Microseismic Hydraulic Fracture Monitoring

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.

StimMAP LIVE Microseismic Fracture Monitoring Service

StimMAP LIVE microseismic fracture monitoring in real time provides fracture monitoring within 30 seconds of microseismic activity. Based on proprietary coalescence microseismic mapping (CMM) that allows processing more events per minute than would be possible with hand picking, there is close agreement for the fracture geometry on the same dataset. The CMM technique provides more events because multiple arrivals can be handled in a single time window.

Accurate fracture characterization

Understanding fracture geometry is key to effective stimulation treatments and well economics. Microseismic fracture monitoring provides imaging of the geometry of a hydraulic fracture to accurately measure fracture geometry. Accurately measuring the fracture geometry offers precise data on hydraulic fracture systems to increase understanding of the fracturing process. This increased understanding in real time

  • reduces well stimulation costs
  • optimizes field drilling plans
  • allows changes in perforation strategies and plan diversion schemes to be made on the fly.

Treatment Execution

Treatment Execution

Schlumberger develops innovative methods and provides the right equipment to perform stimulation treatments in any environment.
Candidate Recognition

Analyzing client data is critical in determining the economic viability of oil and gas reservoirs.
Monitoring Stimulation Treatments

Accurate characterization of the locations, geometry, and dimensions of a hydraulic fracture system makes optimization of reservoir performance possible.
Fracturing Computer-Aided Treatment | InterACT for Stimulation Operations
Offshore vessels

BIGORANGE XVIII Stimulation Vessel | DeepSTIM Stimulation Vessel | DeepSTIM Pronto Offshore Stimulation Equipment | FlexSTIM Offshore Stimulation System
Well Optimization Service

Customize stimulation treatment design and execution to specific reservoir conditions.

Candidate Recognition

Better Wells

Candidate recognition is a key element in improving the economics for producing oil and gas. The process begins with Schlumberger engineers gathering and organizing well data. Then a NODAL systems analysis is performed to determine if the well is producing at or near maximum potential. Specific factors restricting production and their location are determined and wells with the potential for enhanced production from a stimulation treatment are identified.

After the assessment, the overall field is mapped to show the geographic relationship of the wells, their production potentials, and other selected parameters. After identification of the candidates, the Schlumberger engineer develops detailed stimulation treatments.

The DESC Design and Evaluation Services for Clients, where a Schlumberger engineer and the complete range of software and hardware are placed in the client's office, helps in the candidate recognition process.

Monitoring Stimulation Treatments

Accurate characterization of the locations, geometry, and dimensions of a hydraulic fracture system makes optimization of reservoir performance possible.

FracCAT Fracturing Computer-Aided Treatment

Monitor, Record & Control Stimulation Treatments in Real Time

The FracCAT fracturing computer-aided treatment system comprises hardware and software for monitoring, controlling, recording and reporting all types of fracturing treatments. Its real-time displays, plots, surface schematics and wellbore animations present a clear picture of the treatment as it occurs, providing decision-makers with real-time detailed job information from the surface to the perforations.

Technology and software

Using FracCAT technology, treatment design is followed and execution is precise. Integration with the Schlumberger FracCADE design and evaluation software allows job designs to be loaded directly into the FracCAT software.

During the job, the FracCAT system tracks the design and displays actual job parameters compared to planned values. FracCAT software also uses the design to control proppant and additive concentrations in as many as three blenders at the same time. This control capability ensures that actual concentrations follow the plan. Job data are sent to the FracCADE software in real time. If the FracCADE analysis indicates a need for design changes, the changes can be imported directly into the FracCAT software without interrupting the treatment. The FracCAT system works in conjunction with a local area network (LAN) environment, which enables networking of all PCs at the wellsite and also provides a connection to the Internet through satellite or cellular telephone technology. The Internet connectivity provides the ability to transmit real-time data from the remote wellsite to anywhere in the world for real-time analysis.

FracCAT controls make deviations from the schedule, such as extending a proppant stage or starting flush early, as simple as a single mouse-click.

