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Collaborating Authors
hydrocarbon
Top oil executives kicked off the CERAWeek by S&P Global conference in Houston on 18 March by expressing their reservations about the swift transition from fossil fuels, highlighting the potential societal costs of replacing oil and gas infrastructure. ExxonMobil CEO Darren Woods said that while the company has "stuck pretty consistently" to managing the fundamentals of the energy transition, he finds that the external conversation is evolving. "People are now beginning to understand that the energy transition is a very complex issue that will require a lot of different variables to be managed effectively," said Woods. He questioned the need for the narrow set of solutions currently driven by ideology, saying that the world needs to "open up the aperture to consider more solutions because we are going to need everything that works to drive emissions down." Woods noted that when President Biden's administration came in intending to advance reductions in emissions and climate change, the industry responded by challenging itself to offer solutions that could meet that objective.
Abstract This work aims to elucidate the potential applications of 2D basin and petroleum system modeling (BPSM) software in the assessment of hydrocarbon accumulations. To demonstrate how much information can be inferred regarding the existence of hydrocarbons and their mechanisms of accumulation in the subsurface, 2D BPSM was applied to two seismic sections that were utilized as case studies. The faults and horizons were digitally represented throughout the modeling phase to create the 2D BPSM for both seismic sections. The 2D BPSM construction used the age and lithology of each layer of the model as inputs. The hybrid technique was used to simulate hydrocarbon migration paths. The simulation findings showed that when the depth decreases, the degree of maturity declines, as some parts are characterized by transformation ratios of up to 100%. For the Upper Cretaceous source rock in model ABZ88-18, the levels of vitrinite reflectance (Ro%) are in the maturity phase and provide oil with Ro% values ranging from 0.6% to 1.3%. Whereas, in model 370, the Ro% values range from 0.55% to 1.3%. Based on the results of the modeling, new prospective hydrocarbon accumulations were found. Model ABZ88-18's estimated total mass is 292.9 million bbl oil and 11.49 million m gas, compared to model 370's estimated total mass of 178.52 million bbl oil.
- Africa > Middle East > Egypt > Gulf of Suez (1.00)
- Africa > Middle East > Egypt > Suez Governorate > Suez (0.41)
- Phanerozoic > Mesozoic > Cretaceous (0.74)
- Phanerozoic > Cenozoic > Paleogene > Eocene (0.32)
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (1.00)
- Geology > Rock Type > Sedimentary Rock > Organic-Rich Rock > Coal (0.54)
- Geology > Structural Geology > Fault > Dip-Slip Fault > Normal Fault (0.47)
- Geophysics > Seismic Surveying > Surface Seismic Acquisition (0.68)
- Geophysics > Seismic Surveying > Seismic Processing (0.55)
- Europe > Norway > Barents Sea > Hammerfest Basin (0.99)
- Africa > Middle East > Egypt > South Central Desert > Kombombo Basin > West Kom Ombo Concession > Duwi Formation (0.99)
- Africa > Middle East > Egypt > Gulf of Suez > Gulf of Suez Basin > Ras Budran Field (0.99)
- (8 more...)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Geologic modeling (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
Reservoir engineers will face in future the challenge of performing their professions for a global society with a significantly increased demand for hydrocarbons. This will require the reservoir engineers to embrace new technologies and engineering methods. In this webinar, experts will explain the technical current challenges and recent progress in four key areas in reservoir engineering discipline. The presentation highlights that, in general, we are in good shape at present for characterization of conventional oil and gas reservoirs thought (FE) using core data, well logs, subsurface technologies and PTA / RTA. There are important challenges in all the above FE areas, particularly at the molecular scale but probably they will become manageable in the not-too-distant future.
This page considers two equilibrium conditions: * The point at which, at a given temperature and pressure, water becomes saturated in either hydrocarbon vapors or hydrocarbon liquids and forms a separate fluid phase. Both water and hydrocarbon dewpoints are represented as the maximum solubility of each phase in the other. Prediction of hydrate formation is covered in Predicting hydrate formation. BecauseF 2, two intensive variables are needed to specify the system. At a given temperature and pressure, the user can determine the saturated water content of gases, the point at which a liquid water phase will precipitate.
