The Society of Petroleum Engineers (SPE) is hosting its Annual Technical Conference and Exhibition (ATCE) Sept. 24-26 in Dallas, Texas.

“For more than 90 years, ATCE has been the meeting of choice for SPE’s members and other professionals seeking education on current and future technologies that help find and produce hydrocarbons faster, more efficiently, safer and more cost-effectively,” the conference website stated.

The following is a sampling of some of the latest technologies that will be showcased at SPE ATCE 2018.

Editor’s note: The copy herein is contributed from service companies and does not reflect the opinions of Hart Energy.

Complete end-to-end control automation and data management platform

Fracture spread control technology and cloud-based pump maintenance are among the technologies to be showcased by AFGlobal’s AMI Controls & Analytics group. Complete end-toend control automation and data management of hydraulic pressure pumping is provided by the FracCommand Suite control and data management platform. The suite collects fracture spread data and delivers those to the DVCommand control package. The platform is highly configurable to support upgrades and new installations. Its software library includes a family of control modules as well as support for existing controls. Plug-and-play hardware controls and a proprietary transmission control protocol/ internet cache protocol network enable seamless installation and setup. A novel cloud-based system to collect and analyze fracture pump data provides robust support for managing maintenance to reduce field failures. By collecting and analyzing large amounts of data, the AFGlobal system provides the means to improve job performance through consistent, dependable operations and greater efficiency.

Real-time process viscometer for drilling fluids

AMETEK Brookfield, a provider of oilfield in-line process viscometers, has released its latest in-line rotational viscometer, the TT-100 IECEx. The viscometer was designed from the ground up to measure viscosity in drilling fluids. It preserves the timetested Couette geometry measurement method of previous models but adds an increased operating temperature range, more granular speed control, and IECEx, ATEX and North American explosion-proof certifications. Drilling engineers can use the TT-100 IECEx to collect critical viscosity data in real time no matter where in the world opportunity might lead them.

Complete monitoring solution for ESP system

Apergy Artificial Lift (formerly Dover Artificial Lift) is releasing several new technologies to optimize wells. The Apergy Gas Lift group has developed an algorithm to hunt for the optimal gas injection rate with continuous tuning to ensure the well is operating optimally, realizing a bottomhole pressure drawdown, and yielding increased production and decreased downtime. Theta Software’s XSPOC is the engine powering the expansion of LOOKOUT Monitoring’s extended capabilities. No longer only for electric submersible pump (ESP) systems, LOOKOUT is available on gas and rod lift. Continued focus on production optimization is increasing with the use of smart hardware and software in conjunction with smart analytics. Also powered by Theta Software, edge computing is possible on a multitenant platform with web-based, hosted solutions all while being mobile enabled. This allows pattern recognition along with a deeper level of smart analytics to make the best real-time decisions. These technologies allow more actionable data visualization, help predict and prevent catastrophic equipment breakdowns, and enhance safety.

Silica dust control proppant coating technology

ArrMaz’s SandTec proppant coating technology is an engineering control that provides effective silica dust protection across the hydraulic fracturing supply chain. It is proven to reduce silica dust by up to 99%, to below The U.S. Occupational Safety and Health Administration’s permissible exposure limit and action level. While mechanical dust abatement systems do provide dust control, the impracticality of using them at all supply chain transfer points limits their effectiveness while slowing fracturing operations. SandTec provides continuous silica dust protection from sand plant to wellhead without capital-intensive investment by sand companies, transloads and fracturing operators. SandTec is customized to work with silica sands of varying characteristics such as Northern white sand versus Texas brown sand, to ensure optimal silica dust control. The SandTec product line is fracture-fluid compatible and includes an environmentally friendly, U.S. Department of Agriculture- certified 100% biobased product under the BioPreferred program.

PMM improves operational efficiency

Operators are looking for new ways to increase electric submersible pump (ESP) system efficiency and lower lifting costs. Baker Hughes, a GE company’s (BHGE) new Magnefficient permanent magnet motor (PMM) improves efficiency by lowering ESP system energy consumption. The Magnefficient PMM eliminates induction losses, lowering system power consumption by 20% and reducing motor power loss by as much as 67%. The Magnefficient motor has demonstrated positive results in the field and extended the applicability of ESPs into situations that weren’t previously practical. Eight BHGE PMMs have been installed at present, in applications ranging from waterfloods and unconventional oil and gas wells in North America to high-temperature and mature fields in Latin America. Some of the units have been running continuously for more than 800 days, and each installation has achieved a motor efficiency rating of more than 90% with no reported failures.

