CASE STUDIES OF ANAEROBIC METHANE GENERATION AT A VARIETY OF HYDROCARBON FUEL CONTAMINATED SITES
Victor T. Jones, III and Patrick N. Agostino
Exploration Technologies, Inc.
National Ground Water Association
1998 Petroleum Hydrocarbons and Organic Chemicals in Ground Water:
Prevention, Detection, and Remediation
November 11-13, 1998
When conducting soil gas surveys and subsequently mapping the subsurface pollution, it is very important to note and measure biogenic gases. Bacteria that attack hydrocarbons generate carbon dioxide under aerobic conditions and methane under anaerobic conditions. Not only do bacterial activities occur, but percent levels of carbon dioxide and methane are often generated. These biogenic gases are often the largest magnitude components in the entire soil gas mixture. In general, the longer the pollution is present in the subsurface environment, the higher are these biogenic gas levels. Both carbon dioxide and methane can be field screened (measured) with reasonable accuracy in the field using infrared detectors. All screening results, however, should be supported by more rigorous laboratory analyses performed under stringent QA/QC procedures.
Although carbon dioxide is generated by the biodegradation of all types of organic materials and must be used with caution in soil gas investigations, the presence of a concentrated petroleum source such as gasoline, diesel, kerosene, etc., causes a concentrated buildup of carbon dioxide in the subsurface. The average concentration of carbon dioxide in ambient air is only 0.03 percent. Biodegradation of typical soil organic matter generally yields carbon dioxide concentrations between 0.2 to 3-5 percent. Higher concentrations of carbon dioxide measured in various soil vapor samples collected in the vicinity of subsurface petroleum contamination yields values as high as 5 to 30 percent, an indication that biodegradation is significantly enhanced within the area of the contaminant plume.
Ambient air methane ranges from 1.5 to 2 ppm by volume. Methane concentrations generally range from 0.5 to 1 ppm in areas where there is no pollution or deep gas migration, suggesting that normal soils act as a sink for atmospheric methane. Since biogenic methane is generated under anaerobic conditions, it is usually generated deeper in subsurface sediments than is carbon dioxide and appears to correlate mainly with the location of free (liquid) product. As with carbon dioxide, the longer that the pollution is present in the subsurface environment, the higher are the methane soil gas levels. Petroleum contaminated sites often exhibit biogenic methane concentrations ranging from several thousand parts per million (ppm) to percent levels. For example, JP4 jet fuel under the Miami Airport generated methane levels as high as 60 percent (Hayman et al., 1988).
Biogenic methane and carbon dioxide data, when used in tandem with specific organic vapor components (C1-C4 and C5+), are very useful in defining the horizontal (areal) extent of hydrocarbon contaminants in the subsurface environment. The presence or absence of specific petroleum related hydrocarbons aids in interpretation and confirms the relationship of the biogenic gases to their appropriate sources. These two biogenic gases generally can be used for mapping the distribution of contaminated soils, even when the contamination is very old and the lighter hydrocarbon volatiles are nearly absent.
Case One - Guadalajara Service Station
Gasoline, Pre-Existing Leak
Normal-butane and methane plume maps (Figure 4 and Figure 5, respectively), constructed using data collected on a service station in Guadalajara illustrates a simple case where a leaking dispenser line release resulted in a plume of gasoline in the vicinity of the leak. Soil gas samples were collected at a uniform depth of four feet with ETIís manually operated soil gas sampling probe. Methane concentrations up to 200,000 ppm (20%) were detected near the source of the leak. It is important to note that the methane concentrations (and contours) correlate very well with the normal-butane (a major vapor phase component of gasoline) concentrations. In this case, as shown by the plume maps, the contamination was confined to the service station property.
Case Two - Guadalajara Service Station
Gasoline/Diesel, Pre-Existing Leak
In another area of Guadalajara, more than one year after the explosions, liquid hydrocarbons were observed entering a 10-meter deep trench/canal along a street during the installation of a large diameter sewer conduit. A regional soil vapor survey was conducted in the area to determine the source(s) of the liquid hydrocarbons (gasoline and diesel) and the migration pathway(s). The location and geometry of the contaminant plume is well defined by normal-butane (Figure 6). In this case, both the methane (Figure 7) and carbon dioxide (Figure 8) plumes show a clear association with the normal-butane plume and define the subsurface contamination. The normal-butane and methane plume maps are coincident and delineate the location(s) of residual soil and groundwater contamination. The carbon dioxide plume (Figure 8), however, has a larger areal extent than the methane and normal-butane plumes. The outer edges of this carbon dioxide plume form a halo around the main area of residual contamination where oxidizing conditions appear to be dominant. Two active migration pathways, that extend from the residual portion of the plume southward toward the trench, are only apparent on the carbon dioxide plume map. It is highly probable that oxidizing conditions are dominant along these highly oxygenated (highly porous and permeable) active pathways, thus allowing for the generation of predominantly carbon dioxide. Liquid product was observed entering the trench at the two locations where the carbon dioxide plume "extensions" or "fingers" intersect the trench (Figure 8). Based upon the hydrocarbon constituents quantified and mapped, it was determined that both diesel and gasoline had been released at this service station, which is north and upgradient of the trench. Ten monitor wells were installed using the plume maps as a drilling guide. These wells confirmed the groundwater gradient and migration pathway of the contamination. High resolution capillary gas chromatography results of soil vapor samples, and soil and groundwater samples obtained from the trench and monitor wells confirmed that the hydrocarbons entering the trench included a gasoline/diesel mix that originated at the service station. In this case the leak had definitely existed for a considerable period of time; methane concentrations approaching 90,000 ppm (9%) were detected.
