2019年石油工程师协会（SPE）年度技术会议暨展览会（ATCE）将于9月30日至10月2日在加拿大阿尔伯塔省卡尔加里举行。

据会议网站介绍，“TCE 是 SPE 的会员年度会议，以开创性论文和特殊技术活动为特色，旨在加速创新在各个技术学科中的应用。” “来自世界各地的与会者来到 ATCE，了解最新技术、行业最佳实践和新产品发布。”

以下是今年 ATCE 上展示的一些最新创新的示例。

编者注：本文内容由服务公司提供，并不反映 Hart Energy 的意见。

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人工智能软件构建并优化油井输送资源的复杂调度

Actenum 将在 ATCE 上展示其集成的油井交付调度和人工智能 (AI) 支持的优化软件 Actenum Upstream。对于运营商来说，油井交付调度是一个复杂而关键的过程，具有重大的经济影响。如果做得好，它可以最大限度地有效利用昂贵的资源，并产生可观的经济效益。如果做得不好，后果可能很严重——延期生产、周期时间延迟和成本增加只是其中的几个结果。尽管它很重要，但令人惊讶的是，鉴于其复杂性，货物交付调度通常是使用不复杂的软件工具手动完成的。Actenum Upstream 使用人工智能构建并自动优化油井交付资源的复杂调度，使调度与业务目标保持一致。它克服了手动调度的局限性，其功能包括全面的调度逻辑、强大的、基础良好的数据模型和团队范围的调度可视化。这些工具使操作员能够最大限度地提高项目协作和效率、缩短周期时间、降低风险并实现可预测和可靠的生产。actenum.com

耐磨柱塞可承受严酷的磨蚀条件
几十年来，杆式举升系统面临的挑战之一是柱塞被称为柱塞和筒之间的“牺牲部件”。涂有喷涂金属和 TUFFR 的柱塞在对抗这种信念方面一直很可靠，但该行业需要一种超越当前标准的柱塞。Apergy 的新型 Harbison-Fischer UltraClad 柱塞采用该公司的下一代 UltraClad 涂层设计，是一款优质耐磨柱塞。这种极其耐用的柱塞可以承受严酷的磨损条件，并在较长时间内保持高泵效率。事实证明，UltraClad 比传统涂层有所改进，在实验室磨损测试中，UltraClad 的耐磨性比 TUFFR 好 18 倍。apergy.com

系统提供砾石和压裂填充替代方案
GE 公司贝克休斯 (BHGE) 的 GeoFORM 适形砂管理系统提供了传统砂控制方法的替代方案。GeoFORM 系统使用可扩展并符合复杂井剖面的材料，以更少的操作要求提供新水平的防砂性能。GeoFORM 系统像砂筛一样在井下运行，但可由两人安装，不需要特殊的泵送设备或支撑剂，非常适合偏远地区。当使用 GeoFORM 系统代替砾石充填时，每个区域可以节省一到三天的钻机时间。GeoFORM 系统的形状记忆聚合物可提供 3D 过滤，无需泵送砂浆的复杂性。一旦激活，GeoFORM 材料就会填充环空，过滤砂粒并稳​​定井眼。其微观孔隙结构可捕获各种粒径，同时保持高度多孔性，以最大限度地提高碳氢化合物的流动。bhge.com

陶瓷微支撑剂最大限度地支撑与储层的接触
CARBO 推出了 NANOMITE，这是一种陶瓷微支撑剂，其尺寸仅为最小支撑剂的一小部分，通常用于缓解射孔进入问题、改善簇流体分布并最大限度地与储层接触。这可以提高增产效率、降低总体完井成本并提高产量。NANOMITE 是一种具有成本效益的理想解决方案，适用于在处理过程中遇到支撑剂放置、处理压力升高和早期筛选困难的运营商。传统的支撑剂太大，无法融入复杂的裂缝网络的微裂缝中，并且其传输特性限制了其进入该区域的距离。NANOMITE C 的最小颗粒比 100 目压裂砂中的最小颗粒小五倍以上。这使得颗粒能够撑开最窄的次生裂缝和微裂缝，从而增加储层基质的总体产量贡献，同时降低高表面处理压力。碳陶瓷网

系统能够实时监控和分析多孔井平台操作
Cold Bore Technology 的 SmartPAD 是首款基于工业物联网传感器的远程完井操作系统，能够实时监控、跟踪和分析多孔平台操作。它帮助运营商提高效率、增强现场安全性并减少压裂总天数，从而为每个压裂垫节省数十万美元的成本。该系统集成了服务公司的数据，例如线圈、电缆、压裂、回流和其他现场数字数据，并将其与直接从井口提供的传感器驱动的操作数据相结合，以生成关键路径时间线。阀门位置也会实时显示，这是一项重要的安全功能。对运营中每一分钟细节的全面跟踪提供了新的洞察力，运营的即时可见性帮助客户避免了严重事故、设备损坏和危险情况。Coldboretechnology.com

砾石充填完井解决方案
Diverter Plus最近开发了 MicroVert+ 和 SolVert+ GP 系列可降解分流器，专门设计用于采用砾石充填或其他防砂完井方法完井的井。这些颗粒呈现出设计的长方形几何形状和弹性，使它们能够穿过砾石充填层并沉积在地层表面上，然后促进注入流体的均匀分布。制造过程可以对颗粒尺寸进行严格控制，因此产品可以在任何尺寸的砾石充填中获得最佳性能。密度改变和耐溶剂涂层允许在各种流体中使用，包括最具腐蚀性的沥青质和石蜡处理，同时保持悬浮状态，无需高速。这些颗粒表现出 Diverter Plus （其他系列转向器）的水解行为，这意味着随着时间、温度和水的存在，颗粒将化学转化为液体形式。diverterplus.com

每口非常规井的数字孪生
新一代基于物理的模型可以为每口非常规井实现数字孪生。它部署在云端，用于实时监控、处理和历史匹配大量“最佳”（存档）和“动态”（来自传感器的实时数据）的数据。它将油藏、井筒和地面网络建模为一个实体，并具有人工智能增强的自动历史匹配功能，可随着时间的推移进一步完善其预测能力。它可以通过附加功能在连接的油井的整个生命周期内实现生产优化，包括生产瓶颈识别、自动气举优化、虚拟计量和虚拟生产日志。与最近经历了显着效率提升的钻井和完井作业不同，由于使用基于物理的模型对生产进行建模需要付出努力和时间，因此生产优化已经滞后，因此几乎所有油井都依赖于经验模型。Paradigm k 通过专为非常规油藏量身定制的快速且易于使用的模型来缓解这一问题。艾默生网站

旨在降低成本的技术
在今年的 ATCE 上，Expro 将重点介绍 CoilHose，这是一种轻型井循环系统，可最大限度地减少碳氢化合物生产的损失并降低干预的总体成本。该紧凑型系统可快速部署，比标准连续油管作业节省时间和成本。它为套管孔应用、数字和标准井配置工具以及重型打捞提供了一套有线部署干预选项。

Expro 还将展示其新的智能干预技术，这是一种用于去除蜡、水垢和其他固体的自主钢丝绳系统。该技术为运营商节省了大量的人力和支持成本，并通过减少有线卡车来最大限度地减少对环境的影响和社区干扰。

此外，该公司还将展示其生产监控服务，这些服务通过井下监测和地面多相测量提供，有助于最大限度地提高运营商的油藏、油井和资产的产量。 exprogroup.com

识别和评估早期损害
通过 Flex-Chem 的 OptaSTIM 技术可以显着提高页岩油藏完井的产能。由于页岩储层与许多完井流体系统中的添加剂之间的不良相互作用，通常会形成能够严重阻塞流动的不溶性物质。这种损害在油井生产寿命的早期形成，与高度可变的完井结果和生产限制有关。在 ATCE 上，Flex-Chem Corp. 将重点展示其识别和评估这种早期损害的强大能力，以及解决一系列地层和完井设计的技术和方法。补救措施在恢复受损区域的导流能力方面取得了显着的成功，并取得了提高油井产能的良好记录。flex-chem.com

