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# ODSI

Oilfield Data Services Inc.

## Sitemaps

- [XML Sitemap](https://www.odsi-energy.com/sitemap.xml): Contains all public & indexable URLs for this website.

## Posts

- [OILFIELD DATA SERVICES INC. (ODSI) - WELLBORE SOLUTION](https://www.odsi-energy.com/oilfield-data-services-inc-odsi-wellbore-solution-2/) - Introduction to ODSI's wellbore solution using the mechanical energy balance equation.
- [Glossary of Petroleum Engineering Terms](https://www.odsi-energy.com/glossary-of-petroleum-engineering-terms/) - ODSI's glossary of common petroleum engineering terms, including ODSI's internal terminology.
- [AOG Energy 2024](https://www.odsi-energy.com/aog-energy/) - Join ODSI in Perth as AOG Energy returns to the Perth Convention & Exhibition Centre March 13 - 15, 2024. AOG Energy brings together industry leaders, cutting-edge technologies, and forward-thinking strategies, creating a dynamic platform for networking and collaboration. As the leading provider of Automated Real-Time Surveillance (ARTS) solutions, ODSI is excited to showcase our latest advancements and connect with fellow professionals passionate about shaping the future of energy. Don't miss this opportunity to engage with us at AOG Energy and discover how ODSI can empower your operations. If you attend, let us know and we can schedule a time to connect!
- [SPE Deepwater Symposium 2024](https://www.odsi-energy.com/odsi-spe-deepwater-symposium/) - Join ODSI in New Orleans at the SPE Gulf of Mexico Deepwater Technical Symposium , August 15 - 16, 2024. This premier event, hosted by the American Association of Drilling Engineers (AADE) New Orleans Chapter, New Orleans Geological Society (NOGS), and Society of Petroleum Engineers (SPE) Delta Section brings together industry pioneers, cutting-edge technologies, and visionary strategies to tackle the challenges and opportunities in deepwater exploration and production. As the leading provider of Automated Real-Time Surveillance and engineering services, ODSI is proud to be a part of this dynamic symposium, showcasing our latest technologies and expertise. advancements and insights to drive success in the Gulf of Mexico's deepwater sector. Join us at the Deepwater Technical Symposium to explore new horizons, network with industry experts, and discover how ODSI can empower your operations. If you plan on attending, let us know, and we'd be pleased to schedule a time to connect!
- [SPE Annual Technical Conference & Exhibition](https://www.odsi-energy.com/odsi-spe-atce-2024/) - Oilfield Data Services, Inc. (ODSI) is gearing up for the SPE Annual Technical Conference and Exhibition (ATCE) in vibrant New Orleans. ATCE promises to deliver conversations on the past, present, and future of innovation within the Oil & Gas industry, inspiring a new era of energy professionals committed to shaping a resilient and sustainable energy landscape. As the leading provider of Automated Real-Time Surveillance and engineer services, ODSI is thrilled to be a part of this esteemed gathering, showcasing our latest technologies and expertise. Join us at ATCE to discover how ODSI can empower your operations and drive success in the evolving energy landscape. If you plan on attending, let us know, and we'd be pleased to schedule a time to connect!
- [Offshore Northern Seas (ONS) 2024](https://www.odsi-energy.com/offshore-northern-seas-ons/) - Join the forefront of offshore innovation with ODSI at ONS 2024 in Stavanger, Norway. ONS is renowned for its unrivaled gathering of industry pioneers, groundbreaking technologies, and forward-looking strategies, making it a premier platform for shaping the future of offshore energy. As a trusted partner, ODSI is excited to showcase our cutting-edge ARTS solutions and engineering expertise, empowering operators to optimize performance and maximize efficiency in challenging offshore environments. Don't miss this opportunity to connect with ODSI at ONS and explore how our innovative solutions can drive success in your offshore operations. If you plan on attending, let us know, and we'd be pleased to schedule a time to connect!
- [EGYPES 2024](https://www.odsi-energy.com/egypes-2024/) - Join ODSI in Cairo, Egypt at EGYPES 2024, February 19-21, 2024. As the leader in Automated Real-Time Surveillance (ARTS) and engineering services, ODSI is at the forefront of revolutionizing how data is utilized to optimize operations. EGYPES offers a unique platform for industry leaders, cutting-edge technologies, and visionary strategies to converge, shaping the future of Egypt's energy sector. Join us as we showcase our latest ARTS solutions and engineering expertise, empowering operators to enhance productivity and drive efficiency across the entire value chain. Seize the opportunity to connect with ODSI at EGYPES 2024 and discover how our innovative solutions can elevate your operations. If you plan on attending, let us know, and we'd be pleased to schedule a time to connect!
- [APOGCE 2024](https://www.odsi-energy.com/apogce-2024/) - Join Oilfield Data Services, Inc. (ODSI) at the forefront of innovation and excellence at APOGCE 2024, the premier event for the Asia Pacific oil and gas community. As leaders in Automated Real-Time Surveillance (ARTS) and engineering services, ODSI is dedicated to revolutionizing the industry through cutting-edge technologies and unparalleled expertise. APOGCE provides a dynamic platform for industry leaders, innovators, and experts to converge, driving forward the future of energy exploration and production in the Asia Pacific region. Discover how ODSI's advanced ARTS solutions and engineering services can optimize your operations, enhance efficiency, and maximize productivity. Don't miss the chance to connect with ODSI at APOGCE 2024 and unlock the potential for success in your projects. Reserve your place now and meet our team in the heart of the Asia Pacific!
- [Just Calculating P.I. Doesn't Tell You What's Going On](https://www.odsi-energy.com/limitations-of-calculating-pi/) - Is a simple P.I. equation in well performance analysis sufficient? Consider that while changes in P.I. indicate performance shifts, it doesn't reveal the underlying reasons. This presentation delves into the limitations of the P.I. equation, highlighting factors like changing permeability, reservoir pressure, fluid properties, skin, and additional wellbore pressure drops. ODSI introduces methods for analyzing these changes, including data screening, analysis, and Nodal Analysis. The approach is geared towards identifying specific components affecting P.I., thus providing a more nuanced understanding of well performance beyond mere P.I. calculations on the validity of blind mapping models and the requirements for generating results.
- [Failed Subsea Flow Meters - Wet Gas Wells - North Sea](https://www.odsi-energy.com/failed-subsea-flow-meter-wet-gas-wells-north-sea/) - The successful application of Oilfield Data Services Inc.'s (ODSI) Virtual Metering solution, with failed subsea flow meters in two North Sea wet gas wells, saved the operator at least $4 million per well by avoiding the installation of subsea multiphase flow meters (MPFMs). This case study delves into the use of the Well Analyzer Automated Real-Time System (ARTS) for real-time well performance monitoring, including automated rate calculations, PVT adjustments, and pressure transient analysis. This approach helped in accurately calculating gas rates, detecting errors in allocations, and meter calibration. The solution was particularly effective in optimizing field development and net present value (NPV), as well as in the ongoing surveillance and analysis of well performance.
- [Reservoir and Production Engineering Surveillance & Management Course Webinar](https://www.odsi-energy.com/reservoir-production-engineering-surveillance-course-webinar/) - This extensive resource on reservoir and production engineering surveillance and management covers topics such as the importance of proactive surveillance, understanding and analyzing well and reservoir performance, and managing assets to maximize net present value and reserve recovery. The presentation includes an outline of the training, case studies in different contexts (like deepwater oil wells and shale wells), and detailed discussions on effective surveillance practices, identifying and dealing with data issues, and the application of various engineering principles and models in surveillance. There are specific sections on understanding reservoir volumes, pressure drop in a system, and well performance analysis.
- [High Skin or Bad BHP - Phase-thermal effects and PTA (Gas Condensate, Offshore North Sea)](https://www.odsi-energy.com/high-skin-or-bad-bhp-phase-thermal-effects-and-pta-gas-condensate-offshore-north-sea/) - This particular application of the ODSI Well Analyzer employed a direct numerical integration to the Mechanical Energy Balance equation for real-time surveillance of a subsea gas condensate well in the North Sea. Well Analyzer validated the metered gas rate, calculated bottom hole pressure (BHP) at mid-perforation depth, and evaluated the well as a potential candidate for stimulation. The study found that all downhole pressure gauges (PDHGs) had failed, and the analysis was based on historical data. The results demonstrated less than 1% error between measured and calculated gas rates and less than 2 psi error in BHP calculations, using wellhead pressure (WHP) and the calculated gas rate. It also highlights ODSI’s solution for accounting for phase-thermal changes in the wellbore. Ultimately, ODSI found that the well was not a stimulation candidate, emphasizing the importance of valid mid-perf BHP in pressure transient analysis (PTA) to avoid misinterpretation of well conditions, such as overestimation of permeability and skin, or underestimation of reservoir pressure.
- [Well Analyzer for Producing Oil and Gas Wells](https://www.odsi-energy.com/well-analyzer-for-producing-oil-and-gas-wells/) - This exploration of the ODSI Well Analyzer demonstrates enhanced production and reservoir surveillance in producing oil and gas wells. Automated Real-Time Surveillance (ARTS) enables both real-time and historical data analysis. These capabilities are highlighted across five case studies: Offshore Australia, Gas Condensate Well. Focused on continuous gas rate calculation and PVT tuning/liquid yield calibration. North Sea, Gas Condensate Well. Emphasized the importance of mid-completion BHP conversion and well test analysis. North Sea, Wet Gas Subsea Wells. Showcased the ability to calculate individual gas rates and perform auto-PTA. Gulf of Mexico, Gas Condensate Well. Involved validation and modeling of separator rates and BHP conversion from WHP data. Gulf of Mexico, Subsea Deepwater Oil Well. Centered on validating metered rates and determining the origins of water production. Read on to learn how the ODSI Well Analyzer comprises comprehensive capabilities for enhancing the understanding and management of well and reservoir performance.
- [Predicting the Arrival of an Interference Response in a Direct Communication Test](https://www.odsi-energy.com/predicting-interference-response-direct-communication-test/) - This comprehensive resource discusses methods for predicting the arrival of an interference response in a direct communication test. It covers types of interference tests, reservoir physics, and assumptions, along with case studies and mathematical modeling. The presentation aims to provide a deeper understanding of interference responses in direct communication tests, focusing on variables that significantly affect the results and those that do not.