Power sections contain approximately 30% less rubber

SpiroStar Supreme power sections are the next generation in thru-tubing technology that has been developed by BICO Drilling Tools Inc. New power sections contain approximately 30% less rubber than previous generations of Evenwall power sections. This can result in a 35% to 60% increase in power and torque output. The thinner layer of rubber further reduces the probability of chunking due to hysteresis, which makes power sections more suitable for harsh application such as high bottomhole temperature and nitrogen. New hard rubber compounds have improved the sealing surfaces, while providing amplified power. This can reduce stalls up to 40%. High flow rate capacity has been incorporated into the overall design feature to enhance hole cleaning in horizontal or high-angle wells. Moreover, larger chamber capacity permits higher flow rates without creating critical internal velocities that can be detrimental to the motor power section life.

New data science service delivers comprehensive reservoir models

Biota has globally deployed Subsurface DNA Diagnostics on more than 500 wells with a mission to maximize oil and gas reservoir economics. At ATCE Biota will introduce a new data science service that integrates DNA Diagnostics with existing reservoir measurements to deliver a comprehensive reservoir model. Biota will present new case studies in the conventional market with field trials in the Gulf of Mexico and Southeast Asia. The DNA Diagnostics service provides a novel, 4-D and noninvasive measurement of subsurface hydrocarbon fluid movement. These measurements address key questions in production allocation, reservoir connectivity, horizontal well drainage height, fracture hit monitoring and well-to-well connectivity. By delivering new subsurface insight with DNA Diagnostics, users can optimize field development, resulting in $5 million to $10 million net present value uplift per section of resource.

Well seals developed with bismuth-based alloys

BiSN’s Wel-lok M2M technology seals wells with bismuth- based alloys. By harnessing the energy available from a thermite-powered chemical reaction heater and delivering an expandable, malleable metal alloy, BiSN has created an improved solution to the traditional methods of conventional bridge plugs, cement and resins. These seals can be applied throughout the life of a well. Wel-lok M2M technology addresses several downhole sealant challenges, producing significant time, cost and environmental benefits. The modified thermite chemical heater is nonexplosive, so no special licenses or handling permits are required. Each tool can be deployed on any standard wireline without special connection or power requirements. Bismuth expands on solidification, creating a V0 gas-tight seal in accordance with ISO 14310, and bismuth is noncorrosive, environmentally friendly and is not affected by H2S, CO2 or acid washes. In addition, the seal is created within minutes and ready to test within 1 hour.

Perforating system eliminates misruns

The GameChanger perforating system from C&J Energy Services features a semi-disposable gun assembly designed to increase efficiency and reliability by eliminating the misruns and resulting nonproductive time associated with traditional gun systems. Compatible with all manufacturers’ standard shaped charges, the port-free design eliminates pinch points that can damage electrical connections, has no port plugs that can get lodged in the well and significantly decreases the chance of flooded guns. Addressable switches provide real-time confirmation throughout the downhole descent, and with no wires running between guns, the GameChanger system provides a high level of confidence in the wellbore. Using the compact C&J top sub and plug shoot sleeve, the system reduces the length and weight of the gun string, which requires less rigup equipment and provides safer onsite handling.

Identify diversion in real time with zero false positives

Traditional methods of identifying successful diversion assume that when the diverter material reaches the perforation, an increase in treating pressure is observed. While this might be an indication of diversion, it can be misleading. Calfrac’s charting overlay approach identifies diversion in real time with zero false positives. No time-consuming or resource intensive analyses are required. Through the application of this technique, diversion can be identified with greater confidence and in a timely manner such that adjustments can be made to improve stimulation effectiveness in subsequent applications.