Case Three - Guadalajara Service Station
Gasoline, Recent Leak
Liquid product (gasoline) was discovered in a sewer adjacent to a service station in Guadalajara. A monitor well drilled in the street adjacent to the sewer was also found to contain liquid phase gasoline. A soil gas survey was conducted in the vicinity of the sewer and service station using ETI's manually operated four-foot sampling probe. Soil vapor analytical results (and the resulting plume maps) indicate the location and areal extent of the contaminant plume; the main free product (NAPL) plume is clearly defined by normal-butane (Figure 9). The well containing the free product is located within the plume, however, it is not located near the leak (which occurred at a dispenser island). The offsite migration of contaminants to the northwest onto the adjacent property caused minimal impact to the adjacent sewer. Methane (Figure 10) has a similar distribution to normal-butane, and aids in the interpretation of the extent and migration pathways associated with the contaminant plume. The largest methane concentration of 25,000 ppm (2.5%) occurs at site 47 (near the dispenser island leak, where contamination has existed for a long period of time), while much more modest levels 4,000 Ė 15,000 ppm (0.4% - 1.5%) are present over an area where gasoline has appeared to migrate offsite more recently. These lower methane concentrations suggest areas of relatively recent migration of gasoline (involving a shorter biodegradation time). This interpretation, however, should be used with caution, since other site conditions could affect the levels of methane generation.
Case Four - Guadalajara Pipeline Leak
Gasoline, Survey 14 Days After Leak
An excellent opportunity to investigate the time required for gasoline contamination to generate anaerobic methane was provided by a release from a liquid petroleum product pipeline in a residential area of Guadalajara. The release was detected during pressure testing of the pipeline following the sewer explosions in 1992. Although the location of the release (hole in the pipeline) was determined, the volume and product type(s) released were unknown. ETI's task included determining the areal and vertical extent of contamination resulting from the release and the type of product or products lost. It was mandatory that the assessment and remediation of the contamination be performed quickly and efficiently since the residents in the area had been evacuated from their homes. The residents would not be allowed to return to the area until the local government officials were certain that there was no threat to their health and safety. A soil vapor survey was conducted using ETI's manually operated four-foot probes along the pipeline, and on a uniform sampling grid throughout the adjacent residential area. All vapor samples were analyzed for light C1-C4 and C5+ (pentane-xylenes+) hydrocarbons. The results of the soil vapor analyses were used to construct hydrocarbon component plume maps that exhibited the areal extent of the contamination. The soil vapor plume maps were used to determine the placement of boreholes/monitor wells, which were necessary to determine the vertical extent of the contamination. Hydrocarbon constituent plume maps were constructed to illustrate the areal extent of subsurface contamination in soils and groundwater. The normal-butane (a major volatile component of gasoline) soil vapor plume map (Figure 11) was extremely diagnostic in delineating the extent of the contamination, since a gasoline product was released from the pipeline. Boreholes were drilled and sampled, using the soil vapor plume maps as a guide, to determine the vertical extent of the contamination. Integration of the soil vapor and borehole data allowed for a three dimensional interpretation of the subsurface contamination. Monitor wells were installed in the most strategic locations within the plume boundaries, and converted to recovery wells (for NAPL, dissolved and vapor phase contaminants) during the remediation phase of the project. Due to a systematic and efficient approach to the problem, the soils and groundwater in the area were remediated to specified cleanup levels four months after installation of the remediation systems (six months after the commencement of the assessment). Of particular interest is the methane plume map (Figure 12); methane levels associated with the high normal-butane concentrations are generally less than 1000 ppm (0.1%). In this case, the gasoline contamination had occurred only 14 days before the assessment was conducted, therefore, anaerobic degradation (and the formation of biogenic methane) was in its early stages.