- [Real-Time Surveillance of Gas Condensate Well (Offshore Australia)](https://www.odsi-energy.com/real-time-surveillance-of-gas-condensate-well-offshore-australia/) - In this application of the Well Analyzer Automated Real-Time Surveillance (ARTS) for monitoring a gas condensate on a North West Shelf (NWS) Australia gas condensate well, ODSI highlights the use of ARTS for continuous rate and BHP calculations, automated PVT tuning, and oil rate calculation at stock tank conditions. The results showcase accurate gas rate calculation, condensate yield recalibration during shut-ins, and effective real-time auto PTA calibration, emphasizing the system's capability to manage well and reservoir performance with high accuracy.
- [Gas Injector Surveillance - Offshore Australia](https://www.odsi-energy.com/gas-injector-surveillance-offshore-australia/) - ODSI focused on the use of the Well Analyzer Automated Real-Time Surveillance (ARTS) for surveillance of a gas injector well in Offshore Australia. Key features included automated rate calculations, PVT adjustments, pressure transient interpretation, and monitoring of recoverable hydrocarbon volumes. The system enabled real-time performance optimization and included capabilities for identifying issues like wax hydrates, asphaltenes, and corrosion. The results from the surveillance of the gas injector highlighted the accuracy and effectiveness of the ARTS program in managing well and reservoir performance.
- [Developing an Early-Warning System for Well/Reservoir Problems](https://www.odsi-energy.com/developing-early-warning-system-for-well-problems/) - At the SPE API Technical Luncheon, ODSI presented: Developing an Early-Warning System for Well/Reservoir Problems. This presentation discussed the advanced methodologies for identifying and addressing issues in well and reservoir operations. It focused on the integration of real-time data acquisition, processing, and visualization, along with the application of various analytical and evaluation tools. The speaker, Chris Fair, delved into the complexities of wellbore, completion, and reservoir systems, emphasizing the importance of accurate data interpretation and decision-making for early problem detection and efficient reservoir management.
- [Closed Loop Wellbore Components](https://www.odsi-energy.com/closed-loop-wellbore-components/) - "Closed-Loop WB Components" focused on wellbore thermal modeling and its components. It explored various aspects like liquid drop out, liquid surge during startup, phase behavior calculations, and rate modeling. Key areas include developing thermal and PVT models, using temperature and pressure surveys to tune these models, and understanding the continuity equation and mechanical energy balance in different phases. The presentation emphasized the importance of accurate modeling in understanding and managing wellbore dynamics, particularly in multi-phase flow conditions.
- [Well Testing for G&G Guys (and Gals)](https://www.odsi-energy.com/well-testing-for-g-and-g-presentation/) - Chris Fair provides a comprehensive overview of well testing principles and techniques, tailored for geologists and geophysicists in this presentation. It focused on explaining well test interpretation, including the analysis of pressure and rate data to understand well and reservoir behavior. The presentation demystified common terms and concepts in well testing, such as permeability, skin, and damage, and discusses how these factors impact well performance. The goal was to bridge the gap between geological understanding and well test data, enhancing interdisciplinary collaboration in reservoir management.
- [Using Automated Well/Reservoir Surveillance to Enhance Productivity - CIO Review 2019](https://www.odsi-energy.com/cio-review-2019/) - The CIO Review 2019 features ODSI (Oilfield Data Services Inc.), highlighting its innovative approaches in the oil and gas industry. The article focuses on ODSI's advanced data management and analysis tools that cater to the specific needs of the oil and gas sector. The article discusses how ODSI leverages technology to optimize well performance and enhance decision-making processes. It provides insights into ODSI's strategies and solutions, demonstrating their impact on the efficiency and productivity of oil and gas operations.
- [A Systemic Approach to Evaluate the Sanding Potential Caused by Formation Shear Failure in Unconsolidated Oil and Gas Reservoirs](https://www.odsi-energy.com/a-systemic-approach-to-evaluate-the-sanding-potential-caused-by-formation-shear-failure-in-unconsolidated-oil-and-gas-reservoirs/) - ODSI dives into the critical issue of sand production in oil and gas extraction from unconsolidated reservoirs. Bryan Baptista, ODSI, details both microscopic and macroscopic shear failures that contribute to sand production, presents a variety of methodologies for quantifying sanding potential, and incorporates case studies for practical illustration. The presentation concluded with recommendations on how to manage these challenges to optimize recovery and minimize operational risks, emphasizing the importance of both qualitative and quantitative assessments in decision-making processes for well completion strategies.
- [Automated Real-Time Reservoir & Production Engineering Analysis and Surveillance](https://www.odsi-energy.com/automated-real-time-reservoir-production-engineering-analysis-and-surveillance/) - Hear about the implementation and advantages of Oilfield Data Services Inc.’s (ODSI) Automated Real-Time Service (ARTS). ARTS combines physics-based models, automation, and expertise from surveillance engineers to optimize production and maximize EUR. These case studies outline how ARTS provides real-time insights on well and field key performance indicators, enabling proactive management of production systems. It highlights the integration of real-time data analysis for detecting issues, ensuring flow assurance, and facilitating decision-making to improve production efficiency and recovery rates.
- [Deepwater Case Studies of Automated Real-Time Surveillance](https://www.odsi-energy.com/deepwater-case-studies-automated-real-time-surveillance/) - These slides present an in-depth examination of advanced techniques in reservoir engineering, exploring the practical application of these techniques through detailed case studies, specifically focusing on deepwater environments. The presentation highlights the integration of data analysis, modeling, and technological innovations in understanding and optimizing reservoir performance. Emphasis is placed on the challenges and solutions unique to deepwater reservoirs, underscoring the importance of precise data interpretation and decision-making in complex geological settings. Further topics include time-lapse auto-PTA, sand failure pressure from mobility-thickness decay, and formation evaluation ("sanding potential"). Case studies culminate, demonstrating: A $130 million spend on a well intervention was avoided by more accurately assessing the source of a sudden increase in water production. Assessment of a well for a stimulation candidate based on a high skin or bad BHP conversion determination. Analysis of a gas condensate well in offshore Australia with changing yield, where condensate yield was re-calibrated during shut-ins and oil rates were adjusted accordingly, BHP was calculated accurately at the mid-completion depth, and new transients were recognized, and a PTA report generated for each test.
- [Blind Reservoir Mapping](https://www.odsi-energy.com/blind-reservoir-mapping/) - During the first few days and weeks of a well’s production life, we use the drawdown data to determine the distance to and the type of boundaries (fault, strat, OWC, etc.) that are encountered in the reservoir. We perform this analysis WITHOUT seeing the map first. Seeing the map first or imposing a bounded region on the data creates bias. Bias leads to bad decisions. In addition to the location of and types of boundaries, ODSI can also perform a boundary volumetric on the area observed (times the hydrocarbon-porosity thickness function) to determine the in-place hydrocarbons. This value can then be compared to the In-place volumes observed via Static MBAL or the Connected and Mobile hydrocarbon volumes obtained from decline analysis. The document provides examples of blind energy mapping, emphasizing the importance of integrating pressure/rate data in reservoir evaluation, and concludes with a discussion on the validity of blind mapping models and the requirements for generating results.
- [How Much Money Do You Have Left in the Ground?](https://www.odsi-energy.com/how-much-money-do-you-have-left-in-the-ground/) - Dive into a comprehensive look at evaluating hydrocarbon volumes in reservoirs to enhance financial decisions. In this presentation, ODSI outlines the use of Well Analyzer ARTS for real-time and historical data analysis, emphasizing the importance of understanding mobile reservoir volume. This case study demonstrates the application of this technology in determining connected and producible hydrocarbon volumes, ultimately aiding in maximizing economic return from oil and gas assets.
- [VFM/Sudden Water Production in a Deepwater Oil Well](https://www.odsi-energy.com/vfm-sudden-water-production-in-a-deepwater-oil-well/) - Oilfield Data Services Inc. (ODSI) was brought in to diagnose the root cause(s) of sudden water production (zero to 4000 BWPD almost overnight!) in a deepwater subsea GOM oil well. Using the tree gauge and the downhole gauge to perform multi-phase rate calculations, independently of the MPFM. ODSI also performed automated PTA and additional reservoir evaluation work to determine that produced water was extraneous and would not affect the recovery from the reservoir, concluding that an intervention was not warranted. The findings emphasize the importance of accurate meter calibration and thorough reservoir evaluation to understand unexpected production behaviors, highlighting the necessity of integrating real-time data analysis for effective reservoir management and decision-making. ODSI saved the client $130 MM in well intervention costs by conducting this investigation.
- [Water Injector Demo](https://www.odsi-energy.com/water-injector-demo/) - At the Data Driven Production Conference in Aberdeen, November 2017, Chris Fair discussed the development of advanced surveillance systems in oil and gas production. The presentation addresses the critical need for accurate instrumentation, data transfer, and analysis in these systems. It emphasizes the importance of integrating various components like SCADA, database management, and wellbore physics, along with tackling cultural impediments and biases in decision-making. This presentation offers insights into enhancing reservoir and production monitoring through a data-driven approach, focusing on maximizing net present value (NPV) and optimizing asset management.
- [Well Analyzer for Conventional Horizontal Oil Wells, Gas Condensate Wells, and Injector Wells](https://www.odsi-energy.com/well-analyzer-conventional-horizontal-oil-wells-gc-injector/) - The analysis of Well Analyzer (WA) applications in conventional horizontal oil wells were focused on gas condensate (GC) and injector wells. This particular study showcases Well Analyzer's automated real-time surveillance capabilities in real-time data analysis and decision-making. Case study highlights include: Subsea Horizontal Oil Producer with Water Injection: Demonstrates rate calculations and diagnostic pressure transient analysis (PTA). Horizontal Water Injector: Highlights wellbore calculations and the effectiveness of remedial procedures. Vertical Gas Injector: Focuses on gas storage and wellbore integrity. Multi-Phase Horizontal Producer (Oil, Gas, and Water): Analyzes phase separation and well performance. Multi-Zone Completion with Weak Water Drive: Examines water drive mechanisms and production optimization. Read on for a comprehensive view of utilizing the ODSI well analyzer in enhancing oil and gas production efficiency and well performance.