Automated tools for quality checking experimental PVT data, EoS modeling

Calsep has released PVTsim Nova 4.0, which features new pressure-volume-temperature (PVT) technology. Modeling reservoir fluids (EoS modeling) is considered to be a difficult task requiring the experience of experts in the field. Experts often will need days or weeks to construct a robust model. With Calsep’s new Auto QC and Auto EoS technology, even engineers with limited experience in EoS modeling will be able to develop an EoS model in a much shorter time. Auto QC evaluates an input fluid composition. If the data turn out to be inconsistent, the software will automatically make the necessary adjustments. The user selects the number of components for the final EoS model, and PVT data importance is automatically ranked. Calsep’s new Auto EoS tool will deliver an EoS model that provides a good match of all PVT data within minutes.

Proppant prevents salt precipitation, eliminates freshwater injection costs

SALTGUARD is an encapsulated, porous ceramic proppant infused with halite-inhibiting chemicals that is placed throughout the entire fracture as part of the standard fracturing process. CARBO engineered SALTGUARD technology to be uniformly distributed with interconnected porosity in the proppant. The proppant is infused with a halite inhibitor and is then encapsulated to ensure a controlled release of the halite inhibitor on contact with produced water. This technology prevents salt precipitation from the fracture through the surface equipment and eliminates freshwater injection costs. SALTGUARD technology is cost-effective due to reducing the amount of chemical washout; preventing production impairment; eliminating costly remediation treatments, equipment failures and production loss from halite scaling in the fracture; and removing freshwater consumption and associated disposal cost. SALTGUARD has low minimum inhibitor concentration and is effective in brines with a presence of calcium and iron.

Facility provides testing for downhole drilling technologies

Catoosa Test Facility (CTF) provides confidential oilfield tool and technology testing for companies that are developing new drilling, completion and production technologies. All types of advanced prototype downhole drilling technologies are tested and validated at this private and independent testing campus. CTF has discretely tested hundreds of downhole tools and has allowed the largest service companies and the smallest startups the ability to test and find solutions in a safe and cost-effective environment. CTF will be highlighting the new addition of test rig M37 at ATCE. This rig is an all-electric, triple cyber-walking rig custom designed by Nabors Industries to meet the information and data requirements needed to record and capture testing information. CTF has the privilege to be an integral part in the testing of many of the innovative tools and technologies being used today.

Tools enable well control, maximize downhole space

Ideally suited for long reach horizontal, multistage stimulated oil wells, D&L Oil Tools’ ProTension safe tension tool allows complete well control at all times while setting a tubing string in tension using standard field procedure. ProTension is installed between the tubing hanger and the production tubing. Once the tubing hanger is landed, isolating the annulus, tension can then be pulled into the tubing string and safely locked into place without losing well control—no need to remove the BOPs or overstretch the tubing. The tool allows complete rotation of the tubing when setting downhole tools. The Trilobite Tubing Anchor/ Catchers, designed for hydraulically or mechanically set retrievable tubing, have a unique design that uses three double-acting slips to maximize holding power in both tension and compression, while allowing increased annular flow and capillary tube installation outside the anchor. This allows operators to maximize space for gas bypass while running capillary lines, all without compromising the inside diameter of the tubing.

Systems aerate water storage ponds, calculate inventory, monitor flowmeters

Direct Drivehead Inc. will be showcasing its Smart Pumper produced and fracturing water storage pond systems at ATCE. The Smart Pumper produced and fracturing water pond systems aerate the water, calculate inventory, monitor meters flow in and out and water quality, add chemistry as needed, control transfer pumps, and provide other options that reduce HSE risk and improve the operation. Built-in communications let customers know all these data and more while having remote on/off control capabilities in real time.

Water treatment microbiocide protects assets

Dow Microbial Control’s new AQUCAR 736 water treatment microbiocide provides enhanced topside microbial control and near-wellbore efficacy in the North Sea. This stable, one-drum formulation is Cefas gold rated and has shown superior biofilm efficacy over glutaraldehyde and tetrakis-hydroxymethyl-phosphonium alone in field validated trials, effectively protecting valuable assets and keeping them profitable for extended periods. This biocidal product also can be co-dosed with nitrate, making it the strongest drop-in solution available in the North Sea region. Expanded efficacy in the topside and near-wellbore areas combine multiple chemistries into one solution, reducing the platform footprint required for different products. Samples and laboratory data are available for AQUCAR 736.

