Investor Highlights Archive

Expansion in Saudi Arabia

In Saudi Arabia, Schlumberger announced plans to develop a state-of-the-art industrial manufacturing center at the King Salman Energy Park. The 500,000-m2 center will manufacture products for drilling, exploration, production, and midstream operations. The first phase is expected to be completed in the second quarter of 2018.

Also in Saudi Arabia, Saudi Aramco awarded Schlumberger two IDS contracts to provide drilling rigs and services for up to 146 gas wells and up to 128 oil wells over three years. IDS will use enhanced processes and the latest technology to:

  • increase efficiency levels
  • improve cost effectiveness
  • maintain the highest operational safety standards

To read more, please visit the Saudi Aramco site here.

Strategic Partnership

In September 2017, it was announced that BP will be a strategic partner on DrillPlan* digital well construction planning solution and on a future execution solution focused on the drilling of a well. The DrillPlan solution:

  • is the first step in the DELFI* cognitive E&P environment
  • has the potential to deliver a well planning program in days rather than weeks
  • is part of a fully integrated well construction offering

BP will pilot these solutions during its development of the Khazzan field in Oman.

Mitigating the Need for Pilot Holes

GeoSphere* reservoir mapping-while-drilling service enables customers to precisely land wells in the target zone, which decreases the technical risks for completions operations. Examples of how the GeoSphere service helps reduce operating costs include:

  • Offshore Russia, LUKOIL-Nizhnevolzhskneft saved $4.6 million dollars in operating costs by eliminating the need for three pilot wells in the Filanovsky field
  • In the UK sector of the North Sea, Centrica Energy eliminated the need for a pilot hole and complex sidetracking operations in the Chestnut field

In Russia, well construction was performed 19 days faster than planned. In the North Sea, GeoSphere maximized reservoir exposure of the horizontal well in a complex injectite reservoir.

Shale Plays Increase Production

In North America land, Encana refractured wells in two shale plays using the BroadBand Sequence* fracturing service.

  • In the Eagle Ford Shale, the Broadband Sequence service increased oil production in one well from approximately 50 bbl/d to 650 bbl/d and increased flowing pressure from 250 psi to 5,000 psi.
  • In the Haynesville Shale, the BroadBand Sequence service helped increase gas production in one well from 100 Mscf/d to 5,000 Mscf/d, with flowing pressure increasing from 1,500 psi to 6,000 psi.

Selection of the wells for refracturing was based on quality of the reservoir, completion and production history, and location relative to offset wells.

Capital-Efficient Solutions Reduce Average Lead Times and Project Cost

Introduced in 2014, Capital-Efficient Solutions extend to OneSubsea’s market-leading subsea boosting technology and are now an integral part of all customer projects. Capital-Efficient Solutions:

  • reduce the average lead times of subsea products by more than 50%, saving up to 60% in project costs
  • deliver integrated subsea production systems that reduce project cycle time and overall cost.

Adopting prequalified quality plans, suppliers, and materials and welding specifications has enhanced the efficiency and reliability of the product-manufacturing life cycle.

Cognitive E&P Environment Reduces the Cost Per Barrel

DELFI* cognitive E&P environment enables secure collaboration across E&P teams by leveraging digital technologies such as:

  • analytics and machine learning
  • high-performance computing
  • the Internet of Things

These technologies and others work together to improve operational efficiency and deliver optimized production at the lowest cost per barrel. With the launch of the DELFI environment, an E&P Data Lake comprising more than 1,000 3D seismic surveys, 5 million wells, 1 million well logs, and 400 million production records from around the world has been deployed on the Google Cloud Platform.

Digital Well Construction Planning Solution

Schlumberger introduced the DrillPlan* digital well construction planning solution, the first step in the DELFI* cognitive E&P environment.

The DrillPlan solution is part of a fully integrated well construction offering that:

  • enhances user collaboration
  • provides a new way of working

Operators and service companies have access to all the data and science needed in a single, common system, which creates a circular workflow where plans are improved as new data are added.