- [Using the Wellbore as a d/p Meter to Calculate Gas Rate](https://www.odsi-energy.com/wellbore-as-a-d-p-meter-to-calculate-gas-rate-paper/) - The common use of high-resolution tree gauges and downhole permanent pressure/temperature gauges has made it possible to use the measured pressure drop in the wellbore to directly and accurately calculate the gas rate. This is accomplished by first combining an equation of state with a dynamic heat transfer model to create a phase-thermal model (PTM). The PTM is then integrated with a direct solution to the mechanical energy balance (MEB) for flow in pipes. The results obtained using this technique can be as accurate as, or in some cases more accurate than, conventional rate measurements. Since the wellbore may also be used for fluid density validation, the effective gas gravity (an input for many conventional flow rate calculations) may also be determined during shut-ins and used as an input to improve the accuracy of meter provers. The purpose of this paper is to explain the physics behind the gas rate calculation and to present case study results from the implementation of this method in both real-time and historic data processing. The paper will also discuss the limitations of this method and the range of potential applications.
- [LAGCOE 2022](https://www.odsi-energy.com/lagcoe-2022/) - Energy Fest 2022, hosted at the Cajundome & Convention Center in Lafayette, LA, from October 19-21, was a vibrant, festivalized expo aimed at leading the energy industry into the future. It featured a lively show floor for networking, educational experiences, and discussions on collaborative energy production and delivery. This event highlighted cultural, innovative, and sustainable approaches within the energy sector, reflecting LAGCOE's 67-year history of witnessing and contributing to the industry's transformation.
- [APOGCE 2023](https://www.odsi-energy.com/apogce-2023/) - The SPE Asia Pacific Oil & Gas Conference and Exhibition (APOGCE) 2023 took place in Bali from October 10-12, showcasing the latest developments in the oil and gas sector. The event brought together international exhibitors and professionals to discuss industry trends, technologies, and solutions related to the oil and gas sector.
- [ATCE 2023](https://www.odsi-energy.com/atce-2023/) - The SPE Annual Technical Conference and Exhibition (ATCE) 2023, a leading technical energy conference for global exploration and production professionals, focused on innovation and technology developments in the upstream industry, paving the way for sustainable solutions and growth. Held at the Ernest N. Morial Convention Center in New Orleans, Louisiana, it brought together a diverse community of professionals to discuss the future of energy. ODSI exhibited and participated in the event.
- [Webinar: Reservoir and Production Engineering Surveillance & Management](https://www.odsi-energy.com/webinar-reservoir-and-production-engineering-surveillance-management/) - As a leader in Reservoir & Production Engineering Surveillance, ODSI hosted a webinar on June 16, 2023 from 8:00 AM - 12:00 PM. The webinar highlighted President Chris Fair's Industry Insight Presentation from SPE's ATCE 2022.
- [AOG 2023](https://www.odsi-energy.com/aog-2023/) - The 2023 AOG Energy Conference, held in Perth, Australia, focused on the evolution of the energy industry towards clean energy supply capabilities, highlighting the sector's innovation and the diversification of exhibitors' clean energy offerings. It marked a significant step for Australia's energy sector, showcasing technological advancements and promoting diversity and inclusion, including a special focus on Aboriginal business capabilities. The event, revitalized after pandemic disruptions, aimed to connect current industry players with future energy opportunities, reflecting the dynamic changes within the energy landscape.
- [IPTC 2023](https://www.odsi-energy.com/iptc-2023/) - The International Petroleum Technology Conference (IPTC) 2023 was held from March 1-3 in Bangkok, Thailand, emphasizing the theme of "Balancing the Energy Landscape through Innovation and Sustainability." It served as a premier multidisciplinary technical event in the Eastern Hemisphere, showcasing new technology, best practices, and multi-disciplinary activities to emphasize the importance of the value chain and asset value maximization. Oilfield Data Services Inc. (ODSI) attended to engage with the latest industry trends, innovations, and networking opportunities, aligning with the conference's focus on technology and sustainability in the petroleum sector.
- [EGYPS 2023](https://www.odsi-energy.com/egyps-2023/) - The Egypt Petroleum Show (EGYPS) 2023, hosted in Cairo from February 13-15, emerged as a pivotal platform for advancing the dialogue on energy security and climate action amid the global energy transition. The event underscored sustainable energy production, energy transition, decarbonization, and strategies for achieving a net-zero future. President Chris Fair presented, "How to Use AutoPTA", "Creating Dashboards and Threat Arrays from Surveillance Data", & "Using WaveX Methods to Create a 'Blind Map' of the Reservoir Boundaries". The gathering facilitated critical conversations on leveraging the Eastern Mediterranean's role in global energy supply and spotlighted innovations and policies aimed at fostering a resilient and sustainable energy sector.
- [APPEA 2023](https://www.odsi-energy.com/appea-2023/) - The APPEA Conference and Exhibition 2023, held from May 15-18 in Adelaide, Australia, focused on "Lead, Shape, Innovate – Accelerating to Net Zero." It aimed at addressing the dual challenges of ensuring energy security and reducing emissions. As the largest annual upstream oil and gas event in the Southern Hemisphere, it featured discussions on the industry's decarbonization efforts and net-zero emissions goal. The conference attracted key industry leaders, government representatives, and decision-makers, offering insights through strategic keynotes that address technical and business streams.
- [ONS 2022](https://www.odsi-energy.com/ons-2022/) - The ONS - Offshore Northern Seas 2022 conference, held from August 29 to September 1 in Stavanger, Norway, evolved from focusing solely on the North Sea to encompassing broader aspects of the Norwegian Continental Shelf and global offshore energy sectors. It's known for gathering international participants to discuss advancements, challenges, and opportunities in energy production and transportation, reflecting the industry's dynamic shift towards more sustainable practices.
- [The Effect of Wellbore Temperature Changes and Frictional Losses on Well Test Interpretation Results](https://www.odsi-energy.com/wellbore-temperature-changes-frictional-losses-well-test-interpretation-results/) - With the widespread use of downhole pressure gauges (DHPGs) to measure and record downhole pressures in oil and gas wells, engineers have been able to eliminate/reduce the wellbore effects that can mask true reservoir response. However, not every well is equipped with a downhole gauge; even fewer have the downhole gauge at the mid-completion depth, leaving fluids below the gauge that are subject to frictional pressure drop and changing fluid density/head due to heating/cooling. The reservoir signal (delta pressure vs. time) can be slightly masked or completely overwhelmed by the change in pressure head due to changing fluid density as the well bore fluids cool or heat up. The resultant measured rate of pressure change will, therefore, not be representative of the actual reservoir response. In addition, frictional pressure loss as fluids travel up the well bore can appear as pressure loss due to completion skin. This causes wells to have an artificially high skin. using raw pressure data that has not been accurately corrected for changing fluid head/density and frictional losses below the gauge can lead to inaccurate pressure-transient analysis (PTA) results (Hasan 199). This paper will discuss the physics of these processes and explain the reasons for these errors in the PTA results, along with the impact of these errors. Finally, a method for properly correcting the measured pressure to mid-completion pressure will be described. To demonstrate the effects, case studies conducted on two gas wells, a gas-condensate well, and an oil well will be presented.
- [The Propagation of Depletion - The Inclusion of Inertia in the Derivation of the Diffusivity Equation](https://www.odsi-energy.com/odsi-inertia-derivation-diffusion-equation-paper/) - When flow is initiated from a well, a physical shock front is created in the reservoir, beginning at the completion. This shock front moves out into the reservoir as a Mechanical Wave with constant intensity and with velocity decreasing vs. the square of the distance. This is known as infinite acting radial flow (aka ‘transient flow’) and is very well understood (at least at the producing well’s location). The capillary shockwave represents a moving boundary to the pressure decay field that forms around the well (Hurst 1934). This active region of decay behind the moving shock front will adopt a near semisteady state flow regime in the reservoir, as required by the second law of thermodynamics. This depletion region is composed of radial capillaries that produce flow to the well and create pressure or elastic depletion in the reservoir. The cone of influence or region of pressure depletion bounded by the shock front around the well is the active reservoir at any given time. Eventually, the capillary shockwave boundary condition at the radius of investigation will either encounter all of the reservoir boundaries or will continue to grow into an aquifer. Energy is redistributed by a faster-moving inertial wave that passes through the open capillaries. Each capillary has finite rupture strength due to the same initiating capillary pressure that produces the bounding shockwave (Goldsberry 1998, 2000). Hence the cone of influence can be recognized as a structure composed of radiating capillaries behind a moving boundary condition. Each capillary is considered an individual contributor to the flow to the well, and each capillary has a contribution to flow that is in proportion to its volume (Goldsberry 1998). When a capillary reaches a sealing boundary, it ceases to grow and contributes less to the flow of the well than the capillaries that are still growing. Since the well is generally controlled by a choke, the demand upon the cone of influence is constant. This creates an imbalance in the second law of thermodynamics. In order to reconcile this imbalance, the choke-well interaction then produces a secondary cone of influence bounded by its own capillary shockwave boundary condition. The goal of this paper is to describe the primary shockwave boundary condition and the inertial waves that produce pressure redistribution within the cone of influence. Traditionally, the inertial term is ignored in order to create a simplified diffusion equation model. It is not zero. Furthermore, in the classic diffusivity derivation (Earlougher 1977), the capillary entry pressure is assumed to be small and hence neglected. It is also not zero. By excluding these terms in the classic derivation, the result is a simplified model that works for infinite acting radial flow at the producing well location, but does not 2 match observation well data, nor producing well data after the first boundary is encountered. If both inertia and capillary entry/threshold pressure are included in the derivation for the diffusivity equation for transient flow, a model that is based upon a capillary structure emerges, which predicts (and matches real field data) a depletion region that grows predictably with time, with distinct boundary contacts and arrivals of primary and secondary shock fronts.
