National Library of Energy BETA

Sample records for basin williston basin

  1. Little Knife field - US Williston basin

    SciTech Connect (OSTI)

    Wittstrom, M.D.; Lindsay, R.F. )

    1991-03-01

    Little Knife field is a combination structural and stratigraphic trap located near the structural center of the Williston basin, North Dakota. The field is approximately 12 mi (19.3 km) long and 2.5 to 5.5 mi (4 to 8.9 km) wide. Little Knife was discovered by Gulf Oil in 1976 as part of a regional exploration play involving a transition from impermeable to porous carbonate rocks. In 1987, ultimate recovery from the Mission Canyon (Mississippian) reservoir was estimated to be 97.5 MMBO. This included 57.5 MMBO primary, 27 MMBO secondary, and 13 MMBO tertiary (CO{sub 2}) oil. At present the field is still under primary recovery, since utilization efforts have not been successful. Approximately one-third of Little Knife's 130 ft (39.6 m) oil column is trapped by structural closure beneath a regional anhydrite seal in a north-south-trending anticline. The remaining two-thirds of the oil column is trapped where the reservoir beds change facies from porous dolostones and dolomitic limestones to nonporous limestones. Structural entrapment accounts for approximately 50% (127 MMBO) of the OOIP, but covers only 30% of the producing area. Production is from the upper portions of the Mission Canyon Formation, a regressive, shoaling-upward carbonate-anhydrite sequence deposited in a slowly shrinking epeiric sea. The Mission Canyon in the Little Knife area is divided into six zones that record predominantly cyclic, subtidal deposition. These are overlain by prograding lagoonal, tidal flat, and sabkha beds. The source of Mission Canyon oil is thought to be the Bakken Formation, an organic-rich shale at the base of the Mississippian.

  2. Williston basin oil exploration: Past, present, and future

    SciTech Connect (OSTI)

    Jennings, A.H.

    1991-06-01

    Past: In 1951, modern oil exploration came to the Williston basin with the discovery of Paleozoic oil on the large Nesson anticline. This was quickly followed by similar discoveries on Cedar Creek and Poplar anticlines. To the north, the Canadians, lacking large structures, concentrated on Paleozoic stratigraphic traps and were highly successful. US explorationists quickly followed, finding similar traps on the basin's northeastern flank and center. The 1960s saw multiple Devonian salt dissolution structures produce on the western flank. To the northwest, shallow Mississippian and deeper Ordovician pays were found on small structural closures. These later were combined with pays in the Devonian and Silurian to give multiple pay potential. In the basin center large buried structures, visible only to seismic, were located. The 1970s revealed an Ordovician subcrop trap on the southeast flank. Centrally, a Jurassic astrobleme with Mississippian oil caused a flurry of leasing and deep drilling. The 1982 collapse of oil prices essentially halted exploration. 1987 saw a revival when horizontal drilling for the Mississippian Bakken fractured shale promised viable economics. Present: Today, emphasis is on Bakken horizontal drilling in the deeper portion of the basin. Next in importance is shallow drilling such as on the northeastern flank. Future: An estimated on billion barrels of new oil awaits discovery in the Williston basin. Additional exploration in already established production trends will find some of this oil. Most of this oil, however, will almost certainly be found by following up the numerous geological leads hinted at by past drilling.

  3. Thermal history of Bakken shale in Williston basin

    SciTech Connect (OSTI)

    Gosnold, W.D. Jr.; Lefever, R.D.; Crashell, J.J. )

    1989-12-01

    Stratigraphic and thermal conductivity data were combined to analyze the thermostratigraphy of the Williston basin. The present thermostratigraphy is characterized by geothermal gradients of the order of 60 mK/m in the Cenozoic and Mesozoic units, and 30 mK/m in the Paleozoic units. The differences in geothermal gradients are due to differences in thermal conductivities between the shale-dominated Mesozoic and Cenozoic units and the carbonate-dominated Paleozoic units. Subsidence and compaction rates were calculated for the basin and were used to determine models for time vs. depth and time vs. thermal conductivity relationships for the basin. The time/depth and time/conductivity relationships include factors accounting for thermal conductivity changes due to compaction, cementation, and temperature. The thermal history of the Bakken shale, a primary oil source rock in the Williston basin, was determined using four different models, and values for Lopatin's time-temperature index (TTI) were calculated for each model. The first model uses a geothermal gradient calculated from bottom-hole temperature data, the second uses present-day thermostratigraphy, the third uses the thermostratigraphic relationship determined in this analysis, and the fourth modifies the third by including assumed variations in continental heat flow. The thermal histories and the calculated TTI values differ markedly among the models with TTI values differing by a factor of about two between some models.

  4. Sulfur isotope ratios in petroleum research and exploration: Williston basin

    SciTech Connect (OSTI)

    Thode, H.G.

    1981-09-01

    The three major types of crude oil in the Williston basin - the type I oils of the Winnipeg-Red River system, the type II oils of the Bakken-Madison system, and the type III oils of the Tyler-Pennsylvanian system - can be distinguished by their sulfur isotope compositions. They have characteristic delta/sup 34/S values of 5.8 +- 1.2 parts per thousand (ppt), 2.8 +- 0.8 ppt, and -4.0 +- 0.7 ppt respectively. Highly mature oils have less typical values. Type II oils which have migrated over a distance of some 150 km beyond the region of generation have maintained their characteristic delta/sup 34/S values even though sulfur may have been lost. This indicates little or no interaction with reservoir sulfates under normal circumstances. On the periphery of the basin, type II oils altered by water washing and biodegradation have altered delta/sup 34/S values which increase from +2.9 to +9.4 ppt with the increasing degree of crude oil degradation. The Bakken shales, source of the type II oils, have delta/sup 34/S distribution patterns in the reduced sulfur typical of marine sediments. The delta/sup 34/S values for the type II oils match most closely the delta/sup 34/S value of organic sulfur in the black bituminous shales of the lower Bakken.

  5. Thermal modeling of Bakken Formation of Williston basin

    SciTech Connect (OSTI)

    Anderson, D.

    1986-08-01

    Organic geochemical analyses provide a quantitative basis on which conceptual models of thermal maturation may be built. Contour maps of maturation indices of the Mississippian-Devonian Bakken Formation of the Williston basin show anomalous patterns that are not dependent on burial depth. One such area is on the western side of the Nesson anticline. One-dimensional modeling incorporating a uniform, constant heat flow, lithology-dependent thermal conductivities, and decompaction factors indicates that these areas are less mature than surrounding regions. This is due primarily to decreasing burial depth and thinning of low-thermal-conductivity Tertiary and Cretaceous shales. Additional heat transfer to these regions may be due in part to heat transfer by fluid movement through aquifers or vertical fractures. The influence of these fluid systems is simulated through the use of a two-dimensional finite difference program. Basic assumptions are made concerning heat flow, thermal properties, and ground-water flow rates through time. Modeling of the time-temperature history is simplified by restricting the study to the time of greatest maturation, the post-Jurassic.

  6. A two-dimensional regional basin model of Williston basin hydrocarbon systems

    SciTech Connect (OSTI)

    Burrus, J.; Wolf, S.; Doligez, B.

    1996-02-01

    Institut Francais du Petrole`s two-dimensional model, TEMISPACK, is used to discuss the functioning of petroleum systems in the Williston basin along a 330-km-long section, focusing on four regional source intervals: Ordovician Yeoman formation, Lower Devonian Winnipegosis Formation, Upper Devonian-Lower Mississippian Bakken Formation, and Mississippian Lodgepole formation. Thermal history calibration against present temperature and source rock maturity profiles suggests that the Williston basin can be divided into a region of constant heat flow of about 55 mW/m{sup 2} away from the Nesson anticline, and a region of higher heat flow and enhanced thermal maturity in the vicinity of the Nesson anticline. Original kinetic parameters used in the calibration were derived for each of the four source rocks from Rock-Eval yield curves. Bakken overpressures are entirely due to oil generation, not compaction disequilibrium. Very low Bakken vertical permeabilities range from 0.01 to 0.001 and are matched against observed overpressures, whereas Bakken porosities based on the model and confirmed by measurements are inferred to be also unusually low, around 3%.

  7. Horizontal drilling the Bakken Formation, Williston basin: A new approach

    SciTech Connect (OSTI)

    Lefever, J.A. )

    1990-05-01

    Horizontal drilling is an attractive new approach to exploration and development of the Mississippian/Devonian Bakken Formation in the southwestern part of North Dakota. This drilling technique increases the probability of success, the profit potential, the effective drainage area maximizing recoverable reserves, and the productivity by encountering more natural occurring fractures. The target formation, the Mississippian/Devonian Bakken, consists of three members in an overlapping relationship, a lower organic-rich black shale, a middle siltstone/limestone, and an upper organic-rich black shale. It attains a maximum thickness of 145 ft and thins to a feather edge along its depositional limit. Considered to be a major source rock for the Williston basin, the Bakken is usually overpressured where productive. Overpressuring is attributed to intense hydrocarbon generation. Reservoir properties are poor with core fluid porosities being generally 5% or less and permeabilities ranging from 0.1 to 0.2 md. The presence of natural fractures in the shale are necessary for production. Two types of fractures are associated with Bakken reservoirs: large vertical fractures (of tectonic origin) and microfractures (probably related to hydrocarbon generation). An economic comparison between horizontal and vertical wells show that well completion costs are approximately two times higher (average costs; $1,500,000 for a horizontal to $850,000 for a vertical) with average payout for horizontal wells projected to occur in half the time (1.5 yr instead of 3.4 yr). Projected production and reserves are considered to be 2 to 4 times greater from a horizontal well.

  8. Improved recovery demonstration for Williston Basin carbonates. Final report

    SciTech Connect (OSTI)

    Sippel, M.A.

    1998-07-01

    The purpose of this project was to demonstrate targeted infill and extension drilling opportunities, better determinations of oil-in-place, and methods for improved completion efficiency. The investigations and demonstrations were focussed on Red River and Ratcliffe reservoirs in the Williston Basin within portions of Montana, North Dakota and South Dakota. Both of these formations have been successfully explored with conventional 2-dimensional (2D) seismic. Improved reservoir characterization utilizing 3-dimensional (3D) seismic was investigated for identification of structural and stratigraphic reservoir compartments. These seismic characterizations were integrated with geological and engineering studies. The project tested lateral completion techniques, including high-pressure jetting lance technology and short-radius lateral drilling to enhance completion efficiency. Lateral completions should improve economics for both primary and secondary oil where low permeability is a problem and higher-density drilling of vertical infill wells is limited by drilling cost. New vertical wells were drilled to test bypassed oil in ares that were identified by 3D seismic. These new wells are expected to recover as much or greater oil than was produced by nearby old wells. The project tested water injection through vertical and horizontal wells in reservoirs where application of waterflooding has been limited. A horizontal well was drilled for testing water injection. Injection rates were tested at three times that of a vertical well. This demonstration well shows that water injection with horizontal completions can improve injection rates for economic waterflooding. This report is divided into two sections, part 1 covers the Red River and part 2 covers the Ratcliffe. Each part summarizes integrated reservoir characterizations and outlines methods for targeting by-passed oil reserves in the respective formation and locality.

  9. Improved recovery demonstration for Williston Basin carbonates. Quarterly report, October 1, 1994--December 31, 1994

    SciTech Connect (OSTI)

    1995-04-01

    The purpose of this project is to demonstrate targeted infill and extension drilling opportunities, better determinations of oil-in-place, methods for improved completion efficiency and the suitability of waterflooding in certain shallow-shelf carbonate reservoirs in the Williston Basin, Montana, North Dakota and South Dakota. Results of seismic surveys are presented.

  10. Coos Bay Field Gulf Coast Coal Region Williston Basin Illinois

    Gasoline and Diesel Fuel Update (EIA)

    C e n t r a l A p p a l a c h i a n B a s i n Michigan Basin Greater Green River Basin ... Coalbed Methane Fields, Lower 48 States 0 200 400 100 300 Miles Source: Energy ...

  11. Evaluation of injection well risk management potential in the Williston Basin

    SciTech Connect (OSTI)

    1989-09-01

    The UIC regulations promulgated by the EPA under the Safe Drinking Water Act (SDWA) provide the EPA, or an EPA approved state agency, with authority to regulate subsurface injection of fluids to protect USDWs. Oil and gas producing industry interests are concerned primarily with Class 2 wells whose uses as defined by UIC regulations are: disposal of fluids brought to the surface and liquids generated in connection with oil and gas production (SWD); injection of fluids for enhanced oil recovery (EOR); and storage of liquid hydrocarbons. The Williston Basin was chosen for the pilot study of the feasibility of using the risk approach in managing Class 2 injection operations for the following reasons: it is one of the nine geologic basins which was classified as having a significant potential for external casing corrosion, which permitted an evaluation of the effectiveness of the injection well corrosion control measures used by industry; there are 731 active, 22 shut in and 203 temporarily abandoned SWD and water injection wells in the basin; and the basin covers three states. The broad objective of the Williston Basin study is to define requirements and to investigate the feasibility of incorporating risk management into administration of the UIC program. The study does not address the reporting aspects of UIC regulatory and compliance activities but the data base does contain essentially all the information required to develop the reports needed to monitor those activities. 16 refs., 10 figs., 11 tabs.

  12. Developing an oil generation model for resource assessment of Bakken formation, Williston Basin

    SciTech Connect (OSTI)

    Charpentier, R.R.; Krystinik, K.B.

    1984-04-01

    A model was developed for oil generation in the Devonian and Mississippian Bakken Formation, which has been proposed as the main hydrocarbon source rock within the Williston basin. The data consisted of formation temperatures and of density, neutron-porosity, resistivity, and gamma-ray logs from more than 250 wells in North Dakota and Montana. The upper and the lower shale members of the Bakken Formation were studied. Regression analysis, analysis of residuals, and cluster, discriminant, and factor analyses were used in an attempt to separate depositional effects--especially variations in organic content-from maturity. Regression and analysis of residuals indicate differences both areally and between the upper and lower members. In the upper member, and less strongly in the lower member, the center of the basin differs from the basin margins in that it has extreme residuals--either high or low. Clustering and residual analyses show roughly the same areal patterns. Inverse relationships, similar to those suggested by other workers, were found between formation temperature and organic content and between density logs and organic content. Also found, though, was that the addition of other factors, such as neutron porosity, helps to indicate organic content. Preliminary results show that it may be possible to model oil generation by using statistical techniques on well-log data. In particular, the model has the potential to refine estimates of the amount of hydrocarbons generated by the Bakken Formation in the Williston basin.

  13. Fracture-enhanced porosity and permeability trends in Bakken Formation, Williston basin, western North Dakota

    SciTech Connect (OSTI)

    Freisatz, W.B.

    1988-07-01

    Fractures play a critical role in oil production from the Bakken Formation (Devonian and Mississippian) in the North Dakota portion of the Williston basin. The Bakken Formation in the study area is known for its low matrix porosity and permeability, high organic content, thermal maturity, and relative lateral homogeneity. Core analysis has shown the effective porosity and permeability development within the Bakken Formation to be related primarily to fracturing. In theory, lineaments mapped on the surface reflect the geometry of basement blocks and the zones of fracturing propagated upward from them. Fracturing in the Williston basin is thought to have occurred along reactivated basement-block boundaries in response to varying tectonic stresses and crustal flexure throughout the Phanerozoic. Landsat-derived lineament maps were examined for the area between 47/degrees/ and 48/degrees/ north lat. and 103/degrees/ and 104/degrees/ west long. (northern Billings and Golden Valley Counties, and western McKenzie County, North Dakota) in an attempt to identify large-scale fracture trends. In the absence of major tectonic deformation in the craton, a subtle pattern of fracturing has propagated upward through the sedimentary cover and emerged as linear topographic features visible on these large-scale, remote-sensed images.

  14. Stratigraphy and diagenesis of the Mississippian Lodgepole Limestone, Williston Basin, North Dakota

    SciTech Connect (OSTI)

    Grover, P.W. )

    1996-01-01

    Stratigraphic correlation of the Lodgepole Limestone (Bottineau Interval) indicates a sequence of three clinoform-shaped wedges that filled in the early Williston Basin. To date four productive 100m thick mounds have been discovered in the Lodgepole Limestone at Dickinson Field. The mounds seem to have nucleated at the toe of slope of the first highstand system tract and were subsequently buried by the second highstand systems tract. By isopaching each of the systems tracts one can predict were other mounds might have nucleated. Burial depth of the Bakken Shale-Lodgepole Limestone contact grade from 0.6 km at the edge of the Williston Basin to 3.4 km in the center. With increased depth the basal Lodgepole Limestone shows three phases of dolomitization, which are: small clear early dolomite; later iron rich fracture filling saddle dolomite and a later iron rich dolomite that seems to follow stylolites. Pre-oil migration mineralization of the overlying limestone include minor amounts of: anhydrite, pyrite, iron poor sphalerite, late iron rich sphalerite, chalcopyrite and celestite.

  15. Stratigraphy and diagenesis of the Mississippian Lodgepole Limestone, Williston Basin, North Dakota

    SciTech Connect (OSTI)

    Grover, P.W.