以油藏为中心的全流体系统
Flotek 将展示其以油藏为中心的全流体系统，该系统建立在其复杂纳米流体技术的基础上，并被证明可以增强和改善碳氢化合物采收率。此外，Flotek 将展示其以油藏为中心的方法在北美盆地油气藏各种应用中的有效性的全面分析，包括完井、修复、压裂命中和强化注水。Flotek 的化学品已在世界上每个主要盆地的 10,000 多口井中使用，旨在解决油藏生命周期中的每一个挑战，并最大限度地提高新油田和成熟油田的采收率。该公司的流体系统专为油藏量身定制，可提高有效渗透率、减少地层损害并降低挥发性油藏中的气油比。弗洛特金德网站

智能压裂服务有助于提供均匀的流体和支撑剂分布
在非常规油藏中，勘探与生产公司不断调整增产参数，以努力实现每个井眼更多的裂缝并提高油井性能。统一刺激每个集群并及时且经济有效地实现这些成果是一项挑战。哈里伯顿的 Prodigi 智能压裂服务整合了来自数千个阶段的数据以及实时信息，以帮助提供均匀的流体和支撑剂分布。这种数据丰富的方法与先进的控制系统架构相结合，使 Prodigi 服务能够更均匀地输送支撑剂和流体。许多配备光纤传感器的油井表明，Prodigi 智能压裂服务有助于消除表现不佳的阶段。其他好处包括更低的处理压力、更快的阶段泵送时间和减少筛分。迄今为止，Prodigi 服务已为 35 家 E&P 公司提高了 12 个不同盆地 4,500 多个阶段的增产效果。哈里伯顿网站

定向钻井系统实现决策和执行自动化
Helmerich & Payne Technologies 将展示自动化定向钻井解决方案，采用系统化、逻辑化、分阶段的方法来实现定向钻井决策和幻灯片执行的自动化。在尝试遵循预定义的路径时，即使是最优秀、最有经验的司钻也很难正确补偿多个变量，包括电机产量变化、目标不确定性、偏转、曲折风险等。从历史上看，幻灯片执行更像是一种艺术形式，而不是一门科学。自动化这个过程将两者结合起来。该系统可以在更快的时间内处理更多的数据，从而可以通过仅靠人类无法完成的额外分析来实现持续的实时改进。决策和执行的自动化可以降低钻井成本、更安全、更一致的操作、更高的碳氢化合物生产潜力并提高井眼质量。在自主钻井的道路上，自动滑动是整个船队整体方法的重要组成部分。hpinc.com

技术减少了地层水的产量
Hexion 的 AquaBond 技术减少了地层水的产量，同时提高了石油和天然气的产量。它通过降低地层水管理成本来提高油井盈利能力。它的化学成分与支撑剂结合，并在油井的使用寿命内保持原位并有效。最近在圣安德烈斯地层进行的一项案例研究显示，使用该技术仅使用 16.5% 尾部的 20/40 目支撑剂即可取得积极成果。与补偿井相比，地层水产量减少了 15%，而石油产量增加了 28%。在 Granite Wash 中，采用 AquaBond 技术和 40/70 目支撑剂的井与补偿井相比，地层水减少了 43% 以上。此外，平均累计桶油当量增加了40%以上。瀚森网站

7.5 英寸。射孔枪在一个平面上最多可发射三发
Hunting 的 H-2 射孔系统消除了油田面临的常见地面处理效率低下和井下挑战，同时保持了最高的性能标准。H-2是油田中最短的射孔枪。H-2 长度仅为 7.5 英寸，可以在单架飞机上发射最多三发子弹，并且不需要电线或导爆索。H-2 非常适合在钻机高度有限的情况下每级具有高簇数的射孔。在最近与一家主要运营商进行的特拉华盆地现场试验中，H-2 创下了通过电缆泵入水平井的多次射孔枪数量的记录。H-2 与塞子一起使用，一次成功运行了 45 支射孔枪。狩猎国际网

工具分析细乳液和微乳液的界面行为
KRUSS Scientific 的旋转液滴张力计 (SDT) 仪器是乳液和表面活性剂质量控制和开发的理想解决方案，因为它可以轻松分析细乳液和微乳液的界面行为。它通常用于石油工业，对于测量极低的界面张力至关重要，例如在 EOR 过程中。与旧式仪器不同，SDT 通过新获得专利的配件显着减少了繁琐的样品制备体验。与 ADVANCE 软件配合使用，该仪器可以自动控制并利用准备好的且易于调整的模板。kruss-scientific.com

数字井工程平台
RiMo 是一个数字工程平台，它使用关键数据并利用人工智能 (AI) 和机器学习驱动的数据可视化为服务公司和运营商等开发独特的解决方案。MindMesh 已成功解锁物理和数学模型并将其与深度机器学习原理相结合，创建数字孪生，使公司能够快速、更高效、更安全、更经济地运营。该公司的钻柱动力学功能使钻井工程师能够利用静态分析、方向趋势、临界速度以及最重要的时域分析。RiMo 井工程平台可用于软管柱和硬管柱以及水力学的设计。Mind-Mesh 的工作流程使处于团队建设任何阶段的公司都能受益。Mindmeshtech.com

具有高度乳化稳定性的钻井液克服了钻井问题
传统的水基钻井液配方简单，乍一看似乎可以保持钻井液成本较低。然而，当使用闭环系统时，供水和运输多余液体的成本会显着增加液体管理成本。在钻盐时不能应用管理流体量的标准方法，因为它会因盐度水平降低而导致地层的极度冲刷。显着的水流或循环漏失事件也需要各种密度变化。斯伦贝谢旗下公司 MI SWACO 开发了 FluxDril 直接乳化液，以满足钻探标准井眼的要求，并在保持机械钻速的同时处理大量钻井固体。该流体具有高度的乳化稳定性，并克服了遇到的典型钻井相关问题：盐层、水流、酸性气体和枯竭地层中的泥浆损失。FluxDril 液还能够回收大部分乳化基础油，从而降低相关钻井液成本。slb.com/fluxdril

生产各种等级的 PLA 树脂，针对一系列应用进行了优化
虽然聚丙交酯 (PLA) 聚合物是一种生物基可降解热塑性塑料，十多年来一直被用作增强骨折刺激的分流剂，但它仅在过去几年，材料科学和最佳实践已经开始减少分流器应用中的猜测。现在，使用可降解的 PLA 分流器可以在井下实现可预测的石油和天然气产量提高。以 Ingeo 品牌销售的 NatureWorks PLA 树脂有多种等级，针对广泛的消费和工业应用进行了优化。使用可用的丙交酯单体工具箱，NatureWorks 可以微调 PLA 等级的降解速率，以在 49°C 至 149°C（120°F 至 300°F）温度范围内提供所需的井下性能。在 ATCE 上，NatureWorks 将展示其最新的解决方案 DH1000，该解决方案适用于低温井，并展示用于最大程度增产的其他形状、尺寸和品位解决方案。natureworksllc.com

Stimulation and completion fluids designed to enhance performance
Newpark Fluids Systems will introduce its expanded portfolio of stimulation and completion fluids at ATCE. In addition to drilling fluids, Newpark will now enhance operation performance, safety and efficiencies with new completion and stimulation fluids. Tim Armand, president, North America, at Newpark Fluids Systems, said, 鈥淥ur goal is to allow oil and gas companies to conquer the most challenging environments with faster, safer and cleaner results.鈥� Newpark also will feature its hydraulics modeling software that provides customers with a simulated analysis of a given fluid product and tests how well it performs within a particular environment, saving time and resources. newpark.com

