well testing; can operate as a stand-alone unit or with PhaseTester portable multiphase flowmeter with Vx technology.
ClearPhase Mobile Testing Discharge Treatment

Mobile water testing dischrge unit for exploration and development well testing and cleanup; efficient, cost-effective alternative to water storage, transport, and onshore disposal.
Vertical Surge Tank

H2S service vessel that stores liquid hydrocarbons after separation; used to measure liquid flow rates and combined shrinkage and meter factor; also used as second stage separator.
Atmospheric Gauge Tank

Nonpressurized vessel used to measure flow rates and calibrate metering devices on separator lines; can also be used for temporary storage.
Transfer Pump

Pump that pumps oil from tank to burner or from tank into existing flowline; usually fitted with explosion-proof electrical motor for operations in Zone 2 regions; can also be fitted with diesel engine for remote location operations.
Oil and Gas Manifolds

Manifolds that divert oil or gas without flow interruption from a separator to burners for disposal, to a tank for measurements or storage, or to a production line.
U-Boom

Modular boom that keeps flare at a safe distance from the rig structure, reducing heat radiation and fire risk.
V-Boom

Heavy-duty modular triangular boom, designed for use in the North Sea; keeps flare at a safe distance from the rig structure, reducing heat radiation and fire risk.
EverGreen Burner

Single-head, 12-nozzle, well test oil burner for onshore and offshore exploration and development well testing and cleanup; provides environmentally friendly alternative to oil storage that is efficient and cost effective.
Extended Well Tests

Tests (EWTs) used to evaluate productivity and characteristics of a reservoir. EWTs also provide a way to test sand control techniques and process- and production-related technologies.
ArchiTest 2.0

Well test design software that provides a realistic steady-state simulation of actual field conditions to facilitate surface well test planning; main goal is to enhance safety of the well test environment.

Perforating

You want maximum productivity from your reservoir. Whether in new or existing wells, maximum production depends on optimized perforating.

Schlumberger engineered perforating systems can help you achieve the best production or injection in your well by optimizing the relationship between the gun system, wellbore, and your reservoir. Schlumberger perforating systems enable you to

* measure to fully characterize the reservoir rock and fluids
* perforate with the optimum design of gun system and charge
* clean the perforations by controlling wellbore dynamics while perforating
* monitor to maximize reservoir productivity.

Perforating Gun Systems and Charges

Schlumberger offers capsule and hollow carrier gun systems with a wide variety of perforating charges for every environment.
Pipe Recovery and Remedial Services

Schlumberger has solutions for drillpipe, coiled tubing, and tubing recovery and special techniques for cement squeeze, punching tubing, junk shots, and other applications.
Tubing-Conveyed Perforating

Tubing-conveyed perforating (TCP) allows long, heavy gun strings to be run in all well conditions.
Wireline Perforating

Wireline (or electric line) is the traditional way to run perforating guns, providing the advantages of real-time depth control and selectivity.
Completion Perforating

Completion perforating enables large, long strings of guns to be installed with the completion and fired with the right completion fluid in place for immediate cleanup and production.
Completion Perforating Without Killing the Well

The CWOK process uses underbalance, dynamic underbalance (PURE), or extreme underbalance perforating for clean perforations, then removes the guns without killing the well.
Slickline Perforating

Slickline is a fast and efficient conveyance method that can be used for many explosive services such as perforating, setting plugs or packers, or cutting tubing.
Coiled Tubing Perforating

Coiled tubing allows perforating guns to be run into extended-reach or horizontal wells and also allows longer, heavier gun strings to be run.

Early Production Facilities (EPF) -Multiphase Well Testing and Monitoring

Early Production Facilities (EPF)

Begin production early while full field development is being planned and permanent facilities are being built. Early-production facilities (EPFs) can help operators bring their new discoveries on stream fast. Schlumberger has designed and installed modular, fit-for-purpose EPFs worldwide for more than 30 years and to date has completed approximately 70 projects.

EPFs and fast-track schedules can help operators create an early cash flow with only a minimum cash outlay. They also provide real-time production data that can help operators appraise reservoir performance before they install more-expensive long-term facilities. EPFs can be used for small reserves that would be financially risky or uneconomical to produce with a permanent production facility.

