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Results
Multiscale Geomechanical Characterization of Continental Shales Using a Combination of High- and Low-Load Nanoindentation
Nurbekova, Riza (School of Mining and Geosciences, Nazarbayev University, Astana, Kazakhstan ) | Hazlett, Randy Doyle (School of Mining and Geosciences, Nazarbayev University, Astana, Kazakhstan )
Abstract Continental shales are known for their intricate depositional nature and significant vertical and lateral sedimentary variations. Characterizing their mechanical properties requires robust, efficient, and cost-effective methods. Nanoindentation has emerged as an excellent choice, delivering rapid and dependable results. A dual-pronged approach, integrating both high- and low-load nanoindentation, was employed herein to establish a structured framework for statistically assessing the multi-scale mechanical properties of compositionally diverse continental shale samples. High-load nanoindentation experiments on outcrop Kazakhstani shale samples, representative of world class source rocks in the subsurface, revealed the progressive merging and stabilization of initially discrete mechanical attributes within shale constituents (i.e., clay, organic matter, and quartz-feldspar) with increasing indentation depth, suggesting the presence of a minimum probing depth for investigating the bulk mechanical behavior of heterogeneous shale rocks. The acquired bulk mechanical parameters exhibited a robust correlation with the mineralogy of the samples. Additionally, the low-load nanoindentation data were statistically deconvoluted to extract phase-specific mechanical properties of the samples, which were subsequently extrapolated to the macroscopic level using the well-established Mori-Tanaka homogenization technique. The homogenized elastic modulus closely aligned with the empirical data obtained from high-load nanoindentation, further emphasizing the potential of the latter not only for quantifying nano- and micro-scale but also the macro-scale mechanical characteristics of composite materials. Analogies of Kazakhstani shale with Cuyana Basin shale samples, sharing similar characteristics but higher thermal maturity, make these data particularly relevant to local unconventional development plans. Furthermore, the findings offer promise for advancing geomechanical investigations of heterogeneous and anisotropic rocks in the petroleum industry, particularly when core plugs are unavailable. The expected implications of this study are poised to offer valuable insights for determining optimal indentation depths in the empirical assessment of multi-scale mechanical properties in highly heterogeneous shale and other related rocks.
- South America (0.67)
- North America > United States > Oklahoma (0.28)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- South America > Argentina > Cuyana Basin (0.99)
- North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
- Asia > Kazakhstan > Almaty > Zaysan Basin (0.99)
Transitioning Towards FRP Manhole Covers. A Case Study and Success Story on an Urban Scale
Alhusayni, Musab (Oil Sustainability Program) | Mehlisi, Abdulelah (Oil Sustainability Program) | Kanwi, Mohammed (Oil Sustainability Program) | Alazzeh, Mohammad (Al Zamil Industry, Trade & Transport) | Al Shammari, Bandar (National Water Company) | Dubayan, Khaled (Oil Sustainability Program)
ABSTRACT Manhole covers are critical component for the safety of manholes in rural and urban areas. The conventional design of such manhole covers is made from conventional cast iron steel, which is costly, has a greater impact on the environment and will corrode due to the environment in which they are placed in. Alternative options such as FRP manhole covers are made from composite material, corrosion resistant and far more sustainable than the conventional alternative. While FRP Manhole Covers have been adopted in various places around the world, some places such as the GCC region are still reluctant to utilize such applications due to a lack of knowledge and awareness about the benefits, misconceptions about the material as well as the cost in comparison to cast iron. The paper details the methodical approach towards addressing each of the challenges while gaining the maximum benefits of the applications. Additionally, the paper will detail the transition towards such alternatives, while shedding light on the trial process as well as the testing procedure for qualification. INTRODUCTION As the world is recovering from the COVID-19 pandemic, the building and construction industry started to lead the path towards the new normal. While previously construction was a fairly straight forward experience, the world post COVID-19 has proven itself not to be the same anymore. One of the clear differences between the world pre and post COVID-19 was the concern regarding sustainability and CO2 emissions. Typically, CO2 emissions would not be a direct factor in determining a project cost, however it was found that construction companies post COVID-19 monitor their CO2 emissions and try to promote the most sustainable material during their material selection process. Additionally, building and construction companies as well as the relevant entities such as designers factor life cycle cost to ensure that the material selected is the most suitable as well as most advanced material. With such factors a new concept was introduced to the world which is promoted as material transition. Upon closer inspection of the promoted concept, it is safe to assume that polymer material has a clear advantage in both life cycle cost, as well as CO2 emissions especially when compared to material such as cast iron. The unique features of polymer material allow it to be recycled at the end of its use, as well being extremely light weight in comparison to the conventional material. With this in mind, the Oil Sustainability Program (OSP) started researching adoption opportunity which can benefit the environment as well as provide a more feasible solution for the country's several ongoing projects. Upon researching the market, a number of opportunities were identified for mass deployment potential. However, prior to proceeding with the mass deployment, the OSP realized that significant due diligence must be performed to ensure that the opportunity is ready from all aspects. The most important elements to verify that the opportunity is actually ready for mass deployment were noted as the following:- ○ It is technically ready with international and local technical standards available ○ It adds significant technical value in comparison to the conventional alternative ○ It has verified local manufacturers ○ It is relatively easy to deploy and doesn't require significant additional work ○ It has a local partner that is willing to collaborate ○ It has a governing local standard or entity
- Materials > Construction Materials (1.00)
- Construction & Engineering (1.00)
- Materials > Metals & Mining (0.96)
- (4 more...)
