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_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper OTC 32158, “Offshore Hydrogen Pipeline System Qualification: Design and Materials/Welds Testing in Hydrogen Environment,” by Angelo Santicchia, Elvira Aloigi, and Salvatore Terracina, Saipem, et al. The paper has not been peer reviewed. Copyright 2023 Offshore Technology Conference. Reproduced by permission. _ The qualification of a pipeline system for hydrogen transport, important in the transition to a decarbonized energy system even if strictly related to offshore pipelines, is a broad field that requires a systematic approach from basic material knowledge to complex physical models and fracture and fatigue assessments. The authors’ analysis of qualification requirements, including available test types and testing protocols, led to a matrix of potential tests, detailed in the complete paper, to be conducted in hydrogen and air environments for the steel base material, seam weld, and girth weld of offshore pipelines. Offshore Pipeline Materials Requirements vs. Hydrogen Transportation The authors’ work outlines many challenges, including the following: - Although hydrogen pipelines installed and operating onshore are common, at the time of writing, none exist in the offshore environment. - The blending percentage of hydrogen into natural gas in the future-transport scenario is still under discussion. - Small amounts of hydrogen can have a substantial effect on fatigue and fracture on high-strength materials. - The effect of hydrogen on pipe-material fatigue and fracture properties correlates directly to the specificity of the offshore environment, which will be very demanding in terms of longitudinal stress and fatigue. Another important aspect to consider is the effect of hydrogen on weldments both longitudinal and circumferential that are part of pipe-material fabrication and pipeline fabrication. A dedicated engineering team analyzed key standards and the available literature in terms of theoretical studies and experimental tests of materials in hydrogen environments. This activity indicated that, in addition to theoretical and design considerations, characterization of primary material and welding properties in hydrogen environments that will affect the failure modes of offshore pipeline design is a critical step. Testing Protocols and Equipment Slow Strain Rate Test (SSRT). Smooth cylindrical specimens were tested in inert gas (nitrogen), pure hydrogen, and a hydrogen/natural gas mixture for comparative purposes. This testing was aimed at evaluating the susceptibility of the pipeline materials (base material and weld metals) to hydrogen embrittlement when subjected to typical conditions envisaged for future hydrogen service. Tensile cylindrical specimens were tested at room temperature (24°C) in a high-pressure gaseous atmosphere. Tests were carried out in displacement control mode. In the initial part of the tensile test, in the plastic regime, after attainment of material yielding but before reaching the maximum tensile strength of the specimen, the strain distribution along the specimen was approximately uniform.
_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 207431, “Advanced Research and Development in Unconventional Use of Tracer Technology for EOR and IOR: What Lies Beyond?” by Monalisa Chatterjee and Sean Toh, Tracerco, and Ahmed Alshmakhy, SPE, ADNOC, et al. The paper has not been peer reviewed. _ In recent decades, tracers have provided crucial insight into fluid-flow behavior in assessing reservoir connectivity. While advancements in versatility of tracer molecules have been published before in the literature, to the best of the authors’ knowledge, no work has been published to date that discusses the latest advances in unconventional uses of tracer molecules aiding enhanced oil recovery (EOR) and improved oil recovery (IOR) processes. This work is meant to address that gap by exploring four unconventional uses of tracers that hold significant potential. Microencapsulation of Solid Tracers: Enhancing Intelligent Tracers Previous research specified that factors affecting the current technology of solid tracers include physical space restrictions, temperature, tracer-loading capacity, initial surge, release of the tracer into fluid, and target-tracer concentrations. While the first two factors often are dictated by project conditions, advances in the other factors have been largely attributed to the tracer-polymer composition. For the tracers to be released in a controlled manner across a designated period, polymer structure plays a pivotal role in achieving longevity. The complete paper discusses a technique that is an application revolving around microencapsulation of chemical tracers in a solid shell before the addition of polymer material. Encapsulation vs. Microencapsulation. The encapsulation technique is a complex process involving selection of compatible molecular carriers, understanding their effects, and building the appropriate encapsulation (usually molecular encapsulation) to ensure that the capsules meet the desired outcome of each study. In this paper, an advanced subset of encapsulation—microencapsulation—is presented and its applications in inflow chemical tracing are discussed. Microencapsulation involves a particle, usually of micrometer dimensions, comprising a core material surrounded by a wall material significantly different from that of the core. The difference between them mainly arises from the morphology and the internal structure. The process allows the active ingredient to be protected from adverse external environmental conditions by the encapsulating coating agent. By applying the microencapsulation technique, the release profiles of tracers can be further controlled by changing the thickness, material, and morphology of the encapsulating agent. When applied onto tracers, this changes the tracer-release mechanism to a two-step, instead of the typical one-step, process. Oil tracers that generally are oleophilic will be released when in contact with oil; similarly, water tracers that are hydrophilic will be released when in contact with water. The tracers will remain dormant until the phase of interest encounters the polymer bars, and the two-step process allows the encapsulating agent to further improve the longevity of the tracers.