    1996-12-31

    Stratigraphic correlation of the Lodgepole Limestone (Bottineau Interval) indicates a sequence of three clinoform-shaped wedges that filled in the early Williston Basin. To date four productive 100m thick mounds have been discovered in the Lodgepole Limestone at Dickinson Field. The mounds seem to have nucleated at the toe of slope of the first highstand system tract and were subsequently buried by the second highstand systems tract. By isopaching each of the systems tracts one can predict were other mounds might have nucleated. Burial depth of the Bakken Shale-Lodgepole Limestone contact grade from 0.6 km at the edge of the Williston Basin to 3.4 km in the center. With increased depth the basal Lodgepole Limestone shows three phases of dolomitization, which are: small clear early dolomite; later iron rich fracture filling saddle dolomite and a later iron rich dolomite that seems to follow stylolites. Pre-oil migration mineralization of the overlying limestone include minor amounts of: anhydrite, pyrite, iron poor sphalerite, late iron rich sphalerite, chalcopyrite and celestite.

  16. Improved recovery demonstration for Williston basin carbonates. Annual report, June 10, 1994--June 9, 1995

    SciTech Connect (OSTI)

    Sippel, M.; Zinke, S.; Magruder, G.; Eby, D.

    1995-09-01

    The purpose of this project is to demonstrate targeted infill and extension drilling opportunities, better determinations of oil-in-place, methods for improved completion efficiency and the suitability of waterflooding in Red River and Ratcliffe shallow-shelf carbonate reservoirs in the Williston Basin, Montana, North Dakota and South Dakota. Improved reservoir characterization utilizing three-dimensional and multi-component seismic are being investigated for identification of structural and stratigraphic reservoir compartments. These seismic characterization tools are integrated with geological and engineering studies. Improved completion efficiency is being tested with extended-reach jetting lance and other ultra-short-radius lateral technologies. Improved completion efficiency, additional wells at closer spacing and better estimates of oil in place will result in additional oil recovery by primary and enhanced recovery processes.

  17. Basin Play State(s) Production Reserves Williston Bakken ND, MT, SD

    U.S. Energy Information Administration (EIA) Indexed Site

    tight oil plays: production and proved reserves, 2013-14 million barrels 2013 2013 Basin Play State(s) Production Reserves Williston Bakken ND, MT, SD 270 4,844 387 5,972 1,128 Western Gulf Eagle Ford TX 351 4,177 497 5,172 995 Permian Bone Spring, Wolfcamp NM, TX 21 335 53 722 387 Denver-Julesberg Niobrara CO, KS, NE, WY 2 17 42 512 495 Appalachian Marcellus* PA, WV 7 89 13 232 143 Fort Worth Barnett TX 9 58 9 47 -11 Sub-total 660 9,520 1,001 12,657 3,137 Other tight oil 41 523 56 708 185 U.S.

  18. Recognition of hydrocarbon expulsion using well logs: Bakken Formation, Williston Basin

    SciTech Connect (OSTI)

    Cunningham, R.; Zelt, F.B.; Morgan, S.R.; Passey, Q.R. ); Snavely, P.D. III; Webster, R.L. )

    1990-05-01

    The Upper Mississippian-Lower Devonian Bakken Formation forms a source/carrier/reservoir system in the Williston basin. Hydrocarbon expulsion within the Bakken has been identified by overlaying sonic and resistivity logs. Typically, these curves track in organically lean, water-saturated mudrocks because both respond mainly to porosity; however, in thermally mature organic-rich rocks and hydrocarbon reservoirs or carrier beds, the curves separate due to the anomalously high resistivity associated with replacement of pore water by hydrocarbons. Sonic/resistivity-log overlays for wells throughout the Montana and North Dakota parts of the Williston basin reveal significant increases and maximum in-curve separation within the middle siltstone member of the Bakken at subsurface temperatures of about 170 and 200{degree}F, respectively. Sequence-stratigraphic characteristics of the Bakken define the framework within which the expulsion process operates. The organic-rich upper and lower shale members represent the transgressive and early highstand systems tracts of two adjacent depositional sequences. A sequence boundary within the intervening middle siltstone member separates nearshore siltstone and sandstone of the late highstand systems tract in the lower sequence from cross-bedded subtidal to intertidal sandstones of the lowstand systems tract in the upper sequence. Reservoir properties vary across this sequence boundary. The authors attribute the log separation in the siltstone member to hydrocarbons expelled from the adjacent shales. Abrupt shifts in several geochemical properties of the shale members, indicative of hydrocarbon generation occur over the same subsurface temperature range as the rapid increase in log separation in the middle siltstone, thus indicating the contemporaneity of generation and expulsion.

  19. Macrofossils of Bakken Formation (Devonian and Mississippian), Williston Basin, North Dakota

    SciTech Connect (OSTI)

    Thrasher, L.; Holland, F.D. Jr.

    1983-08-01

    Results of this study of the macrofossils of the Bakken Formation in North Dakota have reinforced the suggestion, based on previous paleontological work in Saskatchewan, that the Bakken is of both Devonian and Mississippian age, rather than being entirely of Lower Mississippian age as originally considered. Increased drilling and coring activity in the North Dakota part of the Williston Basin has provided the opportunity for acquiring a larger fauna that was previously available. Based on lithologic character, the Bakken has been divided into three informal members. These consist of a calcareous siltstone unit between two lithologically similar units of carbonaceous shale. These black shales contain similar faunas distinct from that of the middle member. The black shales contain inarticulate brachiopods, conchostracans, and rare cephalopods and fish remains as well as more abundant conodonts, ostracods, and palynomorphs. The middle siltstone unit contains a more abundant and diverse fauna consisting of inarticulate and articulate brachiopods together with corals, gastropods, cephalopods, ostracods, echinoderm remains, and trace fossils. This is the first report of cephalopods, conchostracans, ostracods, corals, trace fossils, and some of the brachiopods in the Bakken, although all, except the gastropods, have been reported from stratigraphic equivalents (Exshaw Formation of south-central Montana, the Leatham Formation of northeastern Utah, and the middle member of the Pilot Shale in western Utah and eastern Nevada).

  20. A chemical kinetic model of hydrocarbon generation from the Bakken Formation, Williston Basin, North Dakota

    SciTech Connect (OSTI)

    Sweeney, J.J.; Braun, R.L.; Burnham, A.K. ); Gosnold, W.D. )

    1992-10-01

    This report describes a model of hydrocarbon generation and expulsion in the North Dakota portion of the Williston Basin. The modeling incorporates kinetic methods to simulate chemical reactions and 1-dimensional conductive heat flow models to simulate thermal histories of the Mississippian-Devonian Bakken Formation source rock. We developed thermal histories of the source rock for 53 wells in the basin using stratigraphic and heat flow data obtained by the University of North Dakota. Chemical kinetics for hydrocarbon generation, determined from Pyromat pyrolysis, were, then used with the diennal histories to calculate the present day value of the Rock-Eval T[sub max] for each well. The calculated Rock-Eval T[sub max] values agreed with measured values within amounts attributable to uncertainties in the chemical kinetics and the heat flow. These optimized thermal histories were then used with a more detailed chemical kinetic model of hydrocarbon generation and expulsion, modified from a model developed for the Cretaceous La Luna shale, to simulate pore pressure development and detailed aspects of the hydrocarbon chemistry. When compared to values estimated from sonic logs, the pore pressure calculation underestimates the role of hydrocarbon generation and overestimates the role of compaction disequilibrium, but it matches well the general areal extent of pore pressures of 0.7 times lithostatic and higher. The simulated chemistry agrees very well with measured values of HI, PI, H/C atomic ratio of the kerogen, and Rock-Eval S1. The model is not as successful in simulating the amount of extracted bitumen and its saturate content, suggesting that detailed hydrous pyrolysis experiments will probably be needed to further refine the chemical model.

  1. Organic carbon in Bakken Formation, United States portion of Williston Basin

    SciTech Connect (OSTI)

    Schmoker, J.W.; Hester, T.C.

    1983-12-01

    The upper and lower members of the Mississippian and Devonian Bakken Formation in the United States portion of the Williston basin are black shales that are extremely rich in organic matter and are the source of much of the oil found in the basin. Organic-carbon values are calculated from formationdensity logs using the equation: TOC = (154.497//rho/) -57.261, where TOC is organic-carbon content (wt. %) and /rho/ is formation density (g/cm/sup 3/). Test calculations comparing this equation to laboratory organic-carbon analyses from 39 wells in North Dakota show an average absolute difference of 1.1% in organic-carbon content. Organic-carbon content, calculated at 159 locations in North Dakota and 107 in Montana, averages 12.1% for the upper member of the Bakken Formation and 11.5% for the lower member. There is a regional depletion of organic carbon, paralleling present-day isotherms, that reflects the conversion of organic matter to oil and subsequent expulsion of the oil from the formation. The mass of organic carbon in the Bakken Formation is approximately evenly divided between the upper and lower members, and it totals about 126 X 10/sup 12/ kg in the study area, of which 102 X 10/sup 12/ kg are in the thermally mature region. The assumption that 167 mg HC/g TOC have migrated out of the mature Bakken shales leads to a tentative estimate that hydrocarbons equivalent to 132 billion bbl of 43/sup 0/ (API gravity) oil have been expelled from the United States portion of the upper and lower members of the Bakken Formation.

  2. A chemical kinetic model of hydrocarbon generation from the Bakken Formation, Williston Basin, North Dakota

    SciTech Connect (OSTI)

    Sweeney, J.J.; Braun, R.L.; Burnham, A.K.; Gosnold, W.D.

    1992-10-01

    This report describes a model of hydrocarbon generation and expulsion in the North Dakota portion of the Williston Basin. The modeling incorporates kinetic methods to simulate chemical reactions and 1-dimensional conductive heat flow models to simulate thermal histories of the Mississippian-Devonian Bakken Formation source rock. We developed thermal histories of the source rock for 53 wells in the basin using stratigraphic and heat flow data obtained by the University of North Dakota. Chemical kinetics for hydrocarbon generation, determined from Pyromat pyrolysis, were, then used with the diennal histories to calculate the present day value of the Rock-Eval T{sub max} for each well. The calculated Rock-Eval T{sub max} values agreed with measured values within amounts attributable to uncertainties in the chemical kinetics and the heat flow. These optimized thermal histories were then used with a more detailed chemical kinetic model of hydrocarbon generation and expulsion, modified from a model developed for the Cretaceous La Luna shale, to simulate pore pressure development and detailed aspects of the hydrocarbon chemistry. When compared to values estimated from sonic logs, the pore pressure calculation underestimates the role of hydrocarbon generation and overestimates the role of compaction disequilibrium, but it matches well the general areal extent of pore pressures of 0.7 times lithostatic and higher. The simulated chemistry agrees very well with measured values of HI, PI, H/C atomic ratio of the kerogen, and Rock-Eval S1. The model is not as successful in simulating the amount of extracted bitumen and its saturate content, suggesting that detailed hydrous pyrolysis experiments will probably be needed to further refine the chemical model.

  3. Conodonts of Bakken Formation (Devonian and Mississippian), Williston basin, North Dakota

    SciTech Connect (OSTI)

    Hayes, M.D.; Holland, F.D. Jr.

    1983-08-01

    The Bakken Formation is a thin (maximum 145 ft, 45 m), clastic unit in the subsurface of Williston basin in the United States and Canada. The Bakken is similar in lithologic character and stratigraphic position to other black shale units deposited on the North American craton during the Late Devonian and Early Mississippian. The Bakken was initially considered entirely Mississippian in age. Paleontologic study of regional physical equivalents and analysis of the macrofauna in Saskatchewan has suggested that the Bakken is actually both Devonian and Mississippian. Conodonts were obtained from cores of the Bakken in an effort to determine the age of the formation in North Dakota and to assess the oil generation potential. Nearly 700 conodonts have been recovered, but are unevenly distributed within the Bakken Formation. A majority was obtained from thin (approximately 0.5 cm), fossil-rich beds within the upper shale. Conodonts from the top of the upper shale reveal a Mississippian (Kinderhookian) age and are here assigned to the Lower Siphonodella crenulata Zone. Only rare, fragmentary conodonts have been found in the middle member. Conodont evidence from the middle of the lower shale suggests a late Devonian (Famennian) age (Upper Polygnathus styriacus Zone) for this member. Conodont color has been established as a geothermometer in carbonate rocks. Color alteration indices of conodonts from the Bakken range from 1.5 to approximately 2.5 and indicate a pattern of increasing temperature with depth. These results suggest possible hydrocarbon generation from shallower depths than has been reported previously for the Bakken. The lack of agreement in interpreted hydrocarbon generation depths may be due to, among other things, the clastic nature of the Bakken Formation.

  4. Developing an oil generation model for resource assessment of the Bakken Formation, US portion of the Williston Basin

    SciTech Connect (OSTI)

    Krystinik, K.B.; Charpentier, R.R.

    1984-01-01

    A study of the Bakken Formation, the proposed source rock for much of the hydrocarbons generated in the Williston basin, was done using well-log data. Principal components analysis, cluster analysis, and discriminant analysis were used on bulk density, neutron porosity, and resistivity logs, and formation temperatures. These analyses indicate that the present-day distribution of organic matter controls much of the variability in the log values. The pattern of present-day total organic carbon (TOC) is high in the central part of the basin near northeastern Montana and along the east edge of the basin. Low values of TOC occur in the area of the Nesson anticline and along the southwest edge of the basin. Using the regression of density on temperature and the analysis of residuals from this regression, it is possible to separate maturity effects from those of original deposition. These analyses reveal that original concentrations of organic matter were low near the shoreline and increased offshore to a high in northeast Montana. The pre-maturation and present-day TOC distributions derived using statistical analyses and well-log data can easily be explained by the depositional pattern and thermal history that would be expected in this basin, and by geochemical analyses. 9 refs., 13 figs., 3 tabs.

  5. Comparison of explosive and vibroseis source energy penetration during COCORP deep seismic reflection profiling in the Williston basin

    SciTech Connect (OSTI)

    Steer, D.N.; Brown, L.D.; Knapp, J.H.; Baird, D.J. [Cornell Univ., Ithaca, NY (United States)] [Cornell Univ., Ithaca, NY (United States)

    1996-01-01

    Comparison of high-fold (50) vibroseis recordings with coincident low-fold (6) explosive source data from deep reflection surveys in the Williston Basin indicates that while vibroseis generated energy decays to ambient noise levels at 7--9 s two-way traveltime (twtt) (20--30 km depth), energy from explosive sources remains above ambient levels to 35--60 s twtt (105--180 km depth). Moreover, single, moderately sized (30 kg) and well-placed charges proved to be as effective as larger (90 kg) sources at penetrating to mantle traveltimes in this area. However, the explosive source energy proved highly variable, with source-to-ground coupling being a major limiting factor in shot efficacy. Stacked results from the vibroseis sources provide superior imagery of shallow and moderate crustal levels by virtue of greater redundancy and shot-to-shot uniformity; shot statics, low fold, and ray-path distortion across the relatively large (24--30 km aperture) spreads used during the explosive recording have proven to be especially problematic in producing conventional seismic sections. In spite of these complications, the explosive source recording served its primary purpose in confirming Moho truncation and the presence of a dipping reflection fabric in the upper mantle along the western flank of the Trans-Hudson orogen buried beneath the Williston Basin.

  6. A comparison of the rates of hydrocarbon generation from Lodgepole, False Bakken, and Bakken formation petroleum source rocks, Williston Basin, USA

    SciTech Connect (OSTI)

    Jarvie, D.M.; Elsinger, R.J.; Inden, R.F.; Palacas, J.G.

    1996-06-01

    Recent successes in the Lodgepole Waulsortian Mound play have resulted in the reevaluation of the Williston Basin petroleum systems. It has been postulated that hydrocarbons were generated from organic-rich Bakken Formation source rocks in the Williston Basin. However, Canadian geoscientists have indicated that the Lodgepole Formation is responsible for oil entrapped in Lodgepole Formation and other Madison traps in portions of the Canadian Williston Basin. Furthermore, geoscientists in the U.S. have recently shown oils from mid-Madison conventional reservoirs in the U.S. Williston Basin were not derived from Bakken Formation source rocks. Kinetic data showing the rate of hydrocarbon formation from petroleum source rocks were measured on source rocks from the Lodgepole, False Bakken, and Bakken Formations. These results show a wide range of values in the rate of hydrocarbon generation. Oil prone facies within the Lodgepole Formation tend to generate hydrocarbons earlier than the oil prone facies in the Bakken Formation and mixed oil/gas prone and gas prone facies in the Lodgepole Formation. A comparison of these source rocks using a geological model of hydrocarbon generation reveals differences in the timing of generation and the required level of maturity to generate significant amounts of hydrocarbons.

  7. Statistical model for source rock maturity and organic richness using well-log data, Bakken Formation, Williston basin, United States

    SciTech Connect (OSTI)

    Krystinik, K.B.; Charpentier, R.R.

    1987-01-01

    A study of the Bakken Formation, the proposed source rock for much of the hydrocarbons generated in the Williston basin, was done using bulk density, neutron porosity, and resistivity logs, and formation temperatures. Principal components, cluster, and discriminant analyses indicate that the present-day distribution of organic matter controls much of the variability in the log values. Present-day total organic carbon values are high in the central part of the basin near northeastern Montana and along the east edge of the basin, and low in the area of the Nesson anticline and along the southwest edge of the basin. Using a regression of density on temperature and the analysis of residuals from this regression, hydrocarbon maturity effects were partially separated from depositional effects. These analyses suggest that original concentrations of organic matter were low near the limits of the Bakken and increased to a high in northeastern Montana. The pre-maturation distribution of total organic carbon and the present-day total organic carbon distribution, as determined by statistical analyses of well-log data, agree with the results of geochemical analyses. The distributions can be explained by a relatively simple depositional pattern and thermal history for the Bakken. 6 figures, 3 tables.