Comparative Evaluation of a Functions for the Soave-Redlich-Kwong Equation of State and the Peng-Robinson Equation of State to Predict Saturation Pressures for Gas(es)-Heavy Oil/Bitumen-Water Systems
Atonge, Esther Anyi (Energy Systems Engineering, Faculty of Engineering and Applied Science, University of Regina) | Yang, Daoyong (Energy Systems Engineering, Faculty of Engineering and Applied Science, University of Regina (Corresponding author))
Summary To accurately predict saturation pressures for gas(es)-heavy oil/bitumen-water systems, several α functions have been selected and evaluated at a reduced temperature (Tr) of 0.70 and 0.60 for the Soave-Redlich-Kwong equation of state (EOS) and Peng-Robinson (PR) EOS, respectively. More specifically, 164 data points of measured saturation pressures of gas(es)-heavy oil/bitumen-water systems are collected from the public domain, while all α functions developed for heavy oil-associated mixtures and water have been reviewed and selected. At Tr = 0.70, the former, including three existing α functions, as well as two newly developed α functions at Tr = 0.70 together with three new α functions at Tr = 0.60, and the latter, including two alpha functions, are used to evaluate saturation pressures for various gas(es)-heavy oil/bitumen-water systems under various conditions. The absolute average relative deviation (AARD) between the measured saturation pressures and their predicted ones is found to decrease with either an increase in the pseudocomponent (PC) number or redefining the acentric factor () at Tr = 0.60 other than the conventional one at Tr = 0.70. In addition to validating our coded program, the CMG WinProp module, together with its default binary interaction parameters (BIPs) is used to, respectively, quantify saturation pressures of the aforementioned systems with an overall AARD of 27.34 and 28.39% for the PR EOS and SRK EOS. The recommended α function newly developed at Tr = 0.60 by Chen and Yang (2017) predicts saturation pressures more accurately with an overall AARD of 3.88 and 1.64% by, respectively, treating the heavy oil as one PC and six PCs.
- North America > Canada > Alberta (0.28)
- North America > United States > Texas (0.28)
- North America > United States > Oklahoma (0.28)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (1.00)
- Reservoir Description and Dynamics > Fluid Characterization > Phase behavior and PVT measurements (1.00)
- Reservoir Description and Dynamics > Fluid Characterization > Fluid modeling, equations of state (1.00)
Summary Over the past decade and spanning many disciplines, significant progress has been made in the discovery and understanding of unconventional hydrocarbon plays, both through laboratory studies and in-situ analysis. As a result, most operators and researchers still have access to large amounts of residual core material in various states of preservation (wax sealed, foil wrapped, chilled, unpreserved, etc.). This core was originally collected to answer specific questions related to the assets being evaluated, but there is now growing interest in reusing and reexamining this legacy material to explore new ideas, opportunities, and understandings, as well as to increase the potential for enhanced oil recovery. In this study, we show the potential of legacy unpreserved core material providing resurrected datasets via advancements in core extraction methodologies (e.g. closed retort). Results from these preserved/unpreserved core comparison experiments demonstrate the impact that running legacy rock volume can have in terms of additional learnings, calibration and knowledge gain.