Drilling the Longest “Super Lateral”

In North America land, Schlumberger used a combination of technologies for Eclipse Resources to drill the longest onshore horizontal lateral. The 19,630-ft “super lateral” in the Utica Shale play:

  • was drilled in a single run of 121 hours
  • achieved a total rate of penetration of 162 ft/h
  • surpassed the previous record, also held by Eclipse, by 158 ft
  • was drilled 37% faster than the first record-length well

The super lateral helped the customer reduce overall AFE cost by decreasing the number of horizontal penetrations required to develop the reservoir. The technologies included:

Increasing ROP by 57%

In North America land, Bits & Drilling Tools increased the rate of penetration (ROP) by 57% for Cimarex in the STACK Meramec play. A combination of:

drilled the fastest mile-long lateral wellbore in the formation.

EPC Contract in India

In India, Reliance Industries Limited awarded OneSubsea an engineering, procurement, and construction (EPC) contract for the supply of a subsea production systems (SPS) package for the offshore R Cluster Project in the Bay of Bengal. The contract includes:

The contract also includes installation and commissioning support and life-of-field services. The contract was formalized in July with expected hardware deliveries to begin in mid-2018.

Integrated Completions Operation Enables Production Increase

In Oman, Schlumberger deployed a combination of technologies for Petroleum Development Oman (PDO) to increase production by an average of 200 m3/d of oil per well and save a total of $700,000 in associated well costs for seven wells in the Sadad North field. The technologies included:

  • QUANTUM RH* retrievable hydraulic-set sealbore production packer
  • SXAR automatic gun release systems

These combined technologies created an integrated “shoot and drop” completions operation that could be deployed in a single trip.

Optimized Workover Program Decreases Water Cut, Increases Production

Offshore India, Schlumberger used a combination of technologies in a well for Oil and Natural Gas Corporation Limited (ONGC) to increase production to 6,100 bbl/d from the original 892 bbl/d and decreased the water cut to 2% from the original 7.7%. These technologies included:

These technologies helped to design the optimal workover program.

Combined Drilling Technologies Saves 7 Days Drilling Time

In the US Gulf of Mexico, Schlumberger used a combination of technologies for Shell to drill more than 5,353 ft in a 24-hour period and save seven days of drilling time in the 16½-in section in the Green Canyon Block. The technologies included:

The Green Canyon Block is a challenging salt formation because drilling through salt creates very high torque levels and fluctuations that can lead to low rates of penetration or tool failures.

Drilling Intelligence Service Reduces Bit Runs

In the UK sector of the North Sea, Schlumberger saved a major operator approximately 10 days of drilling time in a well, equivalent to more than $2.4 million. The technologies included:

The combined technologies reduced the number of bit runs from five to one in challenging well conditions.

Ridged Diamond Bit Technology Saves Operating Time

In North America land, Schlumberger saved a customer 52 hours of operating time between four wells in the Bakken Shale play by using AxeBlade* ridged diamond element bit technology. AxeBlade bit technology:

  • includes a 3D cutting element
  • features a unique ridge-shaped geometry
  • combines the shearing action of a conventional PDC cutter with the crushing action of a tungsten carbide insert

The formation is characterized by heavily interbedded sandstone, shale, and limestone intervals with varying compressive strengths that can limit drilling performance. In addition, AxeBlade bit technology exceeded the customer’s 24-hour footage record twice over the same interval.

Automated Tank-Cleaning Decreases Water Usage

In Norway, Schlumberger helped Statoil decrease water usage by 80% per month on supply vessels by using ATC* automated tank-cleaning technology. The customer has saved approximately $500,000 per month since adopting this technology in April 2016. ATC tank-cleaning technology:

  • reduces health, safety, and environmental risks
  • achieves a higher level of cleaning compared with a manual process

Average monthly performance—based on 25 boats and 150 tanks—reduced confined-space entry by more than 500 hours per month and reduced working at height by 225 hours per month.

Fracturing Service Reduces Overall Well Costs

In China, Schlumberger increased gas production by 50% and reduced overall well costs by $95,000 for PetroChina Company Limited in two horizontal wells in the Ordos basin. The use of Salik* local-sand-enabled flow-channel fracturing service:

  • enabled replacement of more than half of the ceramic proppant normally required
  • helped create high conductivity fractures in the horizontal lateral

The Ordos basin a tight gas unconventional play with heterogeneous sands that present technical challenges.

Transformation Program Saves $10 Million in Operating Costs

In North America, the Schlumberger transformation program has saved $10 million in operation costs over the last 18 months by improving equipment reliability and reducing maintenance costs.