Multiphase Well Testing and Monitoring

Our multiphase flowmeter (MPFM) products and services provide critical well diagnostic information without the complexity of conventional testing operations. With continuous measurements of a well's individual phases without separation, our multiphase measurement capabilities offer many advantages:

* Improved test quality and availability
* Quick well performance trend analyses
* Immediate well diagnostics
* Reduced costs per well tested
* Compact, lightweight, low-maintenance equipment
* Worldwide support for multiphase testing operations
* Multiphase measurement gas mode applicable to oil and gas wells

PhaseTester Multiphase Testing

Measure multiphase flow efficiently with a portable multiphase flow metering service.
PhaseSampler Multiphase Sampling

Capture PVT-quality samples of multiphase fluids at line conditions directly from the flowline.
PhaseWatcher Multiphase Flowmeter

Get permanent multiphase monitoring solutions for onshore and offshore wells.
Vx Technology

Both PhaseTester and PhaseWatcher equipment incorporate Vx technology to acquire superior, dynamic response to fluctuating flow, high-accuracy flow rate measurements, and unmatched resolution and repeatability. Gas mode extends the range of operation for Vx technology from 0% to 100% gas volume fraction (black oil to dry gas). Switching between modes requires only a mouse click.

Downhole Test Tools 2

PosiTest Retrievable Packer

The PosiTest retrievable compression packer is a fullbore, cased-hole, retrievable compression-set packer with a large internal bypass. The packer is designed to withstand high flow rates, elevated temperatures, and high pressures when the appropriate amount of weight is applied to the packer. The sealing elements effectively isolate annulus fluids from the perforated interval.

PosiTest Long-Stroke Packer

The PosiTest long-stroke packer is similar to the standard PosiTest retrievable compression packer except that it is set by string reciprocation instead of string rotation. The long-stroke packer can be easily redressed between operations or converted quickly to run in another casing weight.

Hydraulic Hold-Down

The hydraulic hold-down complements both the PosiTest retrievable compression packer and the PosiTest long-stroke packer. It prevents upward movement as a result of hydraulic forces acting below the packer during stimulation or when a firing head is being activated. This combination functions similarly to the PosiTrieve downhole packer with hold-down section; all hydraulic hold-down modules can be used with the PosiTest long-stroke packer.

Applications

The PosiTest packer has two applications:

• Drillstem testing
• Tubing-conveyed perforating
  

PCT Pressure Controlled Tester Valve

The PCT Pressure Controlled Tester valve, operated by annulus pressure, is the downhole valve used to control formation flows and shut-ins for applications that do not use the IRIS Intelligent Remote Implementation System. The PCT valve must be run in conjunction with either the hydrostatic reference tool or the PORT Pressure Operated Reference Tool, either of which traps a reference pressure inside the PCT valve.

The two distinct sections of the PCT valve are the ball valve seal section and the hydromechanical operator section.

The versatility of the PCT valve can be enhanced by installing a hold-open (HOOP) module that holds the ball open when the annulus pressure is bled off. The HOOP module allows wireline to be run through the ball or circulation through the ball valve when the packer is not set.

Operating pressures for the PCT valve vary with depth but are usually between 6.95 and 10.34 kPa [1,000 and 1,500 psi] applied annulus pressure.

Pump-Through Flapper Safety Valve

The pump-through flapper safety valve (PFSV) provides a reliable means for obtaining downhole shut-in and minimizing wellbore storage during final pressure buildup. It also has the ability to pump into the formation, irrespective of tubing or annulus pressure integrity above the valve.

The PFSV is a fully opening downhole safety valve. It is open when run in the hole and closed permanently when annulus pressure rises above the rupture disk rating. The operator mandrel is biased to internal pressure and locked in the open position to prevent premature closure. Upon bursting the rupture disk, hydrostatic pressure is applied to the operator mandrel, which moves up against an atmospheric chamber, uncovering the spring-loaded flapper. Pumping down the tubing lifts the flapper off its seat and permits killing the well.

Safety Joint

The safety joint (SJB) allows quick release of the test string if the string below the packer becomes stuck. The tool has a coarse thread to carry the string load and allow easy disengagement and re-engagement. The SJB is typically positioned on top of the packer and made up to the same torque as the other tools in the string. It is disengaged by left-hand torque. The shear pins in the tool maintain a consistent breakout torque regardless of wear and tear on the tool. The breakout torque is controlled to 950 ft.lbf by a shear pin. An adjusting ring keeps the right-hand torque from acting on the shear pin. The joint can be engaged by applying weight and rotating it slowly to the right. After disengagement, the retrieved pin is easily screwed back into a downhole box section with a suitable fishing assembly for retrieval of the stuck string

SCAR Inline Independent Reservoir Fluid Sampling

SCAR inline independent reservoir fluid sampling delivers contaminant-free fluid samples from deep within the formation. SCAR sampling is a complete approach, engineered to capture reservoir fluid samples more safely and reliably.