  8. Reservoir characterization of the Ordovician Red River Formation in southwest Williston Basin Bowman County, ND and Harding County, SD

    SciTech Connect (OSTI)

    Sippel, M.A.; Luff, K.D.; Hendricks, M.L.; Eby, D.E.

    1998-07-01

    This topical report is a compilation of characterizations by different disciplines of the Red River Formation in the southwest portion of the Williston Basin and the oil reservoirs which it contains in an area which straddles the state line between North Dakota and South Dakota. Goals of the report are to increase understanding of the reservoir rocks, oil-in-place, heterogeneity, and methods for improved recovery. The report is divided by discipline into five major sections: (1) geology, (2) petrography-petrophysical, (3) engineering, (4) case studies and (5) geophysical. Interwoven in these sections are results from demonstration wells which were drilled or selected for special testing to evaluate important concepts for field development and enhanced recovery. The Red River study area has been successfully explored with two-dimensional (2D) seismic. Improved reservoir characterization utilizing 3-dimensional (3D) and has been investigated for identification of structural and stratigraphic reservoir compartments. These seismic characterization tools are integrated with geological and engineering studies. Targeted drilling from predictions using 3D seismic for porosity development were successful in developing significant reserves at close distances to old wells. Short-lateral and horizontal drilling technologies were tested for improved completion efficiency. Lateral completions should improve economics for both primary and secondary recovery where low permeability is a problem and higher density drilling is limited by drilling cost. Low water injectivity and widely spaced wells have restricted the application of waterflooding in the past. Water injection tests were performed in both a vertical and a horizontal well. Data from these tests were used to predict long-term injection and oil recovery.

  9. Natural CO2 accumulations in the western Williston Basin: A mineralogical analog for CO2 injection at the Weyburn site

    DOE Public Access Gateway for Energy & Science Beta (PAGES Beta)

    Ryerson, F. J.; Lake, John; Whittaker, Steven; Johnson, James W.

    2013-01-17

    The Devonian carbonates of the Duperow Formation on the western flank of the Williston Basin in southwest Saskatchewan contain natural accumulations of CO2, and may have done so for as long as 50 million years. These carbonate sediments are characterized by a succession of carbonate cycles capped by anhydrite-rich evaporites that are thought to act as seals to fluid migration. The Weyburn CO2 injection site lies 400 km to the east in a series of Mississippian carbonates that were deposited in a similar depositional environment. That long-term isolation of natural CO2 can be accomplished within carbonate strata has motivated themore » investigation of the Duperow rocks as a potential natural analog for storage of anthropogenic CO2 in carbonate lithologies. For the Duperow strata to represent a legitimate analog for Midale injection and storage, the similarity in lithofacies, whole rock compositions, mineral compositions and porosity with the Midale Beds must be established. Here we compare lithofacies, whole rock compositions, mineralogy and mineral compositions from both locales. The major mineral phases at both locales are calcite, dolomite and anhydrite. In addition, accessory pyrite, fluorite, quartz and celestine (strontium sulfate) are also observed. Dawsonite, a potential CO2-trapping mineral, is not observed within the CO2-bearing horizons of the Duperow Formation, however. The distribution of porosity in the Midale Vuggy units is similar to that of the Duperow Formation, but the Marly units of the Midale have significantly higher porosity. The Duperow Formation is topped by the Dinesmore evaporite that is rich in anhydrite, and often contains authigenic K-feldspar. The chemistry of dolomite and calcite from the two localities also overlaps. Silicate minerals are in low abundance (<3%) within the analyzed Duperow samples, with quartz and K-feldspar the only silicates observed petrographically or in X-ray diffraction patterns. The Midale Beds contain

  10. A resource evaluation of the Bakken Formation (Upper Devonian and Lower Mississippian) continuous oil accumulation, Williston Basin, North Dakota and Montana

    SciTech Connect (OSTI)

    Schmoker, J.W.

    1996-01-01

    The Upper Devonian and Lower Mississippian Bakken Formation in the United States portion of the Williston Basin is both the source and the reservoir for a continuous oil accumulation -- in effect a single very large field -- underlying approximately 17,800 mi{sup 2} (46,100 km{sup 2}) of North Dakota and Montana. Within this area, the Bakken Formation continuous oil accumulation is not significantly influenced by the water column and cannot be analyzed in terms of conventional, discrete fields. Rather, the continuous accumulation can be envisioned as a collection of oil-charged cells, virtually all of which are capable of producing some oil, but which vary significantly in their production characteristics. Better well-performance statistics are linked regionally to higher levels of thermal maturity and to lower levels of reservoir heterogeneity. Although portions of the Bakken Formation continuous oil accumulation have reached a mature stage of development, the accumulation as a whole is far from depleted.

  11. Bakken and other Devonian-Mississippian petroleum source rocks, northern Rocky Mtns.-Williston basin: Depositional and burial history and maturity estimations

    SciTech Connect (OSTI)

    Peterson, J.A.

    1996-06-01

    The three-member Devonian-Mississippian Bakken-Exshaw organic-rich shaly facies is widely distributed in the northern U.S. and southern Canadian Cordillera. Equivalent facies are also present as far south as Utah and Nevada. Paleogeographically, these rocks thin markedly or pinchout to the west approximately along the Devonian-Mississippian carbonate reef-mound belt of the Cordilleran shelf margin. Although these rocks reach maximum organic richness approximately at the Devonian-Carboniferous transition, similar but somewhat less organic-rich Bakken-like beds are also present in underlying Upper Devonian and overlying Lower Carboniferous carbonate depositional cycles. At least ten cycles are identified in the underlying Duperow and Jefferson Formations, characterized by basal organic-rich Bakken-like shale or shaly carbonate that grades upward into carbonate mound or reefal beds, overlain by evaporite or solution breccia. Cycles in the overlying Lodgepole and Mission Canyon Formations, as many as 10-12 in number, are similar except that the carbonates are composed of algal-oolith, crinoid, or mixed skeletal beds, and end-cycle evaporitic units are less prevalent in the lower cycles. These dark shaly beds are the most important source of hydrocarbon reserves in Montana and the Williston basin. Maximum net thickness of the Devonian-Mississippian organic-rich facies is in the Williston basin. However, variable thicknesses of these potential source rocks is present in parts of Montana as far west as the thrust belt. Burial history studies suggest that in some areas these rocks are probably thermally immature. However, in much of the area original burial depths are sufficient for them to reach the thermally mature stage, and therefore are of importance to further exploration efforts in the Devonian-Mississippian Madison-Duperow-Jefferson Formations.

  12. File:EIA-Williston-NE-Gas.pdf | Open Energy Information

    Open Energy Info (EERE)

    pdf) Description Williston Basin, Northeast Part By 2001 Gas Reserve Class Sources Energy Information Administration Authors Samuel H. Limerick; Lucy Luo; Gary Long; David F....

  13. File:EIA-Williston-S-Gas.pdf | Open Energy Information

    Open Energy Info (EERE)

    pdf) Description Williston Basin, South Part By 2001 Gas Reserve Class Sources Energy Information Administration Authors Samuel H. Limerick; Lucy Luo; Gary Long; David F....

  14. File:EIA-Williston-NW-Gas.pdf | Open Energy Information

    Open Energy Info (EERE)

    pdf) Description Williston Basin, Northwest Part By 2001 Gas Reserve Class Sources Energy Information Administration Authors Samuel H. Limerick; Lucy Luo; Gary Long; David F....

  15. Parana basin

    SciTech Connect (OSTI)

    Zalan, P.V.; Wolff, S.; Conceicao, J.C.J.; Vieira, I.S.; Astolfi, M.A.; Appi, V.T.; Zanotto, O.; Neto, E.V.S.; Cerqueira, J.R.

    1987-05-01

    The Parana basin is a large intracratonic basin in South America, developed entirely on continental crust and filled with sedimentary and volcanic rocks ranging in age from Silurian to Cretaceous. It occupies the southern portion of Brazil (1,100,000 km/sup 2/ or 425,000 mi/sup 2/) and the eastern half of Paraguay (100,000 km/sup 2/ or 39,000 mi/sup 2/); its extension into Argentina and Uruguay is known as the Chaco-Parana basin. Five major depositional sequences (Silurian, Devonian, Permo-Carboniferous, Triassic, Juro-Cretaceous) constitute the stratigraphic framework of the basin. The first four are predominantly siliciclastic in nature, and the fifth contains the most voluminous basaltic lava flows of the planet. Maximum thicknesses are in the order of 6000 m (19,646 ft). The sequences are separated by basin wide unconformities related in the Paleozoic to Andean orogenic events and in the Mesozoic to the continental breakup and sea floor spreading between South America and Africa. The structural framework of the Parana basin consists of a remarkable pattern of criss-crossing linear features (faults, fault zones, arches) clustered into three major groups (N45/sup 0/-65/sup 0/W, N50/sup 0/-70/sup 0/E, E-W). The northwest- and northeast-trending faults are long-lived tectonic elements inherited from the Precambrian basement whose recurrent activity throughout the Phanerozoic strongly influenced sedimentation, facies distribution, and development of structures in the basin. Thermomechanical analyses indicate three main phases of subsidence (Silurian-Devonian, late Carboniferous-Permian, Late Jurassic-Early Cretaceous) and low geothermal gradients until the beginning of the Late Jurassic Permian oil-prone source rocks attained maturation due to extra heat originated from Juro-Cretaceous igneous intrusions. The third phase of subsidence also coincided with strong tectonic reactivation and creation of a third structural trend (east-west).

  16. MASK basin

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    MASK basin - Sandia Energy Energy Search Icon Sandia Home Locations Contact Us Employee Locator Energy & Climate Secure & Sustainable Energy Future Stationary Power Energy Conversion Efficiency Solar Energy Wind Energy Water Power Supercritical CO2 Geothermal Natural Gas Safety, Security & Resilience of the Energy Infrastructure Energy Storage Nuclear Power & Engineering Grid Modernization Battery Testing Nuclear Energy Defense Waste Management Programs Advanced Nuclear Energy

  17. Basin Destination State

    Gasoline and Diesel Fuel Update (EIA)

    4. Estimated rail transportation rates for coal, basin to state, EIA data Basin Destination State 2008 2009 2010 2008-2010 2009-2010 Northern Appalachian Basin Delaware 26.24 - W...

  18. Basin Destination State

    Annual Energy Outlook [U.S. Energy Information Administration (EIA)]

    3. Estimated rail transportation rates for coal, basin to state, EIA data Basin Destination State 2008 2009 2010 2008-2010 2009-2010 Northern Appalachian Basin Delaware 28.49 - W...

  19. Basin Destination State

    Annual Energy Outlook [U.S. Energy Information Administration (EIA)]

    43 0.0294 W - W W - - - Northern Appalachian Basin Florida 0.0161 W W W W 0.0216 W W W W W Northern Appalachian Basin Illinois W W - - - - - - - - - Northern Appalachian Basin...

  20. Basin Destination State

    Gasoline and Diesel Fuel Update (EIA)

    0.0323 0.0284 W - W W - - - Northern Appalachian Basin Florida 0.0146 W W W W 0.0223 W W W W W Northern Appalachian Basin Illinois W W - - - - - - - - - Northern Appalachian...

  1. Texas-Louisiana- Mississippi Salt Basin Greater Green River Basin

    Gasoline and Diesel Fuel Update (EIA)

    Texas-Louisiana- Mississippi Salt Basin Greater Green River Basin W. Gulf Coast Basin ... Major Tight Gas Plays, Lower 48 States 0 200 400 100 300 Miles Source: Energy ...

  2. Basin Destination State

    Annual Energy Outlook [U.S. Energy Information Administration (EIA)]

    10.68 12.03 13.69 14.71 16.11 19.72 20.69 9.1 4.9 Northern Appalachian Basin Massachusetts W W - - - - - - - - - Northern Appalachian Basin Michigan 6.74 8.16 W 8.10 W W...

  3. Basin Destination State

    Gasoline and Diesel Fuel Update (EIA)

    11.34 12.43 13.69 14.25 15.17 18.16 18.85 6.5 3.8 Northern Appalachian Basin Massachusetts W W - - - - - - - - - Northern Appalachian Basin Michigan 7.43 8.85 W 8.37 W W...

  4. Wave Basin | Open Energy Information

    Open Energy Info (EERE)

    Basin Jump to: navigation, search Retrieved from "http:en.openei.orgwindex.php?titleWaveBasin&oldid596392" Feedback Contact needs updating Image needs updating Reference...

  5. K Basin safety analysis

    SciTech Connect (OSTI)

    Porten, D.R.; Crowe, R.D.

    1994-12-16

    The purpose of this accident safety analysis is to document in detail, analyses whose results were reported in summary form in the K Basins Safety Analysis Report WHC-SD-SNF-SAR-001. The safety analysis addressed the potential for release of radioactive and non-radioactive hazardous material located in the K Basins and their supporting facilities. The safety analysis covers the hazards associated with normal K Basin fuel storage and handling operations, fuel encapsulation, sludge encapsulation, and canister clean-up and disposal. After a review of the Criticality Safety Evaluation of the K Basin activities, the following postulated events were evaluated: Crane failure and casks dropped into loadout pit; Design basis earthquake; Hypothetical loss of basin water accident analysis; Combustion of uranium fuel following dryout; Crane failure and cask dropped onto floor of transfer area; Spent ion exchange shipment for burial; Hydrogen deflagration in ion exchange modules and filters; Release of Chlorine; Power availability and reliability; and Ashfall.

  6. Reserves in western basins

    SciTech Connect (OSTI)

    Caldwell, R.H.; Cotton, B.W.

    1995-04-01

    The objective of this project is to investigate the reserves potential of tight gas reservoirs in three Rocky Mountain basins: the Greater Green River (GGRB), Uinta and Piceance basins. The basins contain vast gas resources that have been estimated in the thousands of Tcf hosted in low permeability clastic reservoirs. This study documents the productive characteristics of these tight reservoirs, requantifies gas in place resources, and characterizes the reserves potential of each basin. The purpose of this work is to promote understanding of the resource and to encourage its exploitation by private industry. At this point in time, the GGRB work has been completed and a final report published. Work is well underway in the Uinta and Piceance basins which are being handled concurrently, with reports on these basins being scheduled for the middle of this year. Since the GGRB portion of the project has been completed, this presentation win focus upon that basin. A key conclusion of this study was the subdivision of the resource, based upon economic and technological considerations, into groupings that have distinct properties with regard to potential for future producibility, economics and risk profile.

  7. the Central Basin Platform,

    Office of Scientific and Technical Information (OSTI)

    ... As a result. it is believed that most of the structures formed within the context of an ... order to facilitate flexure modeling of the CBP and adjacent Delaware and Midland basins. ...

  8. K Basin Hazard Analysis

    SciTech Connect (OSTI)

    PECH, S.H.

    2000-08-23

    This report describes the methodology used in conducting the K Basins Hazard Analysis, which provides the foundation for the K Basins Final Safety Analysis Report. This hazard analysis was performed in accordance with guidance provided by DOE-STD-3009-94, Preparation Guide for U. S. Department of Energy Nonreactor Nuclear Facility Safety Analysis Reports and implements the requirements of DOE Order 5480.23, Nuclear Safety Analysis Report.

  9. K Basins Hazard Analysis

    SciTech Connect (OSTI)

    WEBB, R.H.

    1999-12-29

    This report describes the methodology used in conducting the K Basins Hazard Analysis, which provides the foundation for the K Basins Safety Analysis Report (HNF-SD-WM-SAR-062, Rev.4). This hazard analysis was performed in accordance with guidance provided by DOE-STD-3009-94, Preparation Guide for U. S. Department of Energy Nonreactor Nuclear Facility Safety Analysis Reports and implements the requirements of DOE Order 5480.23, Nuclear Safety Analysis Report.

  10. Permian basin gas production

    SciTech Connect (OSTI)

    Haeberle, F.R.

    1995-06-01

    Of the 242 major gas fields in the Permian basin, 67 are on the Central Basin Platform, 59 are in the Delaware basin, 44 are in the Midland basin, 28 are in the Val Verde basin, 24 are on the Eastern Shelf, 12 are in the Horshoe Atoll and eight are on the Northwest Shelf. Eleven fields have produced over one trillion cubic feet of gas, 61 have produced between 100 billion and one trillion cubic feet of gas and 170 have produced less than 100 billion cubic feet. Highlights of the study show 11% of the gas comes from reservoirs with temperatures over 300 degrees F. and 11% comes from depths between 19,000 and 20,000 feet. Twenty percent of the gas comes from reservoirs with pressures between 1000 and 2000 psi, 22% comes from reservoirs with 20-24% water saturation and 24% comes from reservoirs between 125 and 150 feet thick. Fifty-three reservoirs in the Ellenburger formation have produced 30% of the gas, 33% comes from 88 reservoirs in the Delaware basin and 33% comes from reservoirs with porosities of less than five percent. Forty percent is solution gas and 46% comes from combination traps. Over 50% of the production comes from reservoirs with five millidarcys or less permeability, and 60% of the gas comes from reservoirs in which dolomite is the dominant lithology. Over 50% of the gas production comes from fields discovered before 1957 although 50% of the producing fields were not discovered until 1958.