AI for oil and gas
In an environment of prolonged volatility and price compression, unconventional operators are focused on optimizing field development economics. OAG Analytics is a software suite that enables collaborative, data-driven optimization for some of the most expensive decisions in the upstream life cycle, including well spacing, sequencing and landing zone. Addressing the criticality of data quality, OAG Data Manager ensures the right data are ready for analysis by breaking down data silos and providing quality control for a cross-discipline master database. Out of the box, OAG provides artificial intelligence (AI) applications to predict missing rock properties, optimize a section, perform predictive maintenance and frac hit feature engineering. In addition, data scientists and subject matter experts are able to create and share applications specific to a program with in-house developed algorithms. OAG can optimize well spacing, quantify geo parameter impact on production and integrate to Spotfire. oaganalytics.com

Ball-activated steam valve enhances SAGD completions
Installing steam valves along the tubing string in steamassisted gravity drainage (SAGD) completions improves steam distribution along the lateral for uniform reservoir coverage. The Packers Plus Inferno Ball-Activated Steam Valve builds on this enhancement by eliminating the need to use coiled tubing (CT) to open the valves, saving time and cost during completion operations. The Inferno Ball-Activated Steam Valve is installed in the closed position and the sleeves are initially shifted using degradable actuation balls. By using actuation balls, the well does not have to be killed鈥攚hich unnecessarily cools the reservoir鈥攖o activate the valves. Following sleeve activation, the ball is then pumped out into the liner where it degrades. The ball-activated steam valves can be closed and reopened multiple times using a shifting tool. Packers Plus collaborated with an operator to deploy the Inferno Ball Activated Steam Valve in Alberta鈥檚 oil sands, and after three consecutive successful field trial runs, the operator has installed the valves in seven additional wells. packersplus.com

Pump system improves production in vertical, deviated and horizontal oil wells
PMC Pumps Canada Inc. has developed a hydraulically actuated positive displacement pump system to improve production in vertical, deviated and horizontal oil wells. The system can pump at least four times as much liquid as same-sized rod pumps if running at the same strokes per minute. Unlike rod pumps, the PMC pump system can produce liquids at constant flow with little wellbore pressure fluctuation. The PMC pumps do not need rodstring, so they eliminate rod wear-out and reduce sand production. This pump can be used in high-temperature environments with large production steam-assisted gravity drainage wells in Alberta, Canada. Compared with electric submersible pumps, its slow speed and elimination of downhole electric motor increase mechanical reliability and energy efficiency, resulting in longer run time. In addition, such a pump will not have gas lock damage. This pump system will be running and demonstrated during ATCE in a simulated pump test facility in Calgary with pump flow of 600 bbl/d to 4,000 bbl/d, operating at pressures up to 10 MPag and temperatures up to 220 C (428 F). pmcpump.com

A mini separator system simplifies sampling
Solids can impact a number of areas with regard to flow assurance and production chemistry, including stabilizing emulsions and limiting the ability to inject water due to the increased blocking of pores. They also can impact the amount of oil in overboard water and erode pipework and valves. Sampling is vital for learning what solids are being produced and in what quantities. At ATCE, Proserv will discuss its capabilities for addressing the production of solids and will highlight solutions including its subsea solid filtration sampling and handheld solid sampling filtration units. Proserv鈥檚 sampling team also will be emphasizing its topside filtration trolleys, which enable safe and consistent sampling at the wellhead and flowlines, upstream of first stage separation for water chemistry, sand and solid loading, and hydrocarbon composition, all simultaneously. The trolleys minimize production deferment and exposure to toxic gases. proserv.com

Technology allows users to forecast wells, create type curves and value properties
Q Engineering will be showcasing its TypecurveStudio application and its latest release, BasinStudio, at ATCE. Q Engineering addresses processing limitations to unconventional reservoir engineering workflows by harnessing the power of Amazon Web Services. By unlocking cloud computing, Q Engineering has created fast and reliable forecasts of production data. This allows engineers and analysts to forecast wells, create type curves and value properties most efficiently. In an industry that faces Big Data limitations, Q Engineering strives to address these issues to allow users to forecast entire basins at a time to gain the most competitive operator intelligence in any area of interest. This technology allows users to make the most informed decisions in a particular play in the least amount of time. q.engineering

Evaluate subsurface uncertainty
Resoptima removes the traditional limitations of reservoir modeling by unlocking the power of data to evaluate subsurface uncertainty. The company鈥檚 vision is that there is not just one view of the subsurface. The company鈥檚 technology is based on a methodology that enables geoscientists and engineers to continually create and recreate geological and reservoir models by testing uncertainties and assimilating them to collected data. Resoptima鈥檚 ensemble-based solution orchestrates static and dynamic modeling processes, bringing in all data to let users create, evaluate and reevaluate the reservoir in all the complexity a user sees. Powered by Resoptima technology, subsurface uncertainty is transformed by data and physics into actionable insights and measurable value. resoptima.com

Tool for integrated static and dynamic modeling from reservoir to surface networks
Rock Flow Dynamics鈥� comprehensive reservoir management solution, tNavigator, is a single program covering seismic interpretation, well correlation, geological modeling, fluid characterization, well modeling, reservoir simulation and surface network design. The program creates value for both conventional and unconventional assets. This means users deal with only one interface and only one point of data entry. This avoids extra work and makes learning easier. In addition, workflows can be put under the control of tNavigator鈥檚 optimization and uncertainty engine. These workflows can improve understanding of the interactions between the individual elements of the workflow. As an example, the impact of uncertainty in seismic velocity modeling on water handling capacity can be determined easily in a single workflow in the same program using robust physics quickly. Answers to this question on water handling capacity can help to avoid the need for expensive retrofitting of surface facilities. rfdyn.com

Accelerate workflows with a cloud-based technology platform
RS Energy Group (RSEG) provides a high-speed, scalable and adaptive software platform called RS Prism. This technology enables faster data processing and can run analytical queries on billions of rows of data in milliseconds rather than hours or days, uncovering patterns and hidden insights for rapid analysis and decision-making. The comprehensive and accurate assessment of RSEG clients鈥� most critical strategies鈥攊nvolving operational optimization, evaluating potential acquisition targets, competitor surveillance, benchmarking and other key capital allocation decisions鈥攃an be performed in seconds. All RSEG solutions reside in this single platform. RSEG鈥檚 solutions combine public operational, financial and geological data with 20 years of RSEG鈥檚 intellectual property (IP), advanced analytics and applied data science/machine learning models. The merging of this technology and RSEG鈥檚 analytics/IP allows RSEG clients to streamline their daily workflows across asset teams, strategy and planning, investor relations, executive management and others. rseg.com

Improving flowability of crude oil below its wax appearance temperature
At ATCE, Sasol will be presenting its non-ionic surfactants (SPE-195894 paper), which can be included in paraffin treatment formulations for rheology modification of crude oils. The latter helps to control flow assurance issues caused by paraffin wax, a widespread phenomenon costing the petroleum industry billions of dollars yearly. Unlike traditional paraffin inhibitors, which are more effective against low molecular weight waxes, Sasol鈥檚 surfactants target the high molecular weight paraffin chains that can negatively impact pour point, gel strength and wax appearance temperature. The effectiveness of Sasol鈥檚 new chemistry in reducing the deposition of high carbon chain paraffin is an important advantage and represents a significant contribution toward cost-effectively managing a significant industry problem. sasol.com