Eliminate sample contamination

SCAR sampling captures fluid samples individually or sequentially, directly within the flow stream. This collection method eliminates the possibility of contaminants and junk in each sample caused by dead volumes.

More reliable, safer sampling

Single large nitrogen charges can compromise the safety of operations and the integrity of every sample. SCAR samplers have small, independent gas charges to ensure each individual sample remains at or above reservoir pressure. Non-reactive sample chambers also ensure trace elements are retained.

Faster wellsite handling

To meet your specific test requirements, the SCAR system offers a broad range of sizes, ratings, and activation options. Its shorter length allows faster handling at the well site.

Single-Ball Safety Valve

The single-ball safety valve (SBSV) is a fully open downhole safety valve that is run in the open position and closes permanently when the disk is ruptured. The operator mandrel is balanced to internal pressure, and is locked in the open position to prevent premature closure.

Upon rupturing the disk, hydrostatic pressure is applied to the operator mandrel, which closes the valve.

The combination of the large differential pressure (hydrostatic to atmospheric) and the 21-cm² [3 3/4-in²] operator mandrel area yields more than enough force to cut 5.6-mm [7/32-in] wireline cable, even in shallow wells. The operator mandrel locks in the closed position and prevents the tool from reopening until it is retrieved at the surface. The lock can be reset without disassembling the tool, which enables functional testing before running in the hole.

Kits are available to convert the SBSV to a pump-through safety valve (PTSV) or a pipe tester valve (PTV).

Single-Shot Reversing Valve

The single-shot reversing valve (SHRV) operates by applying annulus pressure to burst a rupture disk. Once actuated, the reversing ports are locked open. The SHRV is typically opened at the completion of the drillstem test (DST) to reverse out fluids produced during the test.

A ratchet keeps the valve in the closed position until the disc is ruptured. When the rupture disk bursts, hydrostatic pressure is applied to the operator mandrel, moving it up against the atmospheric-pressured chamber. This results in uncovering eight large circulating ports for efficient well-killing operations. Once annulus pressure pushes the mandrel up, the same ratchet locks the mandrel in place to keep the tool open. The SHRV-H is part of the 88.9-mm [3.5-in] large-bore IRIS Intelligent Remote Implementation System.

The SHRV-J is part of the ultrahighpressure J-string developed for use in wells with bottomhole temperatures greater than 218 degC [425 degF]. New seal technology has enabled successful qualification testing of the J-string tools up to 260 degC [500 degF] at the maximum rated pressure.

Slip Joint

The slip joint (SLPJ) is an expansion/contraction compensating tool. It accommodates any changes in string length caused by temperature and pressure during a drillstem test.

The SLPJ has two distinct parts: an outer housing and a moving inner mandrel. Its rugged design incorporates three main sections. At the top is a splined moving mandrel that allows torque to be transmitted through the tool. Below this are two pressure chambers, one open to tubing pressure and the other open to annulus pressure. The tool is hydraulically balanced and insensitive to applied tubing pressures. The dynamic seals in the balance chambers are dependable chevron V-seals.

Testing SLPJs have a stroke of 5 ft; the total number of SLPJs required depends on well conditions and the type of operation. For a standard test at 10,000 ft, the use of three SLPJs is normal. For tests for which injection or stimulation is planned, the associated cooling can cause a large amount of string contraction, and four or five SLPJs may be required to compensate for string movement during operations.

A special clamp securely joining the mandrel and the housing of the SLPJ is added for safety considerations for when the tool is handled at the surface.

SLPJs make it easier to space out the tubing-conveyed perforating guns when testing is done from a semisubmersible.

Tubing-Fill Test Valve

The tubing-fill test valve (TFTV) enables filling and testing of the tubing while running in the hole.

As the string is lowered into the hole, fluid enters the tubing through the TFTV bypass ports. The fluid creates a differential pressure that causes the flapper to open and then fills the tubing.