- [A Systematic Approach to Evaluate Sanding Potential Caused by Formation Shear Failure in Unconsolidated Oil and Gas Reservoirs](https://www.odsi-energy.com/evaluate-sanding-potential-caused-by-formation-shear-failure/) - This article will address two issues related to sand production in unconsolidated reservoirs. First, it will examine the relationship between formation compressibility (Cf), elastoplastic hysteresis, and the shear failure of the formation macroscopically (when the fluid and formation pressure together cannot support the overburden stress), as well as the methodology to predict this failure pressure. Second, it will explore the means to recognize which formations are more friable and likely to produce sand grains – microscopic shear failure. The two effects are only tangentially related but can occur simultaneously. Logs and petrophysical data should be methodologically used to qualitatively and quantitatively assess the sanding potential of a well or reservoir. The first method is evaluating the compressibility of formation rocks as they first demonstrate elastoplasticity, and then have catastrophic shear failure. The other method evaluates the sanding potential based on the friability of the formation. The most effective way to manage/mitigate catastrophic/macroscopic shear failure is to observe the dynamic behavior of the reservoir. By plotting the build-up permeability vs. skin-less FBHP, the failure pressure of the formation can be determined. Good operating practices then dictate that the well should not be flowed at pressures below the value plus a safety factor. The approach to managing potential sand grain failure (microscopic shear failure) is to design the completion (frac-pack, gravel pack, etc.) to collect the sand grains in the pack and screens, then perform periodic pump-in stimulation treatments to push the fines away from the screens/pack. Two examples, each from the Gulf of Mexico and the Louisiana Gulf Coast, will be presented to demonstrate the methodology for both macroscopic and microscopic shear failure. It should be noted that it is important to differentiate the cause of sand production/fines migration as one of the two (macro/micro) causes. This can be determined by tracking the accretion of skin due to fines. If this occurs coincident with a decrease in permeability or mobility thickness, it should be assumed that the cause is macroscopic shear failure. If the permeability remains constant as skin due to fines increases, it is due to microscopic shear failure. Technically, both mechanisms can occur simultaneously, but it is best to approach the issue conservatively and assume that any increase in skin due to fines that occur with a decrease in mobility thickness is due to macroscopic shear failure. Applying the sanding potential systematically to formation evaluation can improve the completion design; predicting the macroscopic shear failure pressure of the formation contributes to better overall reservoir management.
- [Pitfalls of Surface Well Test Analysis - Guidelines](https://www.odsi-energy.com/pitfalls-surface-well-test-analysis-guidelines/) - Abstract Pressure Transient Analysis (PTA) provides valuable information about the subsurface completion and reservoir. Permanent downhole pressure gauges (PDHG) are not always available in wells. In such cases, wellhead pressure (WHPG) gauges or temporary downhole gauges (DHG) can be used to perform reservoir/ completion diagnostics. Although in some cases, it is safe to use raw WHP data for analysis, in a lot of cases, it should not be done. Fair et al. (2002) presented a methodology to categorize wells that could be tested from the surface (well head) along with a methodology that allows surface-to-bottomhole pressure (BHP) conversion. A few authors in the past have emphasized the importance of converting wellhead pressure and downhole gauge pressure data to mid-completion bottomhole conditions to account for friction and changing fluid density during a test. Performing PTA without correcting the gauge data for these wellbore effects can lead to inaccurate results: especially the over-estimation of skin and permeability, and underestimation of P*, and in-place hydrocarbon volumes, due to reservoir signal suppression. The WHP data could also be nonanalyzable (using conventional methods) if the effects are severe. Hakim et al. (2016) further discussed the importance of this conversion and presented examples where WHP to BHP conversions in various types of wells could be performed with high accuracy using a coupled PVT-thermal wellbore model. This paper will introduce the concept of rate of change in wellbore fluid density (wellbore signal) relative to the rate of reservoir pressure increase/decrease (reservoir signal) during a test. The purpose is to identify the factors affecting the "reservoir signal" in the measured wellhead pressure and rate data during a well flowback and during the commercial production period and to provide guidelines to help the petroleum engineer determine the severity of these factors in a given well/reservoir system. This should help the petroleum engineer in deciding whether to rely on the WHP data or run a DHG to observe the reservoir signal. A 3-step methodology to determine the magnitude of the wellbore signal relative to the reservoir signal will be presented with solved examples of an oil well and a gas-condensate well.
- [Frac Replay Analysis - What, How, and Why?](https://www.odsi-energy.com/frac-replay-analysis/) - Delve into the methodologies and benefits of analyzing hydraulic fracture stimulation in oil and gas wells, emphasizing the importance of utilizing data from fracturing processes to improve future operations. This presentation covers: The concept of Frac Replay Analysis, using vast amounts of data from fracturing. Techniques for analyzing post-treatment data, including pressure, volume, rate, and proppant concentrations. Steps for conducting analyses, such as data importation, building geomechanical models, and pressure matching. The significance of MiniFrac analysis in understanding rock properties and fracture geometry. The role of Frac Replay Analysis in optimizing fracture designs and maximizing the return on investment for field plans.
- [BHP Mid Completion](https://www.odsi-energy.com/bhp-mid-completion/) - Aside from their main solution, ARTS, ODSI also provides solutions for other deepwater well issues. In this case, ODSI was brought in to analyze bottom hole pressure (BHP) in a well with failed downhole gauges. The study used surface data to calculate BHP at various depths, including mid-completion, and compared these results to historical data. Key objectives included validating metered rates and evaluating the well as a potential candidate for stimulation. The results demonstrated high accuracy in rate calculations and BHP conversion, leading to the conclusion that the well was not a stimulation candidate. The study underscores the importance of accurate BHP data in well analysis.
- [Diagnostic Time-Lapse PTA - Deepwater GOM Well](https://www.odsi-energy.com/diagnostic-time-lapse-pta-deepwater-gom-well-2/) - This demonstration of ODSI's Automated Time-Lapse Real-Time Pressure Transient Analysis (PTA) was focused on a deepwater Gulf of Mexico oil well. It emphasized the tool's ability to perform PTA and track key performance indicators over time consistently. The presentation showcases a case where scale and asphaltene issues were identified, leading to a stimulation job that improved productivity index by 300% and reduced skin from 40 to 5, demonstrating the effectiveness of this diagnostic approach in well performance enhancement.
- [OILFIELD DATA SERVICES INC. (ODSI) - The Inclusion of Inertia in the Derivation of the Diffusivity Equation](https://www.odsi-energy.com/odsi-inertia-derivation-diffusion-equation-video/) - When flow is initiated from a well, a physical shock front is created in the reservoir, beginning at the completion. This shock front moves out into the reservoir as a Mechanical Wave with constant intensity and with velocity decreasing vs. the square of the distance. This is known as infinite acting radial flow (aka ‘transient flow’) and is very well understood (at least at the producing well’s location). The capillary shockwave represents a moving boundary to the pressure decay field that forms around the well (Hurst 1934). This active region of decay behind the moving shock front will adopt a near semisteady state flow regime in the reservoir, as required by the second law of thermodynamics. This depletion region is composed of radial capillaries that produce flow to the well and create pressure or elastic depletion in the reservoir. The cone of influence or region of pressure depletion bounded by the shock front around the well is the active reservoir at any given time. Eventually, the capillary shockwave boundary condition at the radius of investigation will either encounter all of the reservoir boundaries or will continue to grow into an aquifer. Energy is redistributed by a faster-moving inertial wave that passes through the open capillaries. Each capillary has finite rupture strength due to the same initiating capillary pressure that produces the bounding shockwave (Goldsberry 1998, 2000). Hence the cone of influence can be recognized as a structure composed of radiating capillaries behind a moving boundary condition. Each capillary is considered an individual contributor to the flow to the well, and each capillary has a contribution to flow that is in proportion to its volume (Goldsberry 1998). When a capillary reaches a sealing boundary, it ceases to grow and contributes less to the flow of the well than the capillaries that are still growing. Since the well is generally controlled by a choke, the demand upon the cone of influence is constant. This creates an imbalance in the second law of thermodynamics. In order to reconcile this imbalance, the choke-well interaction then produces a secondary cone of influence bounded by its own capillary shockwave boundary condition. The goal of this paper is to describe the primary shockwave boundary condition and the inertial waves that produce pressure redistribution within the cone of influence. Traditionally, the inertial term is ignored in order to create a simplified diffusion equation model. It is not zero. Furthermore, in the classic diffusivity derivation (Earlougher 1977), the capillary entry pressure is assumed to be small and hence neglected. It is also not zero. By excluding these terms in the classic derivation, the result is a simplified model that works for infinite acting radial flow at the producing well location, but does not 2 match observation well data, nor producing well data after the first boundary is encountered. If both inertia and capillary entry/threshold pressure are included in the derivation for the diffusivity equation for transient flow, a model that is based upon a capillary structure emerges, which predicts (and matches real field data) a depletion region that grows predictably with time, with distinct boundary contacts and arrivals of primary and secondary shock fronts.
- [Is it Well Bore or Reservoir? Understanding Re-injection Effects during a Well Test](https://www.odsi-energy.com/re-injection-effects-during-a-well-test/) - This article, first appearing in Hart's E&P Magazine, presents a comprehensive analysis of differentiating pressure changes due to wellbore effects from those caused by reservoir responses in pressure-testing of wells. It focuses on the complexities involved in testing gas/condensate or volatile oil wells, especially with downhole gauges. The paper delves into the phenomenon of liquid fallback and re-injection in gas/condensate reservoirs, illustrating the process through figures and test data from a Gulf of Mexico well. It emphasizes the importance of accurate test interpretation, addressing common misattributions of wellbore phenomena as reservoir effects. The study concludes with practical insights for analyzing well tests under challenging conditions, highlighting the critical need for understanding fluid behavior in both the wellbore and the reservoir for accurate well test analysis.