The Center for Reliability and Efficiency in Denton, Texas, which supports the field by monitoring equipment fleets, has developed and implemented prognostic health monitoring capabilities to predict equipment reliability concerns.

Industry’s First OEM Deepwater MPD System

Cameron Drilling Systems and M-I SWACO collaborated on product development to deliver the industry’s first original equipment manufacturer deepwater managed pressure drilling (MPD) system. The integrated solution is comprised of

  • a riser joint
  • surface manifolds
  • a single control system and umbilical
  • and other equipment

To date, Schlumberger has received orders for four of the systems—the first was delivered in May 2017 and the other three will be delivered later this year. This deepwater MPD system received a 2017 Offshore Technology Conference Spotlight on New Technology Award.

Integrated Services Management Optimizes Drilling Time

In the Bulgarian sector of the Black Sea, Schlumberger Integrated Services Management (ISM) enabled Total E&P Bulgaria to drill its first deepwater exploration well. This project included:

  • ISM management of eight product lines
  • ISM management of more than 100 personnel
  • Close collaboration between ISM and the Total E&P Bulgaria team

The ISM team identified drilling optimization opportunities that yielded significant results during on-bottom drilling operations. (Image: Courtesy Noble Corporation)

Integrated Drilling Services Decreases Operation Time

In Russia, Integrated Drilling Services (IDS) decreased operation time by 103 days in three extended reach wells for Rosneft-Sakhalinmorneftegaz on Sakhalin Island. The technologies used included:

  • GeoSphere* reservoir mapping-while-drilling service to reveal subsurface-bedding and fluid contact details more than 100 ft from the wellbore
  • PowerDrive Xceed* ruggedized rotary steerable systems to optimize directional drilling

In addition, cumulative production for these three wells in 2016 was 47% higher than initially expected.

Reducing Drilling Time

In West Texas, Schlumberger enabled Parsley Energy to reduce the average days required to drill a well by 17% in the Midland and Delaware basins. The drilling technologies used included:

The reduced drilling time is based on drilling 80 wells during the past 12 months and is compared with the previous year. In addition, the customer reduced the average total drilling cost per lateral foot by 30%. (Image: Courtesy University of Texas Libraries)

Integrated Production Services

In South Texas, Integrated Production Services (IPS) enabled Lonestar Resources to produce up to 86% more hydrocarbon per 1,000 ft of lateral in 18 wells in the Eagle Ford Shale. This included use of the following technologies:

The results, which are compared with offset wells in two other fields, stem from IPS optimizing drilling, stimulation, and completion plans across long laterals.

Increasing Oil Production

In Iraq, Schlumberger increased oil production by 3,000 bbl/d for BP Iraq N.V. in a carbonate reservoir in the Rumaila field. This was the result of increasing water injectivity to 4,600 bbl/d by using:

  • CoilFLATE* coiled tubing through-tubing inflatable packer
  • ACTive PTC* CT real-time pressure, temperature, and casing collar locator tool

These technologies selectively stimulated zones with low permeability.

Capital-Efficient Solutions from OneSubsea

In North America, BP awarded OneSubsea an engineering, production, and construction (EPC) contract to supply the subsea production system for the Mad Dog 2 development in the Gulf of Mexico. OneSubsea capital-efficient solutions includes:

In addition, Subsea 7, which collaborates with OneSubsea through the Subsea Integration Alliance, was awarded an engineering, procurement, construction, and installation (EPCI) contract for subsea controls, flexible risers, pipeline systems, umbilicals and associated subsea architecture.

Integrated Services Management Reduces Costs

In Ecuador, Schlumberger provided Integrated Services Management (ISM) to reduce total drilling time by 2 1/2 days, saving the customer $250,000 on the Tiputini project. The combined technologies and services included:

  • ONYX* polycrystalline diamond compact (PDC) cutter
  • Stinger* conical diamond element
  • Wireline Dielectric Scanner* multifrequency dielectric dispersion service
  • MDT* modular formation dynamics tester tool
  • PowerJet Nova* extradeep penetrating shaped charges

ONYX and Stinger technologies enabled better steerability and stability as well longer and faster runs. Operations were completed in 7 1/2 days instead of the expected 11 days.