Hardware

FracCAT hardware includes the latest high-performance PC systems. Innovations such as space-saving flat-panel displays and multiple monitors provide best-in-class presentation of data. All these features inside an ergonomically designed control cabin offer the ultimate job control environment and make the FracCAT system the premier tool for fracturing treatments.

Offshore vessels

We bring stimulation services to the world's high seas. BIGORANGE XVIII is purpose-built for environmentally safe North Sea operations. Rapidly deployed DeepSTIM vessels in the Gulf of Mexico are reliable in severe weather, remaining offshore for long periods. Galaxie is an advanced, versatile well stimulation vessel.
BIGORANGE XVIII Stimulation Vessel

Purpose-built stimulation vessel designed for North Sea operations.
DeepSTIM Stimulation Vessel

Advanced, versatile stimulation fleet equipped with dynamic positioning systems.
DeepSTIM Pronto Offshore Stimulation Equipment

Modular, portable, flexible system designed for offshore supply vessels.
FlexSTIM Offshore Stimulation System

Flexible, high-capacity, rapid stimulation system.

PowerSTIM Well Optimization Service

Maximize Production with Enhanced Reservoir Characterization

PowerSTIM well optimization service gives you fit-for-purpose, solution-oriented technology that is effective in a broad range of reservoirs. We customize stimulation treatment design and execution to the specific conditions in your well or field, based on detailed, accurate formation evaluation and modeling.

Based on our analysis, treatment options, such as acid treatments, fracture treatments, or sand management, are considered. The knowledge gained from each stimulation treatment is used to improve the next job in a continuous, closed-loop process that reduces costs, maximizes production, and increases recovery.

A multidisciplinary team

The first step in the PowerSTIM process is forming the team of geoscientists, reservoir and production engineers, and stimulation designers. Initially, the team concentrates on a small group of wells, typically three to five, depending on field and reservoir complexity.

After collecting and analyzing all available data, the team builds a customized model that describes geology and reservoir dynamics. This model, which accurately predicts key parameters and forecasts production, is used to design optimized treatments for the first group of wells.

After these treatments are executed according to the design, the team evaluates the results and uses them to update the model, important information to optimize the next group of completions. The updated model often is available to decision makers within a few hours after the evaluation is finished.

A better approach

The PowerSTIM informed decision report or IDR an "in-time" report, documents the solutions with a complete, historical record for each well treated. InterACT real-time monitoring and data delivery improves collaboration, allowing you to keep an eye on the treatments as they occur.

Unconventional Gas Stimulation

Unconventional Gas Stimulation

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

Directly measure hydraulic fracture geometry.
Shale Gas Dynamic Fluid Diversion Service

Combine fluid-based, tool-free fracture diversion technology with real-time microseismic monitoring.
Staged Fracturing and Completion Services

Maximize reservoir contact with the most efficient and effective services for each well.

Conventional Sandstone Stimulation con't

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
Polymer-Free Fracturing Fluids

The Schlumberger ClearFRAC family of polymer-free fracturing fluids enables a larger effective fracture half-length. The ClearFRAC fluid system also reduces friction pressure, allowing operators to save costs with reduced pumping equipment. Viscosity remains constant at a given temperature until contacted by formation fluids or added chemical breakers.

Applications include

* nitrogen and carbon dioxide (CO2) foam fracturing
* stimulation in hard-to-reach zones
* offshore operations.

The three ClearFRAC formulations each have specific applications.
CO2 Polymer-Free Fracturing Fluid

Significantly reduce operations costs with nitrogen foam fracturing treatments.
Polymer-Free Fracturing Fluid

Maximize conductivity with polymer-free fracturing.
High-Permeability, Polymer-Free Fracturing Fluid

Enhance fracture efficiency using the innovative viscoelastic surfactant (VES) system for low friction pressure and excellent proppant-carrying capacity.
Gelled-Oil Fracturing Fluid

YF GO III continuous-mix, gelled oil service

YF GO III is a patented gelled, oil-base sandstone fluid designed primarily for treating water-sensitive formations. Originally designed for continuous-mix operations, it is used successfully in both continuous and batch-mix conditions. YF GO III can gel diesel, condensates, and a wide variety of crudes as the oil base.
YF GO IV high-temperature, gelled-oil service