- [The Propagation of Depletion - The Inclusion of Inertia in the Derivation of the Diffusivity Equation](https://www.odsi-energy.com/odsi-inertia-derivation-diffusion-equation-presentation/) - When flow is initiated from a well, a physical shock front is created in the reservoir, beginning at the completion. This shock front moves out into the reservoir as a Mechanical Wave with constant intensity and with velocity decreasing vs. the square of the distance. This is known as infinite acting radial flow (aka ‘transient flow’) and is very well understood (at least at the producing well’s location). The capillary shockwave represents a moving boundary to the pressure decay field that forms around the well (Hurst 1934). This active region of decay behind the moving shock front will adopt a near semisteady state flow regime in the reservoir, as required by the second law of thermodynamics. This depletion region is composed of radial capillaries that produce flow to the well and create pressure or elastic depletion in the reservoir. The cone of influence or region of pressure depletion bounded by the shock front around the well is the active reservoir at any given time. Eventually, the capillary shockwave boundary condition at the radius of investigation will either encounter all of the reservoir boundaries or will continue to grow into an aquifer. Energy is redistributed by a faster-moving inertial wave that passes through the open capillaries. Each capillary has finite rupture strength due to the same initiating capillary pressure that produces the bounding shockwave (Goldsberry 1998, 2000). Hence the cone of influence can be recognized as a structure composed of radiating capillaries behind a moving boundary condition. Each capillary is considered an individual contributor to the flow to the well, and each capillary has a contribution to flow that is in proportion to its volume (Goldsberry 1998). When a capillary reaches a sealing boundary, it ceases to grow and contributes less to the flow of the well than the capillaries that are still growing. Since the well is generally controlled by a choke, the demand upon the cone of influence is constant. This creates an imbalance in the second law of thermodynamics. In order to reconcile this imbalance, the choke-well interaction then produces a secondary cone of influence bounded by its own capillary shockwave boundary condition. The goal of this paper is to describe the primary shockwave boundary condition and the inertial waves that produce pressure redistribution within the cone of influence. Traditionally, the inertial term is ignored in order to create a simplified diffusion equation model. It is not zero. Furthermore, in the classic diffusivity derivation (Earlougher 1977), the capillary entry pressure is assumed to be small and hence neglected. It is also not zero. By excluding these terms in the classic derivation, the result is a simplified model that works for infinite acting radial flow at the producing well location, but does not 2 match observation well data, nor producing well data after the first boundary is encountered. If both inertia and capillary entry/threshold pressure are included in the derivation for the diffusivity equation for transient flow, a model that is based upon a capillary structure emerges, which predicts (and matches real field data) a depletion region that grows predictably with time, with distinct boundary contacts and arrivals of primary and secondary shock fronts.
- [Using the Results from Automated Petroleum Engineering Calculations to Accelerate Decision Workflows](https://www.odsi-energy.com/automated-petroleum-engineering-calculations/) - With the advent and common usage of high-resolution tree gauges, downhole permanent pressure/temperature gauges, and continuous flow measurement, many of the common petroleum engineering calculations and analysis tools for production systems can and have been automated. These include a) Well Test Analysis, b) Well Productivity, and c) Static and Flowing Material Balances and Energy Balances. In addition, the use of rigorous wellbore thermal and phase behavior models allows the two gauges (wellhead and downhole) to be used as a giant differential pressure meter - making it possible to calculate gas rates and water cuts independently of the flow measurements, as well as mid-completion bottomhole pressure (BHP). The purpose of this paper is to present the basic physics involved in these calculations/analyses, as well as to discuss the implications that these processes will have on instrumentation selection and on engineering workflows. The crux of the argument for these types of automated systems is that it is much easier for an engineer to check the results than to spend his/her entire day just looking for useful information in the database and then analyzing it (or getting someone else to analyze it). Furthermore, being able to see the "big picture" - seeing what skin, perm, productivity, and apparent hydrocarbon reservoir volumes are now and how they have changed with time, allows engineers to make quicker, more accurate decisions. The use of automated analysis also reduces bias - the computer doesn't care what the answer is. This paper will also include several case studies for both oil and gas wells.
- [A Methodology for Reducing Bias in the Design & Evaluation of Hydraulic Fractures](https://www.odsi-energy.com/reducing-bias-design-evaluation-hydraulic-fractures-paper/) - The purpose of this paper is to present a framework to reduce bias in the design and evaluation of hydraulic fractures. When we mention “bias”, we are referring to human nature. If someone knows what the answer is supposed to be (what someone else wants or to provide a consensus), they are much more likely to provide that answer - even if it is not correct. In addition to frac design (and re-design after pre-frac tests), this process will be extended to the process of post-frac evaluation and the analysis of the frac flowback and other well tests. The process consists of three parts, to be done in isolation from each other. The first is the actual frac design. This includes the gathering of the geophysical and reservoir property information, the creation of the geo-mechanical model, the selection of equipment, and the execution design to meet the operator’s objectives. It also includes any re-design required based on DFIT/minifrac analysis performed prior to the frac. The second part is the review of the fracture operation, often called the Frac Replay. This is where the actual field data (rates, pressures, concentrations, etc.) and geo-mechanical model are used to simulate the pad and proppant placement and concentration in the fractured interval. The final part is an analysis of the frac flowback, as well as any subsequent well tests. If designed and executed properly, the flowback/well test data can provide independent validation of the effective fracture length, fracture efficiency, and drainage radius/volume. The reason for performing these three parts in isolation is that it utilizes service companies, consultants, and in-house experts to the operator’s advantage. If they are not performed independently, the answers are highly susceptible to a forced consensus, especially if the party doing the design or performing the frac job wants to demonstrate the effectiveness of their work. If the results of all three independent parts point to the same conclusions, the operator has more confidence in the outcome. If not, the differences can be examined with an eye to improving future designs and executions.
- [Engineered Flowback and Reservoir Evaluation for Unconventional Wells](https://www.odsi-energy.com/engineered-flowback-and-reservoir-evaluation-for-unconventional-wells-2/) - A flowback procedure is presented that uses a wellbore model coupled with thermal and fluid modeling to calculate the bottomhole pressure (BHP) and maximize the safe initial production/drawdown without over-stressing and damaging the fracture system. After obtaining the BHP, it is then possible to determine the fractured reservoir volume, fracture-dominated volume, and matrix contribution. The paper presents a case history validating the model calculations in an unconventional well. Two methods of decline analysis are presented, ‘Conventional’ and ‘Thermodynamic Transient Analysis’ (TTA), and together, these methods provide insights into the fracture system and overall reservoir volumes by recognizing and applying the appropriate equation for the proper reservoir flow regime. The early flowback period can be used to determine the frac volume, while later periods will begin showing the increasing amount of matrix contribution. The wellbore flow model and decline analysis calculations are verified by a case history presented in the paper, where this flowback process was utilized on a hydraulically fractured East Texas well. The wellhead pressures (WHPs) in this case study highlight the need to accurately calculate BHPs based on the WHP and rates, due to significant differences between the trends and decline rates of the respective pressures.
- [Subsea Well Testing at the Subsea Tree](https://www.odsi-energy.com/subsea-well-testing-subsea-tree/) - Operators are often presented with a dilemma when installing instrumentation in a subsea well. Do they install permanent downhole gauges? If so, is there a backup plan in the eventuality that the downhole gauge fails? In the past, when a downhole gauge on a subsea well failed, the backup plan has either been to “fly blind” or to rely on low-accuracy measurements from subsea tree gauges or pipeline gauges (which can also fail). While tree or pipeline gauges may be adequate to determine if the well is flowing, they are rarely of sufficient accuracy and resolution to optimize production from the well. The need for high-resolution, accurate pressure data is greatest in high permeability wells and in unconsolidated sandstones, where the production of sand can be catastrophic. In 2001, a solution to this problem was developed. It allows an operator to temporarily install a highly accurate pressure recording system on the well in order to perform diagnostic tests on the well bore, completion, and/or reservoir. This option is available to any subsea tree equipped with an Industry Standard “Hotstab” port. Typically, subsea trees are fitted with at least one female hotstab port conforming to ISO/CD 13628-8 enabling a remotely operated vehicle (ROV) to connect instrumentation specifically designed for this application. The ROV is then used to operate the isolation valves to allow well bore communication via the hotstab port. Once pressure communication with the well bore is established, diagnostic tests may begin. The purpose of this paper is to introduce a mobile high-precision, high-accuracy pressure recorder for pressure transient testing at subsea well heads. First, the instrument and subsea tree specifications will be discussed. Then, a detailed procedure for installing this instrument on the subsea tree will be presented. Next, the issue of wellhead to bottomhole pressure conversion will be addressed. Results from field tests with the system will be presented. This new tool makes it possible to test subsea wells in which downhole gauges were not installed or where they have ceased to operate. The tool has also proven useful for pressure integrity tests when commissioning sub sea pipelines.
- [Gas/Condensate and Oil Well Testing - From the Surface](https://www.odsi-energy.com/gas-condensate-oil-well-testing-surface/) - Since Cullender and Smith(1), surface pressures have been used to calculate bottomhole pressures on shallow, dry gas wells. If the original Cullender and Smith equations are modified to account for produced liquids, the correlation may be extended to gas/condensate wells that are single-phase in the well bore. Single-phase liquid wells (water injectors and oil wells above the bubble point) can also yield accurate well test results from the surface. Testing from the surface reduces the cost and eliminates the risk of running tools into well bores. Surface testing also allows the testing of high-pressure/high-temperature wells that cannot be tested with a downhole gauge because of harsh conditions. Thus, to reduce the cost and risk (or when no other option is available), many operators have chosen to run their pressure transient tests from the surface on single-phase wells. Recently, it has become possible to test most naturally- unloading gas/condensate and oil wells from the surface. This is due to advances in multi-phase wellbore modeling along with improved pressure transducer quality. Of these, the most important advances are the improvements in transducer manufacture and calibration that make it possible for a surface pressure gauge to be effectively isolated from ambient and wellbore thermal transients. Although the technology exists to get representative reservoir data from the surface, testing procedures in multi-phase wells have to take into account the fluid’s behavior in the well bore. With this in mind, the purpose of this paper is to propose guidelines for testing multiphase wells from the surface. First, the general framework of the surface-to-bottomhole pressure calculation will be presented. Next, multi-phase wells will be categorized based on the type of fluid and the behavior of the fluid both in the reservoir and in the well bore. This categorization will be the basis for both surface testing candidate selection and recommended test procedures. Afterward, wellbore phase and temperature modeling will be discussed. Next, instrumentation requirements will be presented. Finally, field data comparing calculated bottomhole pressures from surface gauges to measured bottomhole pressures from downhole gauges (and the subsequent analysis) will be presented for both a gas/condensate and an oil well. These examples will be used to demonstrate that in order to test a multi-phase well from the surface, a thermally compensated quartz pressure gauge must be used in conjunction with a properly designed and executed test procedure. An explanation will also be provided as to why the best test that can be performed on a well to determine skin, permeability, and the size of a reservoir is a constant-choke drawdown.