  11. Haynes Wave Basin | Open Energy Information

    Open Energy Info (EERE)

    Wave Basin Jump to: navigation, search Basic Specifications Facility Name Haynes Wave Basin Overseeing Organization Texas A&M (Haynes) Hydrodynamic Testing Facility Type Wave Basin...

  12. the Central Basin Platform,

    Office of Scientific and Technical Information (OSTI)

    ... Bolden, G.P., 1984, Wrench Faulting in Selected Areas of the Permian Basin, &: Moore, G. ... I I I I I 1 I I I I I I 1 I I I I Henry, C.A. and Price, J.G., 1985, Summary of ...

  13. Denver Basin Map | Open Energy Information

    Open Energy Info (EERE)

    Basin Map Jump to: navigation, search OpenEI Reference LibraryAdd to library Web Site: Denver Basin Map Abstract This webpage contains a map of the Denver Basin. Published Colorado...

  14. Sediment Basin Flume | Open Energy Information

    Open Energy Info (EERE)

    Sediment Basin Flume Jump to: navigation, search Basic Specifications Facility Name Sediment Basin Flume Overseeing Organization University of Iowa Hydrodynamic Testing Facility...

  15. Great Basin Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Great Basin Geothermal Area Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Great Basin Geothermal Area Contents 1 Area Overview 2 History and Infrastructure 3...

  16. Fifteenmile Basin Habitat Enhancement Project: Annual Report...

    Office of Scientific and Technical Information (OSTI)

    wild winter steelhead in the Fifteenmile Creek Basin under the Columbia River Basin Fish and Wildlife Program. The project is funded by through the Bonneville Power...

  17. Modeling overpressures in sedimentary basins: Consequences for permeability and rheology of shales, and petroleum expulsion efficiency

    SciTech Connect (OSTI)

    Burrus, J.; Schneider, F.; Wolf, S. )

    1994-07-01

    The prediction of overpressures using Institut Francais du Petrole's 2-D numerical model TEMISPACK is applied to several provinces of the world. In the Paris basin, France, normally pressured Liassic shales are shown to have permeabilities around a microdarcy, independently confirmed by laboratory measurements. In contrast, in the Norway section of the North Sea, Williston Basin, Canada, Gulf Coast, and in the Mahakam delta, observed overpressures of 10-50 MPa are consistently modeled with shale permeabilities around 1-10 nanodarcys. This theoretical value fits well with the lowest permeability measured in compacted shales. For these basins, compaction disequilibrium was found to explain most (>85%) of the overpressures. The only exception was the Williston basin in which overpressures observed in the organic-rich Bakken shales are entirely due to hydrocarbon generation. In Mahakam delta, the rheology of shales is nonlinear, i.e., the strength of shales increases rapidly with death. Consequently, shale compaction cannot be described by the linear behavior often assumed in hydrology. In the absence of fault barriers, numerical simulations and geological evidence suggest that overpressured source rocks have low or very low expulsion efficiency, irrespective of their organic content. However, shales with a permeability on the order of a microdarcy do not hinder petroleum migration.

  18. Subsurface cross section of lower Paleozoic rocks, Powder River basin, Wyoming and Montana

    SciTech Connect (OSTI)

    Macke, D.L.

    1988-07-01

    The Powder River basin is one of the most actively explored Rocky Mountain basins for hydrocarbons, yet the lower Paleozoic (Cambrian through Mississippian) rocks of this interval remain little studied. As a part of a program studying the evolution of sedimentary basins, approximately 3200 km of cross section, based on more than 50 combined geophysical and lithologic logs, have been constructed covering an area of about 200,000 km/sup 2/. The present-day basin is a Cenozoic structural feature located between the stable interior of the North American craton and the Cordilleran orogenic belt. At various times during the early Paleozoic, the basin area was not distinguishable from either the stable craton, the Williston basin, the Central Montana trough, or the Cordilleran miogeocline. Both deposition and preservation in the basin have been greatly influenced by the relative uplift of the Transcontinental arch. Shows of oil and dead oil in well cuttings confirm that hydrocarbons have migrated through at least parts of the basin's lower Paleozoic carbonate section. These rocks may have been conduits for long-distance migration of hydrocarbons as early as Late Cretaceous, based on (1) the probable timing of thermal maturation of hydrocarbon-source rocks within the basin area and to the west, (2) the timing of Laramide structural events, (3) the discontinuous nature of the reservoirs in the overlying, highly productive Pennsylvanian-Permian Minnelusa Formation, and (4) the under-pressuring observed in some Minnelusa oil fields. Vertical migration into the overlying reservoirs could have been through deep fractures within the basin, represented by major lineament systems. Moreover, the lower Paleozoic rocks themselves may also be hydrocarbon reservoirs.

  19. Stormwater detention basin sediment removal

    SciTech Connect (OSTI)

    Gross, W.E.

    1995-12-31

    In the past, stormwater runoff from landfills has been treated mainly by focusing on reducing the peak storm discharge rates so as not to hydraulically impact downstream subsheds. However, with the advent of stricter water quality regulations based on the Federal Clean Water Act, and the related NPDES and SPDES programs, landfill owners and operators are now legally responsible for the water quality of the runoff once it leaves the landfill site. At the Fresh Kills Landfill in New York City, the world`s largest covering over 2000 acres, landfilling activities have been underway since 1945. With the main objective at all older landfill sites having focused on maximizing the available landfill footprint in order to obtain the most possible airspace volume, consideration was not given for the future siting of stormwater basin structures. Therefore, when SCS Engineers began developing the first comprehensive stormwater management plan for the site, the primary task was to locate potential sites for all the stormwater basins in order to comply with state regulations for peak stormwater runoff control. The basins were mostly constructed where space allowed, and were sized to be as large as possible given siting and subshed area constraints. Seventeen stormwater basins have now been designed and are being constructed to control the peak stormwater runoff for the 25-year, 24-hour storm as required by New York State. As an additional factor of safety, the basins were also designed for controlled discharge of the 100-year, 24 hour storm.

  20. EA-64 Basin Electric Power Cooperative | Department of Energy

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    Basin Electric Power Cooperative EA-64 Basin Electric Power Cooperative Order authorizing Basin Electric Power Cooperative to export electric energy to Canada EA-64 Basin Electric Power Cooperative (2.8 MB) More Documents & Publications EA-64-A

  1. H-Area Seepage Basins

    SciTech Connect (OSTI)

    Stejskal, G.

    1990-12-01

    During the third quarter of 1990 the wells which make up the H-Area Seepage Basins (H-HWMF) monitoring network were sampled. Laboratory analyses were performed to measure levels of hazardous constituents, indicator parameters, tritium, nonvolatile beta, and gross alpha. A Gas Chromatograph Mass Spectrometer (GCMS) scan was performed on all wells sampled to determine any hazardous organic constituents present in the groundwater. The primary contaminants observed at wells monitoring the H-Area Seepage Basins are tritium, nitrate, mercury, gross alpha, nonvolatile beta, trichloroethylene (TCE), tetrachloroethylene, lead, cadmium, arsenic, and total radium.

  2. Hydrogeochemical Indicators for Great Basin Geothemal Resources

    Broader source: Energy.gov [DOE]

    Hydrogeochemical Indicators for Great Basin Geothemal Resources presentation at the April 2013 peer review meeting held in Denver, Colorado.

  3. K Basins Groundwater Monitoring Task, K Basins Closure Project: Report for July, August, and September 2006

    SciTech Connect (OSTI)

    Peterson, Robert E.

    2006-12-08

    This report provides information on groundwater monitoring at the K Basins during July, August, and September 2006. Conditions remain very similar to those reported in the previous quarterly report, with no evidence in monitoring results to suggest groundwater impact from current loss of basin water to the ground. The K Basins monitoring network will be modified in the coming quarters as a consequence of remedial action at KE Basin, i.e., removal of sludge and basin demolition.

  4. CLEAR LAKE BASIN 2000 PROJECT

    SciTech Connect (OSTI)

    LAKE COUNTY SANITATION DISTRICT

    2003-03-31

    The following is a final report for the Clear Lake Basin 2000 project. All of the major project construction work was complete and this phase generally included final details and testing. Most of the work was electrical. Erosion control activities were underway to prepare for the rainy season. System testing including pump stations, electrical and computer control systems was conducted. Most of the project focus from November onward was completing punch list items.

  5. Tectonic mechanisms for formation of the Central Basin platform and adjacent basinal areas, Permian basin, Texas and New Mexico

    SciTech Connect (OSTI)

    Yang, Kennming; Dorobek, S.L. )

    1992-04-01

    Formation of the Central Basin platform (CBP), with the Delaware basin to its west and the Midland basin to its east, has been attributed to the crustal deformation in the foreland area of the Marathon Orogen during the late Paleozoic. Because of complexities in the areal distribution and magnitudes of uplift along the length of the CBP, its formative mechanisms are still controversial. Previous interpretations about the mechanisms for uplift of the CBP are based on the characteristics of the boundary faults between the CBP and adjacent basinal areas. Here, an integrated tectonic model is proposed for formation of the uplift and adjacent basins based on studies of the structure of sedimentary layers overlying Precambrian basement rocks of the uplift and restoration of the lower Paleozoic strata in the Delaware basin.

  6. Reserves in western basins: Part 1, Greater Green River basin

    SciTech Connect (OSTI)

    Not Available

    1993-10-01

    This study characterizes an extremely large gas resource located in low permeability, overpressured sandstone reservoirs located below 8,000 feet drill depth in the Greater Green River basin, Wyoming. Total in place resource is estimated at 1,968 Tcf. Via application of geologic, engineering and economic criteria, the portion of this resource potentially recoverable as reserves is estimated. Those volumes estimated include probable, possible and potential categories and total 33 Tcf as a mean estimate of recoverable gas for all plays considered in the basin. Five plays (formations) were included in this study and each was separately analyzed in terms of its overpressured, tight gas resource, established productive characteristics and future reserves potential based on a constant $2/Mcf wellhead gas price scenario. A scheme has been developed to break the overall resource estimate down into components that can be considered as differing technical and economic challenges that must be overcome in order to exploit such resources: in other words, to convert those resources to economically recoverable reserves. Total recoverable reserves estimates of 33 Tcf do not include the existing production from overpressured tight reservoirs in the basin. These have estimated ultimate recovery of approximately 1.6 Tcf, or a per well average recovery of 2.3 Bcf. Due to the fact that considerable pay thicknesses can be present, wells can be economic despite limited drainage areas. It is typical for significant bypassed gas to be present at inter-well locations because drainage areas are commonly less than regulatory well spacing requirements.

  7. K Basins Groundwater Monitoring Task, K Basins Closure Project: Report for January, February, and March 2007

    SciTech Connect (OSTI)

    Peterson, Robert E.

    2007-04-01

    This report describes the results of groundwater monitoring near the K Basins for the period January, February, and March 2007.

  8. Geothermal Resources Of California Sedimentary Basins | Open...

    Open Energy Info (EERE)

    Jump to: navigation, search OpenEI Reference LibraryAdd to library Conference Paper: Geothermal Resources Of California Sedimentary Basins Abstract The 2004 Department of Energy...

  9. Late Paleozoic structural evolution of Permian basin

    SciTech Connect (OSTI)

    Ewing, T.E.

    1984-04-01

    The southern Permian basin is underlain by the NNW-trending Central Basin disturbed belt of Wolfcamp age (Lower Permian), the deep Delaware basin to its west, and the shallower Midland basin to its eat. The disturbed belt is highly segmented with zones of left-lateral offset. Major segments from south to north are: the Puckett-Grey Ranch zone; the Fort Stockton uplift; the Monahans transverse zone; the Andector ridges and the Eunice ridge; the Hobbs transverse zone; and the Tatum ridges, which abut the broad Roosevelt uplift to the north. The disturbed belt may have originated along rift zones of either Precambrian or Cambrian age. The extent of Lower and Middle Pennsylvanian deformation is unclear; much of the Val Verde basin-Ozona arch structure may have formed then. The main Wolfcamp deformation over thrust the West Texas crustal block against the Delaware block, with local denudation of the uplifted edge and eastward-directed backthrusting into the Midland basin. Latter in the Permian, the area was the center of a subcontinental bowl of subsidence - the Permian basin proper. The disturbed belt formed a pedestal for the carbonate accumulations which created the Central Basin platform. The major pre-Permian reservoirs of the Permian basin lie in large structural and unconformity-bounded traps on uplift ridges and domes. Further work on the regional structural style may help to predict fracture trends, to assess the timing of oil migration, and to evaluate intrareservoir variations in the overlying Permian giant oil fields.

  10. Delaware Basin Monitoring Annual Report

    SciTech Connect (OSTI)

    Washington Regulatory and Environmental Services; Washington TRU Solutions LLC

    2001-09-28

    The Delaware Basin Drilling Surveillance Program (DBDSP) is designed to monitor drilling activities in the vicinity of the Waste Isolation Pilot Plant (WIPP). This program is based on Environmental Protection Agency (EPA) requirements. EPA requires the Department of Energy (DOE) to demonstrate the expected performance of the disposal system using a probabilistic risk assessment or performance assessment (PA). This PA must show that the expected repository performance will not release radioactive material above limits set by the EPA's standard and must consider inadvertent drilling into the repository at some future time.

  11. K Basins Groundwater Monitoring Task, K Basins Closure Project: Report for October, November, and December 2006

    SciTech Connect (OSTI)

    Peterson, Robert E.

    2007-03-22

    This report provides information on groundwater monitoring at the K Basins during October, November, and December 2006. Conditions remained very similar to those reported in the previous quarterly report, with no evidence in monitoring results to suggest groundwater impact from current loss of basin water to the ground. The K Basins monitoring network will be modified in the coming months as a consequence of new wells having been installed near KW Basin as part of a pump-and-treat system for chromium contamination, and new wells installed between the KE Basin and the river to augment long-term monitoring in that area.

  12. Northwest Basin and Range Geothermal Region | Open Energy Information

    Open Energy Info (EERE)

    Basin and Range Geothermal Region Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Northwest Basin and Range Geothermal Region Details Areas (51) Power Plants (10)...

  13. Structure and Groundwater Flow in the Espanola Basin Near Rio...

    Office of Environmental Management (EM)

    Structure and Groundwater Flow in the Espanola Basin Near Rio Grande and Buckman Wellfield Structure and Groundwater Flow in the Espanola Basin Near Rio Grande and Buckman...

  14. CRAD, Emergency Management - Office of River Protection K Basin...

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    Emergency Management - Office of River Protection K Basin Sludge Waste System CRAD, Emergency Management - Office of River Protection K Basin Sludge Waste System May 2004 A section ...

  15. PP-64 Basin Electric Power Cooperative | Department of Energy

    Broader source: Energy.gov (indexed) [DOE]

    Basin Electric Power Cooperative to construct, operate, and maintain transmission facilities at the U.S. - Canada Border. PDF icon PP-64 Basin Electric Power Cooperative More ...

  16. Geographic Information System At Nw Basin & Range Region (Nash...

    Open Energy Info (EERE)

    Nw Basin & Range Region (Nash & Johnson, 2003) Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity: Geographic Information System At Nw Basin & Range...

  17. Judith Basin County, Montana: Energy Resources | Open Energy...

    Open Energy Info (EERE)

    6 Climate Zone Subtype B. Places in Judith Basin County, Montana Hobson, Montana Stanford, Montana Retrieved from "http:en.openei.orgwindex.php?titleJudithBasinCounty,...

  18. Climate Change and the Macroeconomy in the Caribbean Basin: Analysis...

    Open Energy Info (EERE)

    in the Caribbean Basin: Analysis and Projections to 2099 Jump to: navigation, search Name Climate Change and the Macroeconomy in the Caribbean Basin: Analysis and Projections to...

  19. L-Shaped Flume Wave Basin | Open Energy Information

    Open Energy Info (EERE)

    L-Shaped Flume Wave Basin Jump to: navigation, search Basic Specifications Facility Name L-Shaped Flume Wave Basin Overseeing Organization United States Army Corp of Engineers...

  20. Delaware basin/Central basin platform margin: The development of a subthrust deep-gas province in the Permian Basin

    SciTech Connect (OSTI)

    Purves, W.J. ); Ting, S.C. )

    1990-05-01

    A deep-gas-prone province was identified along the Delaware basin/Central Basin platform margin, a margin conventionally interpreted to be bounded by high-angle normal or high-angle reverse structures. Redefinition of the tectonic style between the Delaware basin and the adjacent platform resulted in the identification of this Delaware basin/Central Basin platform subthrust province and a giant prospect within it. Definition of a giant-sized gas prospect in northern Pecos County, Texas, revealed that portions of this margin may be characterized by shingled, low-angle, eastward-dipping, basement involved thrust faults. Interpretations suggest that hidden, subthrust footwall structures may trend discontinuously for greater than 100 mi along this structural margin. Subthrust footwall structures formed as basinal buttress points for the Central Basin platform to climb over the Delaware basin. In this area, structural relief of over 19,000 ft over a 10-mi width is believed due to stacking of low-angle thrust sheets. Seismic resolution of this subthrust margin has been complexed by allochtonous hanging-wall gravity-glide blocks and folds and by velocity changes in overlying syn- and posttectonic sediments associated with basin-to-shelf lithofacies changes. Statistical studies indicate that this deep-gas province has a play potential of greater than 10 tcf of gas, with individual prospect sizes exceeding 1 tcfg. The prospects defined along this trend are deep (approximately 20,000 ft) subthrust structural traps that are indigenously sourced and reservoired by dual-matrix porosity. Vitrinite supported maturation modeling suggests that these subthrust structures formed prior to catagenic conversion of the oldest source rocks to oil and later to gas. Tectonically fractured Ordovician Ellenburger and Devonian sediments are considered the principal reservoirs. Shales overlying reservoir intervals form vertical seals.