Technologies identify and assess early-onset damage

Productivity of wells completed in shale reservoirs can be substantially improved by Flex-Chem’s OptaSTIM technology. Insoluble material capable of severely blocking flow commonly forms due to undesirable interactions between shale reservoir formations and additives in many completion fluid systems. This damage, which forms early in the production life of the wells, is associated with highly variable completion outcomes and production restrictions. At ATCE Flex-Chem Corp. will be highlighting its capabilities for identifying and assessing this early- onset damage as well as technologies and methods that address a range of formations and completion designs. Remedial treatments have shown marked success restoring flow conductivity in damaged zones and a proven record increasing well productivity.

Enhance wells producing by ESP with compression

Flogistix LP uses advanced programming logic controllers to optimize compressors, whether it is handling surging flash gas volumes on the vapor recovery side or enhancing an existing well’s production by lowering wellhead pressure. One such application in the wellhead application spectrum is casing drawdown. Casing drawdown is an application where an operator will set a rotary screw compressor on the annulus of a well on mechanical artificial lift. This lift type could be electric submersible pumps (ESP) or sucker rod pumps. Lowering the surface head pressure with a compressor will encourage more inflow of production and create an additional pathway for gas to break out of the pump. Flogistix has helped several operators improve the efficiency and production of wells on ESPs in the Midcontinent. Case studies will be presented at ATCE (referencing SPE-paper 191486).

Formation evaluation and LWD technologies to be showcased

The new Halliburton Xaminer Magnetic Resonance (XMR) service is the latest-generation magnetic resonance technology, engineered to provide excellent bed resolution and evaluate a reservoir’s full range of pore sizes from micro to macro. The combinable XMR sensor provides full magnetic resonance solutions for basic to advanced formation evaluation requirements with a 35-kpsi rating. The EarthStar ultradeep resistivity service, an LWD technology, helps operators map reservoir and fluid boundaries more than 61 m (200 ft) from the wellbore, more than doubling the depth of investigation of current industry offerings. The service delivers a comprehensive reservoir view so operators can eliminate costly pilot holes and sidetracks, make informed geosteering decisions in real time and better plan future field development. Halliburton also will highlight DecisionSpace Production Insights & Engineering, new software capabilities that add analytical dashboards and production engineering capabilities to reduce costs and unlock production potential.

Inflatable packer system optimizes rigless installation of I-PCPs without PSNs

Inflatable Packers International’s InflataLOK is the only inflatable packer system in the industry designed to optimize rigless installation of an insert progressive cavity pump (I-PCP) without the need of a pump-seating nipple (PSN). Conveyed on rodstring, it relies only on hydraulic pressure while eliminating the need for axial loads for its setting sequence. It incorporates inflatable packer technology and a hydraulically actuated anchoring-slip mechanism. It is equipped with seal cups and a shearable intake sub to obtain the required pressure competence to confirm tubing integrity and enable its setting sequence while maximizing flow-through capability after it is set. InflataLOK provides cost-effective rigless optimization in wells completed with I-PCPs. It confirms tubing integrity, allows installation within the production string in extended-reach applications beyond previously installed PSNs and eliminates axial-load limitations commonly encountered with J-Slot anchoring devices.

Enhancements to near-wellbore conductivity, sand flowback control

Recent trends in hydraulic fracturing are moving to proppants in the range of 40/70, 100 mesh or smaller. Pumping into formations with high closure stress, potential fines and embedment issues, or sand flowback issues can be a recipe for disaster. Development of hybrid diverting agents has remedied these issues. A hybrid diverter incorporates both multimode chemical diverting agents that hydrolyze with time, temperature and water, along with a rod-shaped ceramic proppant (RSP). The RSP has superior conductivity to sand or spherical ceramic, so near-wellbore conductivity is enhanced. The RSP also has impressive proppant pack stability and tremendous sand flowback control, keeping the sand in the fracture rather than in the wellbore. This hybrid diverter was highlighted in recent SPE literature (URTeC-2881395 and HFTC- 189868 papers). Field deployment and independent laboratory testing show tremendous promise for operators to maximize their well performance and minimize workover frequency.