- Research Report > New Finding (0.35)
- Overview > Innovation (0.35)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (21 more...)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Well Drilling > Drilling Operations > Coring, fishing (0.70)
- Reservoir Description and Dynamics > Fluid Characterization > Geochemical characterization (0.70)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Core analysis (0.47)
Significant Reduction of the Viscosity of Waxy Oils by Electrical Treatment
Wang, Hao (Hildebrand Department of Petroleum and Geosystems Engineering, the University of Texas at Austin, Austin, Texas, US) | Lu, Yingda (Hildebrand Department of Petroleum and Geosystems Engineering, the University of Texas at Austin, Austin, Texas, US)
Abstract Wax crystallization at low temperatures sharply increases the viscosity of waxy oils, posing difficulties to their pipeline transportation. Conventional methods of lowering the viscosity of waxy oils include adding chemicals or externally heating the pipeline, both of which are energy costly and carbon intensive. In light of the need for low-carbon and sustainable energy production, we present an environmentally benign concept that lowers the viscosity of waxy oils by electric fields generated from renewable sources. The viscosity of model waxy oils (mineral oil + decane + paraffin wax) before and after electrical treatment was characterized by a rheometer equipped with an Electro-Rheology accessory. We monitored the oil's viscosity changes in three consecutive 10-minute stages: before, during, and after the application of DC electrical fields ranging from 0 to 3.5 kV/mm. The results show that the viscosity of waxy oils can be significantly reduced upon the application of electric fields and the highest viscosity reduction achieved is 82%. The magnitude of viscosity reduction strongly depends on the treatment temperature and the strength of the applied electric fields. Notably, the model oil systems used in this work contain no asphaltenes and resins, which challenges the widely agreed theories in the literature that the presence of charged colloidal particles like asphaltene and resin in waxy crude oils are the prerequisites for electrical treatment of waxy oils to be effective. The observed viscosity reduction is speculated to be caused by a combination of electrophoresis, Quincke rotation, and electrohydrodynamics. Overall, this technology of electrical treatment presents new opportunities to remediate wax-related flow assurance issues in a low-carbon and more sustainable manner.
- Overview (0.46)
- Research Report > New Finding (0.35)
- North America > United States > Louisiana > China Field (0.89)
- Europe > United Kingdom > North Sea (0.89)
- Europe > Norway > North Sea (0.89)
- (4 more...)
Investigating Pore Body, Pore Throat, Nano-Pore Wettability Preference in Several Unconventional Kuwaiti Carbonate Reservoirs
Al-Sayegh, Saleh (University of Missouri Science & Technology & Kuwait Oil Company) | Flori, Ralph E. (University of Missouri Science & Technology) | Alajaj, Hussain (University of Missouri Science & Technology) | Al-Bazzaz, Waleed Hussien (Kuwait Institute for Scientific Research)
Abstract This study will investigate measuring the wettability contact angles of native unconventional tight carbonate as well as other unconventional pore system reservoir samples that hosts varied pore shapes and subsequent wettability contact angle distributions in both reservoir matrix and possible natural fractures. Also, the investigation will include validation of the grain/ pore-wall wettability regions and classify the natural wettability preference available inside pores of the rock and their overall wettability performance and recovery efficiency contributions. Further investigation will include modeling pore throat contact angle wettability, and to understand their new physics that will advance reservoir characterization and oil recovery improvement.
- Asia > Middle East > Kuwait (0.71)
- North America > United States > Texas (0.46)
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.71)
- Oceania > New Zealand > North Island > Tasman Sea > Taranaki Basin > Maui Field (0.99)
- Oceania > New Zealand > North Island > Taranaki Basin (0.99)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
- (8 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Carbonate reservoirs (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
- (3 more...)