The tubing can be tested at any depth by pressuring-up on the tubing string against the flapper valve. When the test string is at depth, annulus pressure is applied to rupture a disk, causing the flapper to lock fully open. Once the flapper is open, the tool has fullbore access.

Downhole Test Tools 1

Downhole Test Tools 1

FlexPac Packer Hydraulic Hold-Down

The hydraulic hold-down complements the FlexPac retrievable packer. It prevents the string from moving uphole as a result of hydraulic forces acting below the packer during stimulation or when a firing head is being activated. The slip design is similar to that of the proven hold-down section of the PosiTrieve retrievable downhole packer.

HiPack High-Performance Testing Packer System

The HiPack high-performance testing packer system is a first-of-a-kind retrievable test system that delivers production-level isolation. The HiPack system’s built-in floating seal assembly allows it to function like a production packer, and a straight pull easily releases the packer for added flexibility.

Minimized string complexity

The HiPack packer system minimizes complexity through a simplified string design that eliminates the need for drill collars and slip joints. This simplified string design reduces the number of individual tools, connections, and dynamic seals required downhole for more efficient operations.

Better reservoir connectivity

With the HiPack system, you can select the optimal perforating gun size to achieve a better connection to your reservoir. The system also allows gauges to be positioned below the packer, putting them closer to the reservoir during testing for the highest quality pressure measurements.

Safer, lower-risk operations

The HiPack packer system is set without string rotation or mechanical movement for faster, lower-risk operations, especially in subsea environments. The system provides the option to place a below-packer circulating valve (BPCV) on the test string for a more efficient well kill, particularly important during gas well testing.

Hydraulic Jar

During drillstem tests (DSTs), if a packer or tailpipe becomes stuck, the hydraulic jar is used to provide an upward-moving shock that will help pull the string loose.

The jar consists of a housing and a mandrel that move relative to each other. An oil chamber, separated by a flow restrictor in series with a check valve, is located between the housing and mandrel.

Applying weight to the packer causes the jar to close. If the tools below the jar become stuck, an overpull is applied to the string, which causes the jar to begin metering hydraulic oil. As the oil flows slowly through the restrictor from the upper chamber into the lower chamber, elastic energy is stored in the string. The mandrel housing moves until a seal ring is uncovered, at which time the housing rapidly accelerates to produce an upward impact on the stuck tools.

After the jar has tripped, the string weight is set back down on the packer to reset the tool. Oil flows rapidly through the check valve and back into the upper chamber, allowing jarring to be repeated as necessary.

IRDV Intelligent Remote Dual Valve

The IRDV intelligent remote dual valve allows independent command of two valves in the tool string: a testing valve and a circulating valve. This single command system can operate both valves in multiple conditions and is immune to downhole pressure and temperature changes.

Reliable, independent control

The IRDV features nitrogen-free, hydrostatically powered testing and circulating valves in one tool. Low pressure pulses in the annulus enable independent operation of both valves without interfering with the operation of other tools in your test string.

Reduced operating time

The IRDV enables faster, more efficient operations by issuing direct or sequential commands that eliminate the need to use complex indexing systems. The intelligent command of the system keeps a complete record of tool operations, valuable information that can be used for post-job verification.

Flexible testing operations

Exclusive to the IRDV is a downhole redundancy option. This on-command mechanical override gives greater flexibility during reservoir testing, providing the ability to run multiple IRDVs in your tool string.

Multicycle Circulating and Reversible Valve with Lock Module

The multicycle circulating valve with lock (MCVL) module is a reclosable circulating and reversing valve.

Applying a predetermined number of pressure cycles to the tubing opens the valve. The MCVL cycles by the differential pressure between the tubing and annulus, and it is not dependent on pump rate.

The valve can be locked in the open or closed position by using the lock module. When the lock is engaged, the tool is insensitive to pressure surges in the tubing and annulus. Applying pressure to the annulus ruptures a disc and disengages the lock module.

Multiple-Opening Internally Operated Reversing Valve

The multiple-opening internally operated reversing valve (MIRV) is a tubing-pressure-operated reclosable reversing valve. An index system enables pressure testing of the tubing string while running in the hole. The MIRV is opened by applying a predetermined number of tubing pressure cycles against the tester valve. When the tool is opened, it can be used to reverse circulate, spot stimulation fluids, or change cushions.