Multiphase gathering systems handle production from multiple wells

The Leistritz Multiphase Gathering Systems (MGSs) are expandable versions of the Multiphase Wellhead System designed to handle production from multiple wells. Individual MGSs handle total flow rates up to 550,000 bbl/d equivalent and differential pressures up to 1,400 psi. These systems are fully automated and can be expanded to operate multiple MGSs in parallel for facilities requiring additional flow capacity. The utilization of multiphase pumps at the gathering facilities allows operators to centralize process facilities, reduce the local environmental impact and footprint at the well site, and operate safely and reliably.

Multivariate analysis tool helps drive completion optimization

Fraconomics is powered by multivariate analysis (MVA) from an extensive petrophysical, completion and production database to verify what parameters independently drive production in different areas. It is a scoping tool for horizontal well completion optimization in unconventional reservoirs. Big Data statistical models use readily available information from thousands of wells, whereas detailed physical modeling is laborious and generally done on a few wells. The strengths of both methods were combined in this novel approach by using calibrated physics-based relationships between completion parameters and production as transformed nonlinear variables. This provides a more constrained and physically realistic prediction of production response to suggested completion changes. The hybrid MVA model is then coupled with completion cost models to determine which fracture design and completion methods are the most effective at lowering costs per barrel of oil.

Real-time production visualizer

Microseismic monitoring in real time provides a unique tool to adjust hydraulic stimulation on the fly by measuring the dynamic response of the reservoir. Rapid determination of microseismic location and failure plane allows real-time visualization of the effects of treatment and assessment of the induced fracture volume. Fracture models allow rapid estimation of drainage volume while the well is being fractured. This provides operators with a decision-making tool to address challenges currently seen when transitioning to full-field development. Applications include quantifying the impact of parent wells on child wells in terms of fracture geometry and EUR and ways to mitigate fracture hits or testing different cluster and diverter designs and quantifying differences in fracture geometry and recovery from those parts of the wellbore. In addition, history-matched microseismic- based reservoir models can quantify the impact of changes in various development and treatment parameters to account for the degree of variability seen in unconventional reservoirs.

Prevent system failures, reduce downtime and boost performance

MindMesh will be showcasing its RiMo digital well engineering platform at ATCE. The RiMo platform consumes critical data and leverages artificial intelligence and machine-learning-driven data visualization to develop unique solutions for service companies and operators alike. The company’s global talent pool has successfully unlocked and combined physics and mathematical modeling to deep machine learning principles to create digital twins that quickly can enable companies to run more efficiently, safely and economically than ever before. The company’s drillstring dynamics functionality allows drilling engineers to leverage analysis for static, directional tendencies, critical speed and time domain analysis. The RiMo well engineering platform can be used for the design of soft and stiff string as well as hydraulics. The company’s workflow process has benefited companies that are in any stage of building their team.

Overcome critical failure modes in highly interbedded formations

National Oilwell Varco (NOV) will be featuring its Tektonic drillbit platform with ION application-specific 3-D cutter technology at ATCE. ION cutter technology consists of a high-performance range of polycrystalline diamond cutters that have been specifically designed to overcome critical failure modes in highly interbedded formations. Formations with such characteristics present a challenge for many modern cutter technologies due to recurring dynamic bit dysfunctions, including thermal abrasive wear, excessive bit vibration and high levels of impact damage. The refined diamond feeds and increased sintering pressures of the ION cutters make them more durable and abrasion resistant, while deep-leach technology ensures thermal stability is maintained. ION 3-D cutters feature a durable pointed cutting edge that greatly increases drilling efficiency, making ROP increases of more than 20% possible at the same weight on bit. A polished mirror finish reduces friction on the cutting face, while optimized cutter geometry—obtained using modeled finite element analysis— leads to reductions in drilling torque and mechanical- specific energy.