_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper OTC 31879, “Assessment of the Potential for Hydrogen Production From Bottom‑Fixed Offshore Wind in Uruguay,” by Juan Tomasini, SPE, Pablo Gristo, SPE, and Santiago Ferro, SPE, ANCAP, et al. The paper has not been peer reviewed. Copyright 2022 Offshore Technology Conference. Reproduced by permission. _ With almost the entire electricity matrix having been decarbonized, the next step in the Uruguayan energy transition includes the development of a hydrogen economy. In the complete paper, the authors present the results of the assessment of two regions suitable for bottom-fixed offshore wind energy (OWE) technologies. Results are encouraging and could lead to new possibilities in supporting the development of a hydrogen economy. Introduction For Uruguay, hydrogen is expected to play an important role in tackling the various challenges of the second phase of decarbonization; it holds the potential for use in the transport sector and in raw materials and chemical products. Having no oil production, Uruguay is a net oil importer; therefore, the extensive use of hydrogen in the domestic market may have a profound effect on the national economy and energy sovereignty. Preliminary findings show that Uruguay may have hydrogen production costs between $1.2 and $1.4/kg, placing the country among the world’s net exporters. Green Hydrogen Production From Offshore Renewable Energy Compared with onshore wind, OWE presents several advantages, including a greater capacity of each turbine (fewer turbines required for the same wind-farm capacity) and the availability of larger areas (allowing larger wind-farm capacity). Even if bottom-fixed is the predominant technology for OWE projects, floating technology is attracting increasing investment and public policy support because of its potential to access wind resources at water deeper than 40 m, where bottom-fixed may be less feasible technically, economically, or logistically. Green Hydrogen Production. Contrasting with blue or gray hydrogen (produced from fossil fuels with or without carbon capture and storage, respectively), green hydrogen provides the lowest near-zero-emissions option. Green hydrogen can be produced through the gasification of biomass or the electrolysis of water powered by renewable electricity. Alkaline electrolysis and proton-exchange-membrane (PEM) technologies are widely available commercially. Alkaline electrolysis is a fully mature technology that represents the lower-cost option, but its operational load limits are not as broad as those for PEM; therefore, its coupling with variable renewable sources should be carefully managed. On the other hand, PEM electrolysis is not yet a fully mature technology, with higher costs that are expected to be reduced in the coming years.
- South America > Uruguay (1.00)
- South America > Chile > Santiago Metropolitan > Santiago (0.25)
- Energy > Renewable > Wind (1.00)
- Energy > Renewable > Hydrogen (1.00)
- Government > Regional Government > South America Government > Uruguay Government (0.35)
_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper URTeC 3723023, “Using Machine Learning To Customize Development Unit Spacing for Maximum Acreage Value,” by M. Maguire, SPE, Diamondback Energy; A. Cui, Novi Labs; and T.E. Witham, Diamondback Energy, et al. The paper has not been peer reviewed. _ In the complete paper, machine-learning (ML) models were trained using geologic, completion, and spacing parameters to predict production across the primary developed formations in the Midland Basin. The approach of using ML to test several different combinations of spacing and completion designs can be repeated across a basin to find an economical, customized solution for each development unit. Introduction In contrast to conventional methods, ML offers a data-driven approach that can leverage the large amount of data generated by operators within unconventional plays. Several characteristics of ML models make them well-suited for spacing optimization, including the following: - ML models rely on statistical methods to establish relationships between the input variables and the output variables. - ML handles nonlinear relationships well. - Complex variable interactions can be difficult to understand with traditional methods. The downside is the time required to assemble the input data used for training an ML model. However, once a model is built that has an acceptable level of error along with data examples covering the range of cases to be evaluated, many alternative development scenarios can be quickly evaluated. In addition, with the right variables (features) included, a model could be applicable to an area much larger than that of pilot wells. ML Methods Each ML model used production data (monthly or daily format), directional survey data (to locate the wells and allow for spacing calculations), a header table with a variety of information on all the wells (i.e., completion information, formation, and completed lateral length), and grid data (typically geology data, such as effective porosity). For all models, private data, such as daily production data and detailed completion data, had precedence over data acquired from public sources or a third-party data provider. For a well to be included in the ML model, it generally had to have all data values populated; wells with missing data were excluded. Once the data were gathered, the derivative variables were calculated, along with several spacing parameters. For ML studies of unconventional developments, practitioners face two main subsurface questions: how to subdivide the formations to represent the drainage heights and which rock properties to pass to the model. Drainage heights defined by the operator are based on the geochemical typing data. These heights generally extended further than traditionally defined formations (Fig. 1). Because these drainage boundaries are defined by the true vertical depth (TVD) positions of specific formational tops, the total vertical extent of these drainage heights mirrors the geospatial variation in the TVD positions of their boundary tops. To generate the grids, geologic attributes were calculated from well logs. Log processing began after drainage heights were determined across the Midland Basin. Attributes with high correlation were selectively removed from the model inputs.
