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.

Completion Accessories

Enhance recovery with customized tubing-mounted and flow control equipment.
they are:-
1-Chemical Injection Mandrels
2-Expansion and Separation Assemblies3-Expansion Joints
4-On-Off Attachments
5-Safety Joints
6-Locks and NipplesAccessories
7-Blanking Plugs and Standing Valves
8-Sliding Sleeves and Tubing Drains Accessories
9-Smart Sub Assemblies
10-Tubular Components

ntelligent Completions

Well completions connect you to your reservoir and help you lower production costs, lengthen reservoir life, and optimize hydrocarbon recovery with completions designed for the life of your oil or gas well.
Intelligent completions obtain downhole pressure and temperature data in real time to identify problems in the reservoir or wellbore and optimize production without costly well intervention. Sensing, data transmission, and remote control of zonal flow to isolate the formation from completion fluids help operators minimize fluid loss, manage the reservoir, maintain well integrity, and maximize production.

Flow Control

Flow control valves are used in multizone intelligent completion, comingled-flow completions, auto (natural) gas-lift wells, and well environments with scale deposition, severe erosion, or high temperature conditions.
Flow control valves modify the flow behavior as required for specific operations and can be operated automatically, manually, or remotely as part of an intelligent completion. Used to control upper and lower producing zones, they reduce the production of unwanted water and gas, minimize the costs and risks of well interventions, and maximize well productivity.

Permanent Monitoring Systems

WellWatcher permanent monitoring systems

WellWatcher permanent monitoring systems integrate the most advanced permanent downhole gauges with surface data communication to allow remote monitoring of wells and reservoirs in real time. Pressure, temperature, and flow rate data are transmitted to remote location via satellite, Internet, or cable.

WellWatcher Flux System

The system obtains reservoir data across the sandface of subsea wells in real time to monitor and characterize flow profiles. Electromagnetic induction enables wireless communication and power transmissions between the upper and lower completions.

WellWatcher DTS Fiber Optics

The system captures and transmits distributed temperature profiles with fiber optics reliably, accurately, and in real time to identify the time, location, and reason for changes in flow. Data are transmitted to the surface and then to remote locations via satellite, Internet or cable.

Pressure and Temperature Gauges

These gauges obtain highly accurate, stable measurements with gauges ranging from simple systems to downhole networks.

WellNet Downhole Network and Communication Systems

This telemetry system provides bidirectional, high-rate data communication and transfers electrical power to downhole tools.

Conveyance Components

Connectors and cables are rigorously tested and qualified to meet the highest standards for reliability.

Zonal Isolation

QUANTUM Multiport Packer

The QUANTUM multiPort (QMP) packer is a hydraulically set retrievable packer particularly suited for bypass applications. It is used as the upper packer in stacked configurations in completions with surface-controlled subsurface flow-control valves and tubingmounted reservoir monitoring equipment.

This packer is designed to allow onsite feed-through and connection of electric and hydraulic conduits. Testing of control-line fittings on the packer is accomplished after feed-through. This feature greatly simplifies rig operations and reduces control line terminations. The packer features a one-piece mandrel design with an eccentric flow bore. Bypass lines are fixed relative to the mandrel, eliminating relative movement during releasing. This design facilitates release regardless of the prevailing tubing load condition, i.e., tension or compression at the packer. The QMP packer allows simultaneous setting of multiple packers and is capable of simultaneous testing of bypass seals on the rig floor.

The hydraulically set QMP packer features twin setting pistons that fully energize the sealing elements prior to anchoring the slips.

Retrieval of the QMP packer is accomplished by means of a through-tubing intervention tool and subsequent upward pull on the tubing.

QMP packers are available for a variety of service applications, including H₂S and CO₂ environments.

The QMP packer is designed and tested in accordance with ISO 14310 grade V3.

Benefits

• Simplified operations reduce rig costs.
• Enhanced capabilities allow onsite product customization.
• Reduced rig time achieved by simultaneous setting of multiple packers.

Project Management

Intelligent completions present a wide range of complex technical challenges, especially in deepwater. The Schlumberger Project Management group works closely with operators to plan and design projects; manufacture, test, and install equipment; ensure equipment reliability; and troubleshoot complications. Close collaboration with the operator is considered critical to the success of each project.

Casing

Casing

The delivery system consists of two sizes of casing which were developed to fit two ranges of borehole sizes.

MP38 System has an inside diameter of roughly 38mm (1.5in) and is generally used in boreholes or casing whose inside diameter ranges from 76mm (3in) to 115mm (4.5in).
MP55 System has an inside diameter (ID) of 55mm (2.25in) and is generally used in boreholes or casing whose ID ranges from 98mm (3.9in) to 170mm (6.25in).

Both systems are designed for operation at maximum depths that range from 300m (1,000ft) to over 1,500m (5,000ft).

Both systems are available in plastic and in stainless steel. Steel systems are used in situations where tensile strengths, hydraulic pressures or temperatures are higher than would be suitable for the plastic systems

Regular Couplings

Couplings joining the casing together consist of regular couplings and port couplings. Regular couplings simply join two pieces of casing together, while port couplings provide a controllable pathway for formation fluids on the outside of the coupling to reach the inside of the coupling.

Measurement Ports

The measurement port is the heart of the MP System. Measurement ports are used for the majority of the pressure measurement and fluid sampling operations. Each measurement port coupling has a small check valve that contains a spring that keeps the valve closed so that it will not open due to the application of an exterior fluid pressure. The measurement port is operated by means of a MOSDAX* probe that is lowered into the borehole, locates the measurement port and opens the port valve.

Pumping Ports

In contrast to the measurement port, a pumping port coupling has several relatively large openings. The total area of these openings is approximately equal to the cross-sectional area of the inside of the casing. A sliding sleeve valve controls the pumping port openings. Either mechanical or hydraulic operating tools operate pumping port valves.

Packers

Different levels (monitoring zones) in a borehole are separated by placing impervious layers of backfill around the outside of the casing between monitoring zones or by using water inflated packers.

Westbay has developed a series of modular hydraulically inflated packers that are mounted on plastic or stainless steel mandrels. Each packer has an individual inflation valve attached to the packer. After the packers have been positioned in the borehole, a packer inflation tool is lowered into the borehole and packers are inflated individually.

Magnetic Collars

Magnetic collars can be attached to the outside of the casing near components that will be visited frequently. The collars contain ceramic magnets. When a probe passes by a magnetic collar, a reed switch in the probe is triggered and a "beeping" noise is heard at the surface. This assists the probe operator in determining the location of the probe in the borehole.

Specialized Components

A number of special components are available. These include:

• Y-connectors that permit twin–tubes to be installed in the upper part of the drillhole. This arrangement permits pumping to occur in one tube while sampling and pressure monitoring occur in the other.
• Telescopic casings that can extend or be compressed after installation. These protect the casing components should there be a tendency for the borehole to lengthen or shorten in the future.
• A borehole completion kit that permits de-stressing of the plastic casing during installations in deep boreholes.
  

Tools for Casing Installation and Recovery

Packer Inflation Tools: Each casing system (MP38 and MP55) has a specific tool to inflate packers. These tools have associated winches, hoses and control units for handling the packer inflation activities.

Pumping Port Operating Tools: The operation of pumping ports requires tools that will open and close the pumping port valve. A separate mechanical "open/close" tool is available for the plastic MP38 System. Hydraulic pumping ports for the steel MP38 System and the MP55 System are operated by a modified MOSDAX sampling probe or by a special tool.

Casing Recovery Tools: Casing recovery tools are available for those projects where it is necessary to demonstrate recovery capability before installation proceeds