Improving Tool Reliability

In the Middle East and Asia Area, the transformation program enabled reductions in equipment numbers and tool reliability repair costs for Schlumberger by using Technology Lifecycle Management (TLM). The use of TLM:

  • Decreased the overall cost of equipment repair by 48% and improved turnaround time by 21% in the first three months of operations at the Middle East Center for Reliability and Efficiency in Dhahran, Saudi Arabia, and
  • Improved source reliability for all WesternGeco sources by 47% from 2014 to 2016 in Australia

WesternGeco deployed its newly developed eSource marine seismic energy source on the Amazon Conqueror for a multiclient survey, which uses an acquisition technique that depends on high source reliability to ensure maximum operational efficiency.

Integrated Drilling Services Improves Performance

In the Gulf Cooperation Council (GCC) region, Integrated Drilling Services (IDS) delivered a 40% drilling performance improvement in the first three quarters of 2016 compared with non-integrated drilling services in similar fields. The improvement is based on the feet drilled per hour below the rotary table. This achievement was enabled by a combination of drilling technologies:

  • PowerDrive Archer* high build rate
  • PowerDrive Xceed* ruggedized rotary steerable systems
  • RigHour* multiwell drilling operational efficiency analysis
  • ROPO* rate of penetration optimization software

Schlumberger combined these technologies with integrated workflows overseen by multidisciplinary domain experts in the Saudi Arabia and Abu Dhabi Drilling Technology Integration Centers to reduce both drilling and overall development costs.

Meeting Customer Goals

In the Norwegian sector of the North Sea, Schlumberger deployed the GeoSphere* reservoir mapping-while-drilling service to increase the productivity of wells in the Balder field. The customer had two goals:

  • Avoid costly pilot holes in development wells that often failed to provide sufficient information to help land the producer wells, and
  • Avoid setting the casing in 1-in thin injectite sands

GeoSphere technology mapped the top of massive sands from more than 20 m total vertical depth above and detected the oil/water contact while landing the 12 ¼-in section before penetrating the reservoir. For the 8 ½-in reservoir section, the customer was able to plan a geosteering strategy ahead of the bit by combining seismic interpretation and GeoSphere mapping results.

Avoiding Costly Pilot Holes

In Egypt, Schlumberger used the GeoSphere* reservoir mapping-while-drilling service to eliminate a pilot hole in the Abu Rudeis field, which saved the customer $1.8 million. GeoSphere* reservoir mapping-while-drilling service:

  • Used deep directional electromagnetic measurements to reveal subsurface bedding and fluid contact details more than 100 ft from the wellbore, and
  • Helped manage the geological uncertainty and drilling risk

An unconformity at the top of the oil-bearing sandstone initially required a pilot hole to determine intermediate casing depth while pressurized shales above the target zone required a high mud weight that made penetration of the target sand challenging due to potential mud circulation losses.

Improving Service Delivery

The transformation program enabled an increase in reliability and efficiency as well as product and service delivery in Saudi Arabia. As a result,

  • The reliability of ImPulse* integrated MWD platform tools increased 240%
  • The reliability of adnVISION* azimuthal density neutron service tools increased by 47%

in the first six months of the CRE’s operation. Design, engineering, and maintenance teams at the Middle East CRE in Dhahran collaborated to create ruggedized modular housings for these measurement-while-drilling tools and decrease their susceptibility to movement and wear in a high-shock environment.

First Offshore Source Rock Hydraulic Fracturing

In the UAE, Schlumberger completed the first multistage, offshore source rock hydraulic fracturing treatments in the world. The eight jobs were completed in 40 hours with more than half a million pounds of proppant pumped. The technologies used included:

  • HiWAY* flow-channel fracturing technique
  • UltraMARINE* seawater-base fracturing fluid

stimulating low-permeability, high-stress source rock.

Reducing Rig Time

Offshore Indonesia, Schlumberger saved a customer approximately 6 1/2 days of rig time, equivalent to $5.1 million in cost savings. Using MZ-Xpress* systems to perform multizone fracturing and gravel packing over four zones of completion in a well:

  • Two systems were each installed in a single trip
  • The systems provided multizone sand control

The well had five producing layers across two different casing sizes.