Rise of the robots: enhancing operational efficiency while reducing risk and costs
Robots, science fiction鈥檚 go-to, no longer represent the frontiers of automation. The future is now, as Saudi Aramco harnesses robotics as a foundational element of the company鈥檚 digitalization strategy, able to capture and process data and make asset management more efficient in extreme conditions. Developed by Aramco鈥檚 Research & Development Center, the Shallow Water Inspection and Monitoring Robot, or SWIM-R, is equipped with sensors to conduct visual underwater pipeline inspections, clean marine life growth with a water jet and take ultrasonic thickness readings and cathodic protection voltage measurements in up to 10-m (33-ft) depth. The compact robot easily circumvents physical hazards that can limit a diver鈥檚 access; it also can navigate currents and crawl along the seabed. The only robot of its kind, SWIM-R has 10 patents and has been licensed for global commercialization. saudiaramco.com

Get answers about reservoir model behavior in just a few mouse clicks
In a world as technically intricate as the oil and gas industry鈥攚hen billions of dollars of revenue are on the line鈥攔eservoir engineers must be confident that they have predicted the behavior of complex systems with reasonable accuracy. Experts in the field of reservoir behavior analysis are frequently asked to compare reservoir simulation datasets of a single oil field, interpret those data and determine whether the projections are reasonable or make recommendations
on a plan of recovery. The results are complex and diverse, making it difficult to compare and validate results with reasonable accuracy. Tecplot RS is a reservoir simulation visualization and analysis tool for oil and gas reservoir modeling that is able to load data from many different sources. The program supports all major reservoir simulators and has streamlined 鈥淪mart View鈥� processes to get reservoir engineers their answers in just a few mouse clicks. tecplot.com

Extreme torque solution for longer laterals

West Canadian operators are focused on gaining efficiencies in their operations, as lateral wells are getting longer and directional drilling is becoming more challenging. Tenaris offers its new threaded and coupled Tenaris-Hydril Wedge XP 2.0 connection to cover these encounters. As part of the TenarisHydril Wedge series, the Wedge XP 2.0 provides exceptional over-torque performance achieved by the robustness of the Wedge thread design and a pin-to-pin backup mechanism. In unconventional operations, this new generation of semi-premium connections has demonstrated its ability to reduce running times, decrease connection rejects rates and decrease the risk of pipe stuck in a hole, while optimizing performance. This case will demonstrate real field experience of how the Tenaris-Hydril Wedge XP 2.0 connection delivered under very demanding well conditions. When combined with the company鈥檚 direct mill-to-well solution, Rig Direct services, customers receive streamlined logistics, further enhancing supply chain management, technical and field services. tenaris.com

Mapping proppant reduces risks associated with completion and production
Terves鈥� VisionFrax is a proppant mimicking pumpable acoustic emitter with time-controlled signal generation. Once in situ and exposed to specific downhole conditions, this lightweight proppant exerts an audible signal in response to time, fracture closing or critical stresses. VisionFrax acoustic emission pops providing a signal for sensitive downhole acoustic sensors, enabling mapping of stimulated fracture and proppant placement after the pumping operation. This signal is capable of being received through hydraulic pathways and ultimately allows the completions organization to accurately map the penetration and location of this proppant throughout their frac cavity. VisionFrax is tailored to match pumped proppant and well conditions for a controlled signaling window after well stimulation. VisonFrax is a commercially available product that is made in the U.S. and is being field tested by several customers. tervesinc.com

Offerings for produced water transfer, de-sanding, treatment and recycling
Shale operations are dealing with higher water management costs and more environmental and operational risks than ever before, both of which are becoming an increasingly larger part of operators鈥� costs. Sourcing freshwater and increasing volumes of sand flowback and produced water, which are often trucked out and disposed of, are the primary cause. Addressing these challenges in an environmentally responsible way frequently requires adding more services and personnel at each site. TETRA Technologies鈥� water management solution delivers differentiating offerings for produced water transfer, de-sanding and on-the-fly water treatment and recycling. By integrating and automating the company鈥檚 offerings, efficiency is maximized through job planning and crew optimization, helping reduce manpower for a typical fully integrated completion operation by more than 30%. The step change in efficiency is delivered through fully automated technology that provides greater transparency and quality control throughout the transfer, flowback and recycling of produced water鈥攁ll while simultaneously improving environmental considerations. tetratec.com/water

Machine learning technology for well curve prediction
Analytics Ready LAS (ARLAS) uses machine learning algorithms to fill in gaps in log curves and calculate the curve response of missing log runs. With as little as one curve, ARLAS can predict an entire quad-combo suite allowing users to see data where they didn鈥檛 exist before. Machine learning technology benefits significantly with access to large amounts of sample or training data, and TGS has the largest commercial library in the world from which to learn. Machine learning models improve and data outputs achieve higher accuracies with each iteration. ARLAS accuracy is well above 90% due to more than 75 different machine learning models calibrated for each basin with TGS鈥� vast data library. For example, TGS has more than 316,000 LAS immediately available in the Permian Basin alone, seven times more than other providers. This results in high-quality predicted quad-combo suites across the entire basin. tgs.com

Diverter technology reduces the total number of bridge plugs within a wellbore
SlicFrac is Thru Tubing Solutions鈥� diverter technology that allows operators to reduce the total number of bridge plugs within a wellbore while maintaining the advantages of closer stage spacing and adding additional clusters. The risk of a preset plug can be drastically reduced, along with pump downtime, completion cost and resources associated for the corresponding wireline runs and subsequent mill-out work. Applying SlicFrac diversion technology between bridge plugs allows the operator to achieve maximum cluster efficiency while stimulating the entire stage, without leaving orphan clusters behind. This ensures a more consistent stimulation volume pumped into each perforation cluster, ultimately providing a more balanced treatment and reducing the probability of a runaway frac, which could potentially damage offset wells. thrutubing.com

Organic oil recovery
The Titan Process alters production declines and releases and recovers trapped oil by uniquely creating micro-oil droplets that can move through the tight reservoir rock spaces and be recovered. The process is low cost, requires no capital expense and is biodegradable. The company鈥檚 breakthrough technology (creating micro-oil droplets) is based on a nutrient formula custom- made for each oil field, and this formula activates the biology of the reservoir. The Titan Process has been applied to 48 oil fields on four continents with 340 well applications. Four peer-reviewed SPE papers confirmed more than 200% production increases from 24 commercial well pilots. The Titan Process addresses production declines, trapped oil, increases recovery factor and decreases H₂S. titanoilrecovery.com

Downhole automation increases efficiency
An increasing number of wells in U.S. Permian fields are being drilled using the Tomax AST tool. The tool provides automation through a simple, downhole algorithm that balances the depth of cut versus the rate of change in reactive torque. The nominal results are 40% faster ROP and almost double footage. Reaction time is the key to explain this huge improvement. The AST stabilizes the cut within 20 ms. That is very fast compared to the minutes it takes to tune the drilling parameters upon alerts from the MWD system or other warnings. The prevention of system excitation through the fast reaction time almost eliminates peak loads and thus overheating of the PDC cutting edges. The cutting edges have an obvious effect on both speed and footage. An additional benefit is reduced vibration and risk of damages to other tools in the downhole suite. tomax.no

Technology provides efficiency of up to 96%
WAGO鈥檚 new Pro 2 Power Supply Series is the new industry communication and parameterization standard. With six power supply units ranging from 120 W to 960 W, the Pro 2 Series provides an efficiency of up to 96%. These new power supplies permit easy fieldbus connection via modular type communication modules and incorporate an interface that can be tailored to any application. With combined exceptional highpower density with excellent efficiency, the Pro 2 Series has performance-enhancing Top-Boost, which delivers 600% extra output current and a PowerBoost that provides an additional 150% output current for 5 seconds. The high power density of the WAGO Power Supply Pro 2 allows significant space savings in the control cabinet. The digital twin concept saves time and money from the very beginning鈥攆rom planning to installation to operation鈥攐ver the course of many years. wago.com/us

微支撑剂可提高页岩的抬升率并降低下降率
Zeeopheres Ceramics LLC 的 Deeprop 1000 是美国制造的一种坚固的完美球形微支撑剂，用于支撑水力压裂过程中页岩中产生的扩张的次生裂缝。该材料旨在为比 100 目可穿透小 10 倍的裂缝提供长期导电性。它没有闭合压力或温度限制。利用来自巴尼特、伍德福德、尤蒂卡和二叠纪盆地页岩等几种不同岩石系统的生产数据，已经证明了在油气井中使用这种小型支撑剂的经济效益。使用 Deeprop 1000 的勘探与生产公司报告了一些额外的运营优势，包括降低泵压和远场转向以防止压裂撞击。

The 2019 Society of Petroleum Engineers (SPE) Annual Technical Conference and Exhibition (ATCE) will take place Sept. 30 to Oct. 2 in Calgary, Alberta, Canada.