Case Five - Three Service Stations, Austin Chalk
Gasoline, Pre-Existing Leak (Four Years Old)
This case study involves the soil gas assessment of three gasoline stations at a busy intersection in a major Texas city. Four to seven feet of soil overlies the Austin Chalk, an unconformable surface that provided the lower boundary for the contamination; no groundwater was present in this interval. The surface is nearly completely covered by concrete, which provides a cap. Gasoline had entered the underground telephone conduits four years before ETI's soil gas assessment was conducted. In this area, no significant amount of liquid product (NAPL) was trapped onsite because there is effectively no available near-surface reservoir, except for fractures in the top of the chalk. Methane and normal-butane plume maps constructed using data collected in the area show good correlation (Figure 13 and Figure 14, respectively). Due to the lack of NAPL and the length of time (four years) since the release had occurred, the normal-butane concentrations were relatively low (500 ppm) resulting from volatilization and/or biodegradation. The methane concentrations, however, approached 10,000 ppm (1%), despite the low residual levels of contamination. It is also important to note that the methane plume boundaries are similar to the normal-butane plume boundaries. Despite the shallow depth of the soils (4 to 7 feet) and the confinement provided by the concrete cover, the biogenic methane generated did not spread out and fill all the available space under the concrete cover. It is probable that methane oxidizers consume any methane that migrates to the outer edges of the plume, thereby keeping the biogenic gases confined to the plume geometry defined and controlled by the subsurface contaminants.
Case Six - Natural Condensate Gas Processing Plant
Condensate/Crude Oil, Pre-Existing Leak
Non-aqueous phase liquids (NAPL) were encountered in one of several observations/monitor wells drilled on a gas processing facility. It was suspected by facility personal that a product pipeline entering the property was leaking. ETI conducted a soil vapor survey on the facility in the vicinity of the pipelines and monitor well where the NAPL had been encountered on the groundwater. A sampling grid containing 100-foot centers was initially utilized, and later increased to 50-foot centers in areas where more detail was required. The normal-butane map (Figure 15) clearly shows that the contamination was not limited to the area surrounding the monitor well containing the NAPL. Five distinct contaminant plumes were delineated on the facility. A comparison of liquid product sample chromatograms with soil vapor sample chromatograms indicated that several releases of at least three distinct products (two condensates and a crude oil) had occurred at the facility over time. Hydrocarbon component ratios and various chromatographic signature analyses were used to determine which product was lost in each area of the property. A very good correlation exists between the methane plume map (Figure 16) and the normal-butane plume map (Figure 15) which defines the subsurface liquid product contamination.
Case Seven - Product Pipeline
Benzene - Hexane Mix, Pre-Existing Leak
This study involved the soil vapor assessment of contamination resulting from leakage from a product pipeline carrying an unusual product mix of benzene in a hexane matrix. The methane plume map (Figure 17) correlates well with the benzene plume map shown in Figure 18. However, the methane levels are fairly modest (less than 10,000 ppm, 1%) even though the leak had existed for some time before the survey was conducted.
Case Eight - Gulf Coast Refinery
Gasoline/Diesel, Pre-Existing Leak
This case study involves a soil gas assessment conducted over a refinery located on a Gulf of Mexico beach. The dominant lithology beneath the site is sand, and the groundwater is approximately four feet below the surface. Methane, carbon dioxide and C5+ hydrocarbon plume maps (Figure 19, Figure 20, and Figure 21, respectively) were constructed using results from samples collected with manually operated four-foot soil vapor hand probes. Samples were collected in the vicinity of the loading racks where both gasoline and diesel contamination were known to exist for an extended period of time. High resolution capillary gas chromatography results (Figure 22) confirm areas of predominantly diesel and gasoline/diesel contamination. Lead analyses and high resolution capillary gas chromatography analyses were performed on actual products stored on-site at the time the survey was conducted. The analyses confirmed that the NAPL encountered in monitor wells (Figure 22), and soil vapor signatures of contaminants present in the subsurface were not current formulation fuel products. The contamination was the result of relatively old releases of refined petroleum products. Beneath this site, methane and carbon dioxide concentrations reached levels as high as 200,000 ppm (20%) and 18%, respectively, indicating biodegradation processes had occurred over a long period of time.
Case Nine - Gulf Coast Refinery
Kerosene/Para-Xylene, Pre-Existing Leak
Another example from the same refinery (discussed above) provides some contrast in that different product types were lost in different areas. Two additional plumes mapped using the soil vapor data were related to two different product pipeline leaks: kerosene under the basement of a laboratory, and para-xylene near the eastern boundary of the refinery. High resolution capillary gas chromatography results (Figure 23) identified these two products. The locations of these two separate plumes were delineated using the soil vapor results. The association of the carbon dioxide (Figure 24) and methane (Figure 25) plumes with the C5+ hydrocarbons plume (Figure 26) is obvious. Methane and carbon dioxide concentrations are as high as 200,000 ppm (20%) and 18%, respectively within the kerosene plume, but are considerably lower in the para-xylene release area. The abundant amounts of normal alkanes in the kerosene favor biological reactions, leading to high concentrations of these biogenic gases. Fuel products, such as para-xylene appear to produce less favorable environments for the biodegradation by anaerobic and aerobic bacteria.