  1. Delaware Basin Monitoring Annual Report

    SciTech Connect (OSTI)

    Washington Regulatory and Environmental Services; Washington TRU Solutions LLC

    2003-09-30

    The Delaware Basin Drilling Surveillance Program (DBDSP) is designed to monitor drilling activities in the vicinity of the Waste Isolation Pilot Plant (WIPP). This program is based on Environmental Protection Agency (EPA) requirements. The EPA environmental standards for the management and disposal of transuranic (TRU) radioactive waste are codified in 40 CFR Part 191 (EPA 1993). Subparts B and C of the standard address the disposal of radioactive waste. The standard requires the Department of Energy (DOE) to demonstrate the expected performance of the disposal system using a probabilistic risk assessment or performance assessment (PA). This PA must show that the expected repository performance will not release radioactive material above limits set by the EPA's standard. This assessment must include the consideration of inadvertent drilling into the repository at some future time.

  2. Delaware Basin Monitoring Annual Report

    SciTech Connect (OSTI)

    Washington Regulatory and Environmental Services; Washington TRU Solutions LLC

    2004-09-30

    The Delaware Basin Drilling Surveillance Program (DBDSP) is designed to monitor drilling activities in the vicinity of the Waste Isolation Pilot Plant (WIPP). This program is based on Environmental Protection Agency (EPA) requirements. The EPA environmental standards for the management and disposal of transuranic (TRU) radioactive waste are codified in 40 CFR Part 191 (EPA 1993). Subparts B and C of the standard address the disposal of radioactive waste. The standard requires the Department of Energy (DOE) to demonstrate the expected performance of the disposal system using a probabilistic risk assessment or performance assessment (PA). This PA must show that the expected repository performance will not release radioactive material above limits set by the EPA's standard. This assessment must include the consideration of inadvertent drilling into the repository at some future time.

  3. Delaware Basin Monitoring Annual Report

    SciTech Connect (OSTI)

    Washington Regulatory and Environmental Services; Washington TRU Solutions LLC

    2002-09-21

    The Delaware Basin Drilling Surveillance Program (DBDSP) is designed to monitor drilling activities in the vicinity of the Waste Isolation Pilot Plant (WIPP). This program is based on Environmental Protection Agency (EPA) requirements. The EPA environmental standards for the management and disposal of transuranic (TRU) radioactive waste are codified in 40 CFR Part 191 (EPA 1993). Subparts B and C of the standard address the disposal of radioactive waste. The standard requires the Department of Energy (DOE) to demonstrate the expected performance of the disposal system using a probabilistic risk assessment or performance assessment (PA). This PA must show that the expected repository performance will not release radioactive material above limits set by the EPA's standard. This assessment must include the consideration of inadvertent drilling into the repository at some future time.

  4. Delaware Basin Monitoring Annual Report

    SciTech Connect (OSTI)

    Washington Regulatory and Environmental Services

    1999-09-30

    The Delaware Basin Drilling Surveillance Program (DBDSP) is designed to monitor drilling activities in the vicinity of the Waste Isolation Pilot Plant (WIPP). This program is based on Environmental Protection Agency (EPA) requirements. The EPA environmental standards for the management and disposal of transuranic (TRU) radioactive waste are codified in 40 CFR Part 191 (EPA 1993). Subparts B and C of the standard address the disposal of radioactive waste. The standard requires the Department of Energy (DOE) to demonstrate the expected performance of the disposal system using a probabilistic risk assessment or performance assessment (PA). This PA must show that the expected repository performance will not release radioactive material above limits set by the EPA's standard. This assessment must include the consideration of inadvertent drilling into the repository at some future time.

  5. Delaware Basin Monitoring Annual Report

    SciTech Connect (OSTI)

    Washington Regulatory and Environmental Services; Washington TRU Solutions LLC

    2000-09-28

    The Delaware Basin Drilling Surveillance Program (DBDSP) is designed to monitor drilling activities in the vicinity of the Waste Isolation Pilot Plant (WIPP). This program is based on Environmental Protection Agency (EPA) requirements. The EPA environmental standards for the management and disposal of transuranic (TRU) radioactive waste are codified in 40 CFR Part 191 (EPA 1993). Subparts B and C of the standard address the disposal of radioactive waste. The standard requires the Department of Energy (DOE) to demonstrate the expected performance of the disposal system using a probabilistic risk assessment or performance assessment (PA). This PA must show that the expected repository performance will not release radioactive material above limits set by the EPA's standard. This assessment must include the consideration of inadvertent drilling into the repository at some future time.

  6. Delaware Basin Monitoring Annual Report

    SciTech Connect (OSTI)

    Washington Regulatory and Environmental Services; Washington TRU Solutions LLC

    2005-09-30

    The Delaware Basin Drilling Surveillance Program (DBDSP) is designed to monitor drilling activities in the vicinity of the Waste Isolation Pilot Plant (WIPP). This program is based on Environmental Protection Agency (EPA) requirements. The EPA environmental standards for the management and disposal of transuranic (TRU) radioactive waste are codified in 40 CFR Part 191 (EPA 1993). Subparts B and C of the standard address the disposal of radioactive waste. The standard requires the Department of Energy (DOE) to demonstrate the expected performance of the disposal system using a probabilistic risk assessment or performance assessment (PA). This PA must show that the expected repository performance will not release radioactive material above limits set by the EPA's standard. This assessment must include the consideration of inadvertent drilling into the repository at some future time.

  7. K Basins isolation barriers summary report

    SciTech Connect (OSTI)

    Strickland, G.C., Westinghouse Hanford

    1996-07-31

    The 105-K East and 105-K West fuel storage basins (105-K Basins) were designed and constructed in the early 1950`s for interim storage of irradiated fuel following its discharge from the reactors. The 105-K- East and 105-K West reactor buildings were constructed first, and the associated storage basins were added about a year later. The construction joint between each reactor building structure and the basin structure included a flexible membrane waterstop to prevent leakage. Water in the storage basins provided both radiation shielding and cooling to remove decay heat from stored fuel until its transfer to the Plutonium Uranium Extraction (PUREX) Facility for chemical processing. The 105-K West Reactor was permanently shut down in February 1970; the 105-K East Reactor was permanently shut down in February 1971. Except for a few loose pieces, fuel stored in the basins at that time was shipped to the PUREX Facility for processing. The basins were then left idle but were kept filled with water. The PUREX Facility was shut down and placed on wet standby in 1972 while N Reactor continued to operate. When the N Reactor fuel storage basin began to approach storage capacity, the decision was made to modify the fuel storage basins at 105-K East and 105-K West to provide additional storage capacity. Both basins were subsequently modified (105-K East in 1975 and 105-K West in 1981) to provide for the interim handling and storage of irradiated N Reactor fuel. The PUREX Facility was restarted in November 1983 to provide 1698 additional weapons-grade plutonium for the United States defense mission. The facility was shut down and deactivated in December 1992 when the U.S. Department of Energy (DOE) determined that the plant was no longer needed to support weapons-grade plutonium production. When the PUREX Facility was shut down, approximately 2.1 x 1 06 kg (2,100 metric tons) of irradiated fuel aged 7 to 23 years was left in storage in the 105-K Basins pending a decision on

  8. EA-64-A Basin Electric Power Cooperative | Department of Energy

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    -A Basin Electric Power Cooperative EA-64-A Basin Electric Power Cooperative Order authorizing Basin Electric Power Cooperative to export electric energy to Canada EA-64-A Basin Electric Power Cooperative (1.87 MB) More Documents & Publications EA-64

  9. K Basins Sludge Treatment Process | Department of Energy

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    Process K Basins Sludge Treatment Process Full Document and Summary Versions are available for download K Basins Sludge Treatment Process (27.17 MB) Summary - K Basins Sludge Treatment Process (185.69 KB) More Documents & Publications Compilation of TRA Summaries K Basins Sludge Treatment Project Phase 1 Technology Readiness Assessment (TRA)/Technology Maturation Plan (TMP) Process Guide

  10. K Basins Groundwater Monitoring Task, K Basins Closure Project: Report for April, May, and June 2007

    SciTech Connect (OSTI)

    Peterson, Robert E.

    2007-08-08

    This report provides information on groundwater monitoring near the K Basins during April, May, and June 2007. Conditions remained similar to those reported in the previous quarters report, with no evidence in monitoring results to suggest groundwater impact from current loss of shielding water from either basin to the ground. During the current quarter, the first results from two new wells installed between KE Basin and the river became available. Groundwater conditions at each new well are reasonably consistent with adjacent wells and expectations, with the exception of anomalously high chromium concentrations at one of the new wells. The K Basins monitoring network will be modified for FY 2008 to take advantage of new wells recently installed near KW Basin as part of a pump-and-treat system for chromium contamination, and also the new wells recently installed between the KE Basin and the river, which augment long-term monitoring capability in that area.

  11. Fifteenmile Basin Habitat Enhancement Project: Annual Report...

    Office of Scientific and Technical Information (OSTI)

    This goal was addressed under the Columbia River Basin Fish and Wildlife Program, Measure 703 (c) (1) - Action Item 4.2. Construction of fish habitat structures was completed on ...

  12. Progress Update: H4 Basin Concrete Pour

    ScienceCinema (OSTI)

    None

    2012-06-14

    The Recovery Act funded project in the H area basin. A concrete ditch built longer than half a mile to prevent contaminated water from expanding and to reduce the footprint on the environment.

  13. Carderock Maneuvering & Seakeeping Basin | Open Energy Information

    Open Energy Info (EERE)

    6.1 Water Type Freshwater Cost(per day) Contact POC Special Physical Features 10.7m deep x 15.2m wide trench along length of tank; the Maneuvering & Seakeeping Basin is spanned...

  14. K-Basins S/RIDS

    SciTech Connect (OSTI)

    Watson, D.J.

    1997-08-01

    The Standards/Requirements Identification Document (S/RID) is a list of the Environmental, Safety, and Health (ES{ampersand}H) and Safeguards and Security (SAS) standards/requirements applicable to the K Basins facility.

  15. 183-H Basin sludge treatability test report

    SciTech Connect (OSTI)

    Biyani, R.K.

    1995-12-31

    This document presents the results from the treatability testing of a 1-kg sample of 183-H Basin sludge. Compressive strength measurements, Toxic Characteristic Leach Procedure, and a modified ANSI 16.1 leach test were conducted

  16. Hydrogeochemical Indicators for Great Basin Geothemal Resources

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    Hydrogeochemical Indicators for Great Basin Geothermal Resources Project Officer: Eric Hass Total Project Funding: $1.2 million April 24, 2013 This presentation does not contain any proprietary confidential, or otherwise restricted information. Principal Investigator Stuart F Simmons Colorado School of Mines 2 | US DOE Geothermal Office eere.energy.gov Relevance/Impact of Research * Determine fundamental controls on fluid-mineral equilibria in six geothermal systems across the Great Basin to

  17. Williston Basin. Gulf's CO/sub 2/ mini-test at Little Knife being evaluated

    SciTech Connect (OSTI)

    Hess, T.

    1981-10-01

    The Gulf Oil Exploration and Production Co. nonproducing CO/sub 2/ mini-test at Little Knife field is complete and under evaluation. Although Gulf and the Department of Energy, cosponsors of the $5.62-million project in Billings County, North Dakota, say it is premature to draw conclusions, it appears field test results mirror those achieved in laboratory tests. CO/sub 2/ and tracers have shown up in the observation wells. The objective was to show that CO/sub 2/ miscible displacement is potentially a commercial method of recovering crude oil from high-saturation carbonate reservoirs that have not been extensively waterflooded. The mini-test site, 3-144N-98W in Little Knife field, was appropriate because it was representative of the field.

  18. Tularosa Basin Play Fairway Analysis: Partial Basin and Range Heat and Zones of Critical Stress Maps

    SciTech Connect (OSTI)

    Adam Brandt

    2015-11-15

    Interpolated maps of heat flow, temperature gradient, and quartz geothermometers are included as TIF files. Zones of critical stress map is also included as a TIF file. The zones are given a 5km diameter buffer. The study area is only a part of the Basin and Range, but it does includes the Tularosa Basin.

  19. Petroleum geology of principal sedimentary basins in eastern China

    SciTech Connect (OSTI)

    Lee, K.Y.

    1986-05-01

    The principal petroliferous basins in eastern China are the Songliao, Ordos, and Sichuan basins of Mesozoic age, and the North China, Jianghan, Nanxiang, and Subei basins of Cenozoic age. These basins contain mostly continental fluvial and lacustrine detrital sediments. Four different geologic ages are responsible for the oil and gas in this region: (1) Mesozoic in the Songliao, Ordos, and Sichuan basins; (2) Tertiary in the North China, Jianghan, Nanxiang, and Subei basins; (3) Permian-Carboniferous in the southern North China basin and the northwestern Ordos basin; and (4) Sinian in the southern Sichuan basin. The most prolific oil and gas sources are the Mesozoic of the Songliao basin and the Tertiary of the North China basin. Although the major source rocks in these basins are lacustrine mudstone and shale, their tectonic settings and the resultant temperature gradients differ. For example, in the Songliao, North China, and associated basins, trapping conditions commonly are associated with block faulting of an extensional tectonic regime; the extensional tectonics in turn contribute to a high geothermal gradient (40/sup 0/-60/sup 0/C/km), which results in early maturation and migration for relatively shallow deposits. However, the Ordos and Sichuan basins formed under compressional conditions and are cooler. Hence, maturation and migration occurred late, relative to reservoir deposition and burial, the result being a poorer quality reservoir.

  20. Basin-centered gas evaluated in Dnieper-Donets basin, Donbas foldbelt, Ukraine

    SciTech Connect (OSTI)

    Law, B.E.; Ulmishek, G.F.; Clayton, J.L.; Kabyshev, B.P.; Pashova, N.T.; Krivosheya, V.A.

    1998-11-23

    An evaluation of thermal maturity, pore pressures, source rocks, reservoir quality, present-day temperatures, and fluid recovery data indicates the presence of a large basin-centered gas accumulation in the Dnieper-Donets basin (DDB) and Donbas foldbelt (DF) of eastern Ukraine. This unconventional accumulation covers an area of at least 35,000 sq km and extends vertically through as much as 7,000 m of Carboniferous rocks. The gas accumulation is similar, in many respects, to some North American accumulations such as Elmworth in the Alberta basin of western Canada, the Greater Green River basin of southwestern Wyoming, and the Anadarko basin of Oklahoma. Even though rigorous assessments of the recoverable gas have not been conducted in the region, a comparison of the dimensions of the accumulation to similar accumulations in the US indicates gas resources in excess of 100 tcf in place. The paper describes the geology, the reservoirs, source rocks, seals, and recommendations for further study.

  1. Southern Colombia's Putumayo basin deserves renewed attention

    SciTech Connect (OSTI)

    Matthews, A.J. ); Portilla, O. )

    1994-05-23

    The Putumayo basin lies in southern Colombia between the Eastern Cordillera of the Andes and the Guyana-Brazilian shield. It covers about 50,000 sq km between 0--3[degree]N. Lat. and 74--77[degree]W. Long. and extends southward into Ecuador and Peru as the productive Oriente basin. About 3,500 sq km of acreage in the basin is being offered for licensing in the first licensing round by competitive tender. A recent review of the available data from this area by Intera and Ecopetrol suggests that low risk prospects and leads remain to be tested. The paper describes the tectonic setting, stratigraphy, structure, hydrocarbon geology, reservoirs, and trap types.

  2. Independent focuses Philippines exploration on Visayan basin

    SciTech Connect (OSTI)

    Rillera, F.G.

    1995-08-21

    Cophil Exploration Corp., a Filipino public company, spearheaded 1995 Philippine oil and gas exploration activity with the start of its gas delineation drilling operations in Libertad, northern Cebu. Cophil and its Australian partners, Coplex Resources NL and PacRim Energy NL, have set out to complete a seven well onshore drilling program within this block this year. The companies are testing two modest shallow gas plays, Libertad and Dalingding, and a small oil play, Maya, all in northern Cebu about 500 km southeast of Manila. Following a short discussion on the geology and exploration history of the Visayan basin, this article briefly summarizes Cophil`s ongoing Cebu onshore drilling program. Afterwards, discussion focuses on identified exploration opportunities in the basin`s offshore sector.

  3. New tools attack Permian basin stimulation problems

    SciTech Connect (OSTI)

    Ely, J.W.; Schubarth, S.K.; Wolters, B.C.; Kromer, C. )

    1992-06-08

    This paper reports that profitable stimulation treatments in the Permian basin of the southwestern U.S. combine new tools with technology and fluids previously available. This paper reports that a wide selection of fracturing fluids and techniques needs to be considered to solve the varied problems associated with stimulating hydrocarbon reservoirs that are at diverse depths, temperatures, pressures, and lithologies. The Permian basin of West Texas and New Mexico is the most fertile ground in the U.S. for some of the newer stimulation technologies. In this basin, these new tools and techniques have been applied in many older producing areas that previously were treated with more conventional stimulation techniques, including acidizing and conventional fracturing procedures.