- [A Methodology for Reducing Bias in the Design & Evaluation of Hydraulic Fractures](https://www.odsi-energy.com/reducing-bias-design-evaluation-hydraulic-fractures-presentation/) - Review an in-depth analysis of the biases in hydraulic fracturing. This technical presentation emphasizes the importance of a systematic approach in frac design and evaluation, discussing the various types of biases commonly encountered. It elaborates on key strategies like engineered frac design, frac replay analysis, and thorough workflow optimization to minimize bias. It aims to enhance the accuracy and efficiency of hydraulic fracturing by focusing on data-driven and unbiased methodologies, thereby improving overall project outcomes in the field.
- [The Effect of Wellbore Temperature Changes and Frictional Losses on Well Test Interpretation Results](https://www.odsi-energy.com/wellbore-temperature-changes-frictional-losses/) - This presentation demonstrates the impact of wellbore dynamics on pressure transient analysis (PTA) in oil and gas wells. It emphasizes the importance of considering temperature gradients and frictional losses to accurately interpret well test data. Highlights include: The necessity of accounting for wellbore temperature changes and frictional losses, which are often overlooked in conventional PTA methods. The development of a semi-empirical method for converting downhole and surface gauge data to mid-completion bottomhole conditions. A detailed methodology for predicting wellbore temperature profiles as a function of fluid heat capacity over time. A series of case studies demonstrating the application of the methodology in various well types, including dry gas wells and gas-condensate wells. Read on for the significance of acknowledging these factors for more accurate well test interpretations and better reservoir management decisions.
- [Automated Production and Reservoir Surveillance Systems... and Why We Screw It Up!](https://www.odsi-energy.com/automated-production-and-reservoir-surveillance-systems/) - In his typically candid, often humorous style, Chris Fair dissects the often misguided attempts in the oil and gas industry to implement surveillance systems. He critiques the common missteps, like over-reliance on buzzwords and technologies without a solid understanding of fundamental physics, while emphasizing the need for meaningful data interpretation and decision-making. Fair's engaging style effectively highlights the pitfalls of jumping onto the big data bandwagon without a clear direction or understanding, making a strong case for a more thoughtful and informed approach in the industry.
- [Horizontal Fractured Wells](https://www.odsi-energy.com/horizontal-fractured-wells-presentation/) - This evaluation and optimization of horizontally fractured wells provides a comprehensive overview of the capabilities of Oilfield Data Services Inc. (ODSI). It covers the application of ODSI's proprietary technology for accurate bottom hole pressure (BHP) calculations, minimum and maximum recoverable oil volume estimations, and gas lift optimization. This presentation showcases ODSI's approach to well performance analysis, emphasizing the importance of data-driven decisions in maximizing well productivity and efficiency in the oil and gas industry.
- [Wavex: The Capillary Model](https://www.odsi-energy.com/wavex-capillary-model/) - "Wavex: The Capillary Model" delves into the technical nuances of the capillary model in the context of reservoir engineering. It provides a detailed exploration of the model's application in understanding and managing reservoir fluids dynamics. The focus of this presentation is the intricacies of fluid behavior within reservoirs and the importance of accurate modeling for effective reservoir management. The presentation combines theoretical aspects with practical applications, offering insights into the capillary model's significance in the field of reservoir engineering.
- [Wavex Introduction](https://www.odsi-energy.com/wavex-introduction-presentation/) - "Wavex: An Introduction" introduces the innovative Wavex technology in reservoir engineering. It emphasizes the application of Wavex in understanding reservoir dynamics, particularly focusing on its role in improving fluid flow analysis and reservoir characterization. The presentation blends theoretical concepts with practical applications, showcasing Wavex's utility in enhancing reservoir management and decision-making processes. Through this technology, the presentation underscores a significant advancement in the field, promising improved accuracy and efficiency in reservoir evaluations.
- [Monitoring Water Contacts Using Pressure and Flowrate Measurement](https://www.odsi-energy.com/water-encroachment-presentation/) - This presentation focuses on the advanced methodologies and technologies for monitoring water contacts in reservoirs using pressure and flowrate measurements. It delves into the WAVEX® technology, demonstrating its application in detecting reservoir boundaries and changes, including water contact movement. The presentation highlights the significance of pressure transient analysis in reservoir engineering, showcasing how WAVEX® enhances the understanding of reservoir dynamics and improves decision-making in reservoir management.
- [Water Production Detection (using surface and downhole gauges)](https://www.odsi-energy.com/water-production-detection-presentation/) - Explore the techniques for detecting water production in wells in this presentation. It emphasizes the fine-tuning of wellbore models and introduces three distinct methods for water detection: Temperature Response Analysis: A qualitative approach involving the comparison of measured wellhead temperatures with modeled temperatures to infer water production. Re-injection Cycle Method: This method leverages liquid fallback and re-injection cycles in gas wells to detect water production and calculate water yield. Flash Calculation: Utilizes pressure changes upon well shut-in to perform calculations that estimate liquid yield. These methodologies are critical in accurately identifying and managing water production in well operations, thereby enhancing reservoir management and operational efficiency.
- [ODSI's Automated Reservoir and Production Engineering Software](https://www.odsi-energy.com/odsi-automated-reservoir-and-production-software/) - Dive into an in-depth look at the implementation and benefits of automated reservoir and production engineering software. This presentation focuses on the effective integration of data processing, quality control, and modeling for reservoir evaluation. It covers critical aspects like bias in decision-making, surveillance strategies, and the application of various analysis techniques. This presentation highlights the importance of leveraging automated tools and data-driven approaches for optimized reservoir management and decision-making processes.
- [Well Evaluation Methods](https://www.odsi-energy.com/well-evaluation-methods-presentation/) - ODSI takes a comprehensive look into advanced well evaluation techniques in this presentation. It covered various methodologies including elementary well test analysis, decline analysis, inverse productivity analysis, and nodal analysis simulation. This presentation emphasizes the importance of distinguishing wellbore effects from reservoir phenomena and provides detailed insights into the practical aspects of well test planning and design. Additionally, it highlights advanced diagnostics and their role in enhancing the understanding and management of well and reservoir performance.
- [Building an Effective Reservoir and Production Monitoring System](https://www.odsi-energy.com/building-an-effective-reservoir-and-production-monitoring-system/) - At the Data Driven Production Conference in Aberdeen, November 2017, Chris Fair discussed the development of advanced surveillance systems in oil and gas production. The presentation addresses the critical need for accurate instrumentation, data transfer, and analysis in these systems. It emphasizes the importance of integrating various components like SCADA, database management, and wellbore physics, along with tackling cultural impediments and biases in decision-making. This presentation offers insights into enhancing reservoir and production monitoring through a data-driven approach, focusing on maximizing net present value (NPV) and optimizing asset management.
- [Getting Past the Buzz Words: Automated Production and Reservoir Surveillance Systems...And Why We Screw It Up!](https://www.odsi-energy.com/automated-production-and-reservoir-surveillance-presentation/) - At the Data Driven Drilling & Production Conference, Chris Fair focused on the challenges and potential pitfalls in the implementation of automated production and reservoir surveillance systems in the oil and gas industry. This presentation critically examines the industry's tendency to get caught up in buzzwords and sophisticated technologies without a fundamental understanding of the underlying physics. The presentation emphasizes the importance of meaningful data interpretation, effective decision-making, and the need for a shift in organizational culture and decision-making processes to benefit from technological advancements truly.
- [Augmenting the Production Capabilities of Oil and Gas Companies](https://www.odsi-energy.com/augmenting-production-capabilities/) - The article from Energy Tech Review focuses on the 10th anniversary of ODSI's real-time well/reservoir evaluation package, Well Analyzer-RTS. It highlights ODSI's journey in automating reservoir and production engineering calculations, the challenges of getting engineers to actively use the system, and the steps taken to ensure its effective implementation. The article underscores the importance of proactive surveillance and the integration of in-house engineers for training and value creation. The piece also touches on the broader industry context, discussing the role of digitalization and data analysis in oilfield management.
- [Engineered Frac'd Well Flowbacks & Reservoir Evaluation](https://www.odsi-energy.com/engineered-fracked-well-flowbacks-reservoir-evaluation/) - This comprehensive overview of engineered flowback processes in fractured wells emphasizes reservoir evaluation. Various case studies are included, each focusing on different aspects of the process: 3-Phase Horizontal WHPs Analysis: Examines wellhead pressures in a three-phase horizontal well, focusing on the relationship between modeled production rates and calculated bottom hole pressures (BHP). Minor & Major Frac Stage Cleanups: Discusses the detection and management of cleanup surges and obstructions, highlighting how wellhead pressures are influenced by various operational conditions. Evaluating Stress on the Proppant/Fracture-Dominated Region: Explores methods to assess the stress on proppant in the fracture-dominated region of the well, using historical data and analytical models. Each case study contributes to a deeper understanding of the complexities involved in managing and evaluating fractured wells, emphasizing the importance of precise measurement and analysis in optimizing well performance.

## Pages

- [](https://www.odsi-energy.com/) - Oilfield Data Services Inc. is a specialized engineering firm that automates real-time surveillance for the toughest reservoir and production challenges.