Pumping through the circulating ports at preset pump rates between 0.3 and 1.3 m3/min [2 and 8 bbl/min] closes the tool.

The MIRV can be run in the hole open, which allows the string to fill with mud. After the packer is set, the cushion can be pumped into the string, the MIRV closed, and the test initiated.

Pipe Tester Valve

The pipe tester valve (PTV) is a modified single-ball safety valve (SBSV) with a multiflow evaluator (MFE) ball installed in place of the PCT Pressure Controlled Tester ball. This tool is used in production-type tests for running a cushion, or for pressure testing the pipe string above the valve while running in the hole.

The PTV is normally closed, but it opens permanently when annulus pressure is applied to burst the rupture disk.

When the PTV is used with the dual-ball safety valve or SBSV, one flow test and one shut-in test can be performed with a minimum number of tools.

PORT Pressure-Operated Reference Tool

The PORT Pressure Operated Reference Tool provides a reference pressure to the PCT Pressure Controlled Tester valve and also serves as a bypass when running in the hole. The PORT tool is used to trap a reference pressure within the PCT valve, eliminating the need for a high-nitrogen precharge at the surface. This trapped reference pressure provides a high-closing force for the PCT ball valve.

To operate the tool, pressure is applied to the annulus, causing the disc to rupture. When coming out of the hole, for safety, the downhole reference pressure is bled through the relief valve.

Because the PORT tool is pressure-operated, no set-down weight is required, as it is with the hydrostatic reference tool (HRT). Therefore, the string can be run in tension,greatly simplifying the string design when testing with a permanent packer. In this case, drill collars (weight) and slip joints (length compensation) can be eliminated. Length compensation is provided by the packer stinger when using a permanent packer.

Options

The PORT tool is normally fitted with a formation protector module (FPM) kit when open perforations are present. The FPM kit prevents the annulus overpressure needed to close the PORT tool from communicating with the open formation through the bypass ports

Downhole Test Tools 2

Downhole Pressure Measurement

Downhole Pressure Measurement

Reliable, sensitive downhole recorders obtain precise pressure data in a wide range of environments and allow highly accurate interpretations of that data.
CQG Crystal Quartz Gauge

Provides the most accurate, highest resolution pressure measurements available in the industry during downhole reservoir testing.
DataLatch System

System for data recording and readouts during drillstem testing.
UNIGAGE Pressure Gauge System

System for obtaining accurate pressure data in difficult downhole conditions.

CQG Crystal Quartz Gauge

The field-proven CQG crystal quartz gauge leads the market in high-quality pressure measurements. Designed from unique and proprietary sensor technology, the CQG gauge delivers consistently accurate results for improved reservoir characterization.

Most accurate measurements

The CQG design incorporates a single quartz crystal that measures pressure and temperature at the same point in the crystal. This unique feature dramatically reduces thermal effects and provides the most accurate pressure measurements available.

Highest resolution and accuracy

Small, residual thermal effects are further minimized with real-time dynamic compensation. This one-of-a-kind capability enables a fast pressure response for the highest resolution and accuracy under dynamic downhole conditions.

Minimal drift for ultimate stability

The CQG gauge’s unique dual-mode pressure sensor and highly accurate clock provides long-term pressure measurement with minimal drift for the ultimate stability. This stability and industry-leading resolution allows operators to see further into the reservoir and clearly detect boundaries.

DataLatch System

The DataLatch electrical wireline downhole recorder and transmitter system combines both downhole recording and surface readouts for well testing operations. It is built around a fullbore gauge carrier called the drillstem test gauge adaptor (DGA) and can support up to four UNIGAGE pressure gauges. Each gauge is powered and programmed individually and can be selectively ported to read the pressure above or below the test valve or in the annulus. In its simplest configuration-when only downhole recording is required-the DGA is run as a stand-alone gauge carrier, either above or below the packer. During surface readout operations, the DGA is run in conjunction with the LINC downhole electrical wireline connector. The data obtained by the DataLatch system are redundant, flexible, and high quality.

Typical job sequence

In a typical DataLatch system job, the gauges are programmed at the surface and the DataLatch system is run downhole with the drillstem test string. The gauges record the data as the well is being perforated, cleaned up, and drawn down. The well is then shut in and the LINC running tool (LRT) is run on wireline to retrieve the recorded data for analysis. A decision can then be made either to continue or to end the test. If the test continues, the gauges are reprogrammed for additional flow periods, and the LRT is pulled out of the hole.