- Information Technology > Knowledge Management (0.41)
- Information Technology > Communications > Collaboration (0.41)
Abstract Non-metallic pipe systems are the perfect option for transporting highly corrosive fluids from oil and gas production which are potentially environmentally hazardous, since they contain volatile organic hydrocarbons. The operation of oil and gas production in agricultural lands is common in Europe and requires permeation tight solutions in order to prevent any kind of environmental contamination. In the past, leakages caused by corrosion damages on carbon steel pipes or by permeation of hydrocarbons through pipes made of high-density polyethylene (HDPE) have resulted in environmental damages. In order to prove the suitability of plastic pipes with an integrated aluminum barrier layer tests over a 4-year time period were done in the context of field- and laboratory trials. For the pilot tests performed in a crude oil production system, the oil and water composition was given by the real case. For the systematic laboratory tests, clearly specified test liquids which came as close to providing a representative sample as possible were used. In order to simulate the most severe conditions conceivable, the test liquids were a saturated solution consisting of various volatile hydrocarbons, some of them also chlorinated, and a mixture of pure volatile hydrocarbons with a 10-per-cent share of aromatic toluene. In contrast to single-layer plastic pipes, the pipes featuring a barrier layer were shown to be resistant to permeation of all of the dissolved volatile organic ingredients examined by the tests. These results could be confirmed by the performed pilot test in Romania. Thus, plastic pipes equipped with a metallic barrier layer can be recommended for loss-free transport of aqueous liquids containing hydrocarbons, such as production water in crude oil. Combined with permanent monitoring for the purpose of damage detection, this non-metallic pipe solution complies with even the strictest environmental requirements, thus enabling oil production in environmental sensitive areas and guarantees reliable protection of the environment.
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Health, Safety, Environment & Sustainability > Environment > Waste management (0.94)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (0.68)
- Health, Safety, Environment & Sustainability > Environment > Water use, produced water discharge and disposal (0.68)
Abstract It is challenging to reliably identify fluid components and estimate their saturations in formations with complex lithology, complex pore structure, or varying wettability conditions. Common practices for assessing fluid saturations rely on the interpretation of resistivity measurements. These techniques require model calibration, which is time consuming/expensive and can only differentiate conductive and nonconductive fluids. Interpretation of 2D NMR maps provides a viable alternative for identifying fluid components and fluid volumes. However, conventional techniques for the interpretation of 2D NMR rely on cutoffs in the T1-T2 or D-T2 maps. The application of cutoffs is prone to inaccuracies when fluid-component relaxation responses overlap. To address these shortcomings, we introduce a new workflow for identifying/tracking fluid components and estimating their volumes from the interpretation of 2D NMR measurements. We developed a workflow that approximates 2D NMR maps with a superposition of 2D Gaussian distributions. The algorithm automatically determines the optimum number of Gaussian distributions and their corresponding properties (i.e., amplitudes, variances, and means). Next, a clustering technique is implemented to the dataspace containing the Gaussian distribution parameters obtained for the entire logged interval. Each Gaussian is assigned to a cluster corresponding to different pore/fluid components. We then calculate the volumes under the Gaussian distributions corresponding to each cluster at each depth. The volumes associated with each cluster translate directly into the pore volumes corresponding to the different fluid components (e.g., heavy/light hydrocarbon, bound/free water) at each depth. A highlighted contribution of this work is that, in contrast to the alternative petrophysical interpretation techniques for fluid characterization, the introduced workflow does not require calibration efforts, user-defined cutoffs, or proprietary data sets. Furthermore, approximating 2D NMR data with a superposition of Gaussian distributions improves the accuracy of estimated pore volumes of fluid components with overlapping NMR responses. The clustering using the Gaussian distribution parameters as inputs enables depth tracking of different fluid components without making use of user-defined 2D cutoffs. Finally, the multidimensional nature of the introduced clustering provides the unique capability of identifying different fluid components with 2D NMR response located in the same range of coordinates in a T1-T2 map. We successfully verified the reliability and robustness of the new workflow for enhancing petrophysical interpretation in two organic-rich mudrock formations with complex mineralogy and pore structure.
- North America > United States > Texas (1.00)
- Europe (0.93)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.67)
- Geology > Geological Subdiscipline > Mineralogy (0.61)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Vaca Muerta Shale Formation (0.99)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Sabinas - Rio Grande Basin > Eagle Ford Shale Formation (0.99)
- (25 more...)