Decreasing Maintenance Costs

In North Texas, the transformation enabled improvements in tool reliability and reduced maintenance costs. Six months after implementing prognostic health management (PHM) it achieved an estimated $6 million of savings in operation costs. This involved:

  • The Center for Reliability and Efficiency in Denton
  • Collecting real-time pump data from field locations

Prognostic health management is an engineering discipline focused on predicting the future condition of a component and/or system of components. It is based on the analysis of failure modes, detection of early signs of wear and aging in complex systems and components, and correlation of these signs with an aging profile (or model).

Exceeding Expectations

In the UK sector of the North Sea, Schlumberger used GeoSphere* reservoir mapping-while-drilling service to drill six wells in the Catcher field. As a result, none of the six wells required sidetracking and all six wells came in at or ahead of expectations.

GeoSphere technology:

  • Uses deep, directional electromagnetic measurements
  • Reveals subsurface bedding and fluid contact details more than 100 ft from the wellbore
  • Provides a reservoir-scale view at an unprecedented depth of investigation

Before development, it was predicted that one-in-three wells in the Catcher field would require a sidetrack due to difficult drilling conditions.

Cost Reduction

In Ohio, Schlumberger used a combination of technologies to drill a well in the Utica Shale field. Drilled in one bit run, the lateral extension helped the customer reduce costs by decreasing the number of horizontal penetrations required to develop the reservoir.

The technologies used included:

  • PowerDrive vorteX* powered rotary steerable system
  • TelePacer* modular MWD platform
  • Smith Bits polycrystalline diamond compact (PDC) bit

The well had a total measured depth of 27,048 ft and was drilled in less than 18 days with a completed lateral extension of approximately 18,500 ft.

A World's First

Offshore UAE, Schlumberger completed eight proppant fracturing jobs to stimulate low-permeability, high-stress source rock. The eight jobs represent the world’s first offshore multistage, source-rock, proppant fracturing treatments.

The technologies used included:

  • HiWAY* flow-channel fracturing technique
  • UltraMARINE* seawater-based fracturing fluid technology
  • Mangrove* engineered stimulation design in the Petrel platform

UltraMARINE was engineered to enhance thermal stability and has a bottomhole temperature range of 175 to 325 degF.

Increasing Operational Reliability

The Schlumberger transformation program increased reliability and service delivery in different operating environments via the continued implementation of standard work instructions (SWI).

For the first half of 2016:

  • Testing Services achieved a service delivery record of zero nonproductive time for the 80,000 operating hours in Russia and Central Asia
  • Completions reduced nonproductive time to zero in Western Canada

Testing Services focused on three distinct organizational areas (maintenance, resource planning, and service delivery) while Completions applied SWI to multistage stimulation and liner hanger operations.

Reducing Risk

Offshore Norway, Integrated Services Management (ISM) used a combination of Schlumberger technologies to drill an appraisal well in the Barents Sea. The customer benefitted from a 461 m section of the well that delivered high flow rates under minimal drawdown.

The technologies included:

  • GeoSphere* reservoir mapping-while-drilling service
  • Stinger* conical diamond element
  • PowerDrive Xceed* ruggedized rotary steerable system
  • Drilling Analyst* services
  • STARGLIDE* conical diamond element
  • ENVIROUNIT* offshore slop water treatment system
  • OrientXact* tubing-conveyed oriented perforating system

The Integrated Services Management approach focuses on “de-risking” the operation by managing the collaboration between service providers and operators in order to optimize success.

Coordinating Services

Offshore Canada, Schlumberger completed the first phase of an Integrated Services Management (ISM) contract in the deepwater environment of the Flemish Pass basin. The customer completed the project by the appointed target date despite weather-related challenges.

The phase included nine exploration and appraisal wells where over 19 months Schlumberger:

  • Drilled a total of 24,000 m.
  • Combined technologies to improve drilling efficiency, assure wellbore integrity, and optimize well placement.
  • Placed a well at a water depth of 2,829 m, which is the deepest for offshore Canada.

Integrated Services Management coordinated all the services and provided the customer a single point of contact for the duration of the project.