Case Ten - Guadalajara Railroad Facility
Diesel, Pre-Existing Leak (At Least Eighteen Years)
A plume consisting entirely of railroad diesel fuel was mapped using data obtained from a near surface soil vapor survey. In this case, diesel product was entering a subway station through the walls of a tunnel. At the time of this investigation, the diesel had been accumulating in the subway for over 18 years. Two sumps had been installed to collect and extract the product from the underground station. The continuing source of the diesel product was undetermined. State and federal agencies in Mexico contracted ETI to determine the source and migration pathway(s) of the hydrocarbon contaminants (diesel) entering the subway station and adjacent residential area. A regional soil vapor survey, using ETI's seven-foot manually operated probe, was conducted throughout the residential area and in the vicinity of the subway to determine the source and migration pathway(s) of the liquid diesel product. Soil vapor samples were collected on a regional grid spacing containing 30 meter spacing, with closer spaced detailed sampling performed along the subway and in areas containing underground sewer, water and electrical conduits. The primary source of the diesel contamination was determined to be a railroad maintenance facility, which had been active for approximately 40 years. Soil vapor plume maps (Figure 27, Figure 28, and Figure 29) show the horizontal extent and migration pathways of diesel products lost at the railroad facility located southwest of the subway station. The soil vapor plume patterns are consistent with the reported ground water gradient in the area, which is to the northeast. Liquid product samples were collected from the subway station sumps, and from active and inactive facilities that store and dispense petroleum products in the area. High resolution capillary gas chromatography analyses were used to fingerprint the liquid product samples obtained from monitor wells on the railroad facility and diesel samples collected from the subway sumps. These analyses indicated that the products were derived from the same parent diesel product released at the railroad maintenance facility. Although diesel does not contain significant light vapors, the C5+ plume map (Figure 29) does provide accurate information on the location of the diesel plume. The methane plume map (Figure 28) is nearly identical in form to the C5+ plume, suggesting that methane is generated in very close proximity to the liquid product, where highly reducing conditions exist. In contrast, carbon dioxide (Figure 27) forms a very broad plume, and provides information for detection and delineation of the entire diesel plume.
Case Eleven - Guadalajara LNG Manifold
Cook-Stove Propane, Pre-Existing Leak
A detailed soil vapor survey was conducted on a sampling grid containing 5 to 10 meter spacing in the vicinity of a propane, butane and ethane soil vapor anomaly, detected during the above regional survey. The ratios of propane, butanes, ethane and other trace gases composing this anomaly indicated the probable source of contamination was leakage of LNG (liquid natural gas) utilized throughout Mexico by residences and businesses. Interpretation of the soil vapor data indicated that the source of the subsurface contamination was located in the garden area of a Social Services Building Complex. The supervisor of the complex had no knowledge of underground gas lines on the property. During excavation and gas monitoring operations, active and abandoned lines and valves were discovered in the garden area of the complex. A box containing corroded valves and distribution lines were found at the location containing the highest concentrations of propane (Figure 30) and butanes. The exact location of the underground LNG ("cook-stove" gas) source was determined by the detailed soil vapor survey, and a vapor extraction system was installed in the garden area to extract the potentially explosive gases.
This case study provides an excellent example of the concentrations and relative locations of biogenic methane (Figure 31) and carbon dioxide (Figure 32) associated with a unique fuel product, that consists mainly of propane (and butanes) with a small complement of other light hydrocarbon gases. Analytical laboratory results of the "cook-stove" propane and associated gases are shown in tabular form in Figure 33. The biodegradation cells associated with the propane contamination is unique, since this contamination occurs in soils made up of volcanic tuff. The tuff deposits are very low in organic carbon, making it less likely that the biogenic gases are being generated from the degradation of natural organic material. The highest methane (Figure 31) and carbon dioxide (Figure 32) concentrations form halos around the edges of the highest propane concentrations. The carbon dioxide occurs where oxygen is more plentiful. The slightly lower methane concentrations (10,000 ppm, 1%) observed within the main propane anomaly might be the result of dilution associated with the leaking propane fuel.
Case Twelve - Tank Farm Storage Complex
Gasoline/Diesel/Jet Fuel, Pre-Existing Leak
The final case study addressed in this paper involves an area containing six tank farm storage and distribution terminals. ETI was contracted by city officials to conduct a site assessment to determine the extent of any offsite migration of refined petroleum products (originating at the terminals) that might have occurred down gradient onto residential and public park properties. ETI's 12-foot manual sampling probe was used to collect soil vapor samples on a grid containing approximately 350 sampling sites. As in the previous case studies, the carbon dioxide plume map (Figure 34) shows the largest areal extent, while the methane plume (Figure 35) shows a more focused areal extent. Both plumes correlate well with the C5+ hydrocarbon plume (Figure 36) which is a direct result of the petroleum contaminants present in subsurface soils and groundwater. C5+ concentrations clearly show a good correlation with methane concentrations, which exceed 100,000 ppm (10%). The largest carbon dioxide concentrations are in excess of 14%, and clearly encompass the C5+ and methane anomalies (plume maps).