“ATCE is SPE’s annual meeting of members and features groundbreaking papers and special technical events designed to accelerate the application of innovations in every technical discipline,” according to the conference website. “Attendees come from around the world to ATCE to keep up with the latest technologies, industry best practices and new product launches.”

The following is a sampling of some of the latest innovations that will be showcased at ATCE this year.

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

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AI software builds and optimizes complex scheduling of well delivery resources

Actenum will be featuring its integrated well delivery scheduling and artificial intelligence (AI)-powered optimization software, Actenum Upstream, at ATCE. For operators, well delivery scheduling is a complex and critical process with substantial economic impact. Done well, it maximizes the efficient use of costly resources and yields substantial economic benefits. Done poorly, consequences can be severe—deferred production, cycle time delays and increased costs are but a few of the outcomes. Despite its importance—and surprisingly, in view of its complexity—well delivery scheduling is often done manually using unsophisticated software tools. Actenum Upstream uses AI to build and automatically optimize complex scheduling of well delivery resources, aligning schedules with business objectives. It overcomes the limitations of manual scheduling with capabilities that include comprehensive scheduling logic, a robust, well-based data model and teamwide schedule visualization. These tools enable operators to maximize project collaboration and efficiency, shorten cycle times, reduce risk and achieve predictable and reliable production. actenum.com

Wear-resistant plunger can withstand severe abrasive conditions
One of the challenges that rod lift systems have faced for several decades relates to plungers being dubbed the “sacrificial component” between the plunger and barrel. Plungers coated in spray metal and TUFFR have been reliable at combating this belief, but the industry needs a plunger that goes beyond current standards. Apergy’s new Harbison-Fischer UltraClad Plunger, designed with the company’s next-generation UltraClad coating, is a premium wear-resistant plunger. This extremely durable plunger can withstand severe abrasive conditions and maintain high pump efficiency for longer periods of time. The UltraClad has proven to be an improvement over conventional coatings, with UltraClad having a better wear resistance than TUFFR by a factor of 18 in laboratory abrasion tests. apergy.com

System provides a gravel and frac pack alternative
The GeoFORM conformable sand management system from Baker Hughes, a GE company (BHGE), offers an alternative to conventional sand control methods. The GeoFORM system uses a material that expands and conforms to complex well profiles, delivering a new level of sand control performance with fewer operational requirements. The GeoFORM system is run downhole like a sand screen, but it can be installed by a two-person crew and doesn’t require special pumping equipment or proppant, making it ideal for remote locations. When used in place of a gravel pack, the GeoFORM system can save one to three days of rig time per zone. The GeoFORM system’s shape memory polymer offers 3-D filtration without the complexities of pumping sand slurry. Once activated, the GeoFORM material fills the annulus, filtering sand particles and stabilizing the wellbore. Its microscopic pore structure captures a wide range of particle sizes while remaining highly porous to maximize hydrocarbon flow. bhge.com

Ceramic microproppant maximizes propped contact with the reservoir
CARBO has released NANOMITE, a ceramic microproppant that is a fraction of the size of the smallest proppant commonly deployed to alleviate perforation entry issues, improve cluster fluid distribution and maximize contact with the reservoir. This results in improving stimulation efficiencies, reducing overall completion costs and improving production. NANOMITE is a cost effective, ideal solution for operators experiencing difficulty with proppant placement, elevated treatment pressure and early screenouts during treatment. Traditional proppant is too large to fit into a complex fracture network’s microfractures, and its transport characteristics limit how far it travels into the area. The smallest particles of NANOMITE C are more than five times smaller than the smallest particles in 100 mesh frac sand. This allows the particles to prop open even the narrowest secondary fractures and microfractures, resulting in an increase in overall production contribution from the reservoir matrix while lowering high surface treating pressures. carboceramics.com

System enables real-time monitoring and analysis of multiwell pad operations
Cold Bore Technology’s SmartPAD is the first Industrial Internet of Things sensor-based, remote completions operating system that enables real-time monitoring, tracking and analysis of multiwell pad operations. It is helping operators improve their efficiency, enhance their onsite safety and reduce their overall number of frac days, resulting in costs savings of hundreds of thousands of dollars per pad. The system integrates service company data such as coil, wireline, frac, flowback and other digital data on location and couples it with sensor-driven operational data provided directly from the wellhead to generate a critical path time line. Valve positions are also displayed in real time, which is a significant safety feature. The comprehensive tracking of every minute detail of the operations provides new insight, and the instantaneous visibility of the operations has helped clients avoid serious incidents, damaged equipment and hazardous situations. coldboretechnology.com

Solution for gravel pack completions
DiverterPlus has recently developed the MicroVert+ and SolVert+ GP lines of degradable diverters specifically designed for use in wells completed with a gravel pack or other sand control completion methods. The particles exhibit a designed oblong geometry and elasticity that allows them to traverse the gravel pack and deposit on the formation face itself where they then encourage even distribution of injected fluids. The manufacturing process allows extreme control over particle size, so products are available for optimum performance in any size gravel pack. Density alteration and solvent resistant coatings allow for use in a variety of fluids, including the most aggressive asphaltene and paraffin treatments, while remaining suspended without the need for high velocity. The particles exhibit the hydrolysis behavior of DiverterPlus’ other lines of diverter, meaning that with time, temperature and the presence of water, the particles will chemically convert into a liquid form. diverterplus.com

A digital twin for every unconventional well
A new generation of physics-based models enables the attainment of a digital twin for every unconventional well. It is deployed in the cloud to monitor, process and history-match large volumes of data at “rest” (archived) and “in motion” (live data from sensors) in real time. It models the reservoir, wellbore and surface network as one entity and features artificial intelligence-boosted automated history match that refines its predictive capacity further with time. It enables production optimization throughout the connected wells’ life cycles with additional features, including production bottleneck identification, automated gas-lift optimization, virtual metering and virtual production logs. Unlike drilling and completion operations, which have recently experienced significant efficiency gains, production optimization has lagged due to the effort and time required to model production with physics-based models, hence reliance on empirical models for almost all wells. Paradigm k alleviates that with a fast and easy-to-use model specifically tailored for unconventional reservoirs. emerson.com

Technologies designed to lower costs
At this year’s ATCE, Expro will highlight CoilHose, a light well circulation system that minimizes the loss of hydrocarbon production and lowers the overall cost of intervention. The compact system is rapidly deployed, saving both time and cost over standard coiled tubing operations. It delivers a suite of wire deployed intervention options for cased-hole application, digital and standard well configuration tooling and heavy-duty fishing.

Expro also will present its new intelligent intervention technology, an autonomous wireline system for the removal of waxes, scales and other solids. This technology saves the operator significant manpower and support costs as well as minimizes the environmental impact and community disturbance with the reduction of wireline trucks.