Optimizing Decision-Making

In the United Arab Emirates, Schlumberger conducted appraisal testing operations in an undeveloped field. Five downhole tests were performed to evaluate gas wells with a high H2S content. The combination of technology used eliminated the need for multiple runs while wireless transmission and monitoring of downhole pressure facilitated real-time transient analysis. This optimized decision-making and provided critical information to determine reservoir properties.

Technologies included:

  • Muzic* wireless telemetry
  • Quartet* downhole reservoir testing system
  • Signature* quartz gauges

The Quartet system combines four downhole tools combined into one string that provides single-trip efficiency.

Establishing a Performance Benchmark

Offshore Brazil, Schlumberger used Stinger* conical diamond element technology to drill the 12 ¼-in interval in a pre-salt well in the Lula field. The operations set a new performance benchmark for the customer in cost per meter for 12 ¼-in well sections in the Lula field by:

  • Achieving an average rate of penetration (ROP) of 4.37 m/h, saving 22 hours.
  • Drilling the 441-m section in a single run, saving 41 hours.

Stinger elements, which have twice the diamond thickness of conventional polycrystalline diamond compact cutters, have a sharper conical shape that exerts an ultrahigh concentrated force.

Exceeding Production Expectations

In Kuwait, when conventional stimulation systems did not induce production, Schlumberger used HiWAY* flow-channel fracturing technique with success. The customer achieved production flow rates that are three times higher than initial expectations.

HiWAY technology:

  • Increased conductivity.
  • Reduced water consumption.
  • Reduced proppant consumption.
  • Decreased the operational footprint.
  • Simplified logistics.

In addition, this technology fundamentally changes the way proppant fractures generate conductivity by creating open pathways where the hydrocarbons flow through stable channels rather than the proppant.

Improving the Recovery Factor

In the US Gulf of Mexico, OneSubsea successfully executed the commissioning and startup of subsea boosting systems installed in ultradeep waters. By reducing the back-pressure on the reservoir, the subsea boosting pump technology has the potential to improve the recovery factor by 10% to 30%, which translates to between 50 and 150 million barrels of additional oil recovery.

The subsea boosting system consists of:

  • Three pump modules
  • Three control modules
  • Subsea controls
  • Power distribution system
  • Pump control and instrumentation equipment
  • Step-up transformer that delivers power to the subsea equipment

Placed in water depth of about 7,000 ft, the modules are retrievable and landed in their substations.

Increasing Asset Reliability

In North America, the transformation enabled improvements in reliability and service delivery for Well Services operations that saved a combined total of $17 million. In particular, the use of reliability centered maintenance (RCM):

  • Saved approximately $9 million and reduced nonproductive time by 64% for blenders and hydraulic fracturing pumps over a nine-month period.
  • Saved nearly $8 million in materials and supplies over the same period.
  • Is expected to increase asset availability by 8% and accumulate a total savings of $30 million, over a three-year period, when combined with a new Pump Asset Care Program.

Reliability Centered Maintenance improves asset reliability and manages the consequences of failure by predicting catastrophic failures in advance.

Assessing Environmental Impact

The Marcellus Shale Energy and Environment Laboratory (MSEEL) Consortium monitors unconventional gas production in wells in the Marcellus shale play. As the sole technology and service provider, Schlumberger is working to gain a better understanding of the wells' long-term production performance, environmental and social impact, and to optimize protective management and well treatment strategies for future unconventional developments in the region. The combination of technologies includes:

  • Quanta Geo* photorealistic reservoir geology service
  • XL-Rock* large-volume rotary sidewall coring service to identify a preferred lateral landing target
  • PowerDrive Archer* high-build-rate rotary steerable system
  • SonicPacer* acoustic shale evaluation service
  • PayZone Steering* well placement service
  • Invizion* well integrity services
  • WellWatcher Contact* MSS proppant placement assurance system

The project wells have been completed and are now in production.

Refracturing for Production Increases

Technical experts at a Schlumberger Production Technology Integration Center helped a customer select and rank candidate wells in the Williston Basin. The following technologies were used to refracture multiple wells:

  • BroadBand Sequence* fracturing service
  • BroadBand* unconventional reservoir completion services

BroadBand* technology overcame the challenges posed by the exposed wellbore and the need for effective diversion by sequentially isolating fractures in the wellbore to ensure each cluster in every zone was fractured. Post-job fracture gradient analysis on the wells indicated that new rock was encountered, which resulted in a three-to-sixfold production increase among four refractured wells.