To further confirm the areal extent of the contaminant plumes, and to delineate the vertical extent, over 90 direct-push borings were continuously sampled from surface to ground water (approximately 20 feet depth) using the soil gas plume maps as a guide. Thirteen (13) monitor wells were subsequently installed using the soil vapor and borehole data. Twelve of these 13 wells were found to contain NAPL. Liquid product samples were analyzed using high resolution capillary gas chromatography to determine the product types released at the terminals over a 40-year period. The products released included several formulations of gasoline, diesel and jet fuel. Groundwater samples analyzed for C5+ hydrocarbons (using the same GC method used for the soil gas samples), benzene (Method 8020/602) and MTBE (by GC and confirmed by GCMS) are shown in Figure 37, Figure 38 and Figure 39, respectively.
A good correlation exists between carbon dioxide, methane and C5+ hydrocarbon vapors from the vadose zone soils. The groundwater contaminant plume (Figure 38 and Figure 39) confirms the usefulness of measuring vapor phase biological gases. The very narrow plume (less than 50 feet wide) in the lower portion of the maps should be noted. Liquid product was obtained from four monitor wells installed along this very narrow migration pathway identified by mapping the soil vapor data. These wells could never be properly located by random drilling. The state regulatory agency had installed 17 wells within this general area (one within 50 feet of one of the main plumes) without encountering any NAPL (free product).
Organic Vapor Detector Instruments
Given the utility of soil gas surveys, it is unfortunate that many environmental scientists have a low opinion of the technology. This problem has been addressed in considerable detail by Nyquist et al. (1990) and Robbins et al. (1990a, 1990b) who have found that a large number of the reported failures in the application of this technology are caused by the use of organic vapor detection instruments which do not yield a correct response under most site conditions. The response of total organic detector instruments is significantly affected by moderate to high concentrations of biogenic methane and carbon dioxide. The reduction in response of a PID detector in the presence of anomalous methane (50,000 ppm, or 5%) can be 95% (Figure 40). Although the PID does not detect methane, the methane absorbs energy and reduces the sensitivity of the detector. Infrared detectors (Figure 41), however, shows a good response to methane and other natural gas and/or gasoline type mixtures down to levels around 1000 ppm (0.1%). Heavier molecular weight hydrocarbons also produce a positive response, which make infrared detectors very useful for field screening samples. The infrared instruments are also capable of measuring carbon dioxide.
Soil Gas Surveys
Soil gas surveys are excellent assessment tools for defining the areal (horizontal) extent of subsurface contamination, when used properly, as demonstrated by the case studies addressed above. The main reason some soil gas surveys fail to delineate the areal extent of contamination is the surveys are not performed properly. Many surveys are performed similar to groundwater monitoring events where three volumes of vapors are removed from the probe hole prior to collecting a sample. The objective should be to collect and measure the equilibrated vapors present in the subsurface soils. In nature, equilibrium is established between various vapors (methane, carbon dioxide, C5+ hydrocarbons) and the subsurface petroleum product responsible for the contamination. This equilibrium is in delicate balance (particularly in low-permeability clays) and is easily disturbed.
Soil gas anomalies occur in "hydrocarbon spots" defined by geologic depositional features, and as such, are naturally discontinuous (Jones and Burtell, 1996). This limitation can be overcome by high-density sampling, coupled with a proper understanding of the geological environment. A 15-meter grid spacing (distance between sampling locations) is generally recommended, although on some sites a 3-meter grid may be required. Soil vapors are derived from residual (sorbed) phase, free phase (NAPL) and dissolved phase hydrocarbons present in the subsurface environment. Obviously residual phase contaminants (in soils) contribute more to the hydrocarbon soil gas levels measured than dissolved or liquid phase contaminants. This is a result of the sorbed phase contaminants being present at shallower depths, closer to the depths at which the samples are collected. These differences, however, can be addressed during interpretation of the data, provided adequate sampling (high density, multiple depth samples, etc.) has been performed.
The importance of spacing cannot be overemphasized, both for soil gas samples and monitor wells. The objectives of soil gas and monitor well investigations are to provide the true horizontal and vertical extent of the contaminated areas. Monitor wells are no substitute for soil gas surveys unless they are plentiful and closely spaced. In addition, the borehole/monitor well must be sampled continuously from the surface down to groundwater. The above options are not practical for monitor wells because they are not cost-effective. Soil gas surveys, followed by selected borings (sampled continuously), followed by monitor well installations can collectively and successfully accomplish the desired objectives at a reasonable cost.
Dissolved Gas Samples
Contrary to popular belief, surface geochemical sampling does not have to be confined to soil vapors located entirely above the water table. Equivalent results can be obtained by measuring the gases dissolved in shallow perched groundwater zones or aquifers, which are always in dynamic equilibrium with the surrounding environment. If anomalous gases are contained in the pore space of subsurface soils, then these same gases will generally be dissolved in the subsurface waters.