Abstract The complexity of the microstructure and fluids in unconventional reservoirs presents challenges to the traditional approaches to the evaluation of geological formations and petrophysical properties due to the low porosity, ultralow permeability, complex lithology, and fluid composition. Nuclear magnetic resonance (NMR) techniques have been playing major roles in unconventional shale characterization in the last decades as NMR can provide critical information about the reservoirs for quantifying their petrophysical parameters and fluid properties and estimating productivity. Laboratory NMR techniques at higher frequency (HF), e.g., 23 MHz, especially two-dimensional (2D) T1-T2 mapping, and their applications have been essential for the noninvasive characterization of tight rock samples for identifying kerogen, bitumen, heavy or light hydrocarbons, and bound or capillary water. Traditional T2 cutoffs, established with low frequency (LF) NMR, no longer apply and need new definitions to reflect the inferences from water and hydrocarbons separately. The crushed rock analysis method, as applied to unconventional formations, has been successful in evaluating total porosity and water saturation but also suffers from inconsistency in results due to desiccation and solvent effects. In the past decade, the oil and gas industry has witnessed significant development of HF NMR techniques that couple advances in petrophysics, petroleum engineering, and geochemistry with a broad range of applications. It is necessary to review such technological advances and draw conclusions to benefit unconventional core analysis programs. This article will summarize key advances in laboratory NMR applications in unconventional shale characterization, including monitoring processes of liquids equilibrium, desiccation, and imbibition in fresh shale samples, determination of activation energy of hydrocarbons in shales, monitoring changes in a shale sample during liquid flooding experiments, and direct measurements on kerogen.
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.48)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Sabinas - Rio Grande Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Maverick Basin > Eagle Ford Shale Formation (0.99)
- (24 more...)
The East Texas Basin is a petroleum-rich field located in five counties of East Texas. It is the second-largest oil field in the United States as it covers approximately 140,000 acres. Over 5 billion wells of oil have been produced since Columbus Marion Joiner discovered it in 1930.[1] Since its discovery, there have been many conventional plays on the Woodbine Formation of the Cretaceous, which was deposited when East Texas was a shallow sea by the Sabine Uplift. The area then eroded and was covered unconformably by an impermeable Austin Chalk.
- North America > United States > Texas (1.00)
- North America > Canada > Alberta > Stettler County No. 6 (0.26)
- North America > Canada > Alberta > Starland County (0.26)
- (2 more...)
- Geology > Petroleum Play Type (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.31)
- North America > United States > Texas > Haynesville Shale Formation (0.99)
- North America > United States > Texas > East Texas Salt Basin > Woodbine Formation (0.99)
- North America > United States > Texas > East Texas Salt Basin > East Texas Field > Woodbine Formation (0.99)
- (3 more...)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)
Volumetrics is a static measurement based on a geologic model that uses geometry to describe the volume of hydrocarbons in the reservoir. Volumetrics, volumetric estimation, is currently the only way that is available to assess hydrocarbons-in-place prior to drilling. The purpose of calculating a volumetric estimation is to evaluate a reservoir and calculate the potential reserves of the reservoir in question. Once drilling has started pressure and production data is collected giving a greater insight into the volume that needs to be evaluated. Volumetrics is an integration of geological, fluid and the modeled relationships.
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)
Svein Ellingsrud with Terje Eidesmo are the recipients of the 2007 SEG Virgil Kauffman Gold Medal Award for their work in the field of electromagnetics and reservior characterization. Terje Eidesmo has a PhD in physics from the University of Trondheim (now NTNU), Norway. He started as a petrophysicist at Statoil in 1991, where his main area was nuclear magnetic resonance logging. Terje was responsible for a number of projects within EM technology, as well as R&D and technical services within the improved oil recovery division. Terje held a professorship in petrophysics at the Norwegian University of Science and Technology (NTNU) for several years.
- Geophysics > Borehole Geophysics (0.55)
- Geophysics > Electromagnetic Surveying (0.36)
- Europe > Norway > Norwegian Sea > Møre Basin > PL 442 > Block 6305/8 > Ormen Lange Field > Springar Formation (0.99)
- Europe > Norway > Norwegian Sea > Møre Basin > PL 442 > Block 6305/8 > Ormen Lange Field > Egga Formation (0.99)
- Europe > Norway > Norwegian Sea > Møre Basin > PL 442 > Block 6305/6 > Ormen Lange Field > Springar Formation (0.99)
- (21 more...)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)