UNIGAGE Pressure Gauge System

The Schlumberger UNIGAGE pressure gauge system provides high-quality, high-reliability pressure measurements during reservoir tests in exploration and development wells and during production tests on slicklines. The UNIGAGE system is built around either a high-resolution, high-stability quartz sensor (WCQR or WTQR) or a Schlumberger Sapphire pressure sensor (WTSR or SLSR). Both types of sensors provide high-quality data to ensure accurate interpretation of pressure measurements for optimum reservoir characterization.

The UNIGAGE system is designed for operations in harsh conditions such as H₂S, CO₂, acid, and TCP operations, and is compatible with highpressure, high-temperature jobs to 25,000 psi and 410 degF. Tests up to 1 year in duration can be performed.

A fast-recording rate recorder associated with a high-capacity memory allows the UNIGAGE system to fit with a broad range of test objectives and test durations. In addition, an intelligent memory management system, including memory guard, data reduction, and programmable windows, ensures full coverage of the well test even if more time is needed than was initially expected.

The WCQR sensor with quartz dual-mode oscillator and dynamic compensation provides outstanding metrological performance and is particularly well suited to high-permeability reservoirs with small pressure drawdowns.

The WTQR sensor equipped with a quartz sensor is an excellent choice in terms of accuracy, resolution, stability, reliability, and job duration requirements.

The UltraSapphire ultra high-pressure, high-temperature pressure gauge, WTSR, can be run by itself on monocable electric line for surface readout operations.

The SLSR is a cost-effective, efficient pressure gauge, particularly when run on slickline for downhole recording.

All UNIGAGE systems can be used in conjunction with the DataLatch system. This system has the benefit of a downhole valve to shut in the well, minimizing the ellbore storage effect and thereby shortening the test duration. The data are stored in memory but can be read at any time using a reliable inductive coupling method. An operational tool on an electric line allows full communication with the gauges, including data downloading, gauge reprogramming, and real-time surface readouts.

Benefits

• Provides high-quality data for optimum reservoir characterization
• Ensures reliable measurements in harsh environments and TCP operations
• Reduces test time

Testing—Be Certain

When decisions are critical, when uncertainty adds risk, we help you form a better basis for your decisions. Schlumberger offers the broadest range of testing and measurement services available, from exploration and appraisal through development and production.

Downhole or at the surface, get answers to key questions about productivity, fluid properties, composition, flow, pressure, and temperature.

Combining field-proven testing experience with reservoir-domain expertise, Schlumberger teams work with you to prove reservoir potential, confirm well performance, and improve field productivity.

Be certain.
Exploration and Appraisal

Prove reservoir potential by determining dynamic reservoir properties.
Development

Confirm well performance by optimizing completions and ensuring maximum deliverability from each well.
Production

Improve field productivity and maximize recovery through the maintenance, monitoring, allocation, and optimization of each well's production.

Exploration and Appraisal

Prove Reservoir Potential

Any model on which critical decisions can be made demands direct measurement of fluid properties, composition, flow rates, pressure, and temperature and helps quantify key characteristics such as connected volumes and fluid mobility.

To help you mitigate risk and manage uncertainty, our multidisciplinary teams work with your engineers on every test design. The result is a program of services that safely meets your test objectives and time frame.

Choose from the broadest portfolio of downhole and surface testing services available across the life of the reservoir from a single source. Using leading technologies to deliver a range of unique measurements, Schlumberger teams combine field-proven testing experience with reservoir-domain expertise that adds value to every test.

On land and offshore, in shallow and complex deepwater environments, we work with you to prove reservoir potential.

Development

Confirm Well Performance

Confirming exactly how each well will perform relies on obtaining accurate information and feedback throughout the well's construction. Schlumberger has developed technologies and measurements with unmatched levels of resolution, speed, and accuracy to help answer a wide variety of development questions.

From initial design to well delivery, Schlumberger can help you combine all of your completion, perforating, and cleanup considerations in a comprehensive, coordinated approach. We work with you to help design and validate the results of your development activities. To characterize formation damage. To optimize the design and performance of your well's perforations. To verify cleanup success.

At the same time, initial measurements of flow, fluid properties, composition, pressure, and temperature provide baseline data to help you evaluate each well's performance as production progresses and deliver maximum connectivity to the reservoir and minimum resistance along the flow path.