Maximizing reservoir contact in high stage count wells

Two recent technologies from Packers Plus Energy Services aim to solve completion challenges in extendedreach laterals by maximizing reservoir contact, increasing stimulation efficiency and reducing operational risk. With a wireline-deployed Latch-and-Perf System for limited- entry treatment and a pumpdown Ultra-High Stage Count System for single-point entry treatment, these new completion technologies can be deployed in a variety of applications to increase stage counts and reservoir access. The Latch-and-Perf System uses isolation latches that are pumped from surface on wireline and latch into a locating sub in the wellbore. After the casing is perforated, stimulation can begin. A ball inside the isolation latch provides isolation and fluid diversion for the stage. The Ultra-High Stage Count System uses sleeve actuation tools (SATs) that are pumped from surface and designed to latch into a specific sliding sleeve in the wellbore. Upon the SAT activating and opening the sleeve, a ball inside the SAT provides isolation and fluid diversion for the stage. Both systems provide a full inside diameter during stimulation that enables an effective treatment by maximizing pump rates, and the degradable ball eliminates the need for millout post-stimulation, which reduces operational risk.

Sand logistic technology increases efficiency

At ATCE PropX will be showcasing its Last Mile Frac Sand Logistics Technology including the hardware and software that drive efficiency and safety in this ever-changing sector. Unconventional well stimulations require about 13 MMlb of fracturing sand to be delivered to each well, often in less than one week. This volume of sand requires up to 300 truck deliveries—as many as 40 to 150 truckloads per day, which was nearly impossible using the industry’s legacy sand hauling technology. Today’s systems include smartphone software apps that provide better control and visibility of the proppant ordering, inventory and trucking component. This allows faster and safer unloading of the sand loads at the well site, which allows more round trips per driver per day and cleaner transfer of fracturing sand into the fracture blender, thus resulting in hydraulic fracturing operations meeting or beating the new U.S. Occupational Safety and Health Administration silica dust regulations, which began a three-year phase in June.

Completion diagnostic application for evaluating reservoir quality

ProTechnics has been observing the oil and gas industry embrace the importance of avoiding significant differences in lithology in the same fracturing stage to more evenly stimulate all perforation clusters. In an effort to place perforations across desirable reservoir targets and maximize stimulated reservoir volume, engineered perforating has become popular. To assist operators in this capacity, ProTechnics has developed a completion diagnostic application for evaluating reservoir quality and identifying high leak-off areas (e.g., natural fractures) along the lateral. Utilizing this technique, operators are able to identify natural fractures and design perforating schemes so as to increase completion efficiency, increase production and yield a higher return on investment.

Drilling fluid system reduces environmental and disposal concerns

QMAXDRILL, a high-performance, highly inhibitive, water-based drilling fluid system, can be used in the most challenging and environmentally sensitive drilling applications onshore and offshore. The technology is applicable where highly reactive formations are present and water-based fluids are required, including in troublesome shales. The formulation reduces environmental and disposal concerns that may arise with oils or elevated chlorides, nitrates or sulfates. The dual chemical and mechanical inhibition mechanisms created by the amine and the polymeric combination maximize its performance. For specific applications, further enhancement can be achieved by the use of a proprietary glycol. The QMAXDRILL system offers low filtration rates, a wide range of rheological properties and enhanced lubrication. It is a cost-effective alternative to synthetic- based mud because disposal costs are cut in half when compared to a nonaqueous system. Furthermore, the cost per barrel of the QMAXDRILL system is effective compared to other waterbased mud systems and oil-based fluids.

Service establishes benchmarks, identifies trends

Whether in the field or the office, data are a crucial part of ensuring healthy oil and gas operations. Engineers and accountants alike need easy-to-use and easy-to-understand data with straightforward access. Clean, simplified data make the difference between trusting insights and never knowing if the best information for decision-making has been acquired. myQuorum Data Hub is a cloud-based service that makes well life-cycle data available for whoever needs it and ready for whatever business intelligence tools they want. Well life-cycle reporting tools and myQuorum Data Hub are a powerful combination, enabling drilling and completion operations to establish benchmarks, identify trends and reduce nonproductive time. With complete visibility into active jobs, field costs, budgets and rig performance, managers and executives can quickly and confidently understand what is happening in the field. This is all done through both native data visualization and support for third-party solutions.