In addition, the company will showcase its production surveillance services, which are delivered through downhole monitoring and surface multiphase measurement, helping maximize production from operators’ reservoirs, wells and assets. exprogroup.com

Identifying and assessing early-onset damage
The 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 strong 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. flex-chem.com

Reservoir-centric full-fluid systems
Flotek will be showcasing its reservoir-centric full-fluid systems, which are built upon its Complex nano-Fluid technologies and proven to enhance and improve hydrocarbon recovery. Additionally, Flotek will present its comprehensive analyses of the effectiveness of its reservoir- centric approach across a variety of applications in oil and gas reservoirs in basins across North America, including completions, remediation, frac hits and enhanced waterflooding. Flotek’s chemistries have been used in more than 10,000 wells across every major basin in the world and are designed to address every challenge in the life cycle of the reservoir and maximize recovery in both new and mature fields. The company’s fluid systems are tailored to the reservoir to increase effective permeability, reduce formation damage and lower gasoil ratio in volatile oil reservoirs. flotekind.com

Intelligent fracturing service helps deliver uniform fluid and proppant distribution
In unconventional reservoirs, E&P companies are continually adjusting stimulation parameters in an effort to achieve more fractures per wellbore and improve well performance. Stimulating each cluster uniformly and achieving these outcomes in a timely and cost-effective manner is the challenge. Halliburton’s Prodigi intelligent fracturing service incorporates data from thousands of stages along with real-time information to help deliver uniform fluid and proppant distribution. This data-rich approach, coupled with an advanced control system architecture, enables the Prodigi service to more uniformly deliver proppant and fluid. Numerous wells instrumented with fiber-optic sensors have shown the Prodigi intelligent fracturing service helps eliminate underperforming stages. Additional benefits can include lower treating pressure, faster stage pumping times and reduced screenouts. To date, the Prodigi service has improved stimulation effectiveness on more than 4,500 stages within 12 different basins for 35 E&P companies. halliburton.com

Directional drilling system automates decision-making and execution
Helmerich & Payne Technologies will be showcasing an automated directional drilling solution following a systematic, logical, phased approach to automating both directional drilling decision-making and the execution of slides. Attempting to follow a predefined path, even the best, most experienced drillers struggle to properly compensate for multiple variables including motor yield variations, target uncertainty, deflections, tortuosity risks and more. Slide execution has historically been more of an art form than a science; automating this process combines the two. The system processes a higher volume of data in a faster amount of time, allowing for continuous realtime improvement with additional analysis not possible by a human alone. Automating both the decision-making and the execution leads to reduced drilling costs, safer and more consistent operations, higher hydrocarbon production potential and improved wellbore quality. On the pathway to autonomous drilling, automated sliding is a crucial building block as part of a holistic approach fleetwide. hpinc.com

Technology reduces the production of formation water
Hexion’s AquaBond technology reduces the production of formation water while improving oil and gas production. It increases well profitability by reducing formation water management costs. Its chemistry is bonded to proppant and remains in place and effective for the life of the well. A recent case study in the San Andres Formation showed positive results utilizing just a 16.5% tail in of 20/40 mesh proppants using the technology. Formation water production was reduced by 15%, while oil production increased by 28% compared to offset wells. In the Granite Wash, wells utilizing AquaBond technology with 40/70 mesh proppants realized a reduction of formation water by more than 43% compared to offset wells. Additionally, the average cumulative barrel of oil equivalent was more than 40% higher. hexion.com

7.5-in. perforating gun fires up to three shots on a single plane
Hunting’s H-2 Perforating System has eliminated common surface handling inefficiencies and downhole challenges that the oil field is faced with while maintaining the highest performance standards. The H-2 is the shortest perforating gun in the oil field. At just 7.5 in. in length, the H-2 can fire up to three shots on a single plane and requires no wiring or detonating cord. H-2 is ideal for perforating with high cluster count per stage where rig height is limited. In a recent Delaware Basin field trial with a major operator, H-2 set a record for the number of multiple-shot perforating guns pumped down into a horizontal well on wireline. H-2 was utilized to successfully run 45 perforating guns, in conjunction with a plug, in a single run. hunting-intl.com

Tool analyzes interfacial behaviors of mini and microemulsions
KRUSS Scientific’s Spinning Drop Tensiometer (SDT) instrument is the ideal solution for the quality control and development of emulsions and surfactants, as it easily analyzes the interfacial behaviors of mini and microemulsions. It is commonly used in the petroleum industry where it is essential to measure extremely low interfacial tensions, such as in EOR processes. Unlike older instrumentation, the SDT has significantly reduced the laborious sample preparation experience through newly patented accessories. And paired with the ADVANCE software, the instrument can be automatically controlled and utilizes prepared and easily adaptable templates. kruss-scientific.com

Digital well engineering platform
RiMo is a digital engineering platform that consumes critical data and leverages artificial intelligence (AI) and machine learning driven-data visualization to develop unique solutions to service companies and operators alike. MindMesh 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, safer and economical. The company’s drillstring dynamics functionality allows drilling engineers to leverage analysis for static, directional tendencies, critical speed and, most importantly, time-domain analysis. The RiMo well engineering platform can use be used for the design of soft and stiff string and hydraulics. Mind- Mesh’s workflow process has enabled companies that are in any stage of building their team. mindmeshtech.com

Fluid with a high degree of emulsion stability overcomes drilling problems
Conventional water-based drilling fluids have simple formulations and at first glance appear to keep drilling fluid costs low. However, when using a closed-loop system, the costs of water supply and hauling excess fluid significantly increases fluid management costs. The standard method to manage fluid volume cannot be applied while drilling through salt because it causes extreme washout of the formation due to reduced salinity levels. Significant water flow or lost circulation events also require various density changes. M-I SWACO, a Schlumberger company, developed the FluxDril direct emulsion fluid to meet the requirements for drilling a gauge wellbore and handle high amounts of drilled solids while maintaining ROP. This fluid provides a high degree of emulsion stability and overcomes the typical drilling-related problems encountered: salt formations, water flows, sour gas and mud losses in depleted formations. The FluxDril fluid also has the ability to recover a significant portion of the emulsified base oil, which reduces the associated drilling fluid cost. slb.com/fluxdril

PLA resins produced in various grades, optimized for a range of applications
While polylactide (PLA) polymers, a bio-based and degradable thermoplastic, have been used for more than a decade as a diverter to enhance fracture stimulation, it has only been in the last few years that materials science and best practices have begun to reduce the guesswork in diverter application. It is now possible to achieve predictable oil and gas production enhancements in well after well using degradable PLA diverters. NatureWorks PLA resins sold under the brand name Ingeo are produced in various grades optimized for a wide range of consumer and industrial applications. Using the toolbox of lactide monomers available, NatureWorks fine-tunes the rate of degradation of PLA grades to provide the desired downhole performance over the 49 C to 149 C (120 F to 300 F) temperature range. At ATCE, NatureWorks will be featuring its latest solution, DH1000, which is for lower temperature wells, as well as showcasing additional shape, size and grade solutions for utmost well stimulation. natureworksllc.com

Stimulation and completion fluids designed to enhance performance
Newpark Fluids Systems will introduce its expanded portfolio of stimulation and completion fluids at ATCE. In addition to drilling fluids, Newpark will now enhance operation performance, safety and efficiencies with new completion and stimulation fluids. Tim Armand, president, North America, at Newpark Fluids Systems, said, “Our goal is to allow oil and gas companies to conquer the most challenging environments with faster, safer and cleaner results.” Newpark also will feature its hydraulics modeling software that provides customers with a simulated analysis of a given fluid product and tests how well it performs within a particular environment, saving time and resources. newpark.com