Wells Around Formation Issues WAFI Tool-Machine Learning Tool to Extract Field Issues from Daily Reports
Al-Taha, Ahmad (Petroleum Development Oman - Sultanate of Oman) | Al-Sulaimani, Tariq (Petroleum Development Oman - Sultanate of Oman) | Al-Bahri, AL-Salt (Petroleum Development Oman - Sultanate of Oman)
Abstract The objective of this paper is to share and introduce the Wells Around Formation Issues [WAFI] tool, which was developed by Petroleum Development Oman LLC [PDO] - collaboration between Well Engineering and Data Science teams. This tool's function is to extract Formation Issues from the Daily Drilling Operation Reports [DDOR\ & Other Reports entered by Drilling Site team and display them per formation per field. WAFI is a cutting-edge Well Engineering solution that employs Text Mining techniques to automatically provide offset well information, significantly enhancing efficiency and reducing manual labor spent on data extraction from disparate databases and analysis in Excel. This advanced solution facilitates a deeper understanding of complex relationships between neighboring wells and the well to be drilled. By optimizing this process, our approach aims to effectively pinpoint potential challenge areas, thereby augmenting drilling operations and sustaining overall project success. The tool was trialed in 3 fields in PDO, and it managed to pick up most of the drilling and formation issues identified and expected in each field and in offset wells, based on the Trained Machine Learning Model. The tool picks up the Depth at which the issue occurred, and it links it to the Formation being drilled. The results are viewed in a formation level view or at a Well level view, so it will give an overview of the field issues in offset wells. This will help Team for better planning and preparing for the upcoming wells, and of understanding of the Fields issues. The tool picks up the following Issues: Tight spots, Over Pulls, Reaming and Back Reaming, Vibrations, Stick & Slip, Bit Balling, Fish, Lost Circulation, Fluid Influx, Stuck Pipe & Drill String Failure. The parameters being picked by the model are: Loss Rate range, Flow Rate, Torque, RPM, Overpull and ROP [Rate of Penetration]. This is Phase One of the Tool development, and next plan for Phase Two will include more functionalities and more features, Parameters and enhancements to the tool. Both phases will be discussed in this paper.
Wellbore Stability of Mud-Shale in Ultra-Deep Carboniferous Formation: A Perspective from Mechanochemistry
Zhen, Zhang (PetroChina Tarim Oilfield Company) | Jiaxin, Li (China University of Petroleum) | Yong, Sheng (PetroChina Tarim Oilfield Company) | Lin, Chen (PetroChina Tarim Oilfield Company) | Zheng, Fang (China University of Petroleum) | Yunhu, Lu (China University of Petroleum)
ABSTRACT The wellbore instability is a vital problem when drilling in the ultra-deep carboniferous shale formation in the southwest block of Tarim Oilfield. And, bits are frequently blocked and stuck. Unfortunately, the problems are hardly to be effectively solved by increasing the drilling fluid density. At present, the mechanism of wellbore collapse in the block is still unclear. In this way, it is unable to establish an effective prediction model for wellbore collapse. Therefore, this paper systematically analyses the formation mineral characteristics, physical and chemical properties and stress state in the block to clarify the reasons for wellbore instability of mud shale formation. Consequently, the wellbore stability model of mud shale is established considering the degree of formation collapse, drilling fluid density, activity and plugging. Then, through quantitative analysis and definition of the relationship between the wellbore collapse degree and the density and performance of drilling fluid, the technical countermeasures for wellbore stability are proposed. The analysis model proposed in this paper provides a new way for quantitative design of drilling fluid density and performance in ultra-deep carboniferous mud shale formations. INTRODUCTION Based on statistics, the confirmed recoverable reserves of deep oil and gas reach up to 7.29×1010 t oil equivalent, constituting 49.07% of the world's total recoverable reserves. As much as 70% of China's unconventional oil and gas resources are stored in deep formations, leading to a growing number of ultra-deep wells drilled(Chen et al., 2009; Y. Lu et al., 2011; Zhang et al., 2022). The Tarim Basin in China is a significant region for its vast oil and gas reserves. The Tangu Depression, particularly the Madong buried hill belt in the southwest block of the Tarim Basin, is recognised for its abundant oil and gas resources. However, the Madong structural belt underwent multiple tectonic movements, resulting in extremely complex structural conditions in the basin. The reservoirs in this area are buried deep, reaching depths of more than 6000m on average and are subjected to high temperatures and ultra-high pressure. As a result, this area faces complex wellbore stability issues during exploration and development. In the initial stages of development, due to an unclear understanding of the lithological characteristics and structural stress in the area, complex problems such as well wall collapse, drag, and pipe sticking were common during the drilling process(Zhang & Chen, 2022).