YF GO IV gelled-oil sandstone fluids are designed for broad use in sandstone applications where gelled oil is commonly used (i.e., water-sensitive formations). Originally designed for use only with clean, dry diesel, YF GO IV can be used with many dry, uncontaminated crude oils. The advantages of using YF GO IV include high-temperature stability, low static viscosity, and predictable rheological profiles.
HiWAY Channel Fracturing

How it works

To allow more fracture conductivity in conventional fracturing jobs, HiWAY channel fracturing fundamentally changes the way that proppant fractures generate conductivity. It engineers stable flow channels into the proppant pack that are connected from the tip of the fracture back toward the wellbore, creating the optimal connection between the reservoir and the wellbore. The productivity of the fracture is decoupled from the actual permeability of the proppant used, so rather than flowing through the proppant in the pack, hydrocarbons flow through stable channels—meaning infinite fracture conductivity.

Traditional losses in proppant pack conductivity from crushing, fines, fluid damage, multiphase flow, and non-Darcy effects are eliminated, ensuring more fluid and polymer recovery, meaning optimized production.
What it combines

A unique combination of placement and materials engineering, completions techniques, and process control equipment enables the success of HiWAY channel fracturing. The stability of the flow channels is ensured by using a proprietary fiber, which maintains the structures from surface to reservoir until the fracture has closed and the in situ stress of the rock takes over.
Where it’s used

HiWAY channel fracturing provides more fracture conductivity and optimized production for conventional consolidated rock fracturing treatments of oil and gas wells. For example, it has been successfully applied in the Rocky Mountain region of the US and the Sierras Blancas formation in Argentina for major improvements in time to sales, fluid recovery, initial production rate, and average-well estimated ultimate recovery (EUR).
Organic Clay Acid Stimulation Fluid
High-Performance Formation Cleanup Treatment

Wells in the sandstone formations common to the U.S. Gulf Coast generally have migrating fines that can plug the near-wellbore area and severely limit production. Although conventional stimulation fluids,such as hydrochloric (HCl) or mud acid, can clean up the wellbore and stimulate the sandstone, they do not penetrate deep into the formation nor stabilize fines. Conventional acids can also have adverse effects in formations with certain types of clays, like zeolite and chlorite, that are unstable in HCl acid.

OCA organic clay acid stimulation fluid penetrates deep into the sensitive formation and stabilizes clays and fines without the adverse effects of conventional acid systems.
Innovative acid system

OCA fluid is a high-performance acid system designed for sensitive sandstone sandstone formations that can present the biggest challenge to conventional acidizing treatments. Because of the damaging precipitation of secondary and tertiary reaction products, conventional mud acid has the highest chance of failure in formations with very high temperature or a high clay content that is sensitive to HCl.

OCA fluid combines a retardation effect and advanced chelation technology for stimulation deep into the reservoir with minimal precipitation. It reduces the risk of diminished production as well as secondary and tertiary mineral precipitation that can block pores. Its retarded properties allow a reduced corrosivity. OCA fluid also combats sludging problems that plague conventional acid systems and stabilizes formation fines while maintaining the integrity of the sandstone structures to promote long-term production.
Laboratory testing

Sequential spending tests that simulate deep formation penetration have demonstrated that the reaction between sandstone minerals and conventional acid systems can cause silica gel precipitation.

With conventional acids, silicon can deplete in a spent acid solution as it penetrates deep into the formation. In laboratory tests, the ratio of silicon to aluminum decreases as the acid penetrates deeper into the formation. This decrease indicates the precipitation of formation-damaging hydrated silica gel.

As OCA fluid penetrates deep into the formation, tests show increasingly higher silicon and aluminum concentrations. OCA fluid keeps all the dissolved ions in solution. The OCA fluid continues to dissolve without forming damaging secondary and tertiary hydrated silica precipitation.

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.

Monitoring Stimulation Treatments

Accurate characterization of the locations, geometry, and dimensions of a hydraulic fracture system makes optimization of reservoir performance possible.