  4. Regional geologic characteristics relevant to horizontal drilling, Woodford Shale, Anadarko basin, Oklahoma

    SciTech Connect (OSTI)

    Hester, T.C.; Schmoker, J.W. )

    1991-06-01

    Horizontal drilling in the Late Devonian-Early Mississippian Bakken Formation of the Williston basin has spurred new interest in other black shales as primary hydrocarbon reservoirs. The Late Devonian-Early Mississippian Woodford Shale, which is similar in some respects to the Bakken Formation, is a major source of oil and gas in the Anadarko basin of Oklahoma and could prove to be a significant reservoir rock as well. The three regional geologic characteristics of the Woodford discussed here are of likely importance to horizontal drilling programs, although direct relations to drilling strategy cannot be developed until empirical data from horizontal tests become available. First, the Woodford Shale is composed of three distinct depositional units (the upper, middle, and lower informal members) with different physical and geochemical properties. Second, a paleotopographic high that was rising before and during Woodford deposition divided the Woodford Shale into northeast and southwest depocenters. Third, Woodford depositional patterns are overprinted by thermal-maturity trends shaped primarily by differential burial of the Woodford during Pennsylvanian and Permian time. The Woodford Shale northeast of the forebulge is generally immature to marginally mature, whereas its thermal maturity southwest of the forebulge ranges from mature to postmature with respect to oil generation. A formation resistivity of about 35 ohm-m approximates the updip limit of oil-saturated Woodford Shale from which free oil might be produced from fracture systems.

  5. Ground-water hydraulics of the deep-basin brine aquifer, Palo Duro Basin, Texas panhandle

    SciTech Connect (OSTI)

    Smith, D.A.

    1985-01-01

    The Deep-Basin Brine aquifer of the Palo Duro Basin (Texas Panhandle) underlies thick Permian bedded evaporites that are being evaluated as a potential high-level nuclear waste isolation repository. Potentiometric surface maps of 5 units of the Deep-Basin Brine aquifer were drawn using drill-stem test (DST) pressure data, which were analyzed by a geostatistical technique (kriging) to smooth the large variation in the data. The potentiometric surface maps indicate that the Deep-Basin Brine aquifer could be conceptually modeled as 5 aquifer units; a Lower Permian (Wolfcamp) aquifer, upper and lower Pennsylvanian aquifers, a pre-Pennsylvanian aquifer, and a Pennsylvanian to Wolfcampian granite-wash aquifer. The hydraulic head maps indicate that ground-water flow in each of the units is west to east with a minor northerly component near the Amarillo Uplift, the northern structural boundary of the basin. The Wolfcamp potentiometric surface indicates the strongest component of northerly flow. Inferred flow direction in Pennsylvanian aquifers is easterly, and in the pre-Pennsylvanian aquifer near its pinch-out in the basin center, flow is inferred to be to the north. In the granite-wash aquifer the inferred flow direction is east across the northern edge of the basin and southeast along the Amarillo Uplift.

  6. Atlas of major Appalachian basin gas plays

    SciTech Connect (OSTI)

    Aminian, K.; Avary, K.L.; Baranoski, M.T.; Flaherty, K.; Humphreys, M.; Smosna, R.A.

    1995-06-01

    This regional study of gas reservoirs in the Appalachian basin has four main objectives: to organize all of the -as reservoirs in the Appalachian basin into unique plays based on common age, lithology, trap type and other geologic similarities; to write, illustrate and publish an atlas of major gas plays; to prepare and submit a digital data base of geologic, engineering and reservoir parameters for each gas field; and technology transfer to the oil and gas industry during the preparation of the atlas and data base.

  7. ,"Calif--Los Angeles Basin Onshore Natural Gas Liquids Lease...

    U.S. Energy Information Administration (EIA) Indexed Site

    Data for" ,"Data 1","Calif--Los Angeles Basin Onshore Natural Gas Liquids ... PM" "Back to Contents","Data 1: Calif--Los Angeles Basin Onshore Natural Gas Liquids ...

  8. Colorado Division of Water Resources Denver Basin Webpage | Open...

    Open Energy Info (EERE)

    Denver Basin Webpage Jump to: navigation, search OpenEI Reference LibraryAdd to library Web Site: Colorado Division of Water Resources Denver Basin Webpage Abstract This is the...

  9. Designated Ground Water Basin Map | Open Energy Information

    Open Energy Info (EERE)

    Designated Ground Water Basin Map Jump to: navigation, search OpenEI Reference LibraryAdd to library Web Site: Designated Ground Water Basin Map Abstract This webpage provides...

  10. Hazard categorization of 105-KE basin debris removal project

    SciTech Connect (OSTI)

    Meichle, R.H.

    1996-01-25

    This supporting document provides the hazard categorization for 105-KE Basin Debris Removal Project activities planned in the K east Basin. All activities are categorized as less than Hazard Category 3.

  11. CRAD, Engineering - Office of River Protection K Basin Sludge...

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    Engineering - Office of River Protection K Basin Sludge Waste System CRAD, Engineering - Office of River Protection K Basin Sludge Waste System May 2004 A section of Appendix C to ...

  12. DOE - Office of Legacy Management -- Shirley Basin AEC Ore Buying...

    Office of Legacy Management (LM)

    Shirley Basin AEC Ore Buying Station - WY 0-05 Site ID (CSD Index Number): WY.0-05 Site Name: Shirley Basin AEC Ore Buying Station Site Summary: The history of domestic uranium ...

  13. K West basin isolation barrier leak rate test

    SciTech Connect (OSTI)

    Whitehurst, R.; McCracken, K.; Papenfuss, J.N.

    1994-10-31

    This document establishes the procedure for performing the acceptance test on the two isolation barriers being installed in K West basin. This acceptance test procedure shall be used to: First establish a basin water loss rate prior to installation of the two isolation barriers between the main basin and the discharge chute in K-Basin West. Second, perform an acceptance test to verify an acceptable leakage rate through the barrier seals.

  14. Modeling-Computer Simulations At Northern Basin & Range Region...

    Open Energy Info (EERE)

    navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity: Modeling-Computer Simulations At Northern Basin & Range Region (Pritchett, 2004) Exploration Activity...

  15. Geothermal Literature Review At Nw Basin & Range Region (Laney...

    Open Energy Info (EERE)

    navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity: Geothermal Literature Review At Nw Basin & Range Region (Laney, 2005) Exploration Activity Details...

  16. BASIN ANALYSIS AND PETROLEUM SYSTEM CHARACTERIZATION AND MODELING, INTERIOR SALT BASINS, CENTRAL AND EASTERN GULF OF MEXICO

    SciTech Connect (OSTI)

    Ernest A. Mancini; Donald A. Goddard

    2005-08-01

    The principal research effort for Year 3 of the project is basin modeling and petroleum system identification, comparative basin evaluation and resource assessment. In the first six (6) months of Year 3, the research focus is on basin modeling and petroleum system identification and the remainder of the year the emphasis is on the comparative basin evaluation and resource assessment. No major problems have been encountered to date, and the project is on schedule.

  17. Tularosa Basin Play Fairway Analysis: Strain Analysis

    SciTech Connect (OSTI)

    Adam Brandt

    2015-11-15

    A DEM of the Tularosa Basin was divided into twelve zones, each of which a ZR ratio was calculated for. This submission has a TIFF image of the zoning designations, along with a table with respective ZR ratio calculations in the metadata.

  18. Atmospheric dispersion in mountain valleys and basins

    SciTech Connect (OSTI)

    Allwine, K.J.

    1992-01-01

    The primary goal of the research is to further characterize and understand dispersion in valley and basin atmospheres. A secondary, and related goal, is to identify and understand the dominant physical processes governing this dispersion. This has been accomplished through a review of the current literature, and analyses of recently collected data from two field experiments. This work should contribute to an improved understanding of material transport in the atmospheric boundary layer. It was found that dispersion in a freely draining valley (Brush Creek valley, CO) atmosphere is much greater than in an enclosed basin (Roanoke, VA) atmosphere primarily because of the greater wind speeds moving past the release point and the greater turbulence levels. The development of a cold air pool in the Roanoke basin is the dominant process governing nighttime dispersion in the basin, while the nighttime dispersion in the Brush Creek valley is dominated by turbulent diffusion and plume confinement between the valley sidewalls. The interaction between valley flows and above ridgetops flows is investigated. A ``ventilation rate`` of material transport between the valley and above ridgetop flows is determined. This is important in regional air pollution modeling and global climate modeling. A simple model of dispersion in valleys, applicable through a diurnal cycle, is proposed.

  19. Atmospheric dispersion in mountain valleys and basins

    SciTech Connect (OSTI)

    Allwine, K.J.

    1992-01-01

    The primary goal of the research is to further characterize and understand dispersion in valley and basin atmospheres. A secondary, and related goal, is to identify and understand the dominant physical processes governing this dispersion. This has been accomplished through a review of the current literature, and analyses of recently collected data from two field experiments. This work should contribute to an improved understanding of material transport in the atmospheric boundary layer. It was found that dispersion in a freely draining valley (Brush Creek valley, CO) atmosphere is much greater than in an enclosed basin (Roanoke, VA) atmosphere primarily because of the greater wind speeds moving past the release point and the greater turbulence levels. The development of a cold air pool in the Roanoke basin is the dominant process governing nighttime dispersion in the basin, while the nighttime dispersion in the Brush Creek valley is dominated by turbulent diffusion and plume confinement between the valley sidewalls. The interaction between valley flows and above ridgetops flows is investigated. A ventilation rate'' of material transport between the valley and above ridgetop flows is determined. This is important in regional air pollution modeling and global climate modeling. A simple model of dispersion in valleys, applicable through a diurnal cycle, is proposed.

  20. Summary - K Basins Sludge Treatment Process

    Office of Environmental Management (EM)

    Assessment (TRA) is tric-based process a t y Office of E dge Trea nt ging Basin or ansfer, The ding- y the ent. ch of e below: * * Th ass at t De but Th est ass con a r de dev Re ...

  1. Tularosa Basin Play Fairway Analysis: Water Chemistry

    DOE Data Explorer [Office of Scientific and Technical Information (OSTI)]

    Adam Brandt

    2015-12-15

    This shapefile contains 409 well data points on Tularosa Basin Water Chemistry, each of which have a location (UTM), temperature, quartz and Potassium/Magnesium geothermometer; as well as concentrations of chemicals like Mn, Fe, Ba, Sr, Cs, Rb, As, NH4, HCO3, SO4, F, Cl, B, SiO2, Mg, Ca, K, Na, and Li.

  2. Pennsylvanian-Permian tectonism in the Great Basin: The Dry Mountain trough and related basins

    SciTech Connect (OSTI)

    Snyder, W.S.; Spinosa, C.; Gallegos, D.M. )

    1991-02-01

    Pennsylvanian-Permian tectonism affected the continental margin of western North America from the Yukon to the Mojave Desert. Specific signatures of this tectonism include local angular unconformities, regional disconformities, renewed outpouring of clastic debris from a reactivated Antler and related highlands, and development of deeper water basins with anoxic sediments deposited below wave base. The basins formed include Ishbel trough (Canada), the Wood River basin (Idaho), Cassia basin, Ferguson trough, Dry Mountain trough (all Nevada), and unnamed basins in Death Valley-Mojave Desert region. The Dry Mountain trough (DMT) was initiated during early Wolfcampian and received up to 1,200 m of sediment by the late Leonardian. The lower contact is a regional unconformity with the Ely Limestone, or locally with the Diamond Peak or Vinini formations. Thus, following a period of localized regional uplift that destroyed the Ely basin, portions of the uplifted and exposed shelf subsided creating the Dry Mountain trough. Evidence suggesting a tectonic origin for the DMT includes (1) high subsidence rates (60-140 m/m.y.); (2) renewed influx of coarse clastic debris from the Antler highlands: (3) possible pre-Early Permian folding, thrusting, and tilting within the highlands; and (4) differential subsidence within the Dry Mountain trough, suggesting the existence of independent fault blocks.

  3. Analysis of K west basin canister gas

    SciTech Connect (OSTI)

    Trimble, D.J., Fluor Daniel Hanford

    1997-03-06

    Gas and Liquid samples have been collected from a selection of the approximately 3,820 spent fuel storage canisters in the K West Basin. The samples were taken to characterize the contents of the gas and water in the canisters providing source term information for two subprojects of the Spent Nuclear Fuel Project (SNFP) (Fulton 1994): the K Basins Integrated Water Treatment System Subproject (Ball 1996) and the K Basins Fuel Retrieval System Subproject (Waymire 1996). The barrels of ten canisters were sampled for gas and liquid in 1995, and 50 canisters were sampled in a second campaign in 1996. The analysis results from the first campaign have been reported (Trimble 1995a, 1995b, 1996a, 1996b). The analysis results from the second campaign liquid samples have been documented (Trimble and Welsh 1997; Trimble 1997). This report documents the results for the gas samples from the second campaign and evaluates all gas data in terms of expected releases when opening the canisters for SNFP activities. The fuel storage canisters consist of two closed and sealed barrels, each with a gas trap. The barrels are attached at a trunion to make a canister, but are otherwise independent (Figure 1). Each barrel contains up to seven N Reactor fuel element assemblies. A gas space of nitrogen was established in the top 2.2 to 2.5 inches (5.6 to 6.4 cm) of each barrel. Many of the fuel elements were damaged allowing the metallic uranium fuel to be corroded by the canister water. The corrosion releases fission products and generates hydrogen gas. The released gas mixes with the gas-space gas and excess gas passes through the gas trap into the basin water. The canister design does not allow canister water to be exchanged with basin water.

  4. Okanogan Basin Spring Spawner Report for 2007.

    SciTech Connect (OSTI)

    Colville Tribes, Department of Fish & Wildlife

    2007-09-01

    The Okanogan Basin Monitoring and Evaluation Program collected data related to spring spawning anadromous salmonid stocks across the entire Okanogan River basin. Data were collected using redd surveys, traps, underwater video, and PIT-tag technology then summarized and analyzed using simple estimate models. From these efforts we estimated that 1,266 summer steelhead spawned in the Okanogan River basin and constructed 552 redds;152 of these fish where of natural origin. Of these, 121 summer steelhead, including 29 of natural origin, created an estimated 70 redds in the Canadian portion of the Okanagan basin. We estimated summer steelhead spawner escapement into each sub-watershed along with the number from natural origin and the number and density of redds. We documented redd desiccation in Loup Loup Creek, habitat utilization in Salmon Creek as a result of a new water lease program, and 10 spring Chinook returning to Omak Creek. High water through most of the redd survey period resulted in development of new modeling techniques and allowed us to survey additional tributaries including the observation of summer steelhead spawning in Wanacut Creek. These 2007 data provide additional support that redd surveys conducted within the United States are well founded and provide essential information for tracking the recovery of listed summer steelhead. Conversely, redd surveys do not appear to be the best approach for enumerating steelhead spawners or there distribution within Canada. We also identified that spawning distributions within the Okanogan River basin vary widely and stocking location may play an over riding roll in this variability.

  5. Evaluation of Sichuan Basin in China

    SciTech Connect (OSTI)

    Zhou, J.G.

    1996-06-01

    Sichuan basin lies in the central-south China, in a compression tectonic regime, with an area of approximately 180,000 km{sup 2}. It is a prolific basin with a upside resource potential of gas 5045.38 billion m{sup 3}, and oil 3.56 billion tons. By year-end 1993, the possible geological reserve of gas was 676.136 billion m{sup 3}, and oil 0.14 billion tons; totally about 140 billion m{sup 3} of gas and about 3.5 million tons of oil have been produced to date; thus, there will be 4,229 billion m{sup 3} gas yet to find. During about 40 years` exploration (1950 to 1990), 81 gas/oil fields, including 245 gas pools and 15 oil pools, had been discovered through 2357 wells (total footage 5,804,094 m). 257 surface structures and 189 buried structures (by 91,136 km seismic) had been found in the basin, of which 172 structures had been drilled. The basin contains 21 gas/oil reservoirs of commercial value, distributed from Sinian to Jurassic, in the depths ranging from 7,157 m (well-Guanji) to hundreds of meters. It is evident that the gas and water distribution is not controlled by regional structures or local anticlinal structure but depends on the local development of permeability and fracture porosity in reservoir objectives. Each local occurrence of permeability and porosity functions as a trap for both gas and water, and new gas reservoirs are continuously being found on anticlinal gas fields that have been on production for years.

  6. K Basin sludge treatment process description

    SciTech Connect (OSTI)

    Westra, A.G.

    1998-08-28

    The K East (KE) and K West (KW) fuel storage basins at the 100 K Area of the Hanford Site contain sludge on the floor, in pits, and inside fuel storage canisters. The major sources of the sludge are corrosion of the fuel elements and steel structures in the basin, sand intrusion from outside the buildings, and degradation of the structural concrete that forms the basins. The decision has been made to dispose of this sludge separate from the fuel elements stored in the basins. The sludge will be treated so that it meets Tank Waste Remediation System (TWRS) acceptance criteria and can be sent to one of the double-shell waste tanks. The US Department of Energy, Richland Operations Office accepted a recommendation by Fluor Daniel Hanford, Inc., to chemically treat the sludge. Sludge treatment will be done by dissolving the fuel constituents in nitric acid, separating the insoluble material, adding neutron absorbers for criticality safety, and reacting the solution with caustic to co-precipitate the uranium and plutonium. A truck will transport the resulting slurry to an underground storage tank (most likely tank 241-AW-105). The undissolved solids will be treated to reduce the transuranic (TRU) and content, stabilized in grout, and transferred to the Environmental Restoration Disposal Facility (ERDF) for disposal. This document describes a process for dissolving the sludge to produce waste streams that meet the TWRS acceptance criteria for disposal to an underground waste tank and the ERDF acceptance criteria for disposal of solid waste. The process described is based on a series of engineering studies and laboratory tests outlined in the testing strategy document (Flament 1998).