- [Contact Us](https://www.odsi-energy.com/contact-us/) - [et_pb_section fb_built=”1″ _builder_version=”4.23.4″ background_image=”https://www.odsi-energy.com/wp-content/uploads/2024/01/Generic-Banner-1-scaled.jpg” height=”300px” custom_margin=”||||false|false” global_colors_info=”{}”][et_pb_row _builder_version=”4.23.4″ _module_preset=”default” global_colors_info=”{}”][et_pb_column type=”4_4″ _builder_version=”4.23.4″ _module_preset=”default” global_colors_info=”{}”][et_pb_text _builder_version=”4.24.0″ _module_preset=”default” header_font_size=”35px” custom_margin=”58px|||||” global_colors_info=”{}”]CONTACT US[/et_pb_text][/et_pb_column][/et_pb_row][/et_pb_section][et_pb_section fb_built=”1″ _builder_version=”4.23.4″ _module_preset=”default” custom_padding=”||0px|||” global_colors_info=”{}”][et_pb_row column_structure=”1_2,1_2″ _builder_version=”4.23.4″ _module_preset=”default” width=”90%” max_width=”80%” custom_padding=”||3px|||” global_colors_info=”{}”][et_pb_column type=”1_2″ _builder_version=”4.23.4″ _module_preset=”default” global_colors_info=”{}”][et_pb_text _builder_version=”4.23.4″ _module_preset=”default” global_colors_info=”{}”]Our Office[/et_pb_text][/et_pb_column][et_pb_column type=”1_2″ _builder_version=”4.23.4″ _module_preset=”default” global_colors_info=”{}”][et_pb_text _builder_version=”4.23.4″ _module_preset=”default” global_colors_info=”{}”]Have a Question? Drop it here, and we’ll get
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- [About ODSI](https://www.odsi-energy.com/about-us/) - Oilfield Data Services Inc. is a specialized engineering firm that automates real-time surveillance for the toughest reservoir and production challenges.[et_pb_section fb_built=”1″ _builder_version=”4.23.4″ background_image=”https://www.odsi-energy.com/wp-content/uploads/2024/01/Reservoir-Production-Engineering-1-scaled.jpg” height=”300px” custom_margin=”||||false|false” global_colors_info=”{}”][et_pb_row _builder_version=”4.23.4″ _module_preset=”default” global_colors_info=”{}”][et_pb_column type=”4_4″ _builder_version=”4.23.4″ _module_preset=”default” global_colors_info=”{}”][et_pb_text _builder_version=”4.24.0″ _module_preset=”default” custom_margin=”58px|||||” global_colors_info=”{}”] ABOUT ODSI [/et_pb_text][/et_pb_column][/et_pb_row][/et_pb_section][et_pb_section fb_built=”1″ _builder_version=”4.23.4″ _module_preset=”default” custom_padding=”40px||0px|||” global_colors_info=”{}”][et_pb_row _builder_version=”4.23.4″ _module_preset=”default” width=”90%” max_width=”80%” custom_padding=”6px||3px|||” global_colors_info=”{}”][et_pb_column type=”4_4″ _builder_version=”4.23.4″ _module_preset=”default” global_colors_info=”{}”][et_pb_text _builder_version=”4.23.4″ _module_preset=”default” global_colors_info=”{}”] ABOUT OILFIELD DATA SERVICES, INC [/et_pb_text][/et_pb_column][/et_pb_row][et_pb_row column_structure=”1_2,1_2″ _builder_version=”4.23.4″ _module_preset=”default” max_width=”80%” custom_padding=”0px|||||” global_colors_info=”{}”][et_pb_column type=”1_2″ _builder_version=”4.23.4″ _module_preset=”default” global_colors_info=”{}”][et_pb_text
- [Resources for Petroleum Engineering and Production Optimization - List](https://www.odsi-energy.com/resources-petroleum-engineering-production-optimization-list/) - [et_pb_section fb_built=”1″ _builder_version=”4.23.4″ background_image=”https://www.odsi-energy.com/wp-content/uploads/2024/01/Resources-Banner-scaled.jpg” height=”300px” custom_margin=”||||false|false” global_colors_info=”{}”][et_pb_row _builder_version=”4.23.4″ _module_preset=”default” global_colors_info=”{}”][et_pb_column type=”4_4″ _builder_version=”4.23.4″ _module_preset=”default” global_colors_info=”{}”][et_pb_text _builder_version=”4.23.4″ _module_preset=”default” custom_margin=”58px|||||” global_colors_info=”{}”]RESOURCE LIBRARY[/et_pb_text][/et_pb_column][/et_pb_row][/et_pb_section][et_pb_section fb_built=”1″ _builder_version=”4.23.4″ _module_preset=”default” custom_padding=”||0px|||” global_colors_info=”{}”][et_pb_row _builder_version=”4.23.4″ _module_preset=”default” max_width=”80%” global_colors_info=”{}”][et_pb_column type=”4_4″ _builder_version=”4.23.4″ _module_preset=”default” global_colors_info=”{}”][et_pb_text _builder_version=”4.24.0″ _module_preset=”default” hover_enabled=”0″ global_colors_info=”{}” sticky_enabled=”0″]View Grid | View Lists[/et_pb_text][et_pb_code _builder_version=”4.24.0″ _module_preset=”default” hover_enabled=”0″ global_colors_info=”{}” sticky_enabled=”0″]Filter by typeAllTechnical PapersTechnical PresentationsCase StudiesArticlesVideoSort list byDefaultTitle (A -
- [Resources for Petroleum Engineering and Production Optimization](https://www.odsi-energy.com/resouces-petroleum-engineering-production-optimization/) - View ODSI's Resource Library of Petroleum Engineering and Production Optimization resources. Filter by keyword, file type, or presentation.
- [Reservoir & Production Engineering](https://www.odsi-energy.com/reservoir-production-engineering/) - By leveraging rigorous engineering principles, ODSI removes the guesswork for wells, reservoirs, and production, enabling you to make more profitable decisions.
- [Petroleum Engineering Case Studies](https://www.odsi-energy.com/petroleum-engineering-case-studies/) - With several unique case studies spanning the toughest reservoir and production challenges, ODSI's expertise and specialization sets them apart.
- [ODSI | Petroleum Engineering Events](https://www.odsi-energy.com/petroleum-engineering-events/) - [et_pb_section fb_built=”1″ _builder_version=”4.24.0″ background_image=”https://www.odsi-energy.com/wp-content/uploads/2024/02/Event-Banner_1.png” height=”300px” custom_margin=”||||false|false” global_colors_info=”{}”][et_pb_row _builder_version=”4.23.4″ _module_preset=”default” global_colors_info=”{}”][et_pb_column type=”4_4″ _builder_version=”4.23.4″ _module_preset=”default” global_colors_info=”{}”][et_pb_text _builder_version=”4.23.4″ _module_preset=”default” custom_margin=”58px|||||” global_colors_info=”{}”]PETROLEUM ENGINEERING EVENTS[/et_pb_text][/et_pb_column][/et_pb_row][/et_pb_section][et_pb_section fb_built=”1″ _builder_version=”4.24.0″ _module_preset=”default” custom_padding=”||60px||false|false” hover_enabled=”0″ global_colors_info=”{}” sticky_enabled=”0″ custom_padding_last_edited=”on|desktop” custom_padding_tablet=”||20px||false|false” custom_padding_phone=”||20px||false|false”][et_pb_row _builder_version=”4.23.4″ _module_preset=”default” max_width=”80%” hover_enabled=”0″ global_colors_info=”{}” sticky_enabled=”0″][et_pb_column type=”4_4″ _builder_version=”4.23.4″ _module_preset=”default” global_colors_info=”{}”][et_pb_heading title=”Upcoming Events” _builder_version=”4.24.0″ _module_preset=”default” global_colors_info=”{}”][/et_pb_heading][et_pb_code _builder_version=”4.24.0″ _module_preset=”default” global_colors_info=”{}”]No posts found. [/et_pb_code][et_pb_heading title=”Past Events” _builder_version=”4.24.0″ _module_preset=”default”
- [Methodology](https://www.odsi-energy.com/methodology-odsi/) - More about ODSI's methods: Data-Driven Fluid PVT, Bottom-Hole Pressures (BHPs), Multi-Phase Rates, and Reservoir Analysis
- [Automated Real-Time Surveillance (ARTS)](https://www.odsi-energy.com/automated-real-time-surveillance-arts/) - ODSI's Automated Real-Time Surveillance (ARTS) takes the tedious well/reservoir evaluation process and automates it in a consistent and transparent fashion.