ABSTRACT It has long been recognized that an important step in acquiring mechanical properties from core is to take the measurements at reservoir conditions. However, the actual test often only replicates the effective downhole stresses, while ignoring the elevated temperature downhole. To quantify the effects of temperature in the Eagle Ford Formation, a core testing program was designed to take advantage of having a large volume of similar rock provided by the HFTS 1 phase III horizontal core. This program involved 46 samples taken from ∼2.4 m of horizontal core. This ∼2.4 m of horizontal core represents ∼0.3 m of vertical section inside the Lower Eagle Ford Member. Multiple tests were performed on the core including anisotropy parameters, static and dynamic triaxial testing, pore volume compressibility and tensile strength. Some of the notable results include that the majority of samples showed an increase in tensile strength with temperature, a decrease in shear velocity at temperature, and an increase in Biot coefficient with temperature. PROJECT INTRODUCTION The Zgabay A 14H is the monitoring well associated with the HFTS 1 Phase III refracturing study in the Eagle Ford trend. As part of this study, a horizontal core was taken with the primary objective of understanding hydraulic fracture intensity and behavior in the far field. Geomechanical core testing was one component of the core analysis program designed to help understand and model hydraulic fracture growth. Recent studies by industry and internal testing have shown there is a change in mechanical properties with temperature (Mitra, 2022) However, we had not investigated the effect of temperature on the Eagle Ford Formation. Therefore, with the relatively large volume of rock available in a similar facies provided when taking a horizontal core, we decided to use this unique opportunity to test the effect of temperature, in situ vs. ambient, on core testing results.
- Research Report > Strength Medium (0.54)
- Research Report > Experimental Study (0.54)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.36)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Core analysis (1.00)
ABSTRACT This study involves batch reactor experiments and subsequent analyses of samples from Caney Shale in the Ardmore Basin of South-Central Oklahoma. Samples include mainly rock cores and cuttings recovered from two wells respectively drilled vertically through and horizontally across the Caney Shale. Mineralogical compositions are obtained by X-Ray Diffraction (XRD) measurements whilst microstructure and elemental distribution are acquired by Scanning Electron Microscopy/Energy Dispersive Spectroscopy (SEM/EDS) respectively. Batch experiments are then conducted using selected rock samples and produced fluid from the Caney Formation. Deionized water is also reacted with some samples to serve as standard. Experiments are conducted at 95°C and ambient pressure for 7 and 30 days to assess the geochemical rock-fluid interactions. Results show rock mineralogical compositions are predominantly quartz, feldspar, carbonates, and clay with minor pyrite. Post-experimental mineralogical changes observed in samples include increased amorphous entities especially within the clay portions of XRD plots and dissolution of feldspar and carbonate minerals and formation of new mineral phases, mostly clays and salts. These are corroborated by EDS elemental analyses which show decreased elemental compositions. The implications of reactions mentioned above include but not limited to, scale formation, clay fines migration and shale softening all of which pose significant permeability impairment on formation over time. INTRODUCTION Shale reservoirs account for a large share of unconventional reservoirs in the world (Lyu et al., 2015). However, ultra-low permeability and high clay compositions pose significant challenges when producing from these reservoirs (Dawuda and Srinivasan, 2022, 2023). Producing from these reservoirs therefore requires horizontal drilling and hydraulic fracturing technologies which have proven their efficacy in generating substantial permeability in reservoirs to ensure production (Fujian et al., 2019; Liu et al., 2018). Even after expensive horizontal drilling and hydraulic fracturing, geochemical reactions between engineered fluids and formation leads to fracture constriction and adversely impact petrophysical properties (permeability and porosity) of the reservoir. These technologies are therefore under constant development and improvement in various aspects to ensure fine tuning for specific reservoirs. Under present conditions, much of the hydrocarbon reserves in unconventional shale reservoirs are left unproduced due to rapid decline in permeability following resumption to production after hydraulic fracturing. It is therefore essential to understand the range of geochemical reactions that cause rapid depletion of permeability after hydraulic fracturing and apply these to each shale reservoir to ensure substantial recovery rates.
- Research Report > New Finding (0.48)
- Research Report > Experimental Study (0.48)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Geology > Mineral > Silicate (1.00)
- Geology > Geological Subdiscipline (1.00)