Choose from the broadest portfolio of downhole and surface testing services available from a single source. Using leading technologies to deliver a range of unique measurements, Schlumberger teams combine field-proven testing experience with reservoir-domain expertise that adds value to every test.Each service is designed to be reliable in the most challenging scenarios and to provide the flexibility and accessibility your operations demand.

Production

Improve Field Productivity

Key measurements, such as flow rate, fluid properties, composition, pressure, and temperature—all captured at live well conditions—help identify what's happening downhole and at the surface with greater certainty. Continuous, in-depth knowledge helps pinpoint where improvements can be made, efficiency increased, and field investments focused—all with confidence.

Use this knowledge to dynamically monitor production and sustain productivity levels. Diagnose well problems and address any mechanical issues to restore flow and protect your assets. Interpret data from multiple wells to build up a comprehensive picture of changes across the reservoir, helping optimize its ultimate recovery rate. Build accurate profiles of produced fluids as they flow.

With the information these measurements provide, past downhole events can be better interpreted, and the future impact on production predicted.

Choose from the broadest portfolio of downhole and surface testing services available across the life of the field from a single source. Using leading technologies to deliver a range of unique measurements, Schlumberger teams combine field-proven testing experience with reservoir-domain expertise that adds value to every test.

Throughout your production activities, Schlumberger gives you well information you can act on.

Well Testing

We offer the broadest range of testing and measurement services available, from exploration and appraisal through development to production. Downhole or at the surface, get answers to questions about productivity, fluid properties, composition, flow, pressure, and temperature. Combining field-proven testing experience with reservoir-domain expertise, our teams work with you to prove reservoir potential, confirm well performance, and improve field productivity so you can be certain.

Packers-Subsurface Safety Valves

Packers

Packers systems are among the most important tools in the tubing string. The types of packer systems vary greatly. Often, they're designed or configured to meet specific wellbore or reservoir conditions, such as single-packer or tandem-packer configurations, single-tubing or dual-tubing strings, and the full range of pressure and temperature applications.

The basic requirement of packers systems and associated tools relates to flow from or injection into the formation to the tubing string or production conduit. The packer must enable efficient flow and must not restrict normal production or injection flow.

Subsurface Safety Valves

Work on subsea wells is a costly and hazardous process. Crucial to efficiency and safety are the successful installation, dependable operation, and long-term reliability of subsurface safety and injection valves.

Safety valves, an integral part of well completions, protect offshore and land production installations. Schlumberger surface-controlled subsurface safety valves use the innovative rod piston hydraulicactuation system developed by Schlumberger. All series contain a rugged, metal-to-metal Inconel flapper closure mechanism plus secondary soft seal. Schlumberger offers six main safety valve styles, ranging from basic to the most high-tech design available in the industry.

Multilaterals

Reduce total well construction costs and improve reservoir access.
Increasing reserves while minimizing investment is the focus for multilateral technology, which lets you confidently reenter existing wells. You can drill an additional lateral to increase reservoir exposure or branch more than one lateral to increase reservoir exposure and target complex reservoirs.

RapidConnect

Stable access for the life of the well.
RapidExclude

Reduce trips into the hole

RapidConnect multilateral completion system providing selective drainhole access and connectivity. Get superior junction stability and strength, improved drainage and excellent mechanical integrity with built-in lateral access. Use a simple, low-risk system with running procedures that minimize trips into the hole.

Minimize costs

RapidConnect components can be installed with the RapidAccess multilateral completion system index casing coupling (ICC) or with packer-based systems. With ICC and RapidConnect, you have a planning option for future laterals. At minimal cost, the ICC can be installed in advance for a permanent depth and orientation reference with full casing integrity until the window is milled.

Benefits

• Reduce trips into the hole
• Ensure stable access for the well's life
• Get long-term stability in fragile shales, depleted reservoirs and mobile salts

The Schlumberger RapidExclude

junction is a high-strength junction for multilateral completions
RapidTieBack Quad System

Improve reservoir drainage

RapidExclude multilateral junction for solids exclusion is safe, reliable and extremely robust for full-size drilling diameters. The template and connector, effectively, are a single sand barrier with the continuous, locking rail engagement.

If individual reservoir compartment reserves are uneconomical, the RapidExclude junction using two laterals may penetrate more of the pay zone. A new plan developing a multilateral well producing from two or more compartments may be successful.