Changing the approach to building reliable reservoir models

Resoptima’s ResX reservoir modeling and management software changes the way subsurface teams work. With a focus on next-generation digitalization, ResX breaks with traditional reservoir modeling approaches that persist in treating static and dynamic modeling as separate tasks, with asset teams continuing to work in domain siloes. Grounded in ensemble-based methods, ResX software enables a robust quantification of uncertainty across static and dynamic data conditioning and modeling. The software uses fit-for-purpose machine learning algorithms to augment the know-how of subsurface teams so that geoscientists and reservoir engineers can assess different concepts within a full range of geologically consistent—and equally likely—reservoir models. With the implementation of repeatable workflows, ResX generates models that honor all available data, abide by reservoir physics and incorporate uncertainty throughout the modeling chain. This enables subsurface teams to better understand the subsurface and focus on driving high-value decisions.

Managing high-volume sand applications

The Sand X Beast features a double auger and is designed to manage high-volume sand applications including fracture screenouts. The Beast is used as the primary recovery tank in drillout and flowback. Flowback enters the gas buster, and the sand, water and hydrocarbons continue into the hopper. Sand then falls to the bottom of the hopper while being cleaned, is picked up by a lift system and then discharged into a roll off box or suitable container. Water and hydrocarbons flow over the weir plate and into the Beast tank. This process allows reuse of water for drilling, which saves money and the environment. The Beast also eliminates hazardous waste exposure and the need for confined space entry. The clean sand makes transport and disposal of the sand easier resulting in significant savings.

Optimize hydrocarbon recovery to deliver reservoir performance

At ATCE Schlumberger will be highlighting how it is enhancing performance with domain leadership and digital enablement technologies that optimize hydrocarbon recovery to deliver reservoir performance. The company will be showcasing its WellWatcher Stim stimulation monitoring service and its Tempo instrumented docking perforating gun system. The Well- Watcher Stim service improves fracturing, acidizing and other well operations by confirming downhole events in near real time. For one operator in the North Sea, the system identified stimulation fluid entry into previously treated stage, indicating incomplete isolation and prompted immediate action to drop a second actuation ball and restimulate the untreated stage. The Tempo system combines a plug-in gun design with real-time downhole measurements for enabling and monitoring the well’s dynamic underbalance to create clean perforations that boost reservoir productivity. This is achieved while improving wellsite safety and operational efficiency. In Egypt the system’s onboard diagnostics and radio frequency (RF) filtering technology provided operational assurance and RF protection during 11 perforation runs with no impact on simultaneous operations.

Rotary steerable system helps avoid costly trips, improves ROP

Scientific Drilling’s HALO high-performance rotary steerable system solves U.S. land operators’ reliability and economic challenges while yielding more efficient, smoother wellbores. Designed to complete vertical, curve and lateral sections in one run, it helps avoid costly trips and improves ROP. The system maximizes wellbore exposure in the target zone by drilling curve sections with build rates up to 15 degrees/30 m (100 ft), while its full 3-D Autopilot functionality delivers unparalleled lateral placement. It can be paired with conventional mud motors and operates at a maximum bit speed up to 350 rpm, maximizing performance and reducing rig time. Consisting of an integrated steering unit and MWD survey package with azimuthal gamma ray geosteering and pressure-while-drilling capabilities, the HALO system is fully assembled and qualified prior to delivery to the rig site. This minimizes bottomhole assembly time and mitigates associated HSE risks. Data are transmitted to the surface from the system’s high-speed mud pulse telemetry.

Tool quickly simulates extremely large reservoir models

Stone Ridge Technology’s ECHELON reservoir simulator helps E&P companies save money and make better decisions by allowing engineers to quickly simulate extremely large reservoir models that were previously too large to simulate. Due to this new capability, companies can keep the geologic detail that is typically removed for previous simulators to achieve manageable run times. This allows engineers and managers to better understand the subsurface and make more informed decisions. ECHELON is able to simulate these detailed reservoirs in a fraction of the time that previous generation simulators used to simulate models with much less detail, which makes engineers more efficient and allows them to complete more projects. ECHELON is able to achieve this breakthrough performance by being the first reservoir simulator to completely run on modern graphics processing units.