Gas magnitudes in the free pore space and dissolved in the associated waters will be different, however, they will both be very close to zero in background areas, and show sufficient contrast from background, whenever they are in close proximity to contamination. In areas of very shallow ground water the best sample is generally obtained from analyzing the dissolved gases in the subsurface water sample. If sufficient contrast with background is observed, it is possible to mix samples obtained from different media (soil vapors and dissolved gases in water) in a near surface geochemical reconnaissance survey.
A soil gas survey is an accurate method for quickly and inexpensively measuring the presence and horizontal extent of contamination resulting from a large variety of hydrocarbon products such as gasoline, jet fuel, diesel and chlorinated solvents. The recognition and analysis of biogenic methane and carbon dioxide gases significantly increases the effectiveness of soil gas technology, particularly for the less volatile products, such as diesel and kerosene. Both methane and carbon dioxide can be measured (screened) with reasonable accuracy in the field with very little interference using infrared detectors. Extreme caution must be exercised when using PID detectors since these instruments are sensitive to, and interfered with by nearly everything (methane, carbon dioxide, moisture content, etc.), generally resulting in erratic and erroneous results.
Carbon dioxide is generated at the top, edges, and possibly the bottom of the contaminant mass where oxygen dominates. Methane requires strict anaerobic conditions, and is obviously generated in close proximity to the free product "cores", where oxygen has been scavenged. If samples are collected on a high enough density, every contaminated "core" becomes a biodegradation center that can be individually mapped using the assessment data. Our data show that anaerobic methane is generated in significant concentrations in those areas containing petroleum product contamination. Data from regional environmental studies conducted by ETI verify that biogenic methane is not generated in background areas, located adjacent to those areas containing moderate to high levels of hydrocarbon contamination.
It should be noted that soil gases indicate the presence of contamination, but do not directly reflect the actual concentrations of residual or dissolved phase contaminants, or the thickness of the NAPL in the subsurface. Additional samples/data must always be gathered from direct-push borings and monitor wells to determine the true horizontal and vertical extent of any subsurface contamination. Because the horizontal extent of subsurface contamination is controlled by geologic factors, a geochemical survey plume map should never be considered to provide an exact picture of any or all contaminated layers; the plume map is often a composite of the subsurface contamination at all levels. Samples should be collected at multiple depths and on a high-density grid in order to fully evaluate the horizontal and vertical extent of the contamination within a study area. An understanding of the subsurface geology will also help one appreciate the complexity of the problem (contamination) and allow for a sound interpretation.
Soil gas surveys are cost-effective, time-efficient, and have the advantage of being non-disruptive to normal business operations. ETI's soil gas sampling probes can be used in congested areas, within a refinery or gas plant, where no other equipment can easily be deployed. Because of the lower cost and time involved in conducting a soil gas survey, a greater number of locations can be sampled, greatly increasing the potential for more accurate mapping of the horizontal and vertical extent of the contamination. Using the soil gas data, monitor wells can be placed within the most contaminated areas, thus significantly improving the assessment data. This approach will allow for a more thorough remedial action plan and shorten the time required for cleanup.
Abdul, A.S., S.F. Kia, and T.L. Gibson, 1989. Limitations of monitoring wells for the detection and quantification of petroleum products in soils and aquifers, Ground Water Monitoring Review, Spring. pp. 90-99.
Anderson, R.K, Scalen, R.S., Parker, P.L., and E.W. Behrens, 1983. Seep oil and gas in Gulf of Mexico slope sediments:. Science, v. 222 (4624), pp. 619-621.
Baehr, A.L., 1984. Immiscible Contaminant transport in soils with an emphasis on gasoline hydrocarbons, Ph.D. Dissertation, University of Delaware.
Bond, E.J. and T. Dumas, 1982. A portable gas chromatograph for macro and microdetermination of fumigants in the field. J. Agri. Food Chem., v. 30, no. 986.
Chapelle, Francis H., S. Haack, P. Adriaens, and P. Bradley, 1996. Comparison of Eh and H2 measurements for delineating redox processes in a contaminated aquifer, American Chemical Society, Environmental Science & Technology, v.30, no.12, pp. 3565-3569.
Cherry, J.A., 1996. Conceptual models for chlorinated solvent plumes and their relevance to intrinsic remediation; Symposium on Natural Attenuation of Chlorinated Organics in Ground Water: EPA/540/R-96/509, Sept., Office of Research and Development, U.S. Environmental Protection Agency, Washington, D.C., pp. 29-30.
Claypool, G.E., and I.R. Kaplan, 1974. The origin and distribution of methane in marine sediments, in I.R. Kaplan, ed., Natural gases in marine ssediments: New York, Plenum Press, pp. 99-139.
Drozd, R.J., G.J. Pazdersky, V.T. Jones, and T.J. Weismann, 1981. Use of compositional indicators in prediction of petroleum production potential (abs.). Presented at: the 1981 American Chemical Society Meeting, Atlanta, GA, March 29-April 3.
Eklund, B., 1985. Detection of hydrocarbons in groundwater by analysis of shallow soil gas/vapor, Prepared for the American Petroleum Institute.
