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Flowline blockages can cause losses of millions of dollars of income while blockage remediation is occurring. The most accurate prediction methods allow avoidance of flowline blockages. When hydrocarbon contacts water, the two components separate into two phases in which the mutual component solubility is less than 1.0 mol% at ambient conditions. This splitting of phases affects almost all treatments of mixed water and hydrocarbon systems and is caused by the different molecular attractions within water and hydrocarbons. Hydrocarbon molecules have a weak, noncharged attraction for each other, while water attracts other water molecules through a strong, charged hydrogen bond.
- Information Technology > Knowledge Management (0.41)
- Information Technology > Communications > Collaboration (0.41)
Abstract Generation/accumulation of hydrocarbon has been considered as one of the most plausible mechanisms related to abnormal geopressures observed in many conventional and unconventional reservoirs. In this presentation, we demonstrate that hydrocarbon compositions and phase behaviors of the petroleum fluid can be closely related to the observed abnormal geopressures (either overpressure or underpressure) phenomena. Vapor-Liquid Equilibriums (VLE) of various binary hydrocarbon mixtures as functions of temperature and pressure are determined using the Peneloux Soave-Redlich-Kwong (SRK) Equation of State (EoS) method. Our results indicate that (1) Existence of aromatic hydrocarbon compounds such as Benzene, Ethylbenzene, Toluene, and Xylene (BETX) could mix with hydrocarbon gases in porous spaces under typical offshore shallow well conditions. (2) Abnormal geopressures could occur when the hydrocarbon mixture undergoes a phase transformation acrossing the bubble or dew linee, i.e., when the vapor-liquid co-existance zone disappears. And (3) whether if a geopressure is overpressure or underpressure is determined from the critical temperature (Tc) of the petroleum fluid and the reservoir temperature T. When T > Tc, the hydrocarbon mixture will be in the supercritical phase with increasing pressure and an overpressure zone can be formed, whereas for T < Tc, all hydrocarbon will go into a condensed liquid phase to form an underpressure zone. Our interpretation can be applied to both underpressure and overpressure theoretical models. Accurate knowledge of pore pressure is fundamental to any safe and economic well construction. Various interpretation/prediction models have been developed to incorporate geopressure into the reservoir and basin modeling. This work intends to demonstrate that the phase behavior of hydrocarbons plays an important role in pore pressures.
- Geology > Geological Subdiscipline (0.70)
- Geology > Sedimentary Basin (0.54)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Abstract Potential risks to livestock may occur if they are exposed to releases of petroleum hydrocarbons at or near oil production facilities. In 2004, the American Petroleum Institute (API) published Risk Based Screening Levels for the Protection of Livestock Exposed to Petroleum Hydrocarbons [1]. The API framework, conceptual site model, and screening-level procedures were used in a case study to evaluate potential risks to livestock at the oilfield sites in northeastern Ecuador. API's toxicity reference values (TRVs) as well as their drinking water and soil risk-based screening levels (RBSLs) for livestock were used to evaluate whether levels of hydrocarbons in soil and water could pose a health risk to cattle, calves, sheep, goats, or horses. RBSLs are threshold concentrations in site media (e.g. soil, water, and air) below which no significant unacceptable risks to livestock are expected. Since pigs, chickens, and ducks are also commonly raised in northeastern Ecuador, new TRVs were calculated for them based on a review of all published toxicity values. RBSLs for pigs, chickens, and ducks were then calculated using exposure assumptions aligned with API's conceptual site model. The evaluation presented herein was a screening-level risk assessment using a conservative approach to evaluate potential risks to livestock from exposure to petroleum at the oilfield sites. The RBSLs and TRVs were conservative because they are based on non-lethal endpoints protective of individual livestock, and the mammalian RBSLs for TPH were based on fresh crude oil rather than on the weathered, less toxic oil that is typically found in soils in tropical climates. In this case study, data from over 300 surface soil and 100 surface water samples from seven oilfields in northeastern Ecuador were collected during field inspections conducted from 2004 through 2006. Potential hydrocarbons of concern included: crude oil or total petroleum hydrocarbons (TPH); benzene, toluene, ethylbenzene, and xylene (BTEX); and polycyclic aromatic hydrocarbons (PAHs). Introduction The purpose of this case study was to evaluate claims of potential impacts to livestock in the northern Amazon region of Ecuador. The study area, shown in Figure 1, is an active oilfield concession area currently operated by Petroecuador (beginning in 1990) and formerly operated by Texaco Petroleum Company. Risks to livestock may occur if they are exposed to releases of petroleum hydrocarbons at or near oil production facilities. To address this potential risk, the American Petroleum Institute (API) developed conservative threshold values for petroleum hydrocarbons that can be used to characterize risks to livestock across a variety of conditions. In 2004, API published their Risk Based Screening Levels for the Protection of Livestock Exposed to Petroleum Hydrocarbons [1]. API developed toxicity reference values (TRVs) and soil and water risk-based screening levels (RBSLs) for evaluating risks to cattle, calves, sheep, goats, and horses. In this study, additional TRVs and RBSLs were developed for pigs, chickens, and ducks following the established API framework.