Increase conductive fracture area

SUN Specialty Products has released its Proppant Transport Solution, the ultralightweight proppants FracBlack and OmniProp, developed to enhance well value by placing proppant in far field fracture areas increasing reservoir contact and ultimately production. With a specific gravity of 1.055 g/cu. m, Frac- Black and OmniProp have superior transportability in water-based fluid fractures providing increased reservoir contact for greater hydrocarbon recovery. FracBlack and OmniProp are advanced thermoset nanocomposite beads, featuring near-neutral buoyancy, high strength and thermal stability for applications in most reservoirs with or without conventional proppants. These products can be used to substantially increase the conductive fracture area of unconventional wells, optimizing production performance and stimulated reservoir recovery.

Liner hanger/packer system provides greater well control

The TIW XPak expandable liner hanger/packer system has been used to successfully hang an 185⁄8-in. outer diameter (OD) liner in 24-in. OD, electric resistance weld (ERW) seamed casing. The system design eliminated a two-stage cement job in unstable formations and provided greater well control. The liner penetrated 670 m (2,200 ft) of difficult and unstable geology, including water zones, sloughing shale and lost-circulation zones. The slip design provides a hanging load capacity equal to or greater than conventional liner hangers. Stacked metal-to-metal seals and elastomer backup seals, with no extrusion gaps, provide a HP/HT, gas-tight, liner-top seal. A honed inner diameter receptacle in the upper portion of the expander allows tieback to surface or patching a cased-hole section. Successful qualification testing prior to running the XPak system confirmed the system can effectively seal in ERW seamed casing.

Redesigning bit hydraulics with a split inner blade geometry

Ulterra Drilling Technologies will be showcasing the latest advancement in PDC bit technology—SplitBlade. The industry has long faced the problem of poor cuttings evacuation resulting in reduced ROP, wasted drilling energy and less toolface control. Ulterra has addressed this problem by redesigning bit hydraulics with a split inner blade geometry. By separating the primary blades and placing nozzles at the separation, SplitBlade creates a double-barrel hydraulic flow to help evacuate cuttings quicker. This improved cleaning allows the bit face to engage and fracture rock unimpeded, increasing ROP. SplitBlade’s cone and shoulder layout provide increased control, durability and speed resulting in extended bit life. SplitBlade has changed the economics of drilling by regularly saving operators up to $55,000.

System treats produced water for reuse or surface discharge

Veolia Water Technologies will feature OPUS technology at ATCE. This reverse osmosis (RO)-based system achieves high water recovery using pretreatment processes to protect the RO membranes. OPUS technology is a proven solution in operation for more than 10 years. OPUS II incorporates ceramic membranes to provide an absolute barrier to contaminants in the RO feed water, which significantly reduces system footprint and installation costs. In either design, the RO process operates at an elevated pH, which effectively controls biological, organic and particulate fouling, eliminates scaling due to silica, and increases the rejection of silica, organics and boron. Treated effluent can be reused or discharged, eliminating the need for produced water reinjection. In some locations, treatment and discharge reduce formation pressure and facilitate oil recovery while providing a freshwater resource. System performance is guaranteed when combined with a Veolia operations and maintenance contract.

Technologies that minimize production decline rates

Throughout ATCE Weatherford will feature technologies that execute reliable, safe well construction and minimize production decline rates. The technologies include additions to Weatherford’s portfolio and enhancements to proven solutions. The new Magnus rotary steerable system combines reliable, high-performance drilling with precise directional control. Unique features—including independent pad control and a true inclination hold—help operators sustain drilling, stay on plan and reduce well construction costs. Weatherford also will highlight enhancements to proven technologies. Redesigned for 2018, the Rotaflex long-stroke pumping unit accelerates the transition to rod lift by 15% to 20%. The unit adds new features that reduce opex and simplify maintenance, including an optimized gear reducer, integrated hydraulic rollback system and larger access doors. The ForeSite production optimization platform introduces support for gas-lift systems, electric submersible pumps and additional surface facilities to extend enterprisewide production optimization. Lastly, the R2R advanced perf-and-wash system elevates the perf-and-wash technique; the permanent abandonment solution creates a rock-to-rock hydraulic seal with single-trip efficiency.