AI for oil and gas
In an environment of prolonged volatility and price compression, unconventional operators are focused on optimizing field development economics. OAG Analytics is a software suite that enables collaborative, data-driven optimization for some of the most expensive decisions in the upstream life cycle, including well spacing, sequencing and landing zone. Addressing the criticality of data quality, OAG Data Manager ensures the right data are ready for analysis by breaking down data silos and providing quality control for a cross-discipline master database. Out of the box, OAG provides artificial intelligence (AI) applications to predict missing rock properties, optimize a section, perform predictive maintenance and frac hit feature engineering. In addition, data scientists and subject matter experts are able to create and share applications specific to a program with in-house developed algorithms. OAG can optimize well spacing, quantify geo parameter impact on production and integrate to Spotfire. oaganalytics.com

Ball-activated steam valve enhances SAGD completions
Installing steam valves along the tubing string in steamassisted gravity drainage (SAGD) completions improves steam distribution along the lateral for uniform reservoir coverage. The Packers Plus Inferno Ball-Activated Steam Valve builds on this enhancement by eliminating the need to use coiled tubing (CT) to open the valves, saving time and cost during completion operations. The Inferno Ball-Activated Steam Valve is installed in the closed position and the sleeves are initially shifted using degradable actuation balls. By using actuation balls, the well does not have to be killed—which unnecessarily cools the reservoir—to activate the valves. Following sleeve activation, the ball is then pumped out into the liner where it degrades. The ball-activated steam valves can be closed and reopened multiple times using a shifting tool. Packers Plus collaborated with an operator to deploy the Inferno Ball Activated Steam Valve in Alberta’s oil sands, and after three consecutive successful field trial runs, the operator has installed the valves in seven additional wells. packersplus.com

Pump system improves production in vertical, deviated and horizontal oil wells
PMC Pumps Canada Inc. has developed a hydraulically actuated positive displacement pump system to improve production in vertical, deviated and horizontal oil wells. The system can pump at least four times as much liquid as same-sized rod pumps if running at the same strokes per minute. Unlike rod pumps, the PMC pump system can produce liquids at constant flow with little wellbore pressure fluctuation. The PMC pumps do not need rodstring, so they eliminate rod wear-out and reduce sand production. This pump can be used in high-temperature environments with large production steam-assisted gravity drainage wells in Alberta, Canada. Compared with electric submersible pumps, its slow speed and elimination of downhole electric motor increase mechanical reliability and energy efficiency, resulting in longer run time. In addition, such a pump will not have gas lock damage. This pump system will be running and demonstrated during ATCE in a simulated pump test facility in Calgary with pump flow of 600 bbl/d to 4,000 bbl/d, operating at pressures up to 10 MPag and temperatures up to 220 C (428 F). pmcpump.com

A mini separator system simplifies sampling
Solids can impact a number of areas with regard to flow assurance and production chemistry, including stabilizing emulsions and limiting the ability to inject water due to the increased blocking of pores. They also can impact the amount of oil in overboard water and erode pipework and valves. Sampling is vital for learning what solids are being produced and in what quantities. At ATCE, Proserv will discuss its capabilities for addressing the production of solids and will highlight solutions including its subsea solid filtration sampling and handheld solid sampling filtration units. Proserv’s sampling team also will be emphasizing its topside filtration trolleys, which enable safe and consistent sampling at the wellhead and flowlines, upstream of first stage separation for water chemistry, sand and solid loading, and hydrocarbon composition, all simultaneously. The trolleys minimize production deferment and exposure to toxic gases. proserv.com

Technology allows users to forecast wells, create type curves and value properties
Q Engineering will be showcasing its TypecurveStudio application and its latest release, BasinStudio, at ATCE. Q Engineering addresses processing limitations to unconventional reservoir engineering workflows by harnessing the power of Amazon Web Services. By unlocking cloud computing, Q Engineering has created fast and reliable forecasts of production data. This allows engineers and analysts to forecast wells, create type curves and value properties most efficiently. In an industry that faces Big Data limitations, Q Engineering strives to address these issues to allow users to forecast entire basins at a time to gain the most competitive operator intelligence in any area of interest. This technology allows users to make the most informed decisions in a particular play in the least amount of time. q.engineering

Evaluate subsurface uncertainty
Resoptima removes the traditional limitations of reservoir modeling by unlocking the power of data to evaluate subsurface uncertainty. The company’s vision is that there is not just one view of the subsurface. The company’s technology is based on a methodology that enables geoscientists and engineers to continually create and recreate geological and reservoir models by testing uncertainties and assimilating them to collected data. Resoptima’s ensemble-based solution orchestrates static and dynamic modeling processes, bringing in all data to let users create, evaluate and reevaluate the reservoir in all the complexity a user sees. Powered by Resoptima technology, subsurface uncertainty is transformed by data and physics into actionable insights and measurable value. resoptima.com

Tool for integrated static and dynamic modeling from reservoir to surface networks
Rock Flow Dynamics’ comprehensive reservoir management solution, tNavigator, is a single program covering seismic interpretation, well correlation, geological modeling, fluid characterization, well modeling, reservoir simulation and surface network design. The program creates value for both conventional and unconventional assets. This means users deal with only one interface and only one point of data entry. This avoids extra work and makes learning easier. In addition, workflows can be put under the control of tNavigator’s optimization and uncertainty engine. These workflows can improve understanding of the interactions between the individual elements of the workflow. As an example, the impact of uncertainty in seismic velocity modeling on water handling capacity can be determined easily in a single workflow in the same program using robust physics quickly. Answers to this question on water handling capacity can help to avoid the need for expensive retrofitting of surface facilities. rfdyn.com

Accelerate workflows with a cloud-based technology platform
RS Energy Group (RSEG) provides a high-speed, scalable and adaptive software platform called RS Prism. This technology enables faster data processing and can run analytical queries on billions of rows of data in milliseconds rather than hours or days, uncovering patterns and hidden insights for rapid analysis and decision-making. The comprehensive and accurate assessment of RSEG clients’ most critical strategies—involving operational optimization, evaluating potential acquisition targets, competitor surveillance, benchmarking and other key capital allocation decisions—can be performed in seconds. All RSEG solutions reside in this single platform. RSEG’s solutions combine public operational, financial and geological data with 20 years of RSEG’s intellectual property (IP), advanced analytics and applied data science/machine learning models. The merging of this technology and RSEG’s analytics/IP allows RSEG clients to streamline their daily workflows across asset teams, strategy and planning, investor relations, executive management and others. rseg.com

Improving flowability of crude oil below its wax appearance temperature
At ATCE, Sasol will be presenting its non-ionic surfactants (SPE-195894 paper), which can be included in paraffin treatment formulations for rheology modification of crude oils. The latter helps to control flow assurance issues caused by paraffin wax, a widespread phenomenon costing the petroleum industry billions of dollars yearly. Unlike traditional paraffin inhibitors, which are more effective against low molecular weight waxes, Sasol’s surfactants target the high molecular weight paraffin chains that can negatively impact pour point, gel strength and wax appearance temperature. The effectiveness of Sasol’s new chemistry in reducing the deposition of high carbon chain paraffin is an important advantage and represents a significant contribution toward cost-effectively managing a significant industry problem. sasol.com

Rise of the robots: enhancing operational efficiency while reducing risk and costs
Robots, science fiction’s go-to, no longer represent the frontiers of automation. The future is now, as Saudi Aramco harnesses robotics as a foundational element of the company’s digitalization strategy, able to capture and process data and make asset management more efficient in extreme conditions. Developed by Aramco’s Research & Development Center, the Shallow Water Inspection and Monitoring Robot, or SWIM-R, is equipped with sensors to conduct visual underwater pipeline inspections, clean marine life growth with a water jet and take ultrasonic thickness readings and cathodic protection voltage measurements in up to 10-m (33-ft) depth. The compact robot easily circumvents physical hazards that can limit a diver’s access; it also can navigate currents and crawl along the seabed. The only robot of its kind, SWIM-R has 10 patents and has been licensed for global commercialization. saudiaramco.com