Hayman, J.W., R.B. Adams, and J.J. McNally, 1988. Anaerobic biodegradation of hydrocarbon in confined soils beneath busy places: A unique problem of methane control, In Proceedings of Petroleum Hydrocarbons and Organic Chemicals in Ground Water: Prevention, Detection and Restoration. Houston, Texas Nov 9-11, NGWA. V.1, pp. 383-396.
Hoag, G.E. and M.C. Marley, 1986. Gasoline residual saturation in unsaturated uniform aquifer materials, ASCE, Jour. Env. Eng. Div., v. 112, no. 3, pp. 586-604.
Janezic, G.G., 1979. Biogenic light hydrocarbon production related to near-surface geochemical prospecting for petroleum (abs.). AAPG, April.
Johnson, P.C., M.W. Kemblowski, and J.D. Colthart, 1988. Practical screening models for soil venting applications, In Proceedings of NWWA/API Conference on Petroleum Hydrocarbons and Organic Chemicals in Ground Water, Houston, Texas.
Johnson, P.C., S. Stanley, M. Demblowski, D. Byers, and J. Colthart, 1990. A practical approach to the design, operation, and monitoring of in situ soil-venting systems, Ground Water Monitoring Review, Spring, pp. 159-178.
Jones, V.T., and R.J. Drozd, 1979. Predictions of oil or gas potential by near surface geochemistry. AAPG Bull., V. 63, 699 pp.
Jones, V.T. and H.W. Thune, 1982. Surface detection of retort gases from an underground coal gasification reactor in steeply dipping beds near rawlins, Wyoming. Soc. Petrol. Engineers, SPE 11050, 24 pp.
Jones, V.T., 1983. Surface monitoring of retort gases from an underground coal gasification reactor: time dynamics (abs.). Proceedings of the 1983 American Chemical Society Annual Meeting, Washington, D.C., September.
Jones, V.T., and R.J. Drozd, 1983. Prediction of oil or gas potential by near-surface geochemistry, AAPG Bull., V. 67, pp 932-952.
Jones, V.T., 1984. Overview of hydrocarbon extractions in soils and waters: research needs and problems. Presented at: American Petroleum Institute Workshop for Sampling and Analytical Methods for Determining Petroleum Hydrocarbons in Groundwater and Soil, November 27-29, Denver, API publication no. 841-44490.
Jones, V.T., Burtell, S.G., Hodgson, R.A., Whelan, T., Milan, C., Ando, T., Okada, K., Agtsuma, T., and Takono, O., 1985. Remote Sensing and Surface Geochemical Study of Railroad Valley, Nye County, Nevada. Presented at: the Fourth Thematic Mapper Conference, Remote Sensing for Exploration Geology, San Francisco, California, April 1-4.
Jones, V. T. and Burtell S. G., 1996. Hydrocarbon flux variations in natural and anthropogenic seeps, in D. Schumacher & M.A. Abrams, eds., Hydrocarbon migration and its near-surface expression: AAPG Memoir 66, p. 203-221.
Jones, V.T., Matthews, M.D., and D. Richers, 2000. Light hydrocarbons in petroleum and natural gas exploration. Handbook of Exploration Geochemistry: Geochemical Remote Sensing of the Sub-surface. Vol. 7, Chapter 5, Elsevier Science Publishers, Editor Martin Hale.
Kaplan, I.R., 1994. Identification of formation process and source of biogenic gas seeps, Isr. J. Earth Sci.; v. 43, pp. 297-308.
Kerfoot, H.B. and C.L. Mayer, 1986. The use of industrial hygiene samplers for soil-gas surveying, Ground Water Monitoring Review, V.6, p.74.
Lappala, E. and G. Thompson, 1983. Detection of groundwater contamination by shallow soil gas sampling in the vadose zone theory and applications, NGWA Conference Proceedings on Characterization and Monitoring of the Vadose Zone, Las Vegas, Nevada, Dec. 8-10, pp. 20-28.
MacDonald, I. R., G. S. Boland, J. S. Baker, J. M. Brooks, M. C. Kennicutt, and R. R. Bidigare,, 1989, Gulf of Mexico hydrocarbon seep communities, II. Spatial distribution of organisms at Bush Hill: Marine Biology, v. 101, p. 235-247.
Marrin, D.L., 1987a. Soil-gas sampling strategies: Deep vs. shallow aquifers. Proceedings of the First National Outdoor Action Conference on Aquifer Restoration, Ground Water Monitoring, and Geophysical Methods. NGWA, p.437.
Marrin, D.L., 1987b. Soil gas analysis of methane and carbon dioxide: Delineating and Monitoring Petroleum Hydrocarbons, Proceedings of the Conference on Petroleum Hydrocarbons and Organic Chemicals in Ground Water, NGWA/API, in press.
Matthews, M.D., V.T. Jones, and D.M. Richers, 1984. Remote sensing and hydrocarbon leakage. Presented at: the 3rd Inter. Sympos. on Remote Sensing of the Environment, ERIM, Colorado Springs, April.