Pulling It All Together

The Schlumberger Integrated Services Management (ISM) multiyear contract for Shell on the Sail and Drill project concluded in February 2016 after drilling a total of five wells in three countries—Benin, Turkey and Gabon. The ISM model:

  • Aligns all project participants to the objectives
  • Promotes collaboration, innovation, and custom solutions
  • Provides immediate access to local knowledge and resources
  • Integrates technologies and solutions from all providers

A total of 16,120 m were drilled and the customer acknowledged the key role ISM played in the Sail and Drill project by providing unparalleled support during unplanned events

A Performance-Based Model

Offshore Brazil, Schlumberger drilled four challenging pre-salt wells and one sidetrack for a client during a 30-month campaign in the ultra-deepwater Campos basin. The performance-based model improved commercial alignment and included:

  • A combination of "while-drilling" technologies enhanced characterization of the complex reservoir.
  • Downhole drilling tool reliability.
  • The use of Standard Work Instructions.
  • Planning and coordination support from Integrated Services Management (ISM).

As a result, nonproductive time was less than 8 hours from a total operating time of 7,300 hours in which 75 bottomhole assembly runs drilled more than 15 km. In addition, the final well among four was completed 26 days ahead of schedule.

How to Avoid Workover Operations

Schlumberger used a combination of technologies offshore Mexico to achieve complete zonal isolation in two deepwater exploration wells. This included:

  • Invizion* well integrity services
  • SonicScope* multipole sonic-while-drilling service

These technologies provided a comprehensive analysis of the cementing jobs, and the high-quality zonal isolation enabled the customer to avoid costly workover operations that can add approximately $1.2 million per day in operating costs.

Integration in Action

Discovered in 2008 by Det norske, the Ivar Aasen field offshore Norway sits below 112 meters of water in the North Sea and contains approximately 210 million barrels of oil equivalent.

  • Schlumberger signed a five-year integrated services contract with Det norske in 2014.
  • We are optimizing resources between three locations: the offshore rig, the shore base in Trondheim, and a remote operations center in Stavanger.
  • Technology: StingBlade* conical diamond element bit; GeoSphere* reservoir mapping-while-drilling service.

This integrated services project resulted in the drilling and completion of five wells among the top 10 best performers in the last eight years on the Norwegian Continental Shelf. On one of the wells the total operational savings due to the integrated approach, which was backed by our transformation, halved the time needed to drill and complete the well compared with the planned budget.

An Agile Response

The procurement and timely delivery of high-quality proppant and fluids to the wellsite are critical to the success of hydraulic fracturing operations. Recognizing that the supply chain can be a differentiator in the dynamic North American hydraulic fracturing market, Schlumberger has more closely aligned the supply chain with business needs through Sales & Operations Planning (S&OP). This included activities such as:

  • Creating a consistent process for S&OP.
  • Introducing professionalized planning systems.
  • Improving the connectivity between supply chain and the business.
  • Centralizing the management of product allocation and delivery

A centralized logistics tower oversees the movement of product and equipment used in North American hydraulic fracturing operations. State-of-the-art IT, including mobile technology, enables efficient carrier procurement and invoicing and provides real-time visibility of our logistics network.

Microelectronics Take the Heat

Schlumberger has an extensive lineup of measurements-while-drilling (MWD) services, which were introduced in the 1980s as a means to optimize well trajectory in real time. TeleScope ICE* ultrahigh-temperature measurements-while-drilling service uses proprietary microelectronics that are ruggedized to withstand the challenging conditions associated with drilling ultrahigh-temperature reservoirs. Important points of the TeleScope ICE design process included:

  • Using a systems engineering approach to design that was borrowed from the aircraft industry.
  • Identifying potential failure modes and finding solutions that were expected to have the highest impact on reliability.
  • Testing beyond the limits of its mission profile to build in additional reliability.
  • Incorporating enabling technologies that can be used across multiple product lines.

The proprietary microelectronics in TeleScope ICE service are also used in PowerDrive ICE* ultrahigh-temperature rotary steerable system and Signature* quartz gauges. The technology employed by PowerDrive ICE service means that customers can now use a rotary steerable system in ultrahigh-temperature reservoirs.

Current Highlights