- [Glossary](https://www.odsi-energy.com/glossary-old/)

## Downloads

- [Predicting the Arrival of an Interference Response](https://www.odsi-energy.com/download/predicting-the-arrival-of-an-interference-response/)
- [CIO Review - Using Automated Well/Reservoir Surveillance to Enhance Productivity](https://www.odsi-energy.com/download/cio-review-using-automated-well-reservoir-surveillance-to-enhance-productivity/)
- [How Much Money Do You Have Left in the Ground?](https://www.odsi-energy.com/download/how-much-money-do-you-have-left-in-the-ground/)
- [Automated Real-Time Surveillance and Production Monitoring](https://www.odsi-energy.com/download/automated-real-time-surveillance-and-production-monitoring/)
- [VFM/Sudden Water Production in a Deepwater Oil Well](https://www.odsi-energy.com/download/vfm-sudden-water-production-in-a-deepwater-oil-well-case-study/)
- [A Systemic Approach to Evaluate the Sanding Potential Caused by Formation Shear Failure in Unconsolidated Oil and Gas Reservoirs](https://www.odsi-energy.com/download/a-systemic-approach-to-evaluate-the-sanding-potential-caused-by-formation-shear-failure-in-unconsolidated-oil-and-gas-reservoirs/)
- [Just Calculating P.I. Doesn't Tell You What's Going On](https://www.odsi-energy.com/download/just-calculating-p-i-doesnt-tell-you-whats-going-on/)
- [Monitoring Water Contacts Using Pressure and Flowrate Measurements](https://www.odsi-energy.com/download/monitoring-water-contacts-using-pressure-flowrate/)
- [Blind Reservoir Mapping](https://www.odsi-energy.com/download/blind-reservoir-mapping/)
- [BHP Mid Completion](https://www.odsi-energy.com/download/bhp-mid-completion/)
- [Diagnostic Time-Lapse PTA - Deepwater GoM Well](https://www.odsi-energy.com/download/diagnostic-time-lapse-pta-deepwater-gom-well/)
- [Failed Subsea Flow Meter - Wet Gas Wells - North Sea](https://www.odsi-energy.com/download/failed-subsea-flow-meter-wet-gas-wells-north-sea/)
- [Gas Injector Surveillance - Offshore Australia](https://www.odsi-energy.com/download/gas-injector-surveillance-offshore-australia/)
- [High Skin or Bad BHP - Phase-Thermal Effects and PTA (Gas Condensate, Offshore North Sea)](https://www.odsi-energy.com/download/high-skin-or-bad-bhp-phase-thermal-effects-and-pta-gas-condensate-offshore-north-sea/)
- [Real-Time Surveillance of Gas Condensate Well - Offshore Australia](https://www.odsi-energy.com/download/real-time-surveillance-of-gas-condensate-well-offshore-australia/)
- [Reservoir Volume Monitoring GoM Gas Condensate Well](https://www.odsi-energy.com/download/reservoir-volume-monitoring-gom-gas-condensate-well/)
- [Scale Detection in North Sea Water Injector](https://www.odsi-energy.com/download/scale-detection-in-north-sea-water-injector/)
- [VFM / Sudden Water Production in a Deepwater GOM Oil Well](https://www.odsi-energy.com/download/vfm-sudden-water-production-in-a-deepwater-gom-oil-well/)
- [Is it Well Bore or Reservoir? Understanding Re-injection Effects during a Well Test](https://www.odsi-energy.com/download/is-it-well-bore-or-reservoir-understanding-re-injection-effects-during-a-well-test/)
- [Subsea Well Testing at the Subsea Tree](https://www.odsi-energy.com/download/subsea-well-testing-at-the-subsea-tree/)
- [Gas/Condensate and Oil Well Testing - From the Surface](https://www.odsi-energy.com/download/gas-condensate-and-oil-well-testing-from-the-surface/)
- [A Methodology for Reducing Bias in the Design & Evaluation of Hydraulic Fractures - paper](https://www.odsi-energy.com/download/a-methodology-for-reducing-bias-in-the-design-evaluation-of-hydraulic-fractures-paper/)
- [Using the Results from Automated Petroleum Engineering Calculations to Accelerate Decision Workflows](https://www.odsi-energy.com/download/using-the-results-from-automated-petroleum-engineering-calculations-to-accelerate-decision-workflows/)
- [Using the Wellbore as a d/p Meter to Calculate Gas Rate - presentation](https://www.odsi-energy.com/download/using-the-wellbore-as-a-d-p-meter-to-calculate-gas-rate-presentation/)
- [The Effect of Wellbore Temperature Changes and Frictional Losses on Well Test Interpretation - Paper](https://www.odsi-energy.com/download/the-effect-of-wellbore-temperature-changes-and-frictional-losses-on-well-test-interpretation-paper/)
- [Pitfalls of Surface Well Test Analysis - Guidelines](https://www.odsi-energy.com/download/pitfalls-of-surface-well-test-analysis-guidelines/)
- [Propagation of Depletion - The Inclusion of Inertia in the Derivation of the Diffusivity Equation - paper](https://www.odsi-energy.com/download/propagation-of-depletion-the-inclusion-of-inertia-in-the-derivation-of-the-diffusivity-equation-paper/)
- [A Systematic Approach to Evaluate Sanding Potential Caused by Formation Shear Failure in Unconsolidated Oil and Gas Reservoirs](https://www.odsi-energy.com/download/a-systematic-approach-to-evaluate-sanding-potential-caused-by-formation-shear-failure-in-unconsolidated-oil-and-gas-reservoirs/)
- [Reservoir Production Engineering Surveillance Course - Webinar](https://www.odsi-energy.com/download/reservoir-production-engineering-surveillance-course-webinar/)
- [Engineered Flowback and Reservoir Evaluation for Unconventional Wells](https://www.odsi-energy.com/download/engineered-flowback-and-reservoir-evaluation-for-unconventional-wells/)
- [A Methodology for Reducing Bias - Presentation](https://www.odsi-energy.com/download/a-methodology-for-reducing-bias-presentation/)
- [ODSI - Gas Rate Calculations](https://www.odsi-energy.com/download/odsi-gas-rate-calculations/)
- [Well Analyzer - Deepwater Case Studies](https://www.odsi-energy.com/download/well-analyzer-deepwater-case-studies/)
- [Closed Loop WB Components](https://www.odsi-energy.com/download/closed-loop-wb-components/)
- [Building an Effective Reservoir and Production Monitoring System](https://www.odsi-energy.com/download/building-an-effective-reservoir-and-production-monitoring-system/)
- [Engineered Frac'd Well Flowback and Reservoir Evaluation for Unconventional Wells](https://www.odsi-energy.com/download/engineered-fracd-well-flowback-and-reservoir-evaluation-for-unconventional-wells/)
- [Frac Replay Analysis - What, How and Why?](https://www.odsi-energy.com/download/frac-replay-analysis-what-how-and-why/)
- [Getting Past the Buzzwords](https://www.odsi-energy.com/download/getting-past-the-buzzwords/)
- [Horizontal Fractured Wells](https://www.odsi-energy.com/download/horizontal-fractured-wells/)
- [ODSI Well Analyzer for Producing Oil and Gas Wells](https://www.odsi-energy.com/download/odsi-well-analyzer-for-producing-oil-and-gas-wells/)
- [The Effect of Wellbore Temperature Changes and Frictional Losses on Well Test Interpretation Results](https://www.odsi-energy.com/download/the-effect-of-wellbore-temperature-changes-and-frictional-losses-on-well-test-interpretation-results/)
- [Developing an Early Warning System for Well/Reservoir Problems](https://www.odsi-energy.com/download/developing-an-early-warning-system-for-well-reservoir-problems/)
- [Automated Reservoir and Production Surveillance Systems - And Why We Screw It Up!](https://www.odsi-energy.com/download/automated-reservoir-and-production-surveillance-systems-and-why-we-screw-it-up/)
- [The Propagation of Depletion](https://www.odsi-energy.com/download/the-propagation-of-depletion/)
- [Total Pau ODSI Presentation on WA RTS](https://www.odsi-energy.com/download/total-pau-odsi-presentation-on-wa-rts/)
- [WA for Conventional Horizontal Oil Wells, GC wells, and injector wells](https://www.odsi-energy.com/download/wa-for-conventional-horizontal-oil-wells-gc-wells-and-injector-wells/)
- [Water Inejctor Demo Allocations Auto-PTA Scale Buildup](https://www.odsi-energy.com/download/water-inejctor-demo-allocations-auto-pta-scale-buildup/)
- [Water Production Detection](https://www.odsi-energy.com/download/water-production-detection/)
- [Wavex Intro](https://www.odsi-energy.com/download/wavex-intro/)
- [Wavex - The Capillary Model](https://www.odsi-energy.com/download/wavex-the-capillary-model/)
- [Well Evaluation Methods](https://www.odsi-energy.com/download/well-evaluation-methods/)
- [Energy Tech Review](https://www.odsi-energy.com/download/energy-tech-review/)
- [Well Testing for G&G Guys (and Gals)](https://www.odsi-energy.com/download/well-testing-for-gg-guys-and-gals/)
- [ODSI CIO Review](https://www.odsi-energy.com/download/odsi-cio-review/)

## Glossary Terms

- [GOR](https://www.odsi-energy.com/glossary/gor/) - The Gas-Oil Ratio is a measure that represents the volume of gas produced or released per unit volume of oil, typically expressed in cubic feet of gas per barrel of oil.
- [DSTs](https://www.odsi-energy.com/glossary/dsts/) - A Drillstem Test (DST) involves a series of measurements and calculations to assess the properties of a formation. The primary focus is on determining the formation pressure, permeability, and the well's potential productivity.
- [KPIs](https://www.odsi-energy.com/glossary/kpis/) - Key Performance Indicators (KPIs) are metrics used to evaluate and measure the efficiency, performance, and success of drilling and production activities.
- [MPFM](https://www.odsi-energy.com/glossary/mpfm/) - Multiphase Flow Meter (MPFM) is a device used in the oil and gas industry to measure the simultaneous flow rates of gas, oil, and water in a pipeline without requiring separation.
- [P.I.](https://www.odsi-energy.com/glossary/p-i/) - Productivity Index (P.I.) is a measure used to quantify the efficiency of a well in producing hydrocarbons, calculated as the rate of production per unit of pressure drop in the reservoir.
- [PTA](https://www.odsi-energy.com/glossary/pta/) - Pressure Transient Analysis (PTA) is a sophisticated method for interpreting well and reservoir performance based on the analysis of pressure changes over time.
- [PVT](https://www.odsi-energy.com/glossary/pvt/) - Pressure-Volume-Temperature (PVT) analysis is a crucial aspect of reservoir engineering and production optimization. It involves studying the behavior of petroleum fluids (oil, gas, and water) under different pressure, volume, and temperature conditions, typically within reservoirs or wellbores. This analysis helps in determining important parameters such as fluid properties, phase behavior (e.g., whether the fluid is in gas, liquid, or mixed phase), and reservoir performance characteristics, which are essential for reservoir management, production forecasting, and overall field development planning.
- [WHP](https://www.odsi-energy.com/glossary/whp/) - Wellhead pressure (WHP) is the pressure at the surface of a well, measured at the wellhead, which reflects the fluid pressure within the wellbore, critical for monitoring and controlling the production and safety of oil and gas operations.
- [DHGP](https://www.odsi-energy.com/glossary/dhgp/) - Downhole Gauge Pressure is a measure of pressure relative to ambient atmospheric pressure. In the context of downhole applications, it refers to the pressure within a wellbore minus the atmospheric pressure at the surface.

## Categories

- [Technical Papers](https://www.odsi-energy.com/category/technical-papers/)
- [Technical Presentations](https://www.odsi-energy.com/category/technical-presentations/)
- [Case Studies](https://www.odsi-energy.com/category/case-studies/)
- [Video](https://www.odsi-energy.com/category/video/)
- [Articles](https://www.odsi-energy.com/category/articles/)
- [Event](https://www.odsi-energy.com/category/events/)

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- [SPE](https://www.odsi-energy.com/tag/spe/)
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