Identify risk

With risk assessment to identify the best location, RapidExclude can be used for

• new or reentry wells
• infill well drilling in mature assets
• wells with different pressure regimes requiring inflow control.

Benefits

• Improve reservoir drainage

RapidTieBack Quad System
Reliable multilateral access for maximum reservoir exposure.

Reliable multilateral access for maximum reservoir exposure

RapidTieBack nonmilling multilateral drilling and completion system lets you place closely spaced multiple junctions in the zone of interest and commingle production. Used primarily in heavy oil applications; also in many other oil and gas reservoirs.

This is an economical and reliable approach to using multilaterals for the optimization of heavy-oil reservoirs.

Increase flexibility

The premilled window and mechanically installed tieback require no steel milling, reducing the risk of equipment damage from milling debris. The multiple lateral branches can be selectively accessed.

The big bore lets you use openhole or liners in the lateral branches. The large-diameter liner sleeve allows you to pass completion tools, such as an electrical submersible pump (ESP), through the junction.

Multilateral Reentry System

Controlled, selective entry on coiled tubing for multilateral wells.

Discovery MLT Multilateral Reentry System

Controlled, selective entry on coiled tubing for multilateral wells

Discovery MLT multilateral reentry system is cost-effective and operationally simple for maximizing performance of multilateral wells. The system sends a pressure signal to the surface confirming you've accessed the correct lateral.

Adjusting the suborientation, or bend, from surface and the real-time feedback to surface of window identification save a substantial amount of time. This significantly increases the chance of successful reentry on the first attempt. Only one run to the bottom of the lateral is required for confirmation.

Discovery MLT software

Using Discovery MLT software, you can display several essential parameters, such as the tool orientation relative to the lateral window. The application also monitors previous indexes and guides you through indexing cycles for accurate, real-time information downhole.

After the window is profiled, the software memorizes the window orientation and monitors the BHA orientation, facilitating the location of other windows.

You can determine job feasibility with our CoilCADE CT design and evaluation software and monitor and record real-time data with CoilCAT acquisition software.

RapidX

The RapidX multilateral system provides a simplistic approach to a TAML Level 5 multilateral solution

The RapidX is a ultra high strength junction that provides a full size-drilling diameter, through 9-5/8" casing with large size completion and intervention diameter that meets and exceeds the specifications required for TAML Level 5. The junction design is an evolution of the field proven RapidConnect and RapidExclude systems, to provide sand exclusion and hydraulic isolation at the junction without the need to manipulate a cumbersome completion into the lateral.

Improve reservoir drainage

The RapidX assures access for the life of the well and improved reservoir drainage. With a systematic quantitative risk assessment to identify the best location, the RapidX junction can be used for new or reentry wells, wells with different pressure regimes requiring inflow control or infill wells in mature assets. RapidX provides stability with a lateral exit in unstable shale, cap rock, and sand control at the junction with an exit in the reservoir. The RapidX multilateral system provides a simplistic approach to a TAML Level 5 multilateral solution.

Features

• Internal and external hydraulic tight junction with 2500 psi rating
• TAML level 5 junction without the need to deploy cumbersome completion in upper lateral
• Ability to Cement, Gravel Pack, Run Expandable and Premium Screens in upper lateral
• Simple proven system
• Flexible Junction placement
• Continuous locking rail
• Available in 9-5/8" main bore x 7" lateral
• Large diameter completion
• Rigless, Slick Line or Coil Tubing selective reentry
• Able to integrate Flow Control Valves and/or Pressure Gauges
• No casing orientation required
• Fully retrievable
• For new and reentry wells

Isolation Valves

Prevent formation damage and improve well productivity

Formation isolation valves (FIVs)

• isolate formations without the use of kill fluids
• protect formations from fluid loss damage during completions and workovers
• contain reservoir fluid
• enhance production
• increase wellbore safety
• simplify completion operations.

Reduce well intervention costs

In one North Sea installation, an operator needed to perforate underbalanced horizontal sections and maintain a high productivity index by not killing the wells after perforating. An FIV, with specialized completion equipment and a new perforating technique, saved the operator approximately $400,000 per well and achieved a productivity index of 150 bbl/psi.

Improve safety

FIV reliability means better safety in remedial workovers such as pump replacements. The valve provides a two-way barrier that isolates the formation and contains reservoir fluids, providing increased wellbore safety.