- South America > Ecuador (1.00)
- North America > United States (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- South America > Ecuador > Sucumbรญos > Oriente Basin > Shushufindi Field > Napo Formation (0.94)
- South America > Ecuador > Sucumbรญos > Oriente Basin > Lago Agrio Field (0.94)
- South America > Ecuador > Orellana > Oriente Basin > Sacha Field (0.94)
- (4 more...)
Abstract Complex hydrocarbon charging and distribution in which reservoirs are filled by oil and gas phases with different densities and genetic types inter-fingering within the basin, are common phenomena, and often attributed to vertical migration. This paper discusses the factors that control vertical hydrocarbon migration and presents modelling of the hydrocarbon charging and entrapment history in a tertiary basin in Southeast Asia as a case study. According to the Young-Laplace flow theory of the secondary hydrocarbon migration mechanics, migration occurs in a state of capillary equilibrium in a flow regime dominated by buoyancy and capillary forces. In this study, the invasion percolation simulation algorithm, based on the Young-Laplace flow, was used. During the simulation, three-dimensional (3D) seismic data were used as the high-resolution base grid for migration to capture the effect of both structure and facies heterogeneities on fluid flow. A model of an unfaulted system was presented to make the case. In the study area there is inter-fingering between oil and gas across different formations; most oils are trapped in the deeper formation, oil and gas inter-fingering occurs in the middle formation, and the upper formation contains mostly gas. This arrangement is possible because of the interplay between the expelled fluid buoyancy and relatively weak intra-formational seals within the basin. The modeling results were then calibrated to known accumulations or fluid presence in wells. In a basin dominated by a vertical migration regime, hydrocarbons are prevented from travelling far from the kitchen, thus decreasing prospectivity away from the kitchen. Through a case study, this paper helps to understand the factors that influence hydrocarbon retention and migration that control fluid distribution within a basin. Eventually the study helps geologists to understand prospectivity risking related to hydrocarbon charging, which is one of the main risks in exploration especially in mature basins.
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.69)
- Geology > Sedimentary Geology > Depositional Environment > Marine Environment (0.47)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.30)
- Geophysics > Seismic Surveying > Surface Seismic Acquisition (0.56)
- Geophysics > Seismic Surveying > Seismic Processing (0.46)
- Asia > Indonesia > Java > Northwest Java Basin > Talang Akar Formation (0.99)
- Asia > Indonesia > East Java > East Java Basin > Ketapang Block > Bukit Tua Field (0.99)
Abstract The detection and measurement of migrated hydrocarbons in near-surface marine sediments is a relatively routine exploration method to investigate issues of hydrocarbon charge. The presence of near-surface migrated thermogenic hydrocarbons provides strong evidence that an active petroleum system is present, as well as critical information on source, maturity and migration pathways. There are multiple methods currently applied by industry to collect, prepare, extract, and analyze migrated hydrocarbons within near-surface marine sediments. To improve the detection of seabed thermogenic hydrocarbon seepage, core samples should be collected along likely major migration pathways (cross stratal leakage features) identified by conventional deep seismic and high-resolution seafloor imaging technology. Real time imaging provides greater detail to confirm targeted features for more precise core targeting. Not all targeted cores will hit the designated feature and thus collecting replicates along major migration features is critical. Collecting sediment samples below the Zone of Maximum Disturbance (ZMD) to avoid possible transition zone alteration effects and recent organic matter (ROM) masking problems is critical. Choosing a coring device best suited for local seabed conditions will maximize both penetration and sediment recovery. Multiple sections per core should be collected at variable depths providing a geochemistry profile. Geochemical analysis should include a full range of hydrocarbon types; hydrocarbon gases (C1 to C5), gasoline plus range hydrocarbons (C5 to C12), and high molecular weight hydrocarbons (C12+). Two types of geochemistry samples should be collected; one to capture the volatile light hydrocarbons (C1 to C12) and non-hydrocarbon gases; and a second for the higher molecular weight hydrocarbons (C12+). The light hydrocarbons require special handling and containers to limit volatile loss and prevent post sampling microbial alteration. Bulk sediment measurements such as quantity of organic matter and sand percent can provide additional important non geochemical information. Identification of background versus anomalous populations is critical when evaluating sub-surface migrated seabed hydrocarbons. Sediment hydrocarbons are normally highly altered and may not resemble conventional reservoir oil. Novel petroleum related hydrocarbon compounds need to be examined to fully evaluate organic maturity and source facies. Mapping thermogenic hydrocarbon seeps (oil and gas) relative to key cross-stratal migration pathways via fluid flow modeling and seismic attribute analysis provides an effective petroleum systems tool to better understand the near-surface petroleum relative to subsurface hydrocarbon generation and entrapment. Bear in mind not all surface geochemical surveys will result in the detection of statistically valid thermogenic hydrocarbon seepage.
- North America > United States > Texas (0.46)
- North America > Canada > Alberta > Woodlands County (0.24)
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Oceania > Australia > Western Australia > Timor Sea > Bonaparte Basin > Vulcan Basin (0.99)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Green Canyon > Block 608 > Marco Polo Field (0.99)
- Well Drilling > Drilling Operations > Coring, fishing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Fluid Characterization > Geochemical characterization (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)