  7. SE Great Basin Play Fairway Analysis

    SciTech Connect (OSTI)

    Adam Brandt

    2015-11-15

    This submission includes a Na/K geothermometer probability greater than 200 deg C map, as well as two play fairway analysis (PFA) models. The probability map acts as a composite risk segment for the PFA models. The PFA models differ in their application of magnetotelluric conductors as composite risk segments. These PFA models map out the geothermal potential in the region of SE Great Basin, Utah.

  8. NATURAL GAS RESOURCES IN DEEP SEDIMENTARY BASINS

    SciTech Connect (OSTI)

    Thaddeus S. Dyman; Troy Cook; Robert A. Crovelli; Allison A. Henry; Timothy C. Hester; Ronald C. Johnson; Michael D. Lewan; Vito F. Nuccio; James W. Schmoker; Dennis B. Riggin; Christopher J. Schenk

    2002-02-05

    From a geological perspective, deep natural gas resources are generally defined as resources occurring in reservoirs at or below 15,000 feet, whereas ultra-deep gas occurs below 25,000 feet. From an operational point of view, ''deep'' is often thought of in a relative sense based on the geologic and engineering knowledge of gas (and oil) resources in a particular area. Deep gas can be found in either conventionally-trapped or unconventional basin-center accumulations that are essentially large single fields having spatial dimensions often exceeding those of conventional fields. Exploration for deep conventional and unconventional basin-center natural gas resources deserves special attention because these resources are widespread and occur in diverse geologic environments. In 1995, the U.S. Geological Survey estimated that 939 TCF of technically recoverable natural gas remained to be discovered or was part of reserve appreciation from known fields in the onshore areas and State waters of the United. Of this USGS resource, nearly 114 trillion cubic feet (Tcf) of technically-recoverable gas remains to be discovered from deep sedimentary basins. Worldwide estimates of deep gas are also high. The U.S. Geological Survey World Petroleum Assessment 2000 Project recently estimated a world mean undiscovered conventional gas resource outside the U.S. of 844 Tcf below 4.5 km (about 15,000 feet). Less is known about the origins of deep gas than about the origins of gas at shallower depths because fewer wells have been drilled into the deeper portions of many basins. Some of the many factors contributing to the origin of deep gas include the thermal stability of methane, the role of water and non-hydrocarbon gases in natural gas generation, porosity loss with increasing thermal maturity, the kinetics of deep gas generation, thermal cracking of oil to gas, and source rock potential based on thermal maturity and kerogen type. Recent experimental simulations using laboratory

  9. K Basins fuel encapsulation and storage hazard categorization

    SciTech Connect (OSTI)

    Porten, D.R.

    1994-12-01

    This document establishes the initial hazard categorization for K-Basin fuel encapsulation and storage in the 100 K Area of the Hanford site. The Hazard Categorization for K-Basins addresses the potential for release of radioactive and non-radioactive hazardous material located in the K-Basins and their supporting facilities. The Hazard Categorization covers the hazards associated with normal K-Basin fuel storage and handling operations, fuel encapsulation, sludge encapsulation, and canister clean-up and disposal. The criteria categorizes a facility based on total curies per radionuclide located in the facility. Tables 5-3 and 5-4 display the results in section 5.0. In accordance with DOE-STD-1027 and the analysis provided in section 5.0, the K East Basin fuel encapsulation and storage activity and the K West Basin storage are classified as a {open_quotes}Category 2{close_quotes} Facility.

  10. K basins interim remedial action health and safety plan

    SciTech Connect (OSTI)

    DAY, P.T.

    1999-09-14

    The K Basins Interim Remedial Action Health and Safety Plan addresses the requirements of the Comprehensive Environmental Response, Compensation and Liability Act (CERCLA), as they apply to the CERCLA work that will take place at the K East and K West Basins. The provisions of this plan become effective on the date the US Environmental Protection Agency issues the Record of Decision for the K Basins Interim Remedial Action, currently planned in late August 1999.

  11. Playa basin development, southern High Plains, Texas and New Mexico

    SciTech Connect (OSTI)

    Gustavson, T.C. (Univ. of Texas, Austin, TX (United States)); Holliday, V.T. (Univ. of Wisconsin, Madison, WI (United States))

    1992-01-01

    More than 20,000 playa basins have formed on fine-grained eolian sediments of the Quaternary Blackwater Draw and Tertiary Ogallala Formations on the High Plains of TX and NM. Numerous hypotheses have been proposed for the development of playa basins: (1) subsidence due to dissolution of underlying Permian bedded salt, (2) dissolution of soil carbonate and piping of clastic sediment into the subsurface, (3) animal activity, and (4) deflation. Evidence of eolian processes includes lee dunes and straightened shorelines on the eastern and southern margins of many playas. Lee dunes, which occur on the eastern side of ca 15% of playa basins and contain sediment deflated from adjacent playas, are cresentic to oval in plain view and typically account for 15--40% of the volume of the playa basin. Quaternary fossil biotas and buried calcic soils indicate that grasslands and semi-arid to aid climatic conditions prevailed as these basins formed. Evidence of fluviolacustrine processes in playa basins includes centripetal drainage leading to fan deltas at playa margins and preserved deltaic and lacustrine sediments. Playa basins expanded as fluvial processes eroded basin slopes and carried sediment to the basin floor where, during periods of minimal vegetation cover, loose sediment was removed by deflation. Other processes that played secondary roles in the development of certain playa basins include subsidence induced by dissolution of deeply buried Permian salt, dissolution of soil carbonate and piping, and animal activity. Two small lake basins in Gray County, TX, occur above strata affected by dissolution-induced subsidence. Dissolution of soil carbonate was observed in exposures and cores of strata underlying playa basins. Cattle, and in the past vast numbers of migrating buffalo, destroy soil crusts in dry playas, making these sediments more susceptible to deflation, and carry sediment out of flooded playas on their hooves.

  12. EIS-0495: Walla Walla Basin Spring Chinook Hatchery Program;...

    Broader source: Energy.gov (indexed) [DOE]

    Walla Walla Basin Spring Chinook Hatchery Program Public Comment Opportunities No public comment opportunities available at this time. Documents Available for Download...

  13. Geothermal Resource Analysis and Structure of Basin and Range...

    Open Energy Info (EERE)

    Analysis and Structure of Basin and Range Systems, Especially Dixie Valley Geothermal Field, Nevada Jump to: navigation, search OpenEI Reference LibraryAdd to library Report:...

  14. Geothermal Resource Analysis And Structure Of Basin And Range...

    Open Energy Info (EERE)

    And Structure Of Basin And Range Systems, Especially Dixie Valley Geothermal Field, Nevada Jump to: navigation, search OpenEI Reference LibraryAdd to library Report: Geothermal...

  15. Kinematic model for postorogenic Basin and Range extension |...

    Open Energy Info (EERE)

    Article: Kinematic model for postorogenic Basin and Range extension Abstract The Raft River extensional shear zone is exposed in the Albion-Raft River-Grouse Creek...

  16. Contemporary Strain Rates in the Northern Basin and Range Province...

    Open Energy Info (EERE)

    province using data from continuous GPS (CGPS) networks, supplemented by additional campaign data from the Death Valley, northern Basin and Range, and Sierra Nevada-Great Valley...

  17. Modeling-Computer Simulations At Nw Basin & Range Region (Blackwell...

    Open Energy Info (EERE)

    generic Basin and Range systems based on Dixie Valley data that help to understand the nature of large scale constraints on the location and characteristics of the geothermal...

  18. Modeling-Computer Simulations At Northern Basin & Range Region...

    Open Energy Info (EERE)

    generic Basin and Range systems based on Dixie Valley data that help to understand the nature of large scale constraints on the location and characteristics of the geothermal...

  19. Geographic Information System At Nw Basin & Range Region (Coolbaugh...

    Open Energy Info (EERE)

    David Blackwell, Gary Oppliger (2005) A Map Of Geothermal Potential For The Great Basin, Usa- Recognition Of Multiple Geothermal Environments Additional References Retrieved from...

  20. The petroleum geology of the sub-Andean basins

    SciTech Connect (OSTI)

    Mathalone, J.M.P.

    1996-08-01

    The sub-Andean trend of basins spans the entire length of South America from Venezuela in the north to Argentina in the south. All the basins produce hydrocarbons with the exception of the Argentinean Bolsones complex and the Peruvian Madro de Dios which is prospective but virtually unexplored. There have been some 119 billion barrels of oil and 190 TCF of gas discovered to date, comprising 93% of the continent`s oil reserves. The basins lie immediately east of the Andes mountain range and are mainly asymmetric Upper Tertiary, westerly dipping foreland basins that overlie a series of earlier Tertiary, Mesozoic and Paleozoic depocentres. All the basins have been compressively deformed as recently as the Upper Miocene, by the eastwards growth of the Andean Cordillera. Giant oil and gas fields sourced from shales of varying age, have been found along the whole trend of basins, with a predominance of gas in the south. The rich marine Upper Cretaceous La Luna and equivalent shales of Venezuela, Colombia and Ecuador have been responsible for generating 86% of the hydrocarbons discovered to date in the sub-Andean basins. Proven sources include Devonian, Carboniferous, Permian and Triassic shales in the central area, comprising Peru, Bolivia and northern Argentina. In southern Argentina, oils have been sourced from Uppermost Jurassic and Lower Cretaceous marine and lacustrine shales. Over 7500 wildcat wells have been drilled in basins along the trend, with a 15% success rate. Many of the basins are very lightly explored, with considerable potential for future discoveries.

  1. Teleseismic-Seismic Monitoring At Nw Basin & Range Region (Biasi...

    Open Energy Info (EERE)

    Teleseismic-Seismic Monitoring At Nw Basin & Range Region (Biasi, Et Al., 2008) Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity:...

  2. Teleseismic-Seismic Monitoring At Northern Basin & Range Region...

    Open Energy Info (EERE)

    Teleseismic-Seismic Monitoring At Northern Basin & Range Region (Biasi, Et Al., 2008) Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity:...

  3. Data Acquisition-Manipulation At Nw Basin & Range Region (Blackwell...

    Open Energy Info (EERE)

    References D. D. Blackwell, K. W. Wisian, M. C. Richards, Mark Leidig, Richard Smith, Jason McKenna (2003) Geothermal Resource Analysis And Structure Of Basin And Range...

  4. Data Acquisition-Manipulation At Northern Basin & Range Region...

    Open Energy Info (EERE)

    References D. D. Blackwell, K. W. Wisian, M. C. Richards, Mark Leidig, Richard Smith, Jason McKenna (2003) Geothermal Resource Analysis And Structure Of Basin And Range...

  5. Geothermometry At Nw Basin & Range Region (Shevenell & De Rocher...

    Open Energy Info (EERE)

    Geothermometry At Nw Basin & Range Region (Shevenell & De Rocher, 2005) Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity: Geothermometry At Nw...

  6. Water Sampling At Northern Basin & Range Region (Laney, 2005...

    Open Energy Info (EERE)

    Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity: Water Sampling At Northern Basin & Range Region (Laney, 2005) Exploration Activity Details...

  7. Water Sampling At Nw Basin & Range Region (Laney, 2005) | Open...

    Open Energy Info (EERE)

    Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity: Water Sampling At Nw Basin & Range Region (Laney, 2005) Exploration Activity Details...

  8. Independent Oversight Review, Hanford K Basin and Cold Vacuum...

    Broader source: Energy.gov (indexed) [DOE]

    Hanford K Basin and Cold Vacuum Drying Facility Found Fuel Multi-Canister Overpack Operations This report provides the results of an independent oversight review of operations...

  9. Geodetic Survey At Nw Basin & Range Region (Laney, 2005) | Open...

    Open Energy Info (EERE)

    Laney, 2005) Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity: Geodetic Survey At Nw Basin & Range Region (Laney, 2005) Exploration Activity...

  10. Geodetic Survey At Northern Basin & Range Region (Laney, 2005...

    Open Energy Info (EERE)

    Laney, 2005) Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity: Geodetic Survey At Northern Basin & Range Region (Laney, 2005) Exploration Activity...

  11. Oregon Willamette River Basin Mitigation Agreement | Open Energy...

    Open Energy Info (EERE)

    River Basin Mitigation Agreement Author State of Oregon Recipient Bonneville Power Administration Published Publisher Not Provided, 10222010 DOI Not Provided Check for DOI...

  12. Modeling-Computer Simulations At Nw Basin & Range Region (Pritchett...

    Open Energy Info (EERE)

    navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity: Modeling-Computer Simulations At Nw Basin & Range Region (Pritchett, 2004) Exploration Activity Details...

  13. Modeling-Computer Simulations At Nw Basin & Range Region (Biasi...

    Open Energy Info (EERE)

    navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity: Modeling-Computer Simulations At Nw Basin & Range Region (Biasi, Et Al., 2009) Exploration Activity...

  14. Modeling-Computer Simulations At Northern Basin & Range Region...

    Open Energy Info (EERE)

    navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity: Modeling-Computer Simulations At Northern Basin & Range Region (Biasi, Et Al., 2009) Exploration...

  15. Geographic Information System At Northern Basin & Range Region...

    Open Energy Info (EERE)

    DOE-funding Unknown References Mark Coolbaugh, Richard Zehner, Corne Kreemer, David Blackwell, Gary Oppliger (2005) A Map Of Geothermal Potential For The Great Basin,...

  16. Isotopic Analysis At Northern Basin & Range Region (Cole, 1983...

    Open Energy Info (EERE)

    Cole, 1983) Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity: Isotopic Analysis At Northern Basin & Range Region (Cole, 1983) Exploration Activity...

  17. Geographic Information System At Northern Basin & Range Region...

    Open Energy Info (EERE)

    Nash & Johnson, 2003) Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity: Geographic Information System At Northern Basin & Range Region (Nash &...

  18. Field Mapping At Northern Basin & Range Region (Blewitt Et Al...

    Open Energy Info (EERE)

    to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity: Field Mapping At Northern Basin & Range Region (Blewitt Et Al, 2005) Exploration Activity Details...

  19. Lithium In Tufas Of The Great Basin- Exploration Implications...

    Open Energy Info (EERE)

    In Tufas Of The Great Basin- Exploration Implications For Geothermal Energy And Lithium Resources Jump to: navigation, search OpenEI Reference LibraryAdd to library Conference...

  20. Field Mapping At Northern Basin and Range Geothermal Region ...

    Open Energy Info (EERE)

    extension over broad areas of the northern Basin and Range. References Dumitru, T.; Miller, E.; Savage, C.; Gans, P.; Brown, R. (1 April 1993) Fission track evidence for...

  1. Calif--San Joaquin Basin onsh Shale Proved Reserves (Billion...

    U.S. Energy Information Administration (EIA) Indexed Site

    onsh Shale Proved Reserves (Billion Cubic Feet) Calif--San Joaquin Basin onsh Shale Proved Reserves (Billion Cubic Feet) No Data Available For This Series - No Data Reported; --...

  2. Preparing T Plant to Store K-Basin Sludge

    SciTech Connect (OSTI)

    MCKENNEY, D.E.

    2003-01-01

    This paper will explain the history and status of the modification of the Hanford T Plant facility for storage of K Basin sludge.

  3. Geothermal Reservoir Assessment Case Study, Northern Basin and...

    Open Energy Info (EERE)

    Basin and Range Province, Northern Dixie Valley, Nevada Abstract NA Authors Elaine J. Bell, Lawrence T. Larson and Russell W. Juncal Published U.S. Department of Energy,...

  4. Data Acquisition-Manipulation At Northern Basin & Range Region...

    Open Energy Info (EERE)

    - 2) Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity: Data Acquisition-Manipulation At Northern Basin & Range Region (Coolbaugh, Et Al., 2005 - 2)...

  5. Data Acquisition-Manipulation At Nw Basin & Range Region (Coolbaugh...

    Open Energy Info (EERE)

    - 2) Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity: Data Acquisition-Manipulation At Nw Basin & Range Region (Coolbaugh, Et Al., 2005 - 2)...

  6. Isotopic Analysis At Nw Basin & Range Region (Laney, 2005) |...

    Open Energy Info (EERE)

    Location Northwest Basin and Range Geothermal Region Exploration Technique Isotopic Analysis- Fluid Activity Date Usefulness not indicated DOE-funding Unknown Notes...

  7. Compound and Elemental Analysis At Nw Basin & Range Region (Laney...

    Open Energy Info (EERE)

    Northwest Basin and Range Geothermal Region Exploration Technique Compound and Elemental Analysis Activity Date Usefulness not indicated DOE-funding Unknown Notes Geochemical...

  8. Compound and Elemental Analysis At Northern Basin & Range Region...

    Open Energy Info (EERE)

    Northern Basin and Range Geothermal Region Exploration Technique Compound and Elemental Analysis Activity Date Usefulness not indicated DOE-funding Unknown Notes Geochemical...