FracCAT Fracturing Computer-Aided Treatment

Monitor, Record & Control Stimulation Treatments in Real Time

The FracCAT fracturing computer-aided treatment system comprises hardware and software for monitoring, controlling, recording and reporting all types of fracturing treatments. Its real-time displays, plots, surface schematics and wellbore animations present a clear picture of the treatment as it occurs, providing decision-makers with real-time detailed job information from the surface to the perforations.

Technology and software

Using FracCAT technology, treatment design is followed and execution is precise. Integration with the Schlumberger FracCADE design and evaluation software allows job designs to be loaded directly into the FracCAT software.

During the job, the FracCAT system tracks the design and displays actual job parameters compared to planned values. FracCAT software also uses the design to control proppant and additive concentrations in as many as three blenders at the same time. This control capability ensures that actual concentrations follow the plan. Job data are sent to the FracCADE software in real time. If the FracCADE analysis indicates a need for design changes, the changes can be imported directly into the FracCAT software without interrupting the treatment. The FracCAT system works in conjunction with a local area network (LAN) environment, which enables networking of all PCs at the wellsite and also provides a connection to the Internet through satellite or cellular telephone technology. The Internet connectivity provides the ability to transmit real-time data from the remote wellsite to anywhere in the world for real-time analysis.

FracCAT controls make deviations from the schedule, such as extending a proppant stage or starting flush early, as simple as a single mouse-click.

Hardware

FracCAT hardware includes the latest high-performance PC systems. Innovations such as space-saving flat-panel displays and multiple monitors provide best-in-class presentation of data. All these features inside an ergonomically designed control cabin offer the ultimate job control environment and make the FracCAT system the premier tool for fracturing treatments.

Offshore vessels

We bring stimulation services to the world's high seas. BIGORANGE XVIII is purpose-built for environmentally safe North Sea operations. Rapidly deployed DeepSTIM vessels in the Gulf of Mexico are reliable in severe weather, remaining offshore for long periods. Galaxie is an advanced, versatile well stimulation vessel.
BIGORANGE XVIII Stimulation Vessel

Purpose-built stimulation vessel designed for North Sea operations.
DeepSTIM Stimulation Vessel

Advanced, versatile stimulation fleet equipped with dynamic positioning systems.
DeepSTIM Pronto Offshore Stimulation Equipment

Modular, portable, flexible system designed for offshore supply vessels.
FlexSTIM Offshore Stimulation System

Flexible, high-capacity, rapid stimulation system.

Conventional Sandstone Stimulation

Conventional Sandstone Stimulation

Matrix stimulation and hydraulic fracturing techniques are designed to repair and improve the natural connection of the wellbore with the reservoir.
Scale Control

Remove and prevent scale within wellbores and the reservoir.
Jet Blaster Scale Removal | ScaleFRAC Scale Inhibitor | ScaleMAT Acid-Compatible Scale Inhibitor | ScalePROP Scale Inhibitor Proppant | ScaleSOLV Carbonate Scale Dissolver
Polymer-Free Fracturing Fluids

Achieve a larger effective fracture half-length with ClearFRAC polymer-free fluids.
CO2 Polymer-Free Fracturing Fluid | Polymer-Free Fracturing Fluid | High-Permeability, Polymer-Free Fracturing Fluid
Gelled-Oil Fracturing Fluid

Use water-free, oil-base fluid for fracturing treatments in water-sensitive formations.
HiWAY Channel Fracturing

Experience more fracture conductivity by removing the link between fracture flow and proppant conductivity.
Organic Clay Acid Stimulation Fluid

Penetrate deep into sensitive sandstone matrix formations.
Matrix Acidizing Diverter

Direct treating fluids away from high-water-cut intervals.
High-Water-Cut Acidizing Diverter

Reduce water cut and increase production with an advanced acid diverter.
Simplified Sandstone Acidizing System

Stimulate sandstone reservoirs with a single fluid-stage formulation.
Proppant Flowback Control

Prevent flowback from hydraulic fractures.

Proppant Distribution

Create a fiber-based network within the fracturing fluid.
Microseismic Hydraulic Fracture Monitoring

Measure hydraulic fracture geometry in real time.
Staged Fracturing and Completion Services

Maximize reservoir contact by offering the most efficient and effective services for each well.

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

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
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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.

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Measure hydraulic fracture geometry in real time.
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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.