Newell, C.J., Gonzales, J. Miller, R.N., Rifai, S.H., Wiedemeier, T.H., and J.A. Winters, 1995. Modeling intrinsic remediation with multiple electron acceptors: results from seven sites, In Proceedings of Petroleum Hydrocarbons and Organic Chemicals in Ground Water: Prevention, Detection and Restoration. Houston, Texas Nov 29-Dec 1, NGWA., pp. 33-47.
Nohsen, M., M. Nimmons, and E. Sirota, 1983. Delineation of underground hydrocarbon leaks by organic vapor detection, NGWA Conference Proceedings on Characterization and Monitoring of the Vadose Zone, Las Vegas, Nevada, Dec. 8-10, pp. 94-97.
Mousseau, R.J. and J.C. Williams, 1979. Dissolved hydrocarbons in coastal waters of north america (abs). AAPG Bulletin, V. 63, pp. 699-700.
Nyquist, J.E., D.L. Wilson, L.A. Norman, and R.B. Gammage, 1990. Decreased sensitivity of photoionization detector total organic vapor detectors in the presence of methane. Am. Ind. Hyg. Assoc. J. 51(6):326-330.
Pirkle, R.J. and R.J. Drozd, 1984. Hydrocarbon contamination in the near soil (abs). Presented at: the 187th Annual Meeting. American Chemical Society, St. Louis, MO., April 8-13.
Price, A. and A. Heatherington, 1984. The influence of soil/sediment ph of minerals on the adsorbed hydrocarbon technique for geochemical exploration for petroleum (abs). Presented at: the 187th ACS National Meeting, St. Louis, April 8-13.
Richers, D.M., 1984. Comparison of commonly applied soil-gas techniques used in evaluating hydrocarbon potential. Presented at: the 187th Annual Meeting of the American Chemical Society, St. Louis, Missouri, April.
Robbins, G.A., B.G. Deyo, M.R. Temple, J.D. Stuart, and M.J. Lacy, 1990a. Soil-gas surveying for subsurface gasoline contamination using total organic vapor detection instruments - Part I. theory and laboratory experimentation, Ground Water Monitoring Review, Summer, pp.122-131.
Robbins, G.A., B. McAninch, F. Gavas, and P. Ellis, 1995. An evaluation of soil-gas surveying for H2S for locating subsurface hydrocarbon contamination, Ground Water Monitoring Review, Winter, pp. 124-132.
Salanitro, J. P., 1997, Houston geological society environmental division presentation, Bulletin, Jan. 1997
Spittler, T.M., L. Fitch and S. Clifford, 1985. A new method for detection of organic vapors in the vadose zone, Proceedings of the Conference on Characterization and Monitoring of the Vadose Zone, National Water Well Association.
Teplitz, A.J. and J.K. Rodgers, 1935. Research Project DA-51-3(1). Gulf Research and Development Company, Achives Location 71-B23, Box 14D-34.
Thompson, K.F.M., 1966. Postulated generation of bacterial methane from seepage petroleum in sea floor sediments of the Gulf of Mexico, in D. Schumacher and M.A. Abrams, eds., Hydrocarbon migration and its near surface expression: AAPG Memoir 66, pl. 331-334.
Valkenburg, N. 1994. The evolution of groundwater remediation strategies. The National Environmental Journal July/August. pp. 12-15.
Vance, David B., 1993. Remediation by In-situ Aeration, The National Environmental Journal, July/August, pp 12-15.
Ward, C.H., 1996. Introductory talk: Where are we now? Moving to a risk-based approach, Symposium on Natural Attenuation of Chlorinated Organics in Ground Water: EPA/540/R-96/509, Sept., Office of Research and Development, U.S. Environmental Protection Agency, Washington, D.C., pp. 1-3.
Weismann, T.J., 1980. Developments in geochemistry and their contribution to hydrocarbon exploration. Proceedings of: the 10th World Petroleum Congress. Bucharest, Romania, V. 2, pp. 369-386.
Wiedemeier, T.H., Kampbell, D.H., Miller, R.N., and J.T. Wilson, 1995. Significance of anaerobic processes for the intrinsic bioremediation of fuel hydrocarbons, In Proceedings of Petroleum Hydrocarbons and Organic Chemicals in Ground Water: Prevention, Detection and Restoration. Houston, Texas Nov 29-Dec 1, NGWA., pp. 49-61.
Williams, J.C., R.J. Mousseau, and T.J. Weismann, 1981. Correlation of well gas analysis with hydrocarbon seeps (abs). Proceedings of: the 1981 American Chemical Society Meeting. Atlanta, GA, March 29-April 3.
Wilson, S.B., and R.A. Brown, 1989. In situ bioreclamation: a cost-effective technology to remediate subsurface organic contamination; Groundwater Monitoring Review, Winter 1989, pp. 173-179.
©2002 Exploration Technologies, Inc.