- Geology > Geological Subdiscipline > Geomechanics (0.49)
- Geology > Geological Subdiscipline > Geochemistry (0.35)
- Well Drilling (1.00)
- Reservoir Description and Dynamics (1.00)
- Management (1.00)
- (2 more...)
Because of its comprehensive nature, much of the complete paper is dedicated to a review of the characteristics of heavy oil reservoirs and their exploitation, including thermal and nonthermal methods and the literature dedicated thereto. This synopsis will concentrate on the authors' reviews of work flows to manage these reservoirs and field applications of the methodologies they review.
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (1.00)
- Geology > Geological Subdiscipline (1.00)
_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 206108, “Diagnostic Plots of Pressure-Transient, Rate-Transient, and Diagnostic Fracture Injection/Falloff Tests,” by David Craig, SPE, Occidental, and Thomas Blasingame, SPE, Texas A&M University. The paper has not been peer reviewed. _ All transient-test interpretation methods use diagnostic plots for the identification of wellbore or fracture storage distortion, flow regimes, and other parameters. The associated diagnostic plots are not interchangeable between such tests. The objective of this work is to clearly define the appropriate diagnostic plots for each type of transient test. Introduction In the complete paper, the authors review constant-rate drawdown solutions for a few specific cases of interest and the plotting function used to match buildup data to the drawdown solutions. They extend their review to the cases of buildup or falloff analysis following short flow periods and illustrate the differences between analysis of buildup or falloffs following short and long flow periods. After covering pressure-transient testing, they discuss rate-transient diagnostic plots and the ambiguity observed during analysis of multifractured horizontal well diagnostic plots and the uncertainty of analyst straight lines. Finally, they discuss and demonstrate the correct plotting functions and flow-regime interpretation for diagnostic fracture injection and falloff tests. Multiple examples from the literature are included as part of the discussion. Pressure-Transient Diagnostic Plots Pressure-transient-testing diagnostic plots evolved from the solutions to constant-rate drawdown problems. The authors’ intent is to review infinite-acting solutions for radial flow with wellbore storage and skin and flow through an infinite-conductivity fracture. On a log-log plot, the characteristic slopes, detailed in the complete paper, are unit slope, ½ slope, and zero slope. Many authors have proposed plotting functions for overlaying the observed pressure response from transient tests other than a constant-rate drawdown on the drawdown solutions. In many cases, the slopes identifying storage distortion and flow regimes from drawdown solutions will match and can be used to identify storage and flow regimes from pressure-buildup tests. A situation in which pressure-buildup or falloff test plotting functions fail to match the drawdown solution is when the flow period before shut-in is short. Short-flow transient tests have been reviewed by multiple authors. In lower-permeability reservoirs, pressure-transient tests with short flow periods are very common, and, in unconventional reservoirs, short-flow transient tests are the most-common transient test. Diagnostic plots constructed based on the characteristic shapes of the dimensionless pressure and the dimensionless pressure derivative with respect to the natural logarithm of dimensionless time for constant-rate drawdown solutions cannot be applied in the same manner for short-flow transient tests. With short-flow transient tests, the observed derivative of pressure difference with respect to the natural logarithm of time matches the negative product of dimensionless time and the second derivative of dimensionless pressure with respect to dimensionless time. Additionally, the commonly known impulse derivative, which is defined as the product of time and the derivative of pressure difference with respect to the natural logarithm of time, will match the negative product of dimensionless time squared and the second derivative of dimensionless pressure with respect to dimensionless time.