Get answers about reservoir model behavior in just a few mouse clicks
In a world as technically intricate as the oil and gas industry—when billions of dollars of revenue are on the line—reservoir engineers must be confident that they have predicted the behavior of complex systems with reasonable accuracy. Experts in the field of reservoir behavior analysis are frequently asked to compare reservoir simulation datasets of a single oil field, interpret those data and determine whether the projections are reasonable or make recommendations
on a plan of recovery. The results are complex and diverse, making it difficult to compare and validate results with reasonable accuracy. Tecplot RS is a reservoir simulation visualization and analysis tool for oil and gas reservoir modeling that is able to load data from many different sources. The program supports all major reservoir simulators and has streamlined “Smart View” processes to get reservoir engineers their answers in just a few mouse clicks. tecplot.com

Extreme torque solution for longer laterals

West Canadian operators are focused on gaining efficiencies in their operations, as lateral wells are getting longer and directional drilling is becoming more challenging. Tenaris offers its new threaded and coupled Tenaris-Hydril Wedge XP 2.0 connection to cover these encounters. As part of the TenarisHydril Wedge series, the Wedge XP 2.0 provides exceptional over-torque performance achieved by the robustness of the Wedge thread design and a pin-to-pin backup mechanism. In unconventional operations, this new generation of semi-premium connections has demonstrated its ability to reduce running times, decrease connection rejects rates and decrease the risk of pipe stuck in a hole, while optimizing performance. This case will demonstrate real field experience of how the Tenaris-Hydril Wedge XP 2.0 connection delivered under very demanding well conditions. When combined with the company’s direct mill-to-well solution, Rig Direct services, customers receive streamlined logistics, further enhancing supply chain management, technical and field services. tenaris.com

Mapping proppant reduces risks associated with completion and production
Terves’ VisionFrax is a proppant mimicking pumpable acoustic emitter with time-controlled signal generation. Once in situ and exposed to specific downhole conditions, this lightweight proppant exerts an audible signal in response to time, fracture closing or critical stresses. VisionFrax acoustic emission pops providing a signal for sensitive downhole acoustic sensors, enabling mapping of stimulated fracture and proppant placement after the pumping operation. This signal is capable of being received through hydraulic pathways and ultimately allows the completions organization to accurately map the penetration and location of this proppant throughout their frac cavity. VisionFrax is tailored to match pumped proppant and well conditions for a controlled signaling window after well stimulation. VisonFrax is a commercially available product that is made in the U.S. and is being field tested by several customers. tervesinc.com

Offerings for produced water transfer, de-sanding, treatment and recycling
Shale operations are dealing with higher water management costs and more environmental and operational risks than ever before, both of which are becoming an increasingly larger part of operators’ costs. Sourcing freshwater and increasing volumes of sand flowback and produced water, which are often trucked out and disposed of, are the primary cause. Addressing these challenges in an environmentally responsible way frequently requires adding more services and personnel at each site. TETRA Technologies’ water management solution delivers differentiating offerings for produced water transfer, de-sanding and on-the-fly water treatment and recycling. By integrating and automating the company’s offerings, efficiency is maximized through job planning and crew optimization, helping reduce manpower for a typical fully integrated completion operation by more than 30%. The step change in efficiency is delivered through fully automated technology that provides greater transparency and quality control throughout the transfer, flowback and recycling of produced water—all while simultaneously improving environmental considerations. tetratec.com/water

Machine learning technology for well curve prediction
Analytics Ready LAS (ARLAS) uses machine learning algorithms to fill in gaps in log curves and calculate the curve response of missing log runs. With as little as one curve, ARLAS can predict an entire quad-combo suite allowing users to see data where they didn’t exist before. Machine learning technology benefits significantly with access to large amounts of sample or training data, and TGS has the largest commercial library in the world from which to learn. Machine learning models improve and data outputs achieve higher accuracies with each iteration. ARLAS accuracy is well above 90% due to more than 75 different machine learning models calibrated for each basin with TGS’ vast data library. For example, TGS has more than 316,000 LAS immediately available in the Permian Basin alone, seven times more than other providers. This results in high-quality predicted quad-combo suites across the entire basin. tgs.com

Diverter technology reduces the total number of bridge plugs within a wellbore
SlicFrac is Thru Tubing Solutions’ diverter technology that allows operators to reduce the total number of bridge plugs within a wellbore while maintaining the advantages of closer stage spacing and adding additional clusters. The risk of a preset plug can be drastically reduced, along with pump downtime, completion cost and resources associated for the corresponding wireline runs and subsequent mill-out work. Applying SlicFrac diversion technology between bridge plugs allows the operator to achieve maximum cluster efficiency while stimulating the entire stage, without leaving orphan clusters behind. This ensures a more consistent stimulation volume pumped into each perforation cluster, ultimately providing a more balanced treatment and reducing the probability of a runaway frac, which could potentially damage offset wells. thrutubing.com

Organic oil recovery
The Titan Process alters production declines and releases and recovers trapped oil by uniquely creating micro-oil droplets that can move through the tight reservoir rock spaces and be recovered. The process is low cost, requires no capital expense and is biodegradable. The company’s breakthrough technology (creating micro-oil droplets) is based on a nutrient formula custom- made for each oil field, and this formula activates the biology of the reservoir. The Titan Process has been applied to 48 oil fields on four continents with 340 well applications. Four peer-reviewed SPE papers confirmed more than 200% production increases from 24 commercial well pilots. The Titan Process addresses production declines, trapped oil, increases recovery factor and decreases H₂S. titanoilrecovery.com

Downhole automation increases efficiency
An increasing number of wells in U.S. Permian fields are being drilled using the Tomax AST tool. The tool provides automation through a simple, downhole algorithm that balances the depth of cut versus the rate of change in reactive torque. The nominal results are 40% faster ROP and almost double footage. Reaction time is the key to explain this huge improvement. The AST stabilizes the cut within 20 ms. That is very fast compared to the minutes it takes to tune the drilling parameters upon alerts from the MWD system or other warnings. The prevention of system excitation through the fast reaction time almost eliminates peak loads and thus overheating of the PDC cutting edges. The cutting edges have an obvious effect on both speed and footage. An additional benefit is reduced vibration and risk of damages to other tools in the downhole suite. tomax.no

Technology provides efficiency of up to 96%
WAGO’s new Pro 2 Power Supply Series is the new industry communication and parameterization standard. With six power supply units ranging from 120 W to 960 W, the Pro 2 Series provides an efficiency of up to 96%. These new power supplies permit easy fieldbus connection via modular type communication modules and incorporate an interface that can be tailored to any application. With combined exceptional highpower density with excellent efficiency, the Pro 2 Series has performance-enhancing Top-Boost, which delivers 600% extra output current and a PowerBoost that provides an additional 150% output current for 5 seconds. The high power density of the WAGO Power Supply Pro 2 allows significant space savings in the control cabinet. The digital twin concept saves time and money from the very beginning—from planning to installation to operation—over the course of many years. wago.com/us

Microproppant provides uplift and a reduced decline rate in shale
Zeeopheres Ceramics LLC’s Deeprop 1000 is a strong, perfectly spherical microproppant made in the U.S. that is used to support dilated secondary fractures created in shale during the hydraulic fracturing process. The material is designed to provide long-term conductivity in fractures that are 10 times smaller than 100 mesh can penetrate. It has no closure pressure or temperature limits. The economic benefits of utilizing this small proppant in both oil and gas wells have been demonstrated utilizing production data from several different rock systems including the Barnett, Woodford, Utica and Permian Basin shales. Several additional operational benefits including reduced pumping pressures and far-field diversion to prevent frac hits have been reported by the E&P companies that have used Deeprop 1000.