This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 208782, “Annular Creep Barrier Evaluation and Qualification Using Ultrasonic Measurements,” by Eric van Oort, SPE, The University of Texas at Austin, and Akshay Thombare, SPE, and Munir Aldin, SPE, Metarock Laboratories, et al. The paper has not been peer reviewed. Creep barriers can simplify well abandonments, particularly in high-cost offshore environments. Evaluation and qualification of creep barriers in the field, however, have proven challenging and labor-intensive when casing is perforated and annular rock material is pressure-tested to verify its sealing ability. This work seeks to eliminate the need for pressure testing by allowing the barrier to be qualified using only cased-hole log measurements. Creep Barrier Formation and Stimulation Plastically deforming shale and salt or evaporite formations under certain conditions can move into uncemented or poorly cemented annular spaces, filling them and contacting the casing to form an effective pressure-tight barrier. Supporting evidence overwhelmingly points toward creep as the fundamental rock-mechanical mechanism behind this type of barrier formation. Creep barriers have, in fact, become commonplace considerations in the plugging and abandonment of offshore wells in the UK and the Norwegian sectors of the North Sea, leading to simplified and more-cost-effective rigless offshore well-plugging operations. The latter is accomplished by eliminating the need for casing cutting and pulling or casing milling followed by setting openhole abandonment plugs. Materials that present alternatives to ordinary Portland cement (OPC) for well plugging-and-abandonment barrier construction include the use of shale or salt as a barrier (SAAB). Comparison of category scores for SAAB with other materials reveals that SAAB offers a well-rounded performance envelope with no weaknesses in any categories, whereas the other materials, including cement, show weaknesses in one or more categories. A main advantage of SAAB is that it offers the ability to “replace” the caprock, the desired goal in most well abandonments. Moreover, for many materials including OPC, long-term (i.e., hundreds or thousands of years and beyond) sealing performance is unknown for well abandonment. The only category in which SAAB technology appears to lag is in its technology readiness level score. This, then, provides motivation for further research.
- Europe > United Kingdom (0.56)
- Europe > Norway (0.56)
- North America > United States > Texas > Travis County > Austin (0.25)
This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 199707, “A Data-Driven Approach to Screenout Detection for Horizontal Wells,” by Xiaodan Yu, Whitney Trainor-Guitton, and Jennifer Miskimins, SPE, Colorado School of Mines. The paper has not been peer reviewed. Multistage hydraulic fracturing has gained global popularity as more tight geologic formations are developed economically for hydrocarbon resources. However, screenout is a major issue caused by the blockage of proppant inside the fractures. The complete paper presents a screenout-classification system based on Gaussian hidden Markov models (GHMMs) trained on simulated data that predicts screenouts and provides early warning by learning prescreenout patterns in surface-pressure signals. The methodology is a useful tool for early screenout detection and shows the promise of other fracturing time-series data analysis. Materials and Methods In the complete paper, fracturing treatment data are generated using a hydraulic fracturing simulation software. A well-logging profile acquired from a vertical well located in the Denver-Julesburg (DJ) Basin is used to generate the reservoir rock properties in the fracturing simulations.
This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper IPTC 21430, “Deepwater Subsea BOP Technological and Reliability Advancement,” by Mahesh Picha, SPE, Malik Faisal Abdullah, and Ashutosh Rai, Petronas, et al. The paper has not been peer reviewed. Copyright 2021 International Petroleum Technology Conference. Reproduced by permission. Subsea blowout preventer (SBOP) reliability is a major challenge in deepwater drilling and completion operations, accounting for a large portion of major equipment failures and nonproductive time (NPT) costs annually. The complete paper focuses on SBOP technological advancement since the Macondo incident in 2010, with emphasis on reliability, equipment-condition monitoring, and statistical root-cause analysis. The development of new technologies has targeted overall cost optimization of the well life cycle but also has been aimed at assuring SBOP functionality. Introduction Drilling contractors are required to establish minimum standards of redundancy and reliability of their SBOP systems and are required to implement an auditable risk-management process to ensure that their SBOP systems operate above minimum standards. A 2015 study found that 38% of NPT events were related to SBOP issues. Of this 38%, 56% were associated with maintenance, 22% with manufacturing issues, 16% with not following operational procedures, and 6% with training time. Because maintenance-related NPT was the major contributor, a detailed analysis was performed and found that frequency of the maintenance cycle, insufficient detailing of maintenance procedures, a lack of specific tools, insufficient spare parts onboard, and unavailability of technical documentation were responsible.
- Europe > United Kingdom (0.29)
- Asia > Malaysia (0.25)
This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper URTEC 208291, “Introducing Iterative Ensemble Kalman Smoother to History-Matching Horizontal Coalbed Methane Wells,” by Rubakumar Sankararaj, SPE, and Sylvain Ducroux, SPE, Resoptima, and Dan Kuznetsov, SPE, Arrow Energy, et al. The paper has not been peer reviewed. This study presents the iterative ensemble Kalman smoother applied to a low-permeability coalbed methane (CBM) field in Australia. All wells in the studied reservoir are completed with an artificial lift system and permanent downhole gauges. A forecast study was conducted to validate the history-matched ensemble. The results showed a good match of 12 months of the new production data not used in history matching, which highlights the robust prediction capabilities of the approach. Geology of the Study Area Because of its strategic geologic and geographic situation in Queensland State, the Bowen-Surat area constitutes one of the more economically significant sedimentary provinces of the Australian mainland and one of the world’s major coal and coal-seam-gas-producing regions. This study considers the Q seam from the Late Permian. Although its thickness varies in the basin because of merging and splitting, it is continuous locally, with an approximate thickness of 5–6 m.