  9. Isotopic Analysis At Northern Basin & Range Region (Laney, 2005...

    Open Energy Info (EERE)

    Location Northern Basin and Range Geothermal Region Exploration Technique Isotopic Analysis- Fluid Activity Date Usefulness not indicated DOE-funding Unknown Notes...

  10. Micro-Earthquake At Northwest Basin and Range Geothermal Region...

    Open Energy Info (EERE)

    Micro-Earthquake At Northwest Basin and Range Geothermal Region (1976) Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity: Micro-Earthquake At...

  11. Cold test data for equipment acceptance into 105-KE Basin

    SciTech Connect (OSTI)

    Packer, M.J.

    1994-11-09

    This document provides acceptance testing of equipment to be installed in the 105-KE Basin for pumping sludge to support the discharge chute barrier doors installation.

  12. EIS-0522: Melvin R. Sampson Hatchery, Yakima Basin Coho Project...

    Energy Savers [EERE]

    Sampson Hatchery, Yakima Basin Coho Project; Kittitas County, Washington Contact Dave Goodman jdgoodman@bpa.gov (503) 230-4764 More Information http:efw.bpa.gov...

  13. Dixie Valley - Geothermal Development in the Basin and Range...

    Open Energy Info (EERE)

    Not Provided DOI Not Provided Check for DOI availability: http:crossref.org Online Internet link for Dixie Valley - Geothermal Development in the Basin and Range Citation Dixie...

  14. Great Basin College Direct Use Geothermal Demonstration Project

    SciTech Connect (OSTI)

    Rice, John

    2014-10-21

    This is the final technical report for the Great Basin College Direct Use Geothermal Demonstrationn Project, outlining the technical aspects of the User Group System.

  15. Supai salt karst features: Holbrook Basin, Arizona

    SciTech Connect (OSTI)

    Neal, J.T.

    1994-12-31

    More than 300 sinkholes, fissures, depressions, and other collapse features occur along a 70 km (45 mi) dissolution front of the Permian Supai Formation, dipping northward into the Holbrook Basin, also called the Supai Salt Basin. The dissolution front is essentially coincident with the so-called Holbrook Anticline showing local dip reversal; rather than being of tectonic origin, this feature is likely a subsidence-induced monoclinal flexure caused by the northward migrating dissolution front. Three major areas are identified with distinctive attributes: (1) The Sinks, 10 km WNW of Snowflake, containing some 200 sinkholes up to 200 m diameter and 50 m depth, and joint controlled fissures and fissure-sinks; (2) Dry Lake Valley and contiguous areas containing large collapse fissures and sinkholes in jointed Coconino sandstone, some of which drained more than 50 acre-feet ({approximately}6 {times} 10{sup 4} m{sup 3}) of water overnight; and (3) the McCauley Sinks, a localized group of about 40 sinkholes 15 km SE of Winslow along Chevelon Creek, some showing essentially rectangular jointing in the surficial Coconino Formation. Similar salt karst features also occur between these three major areas. The range of features in Supai salt are distinctive, yet similar to those in other evaporate basins. The wide variety of dissolution/collapse features range in development from incipient surface expression to mature and old age. The features began forming at least by Pliocene time and continue to the present, with recent changes reportedly observed and verified on airphotos with 20 year repetition. The evaporate sequence along interstate transportation routes creates a strategic location for underground LPG storage in leached caverns. The existing 11 cavern field at Adamana is safely located about 25 miles away from the dissolution front, but further expansion initiatives will require thorough engineering evaluation.

  16. Stratigraphy of Pennsylvanian detrital reservoirs, Permian basin

    SciTech Connect (OSTI)

    Van Der Loop, M. )

    1992-04-01

    Significant oil reserves have been found to date in stratigraphic traps in Pennsylvanian detrital reservoirs on the Central Basin platform and Reagan uplift of the Permian basin. The 32 MMBOEG Arenoso field area, discovered in 1966, is the largest producing field. Along a 75 mi northwest-southeast trend, 23 other smaller fields will produce an average 850 MBOEG each, for a total estimated ultimate recovery to date in the trend of 52 MMBOEG. These stratigraphic traps are elusive and complex. However, reservoir quality is excellent, and because of the poorly understood trap types, significant reserves remain to be found in the trend. The Pennsylvanian detrital consists of chert cobble conglomerates, coarse sands, red shales, and gray limestones deposited in an environment that grades seaward from alluvial fan to braided stream to shallow marine. The chert cobble conglomerates of the alluvial fan facies and the coarse sands of the braided stream facies are the highest quality pay zones. Porosities range from 5 to 20%, with permeability ranging up to 26 d. The total unit is seldom more than 400 ft thick; reservoir rock thicknesses within the unit range up to 100 ft. Because of the complex nature of the alluvial fan and braided stream deposits, dry development wells can be expected within fields. These Strawn deposits are located adjacent to and overlying the eroded lower Paleozoic uplifts of the southern Central Basin platform. The major source of the chert cobbles is erosion of the Devonian tripolitic chert. Renewed structural uplift combined with sea level drop in the middle Wolfcampian locally truncated some Pennsylvanian detrital alluvial fan deposits, and complicated or destroyed a potential trap by depositing Wolfcamp chert conglomerates on top of the Pennsylvanian conglomerates.

  17. New interpretations of Pennsylvanian and Permian stratigraphy, San Juan basin and southeast Paradox basin

    SciTech Connect (OSTI)

    Huffman, A.C. Jr.; Condon, S.M. )

    1989-09-01

    The Honaker Trail, Paradox, and Pinkerton Trail Formations of the Hermosa Group are recognized throughout most of the San Juan basin. The Paradox Formation is extended southeastward beyond the limits of its evaporite facies into the basin, where it consists of thick shelf-carbonate rocks and thin black shale, sandstone, and siltstone interbeds. Where the Hermosa Group thins onto the marginal uplifts, the Paradox loses the thick carbonate rocks and becomes indistinguishable from the rest of the Hermosa. The Hermosa is correlated in the subsurface with the Madera and Sandia Formations to the southeast. The transitional Rico Formation, between the marine Hermosa Group and the continental Cutler Formation, is identified throughout the subsurface of the San Juan basin and is correlated with similar deposits out-cropping along the northern and eastern margins. The Cutler Formation includes the Organ Rock, Cedar Mesa, and Halgaito members throughout most of the basin. In the vicinity of the Hogback monocline, the Cedar Mesa Sandstone Member undergoes a gradational eastward facies change from cyclic evaporite and sandstone to thick-bedded sandstone. The subsurface Cedar Mesa is correlated in part with similar rocks in the outcropping Abo and Supai Formations.

  18. Basin Analysis and Petroleum System Characterization and Modeling, Interior Salt Basins, Central and Eastern Gulf of Mexico

    SciTech Connect (OSTI)

    Ernest A. Mancini; Paul Aharon; Donald A. Goddard; Roger Barnaby

    2006-02-28

    The principal research effort for Year 3 of the project is basin modeling and petroleum system identification, comparative basin evaluation and resource assessment. In the first six (6) months of Year 3, the research focus is on basin modeling and petroleum system identification and the remainder of the year the emphasis is on the comparative basin evaluation and resource assessment. No major problems have been encountered to date, and the project is on schedule. The principal objectives of the project are to develop through basin analysis and modeling the concept that petroleum systems acting in a basin can be identified through basin modeling and to demonstrate that the information and analysis resulting from characterizing and modeling of these petroleum systems in the North Louisiana Salt Basin and the Mississippi Interior Salt Basin can be used in providing a more reliable and advanced approach for targeting stratigraphic traps and specific reservoir facies within a geologic system and in providing a refined assessment of undiscovered and underdeveloped reservoirs and associated oil and gas resources.

  19. Origin Basin Destination State STB EIA STB EIA Northern Appalachian...

    Annual Energy Outlook [U.S. Energy Information Administration (EIA)]

    Delaware W 28.49 W 131.87 21.6% 59 W 100.0% Northern Appalachian Basin Florida W - - - - - - - Northern Appalachian Basin Indiana W 20.35 W 64.82 31.4% 1,715 W 75.9% Northern...

  20. Origin Basin Destination State STB EIA STB EIA Northern Appalachian...

    Gasoline and Diesel Fuel Update (EIA)

    Florida W 38.51 W 140.84 27.3% 134 W 100.0% Northern Appalachian Basin Georgia - W - W W W - W Northern Appalachian Basin Indiana W 16.14 W 63.35 25.5% 1,681 W 88.5% Northern...

  1. Calif--Los Angeles Basin Onshore Crude Oil Reserves in Nonproducing...

    U.S. Energy Information Administration (EIA) Indexed Site

    Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Calif--Los Angeles Basin ... Proved Nonproducing Reserves of Crude Oil CA, Los Angeles Basin Onshore Proved ...

  2. Geodetic Survey At Nw Basin & Range Region (Blewitt Et Al, 2005...

    Open Energy Info (EERE)

    Geodetic Survey At Nw Basin & Range Region (Blewitt Et Al, 2005) Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity: Geodetic Survey At Nw Basin &...

  3. Rocky Mountain Basins Produced Water Database

    DOE Data Explorer [Office of Scientific and Technical Information (OSTI)]

    Historical records for produced water data were collected from multiple sources, including Amoco, British Petroleum, Anadarko Petroleum Corporation, United States Geological Survey (USGS), Wyoming Oil and Gas Commission (WOGC), Denver Earth Resources Library (DERL), Bill Barrett Corporation, Stone Energy, and other operators. In addition, 86 new samples were collected during the summers of 2003 and 2004 from the following areas: Waltman-Cave Gulch, Pinedale, Tablerock and Wild Rose. Samples were tested for standard seven component "Stiff analyses", and strontium and oxygen isotopes. 16,035 analyses were winnowed to 8028 unique records for 3276 wells after a data screening process was completed. [Copied from the Readme document in the zipped file available at http://www.netl.doe.gov/technologies/oil-gas/Software/database.html] Save the Zipped file to your PC. When opened, it will contain four versions of the database: ACCESS, EXCEL, DBF, and CSV formats. The information consists of detailed water analyses from basins in the Rocky Mountain region.

  4. Biothem-based Mississippian transect from the Basin and Range Province to the Anadarko basin

    SciTech Connect (OSTI)

    Frye, M.W. ); Lane, H.R. ); Couples, G.D. )

    1991-03-01

    A west-to-east transect, constructed using the 'Biostratigraphic Package Approach' of Lane and Frye and illustrating the biostratigraphic, lithologic, and depositional sequence relationships within the Mississippian system, extends from the basin and range province across the Transcontinental Arch (TA) and into the Anadarko basin. The transect is based on both published and proprietary biostratigraphic data. It was constructed primarily to portray the regional distribution and exploration significance of biotherms relative to the axis of the TA. These biotherms are biostratigraphic units that are wedge- or lens-shaped bodies of strata that are bounded by paleontologically recognizable unconformities in their updip extents, are conformable with underlying and overlying biothems in their maximum shelfal development, are conformable or bounded by surfaces of nondeposition and or submarine erosion in their downdip, basinal extremities, and also contain a logical sequence of depositionally related facies. An unexpected result of constructing the transect was the recognition of an apparent compensatory temporal and spatial distribution of Mississippian biothems. This distribution is interpreted to imply that biothems deposited during relative highstand events on one flank of the TA are time-equivalent to biothems deposited during relative lowstand events on the opposite flank of the TA. Platescale tilting, along with local subsidence and uplift, is suggested as the overriding mechanism controlling deposition along the extent of the transect.

  5. BASIN-CENTERED GAS SYSTEMS OF THE U.S.

    SciTech Connect (OSTI)

    Marin A. Popov; Vito F. Nuccio; Thaddeus S. Dyman; Timothy A. Gognat; Ronald C. Johnson; James W. Schmoker; Michael S. Wilson; Charles Bartberger

    2000-11-01

    The USGS is re-evaluating the resource potential of basin-centered gas accumulations in the U.S. because of changing perceptions of the geology of these accumulations, and the availability of new data since the USGS 1995 National Assessment of United States oil and gas resources (Gautier et al., 1996). To attain these objectives, this project used knowledge of basin-centered gas systems and procedures such as stratigraphic analysis, organic geochemistry, modeling of basin thermal dynamics, reservoir characterization, and pressure analysis. This project proceeded in two phases which had the following objectives: Phase I (4/1998 through 5/1999): Identify and describe the geologic and geographic distribution of potential basin-centered gas systems, and Phase II (6/1999 through 11/2000): For selected systems, estimate the location of those basin-centered gas resources that are likely to be produced over the next 30 years. In Phase I, we characterize thirty-three (33) potential basin-centered gas systems (or accumulations) based on information published in the literature or acquired from internal computerized well and reservoir data files. These newly defined potential accumulations vary from low to high risk and may or may not survive the rigorous geologic scrutiny leading towards full assessment by the USGS. For logistical reasons, not all basins received the level of detail desired or required.

  6. Source rocks of the Sub-Andean basins

    SciTech Connect (OSTI)

    Raedeke, L.D. )

    1993-02-01

    Seven source rock systems were mapped using a consistent methodology to allow basin comparison from Trinidad to southern Chile. Silurian and Devonian systems, deposited in passive margin and intracratonic settings, have fair-good original oil/gas potential from central and northern Bolivia to southern Peru. Kerogens range from mature in the foreland to overmature in the thrust belt. Permian to Carboniferous deposition in local restricted basins formed organic-rich shales and carbonates with very good original oil/gas potential, principally in northern Bolivia and southern Peru. Late Triassic to early Jurassic marine shales and limestones, deposited in deep, narrow, basins from Ecuador to north-central maturity. Locally, in the Cuyo rift basin of northern Argentina, a Triassic lacustrine unit is a very good, mature oil source. Early Cretaceous to Jurassic marine incursions into the back-arc basins of Chile-Argentina deposited shales and limestones. Although time transgressive (younging to the south), this system is the principal source in southern back-arc basins, with best potential in Neuquen, where three intervals are stacked A late Cretaceous marine transgressive shale is the most important source in northern South America. The unit includes the La Luna and equivalents extending from Trinidad through Venezuela, Colombia, Ecuador, and into northern Peru. Elsewhere in South America upper Cretaceous marine-lacustrine rocks are a possible source in the Altiplano and Northwest basins of Bolivia and Argentina. Middle Miocene to Oligocene source system includes shallow marine, deltaic, and lacustrine sediments from Trinidad to northern Peru.

  7. Basin Analysis and Petroleum System Characterization and Modeling, Interior Salt Basins, Central and Eastern Gulf of Mexico

    SciTech Connect (OSTI)

    Ernest A. Mancini; Paul Aharon; Donald A. Goddard; Roger Barnaby

    2006-05-26

    The principal research effort for Phase 1 (Concept Development) of the project has been data compilation; determination of the tectonic, depositional, burial, and thermal maturation histories of the North Louisiana Salt Basin; basin modeling (geohistory, thermal maturation, hydrocarbon expulsion); petroleum system identification; comparative basin evaluation; and resource assessment. Existing information on the North Louisiana Salt Basin has been evaluated, an electronic database has been developed, and regional cross sections have been prepared. Structure, isopach and formation lithology maps have been constructed, and burial history, thermal maturation history, and hydrocarbon expulsion profiles have been prepared. Seismic data, cross sections, subsurface maps and burial history, thermal maturation history, and hydrocarbon expulsion profiles have been used in evaluating the tectonic, depositional, burial and thermal maturation histories of the basin. Oil and gas reservoirs have been found to be associated with salt-supported anticlinal and domal features (salt pillows, turtle structures and piercement domes); with normal faulting associated with the northern basin margin and listric down-to-the-basin faults (state-line fault complex) and faulted salt features; and with combination structural and stratigraphic features (Sabine and Monroe Uplifts) and monoclinal features with lithologic variations. Petroleum reservoirs include Upper Jurassic and Cretaceous fluvial-deltaic sandstone facies; shoreline, marine bar and shallow shelf sandstone facies; and carbonate shoal, shelf and reef facies. Cretaceous unconformities significantly contribute to the hydrocarbon trapping mechanism capacity in the North Louisiana Salt Basin. The chief petroleum source rock in this basin is Upper Jurassic Smackover lime mudstone beds. The generation of hydrocarbons from Smackover lime mudstone was initiated during the Early Cretaceous and continued into the Tertiary. Hydrocarbon

  8. Structural evolution of Val Verde basin, west Texas

    SciTech Connect (OSTI)

    Sanders, D.E.; Petersen, N.

    1984-04-01

    The Val Verde basin is a northwest-southeast trending foreland basin contained within the southern portion of the Permian basin. The Val Verde basin has several large fields, e.g., Brown Bassett and JM, which have a combined ultimate recovery of over 1 tcf of gas. Structurally, the major fields are complexly faulted features related to differential uplift of basement blocks. Middle and Upper Permian strata are not present in the central and southern Val Verde basin. Appreciable amounts of Permian sediment were eroded prior to deposition of Cretaceous strata, thus, Cretaceous rocks unconformably overlie Wolfcamp sediments. Restored estimates for vitrinite reflectance data indicate a minimum of 8000-10,000 ft (2400-3000 m) of Permian rocks have been eroded. Therefore, in the central and southern portions of the basin, Paleozoic rocks are inferred to have occupied depths several miles deeper than present. Vitrinite reflectance values for Ellenburger (Ordovician) rocks at Brown Bassett are approximately 1.8 to 2.0% R/sub o/. Ellenburger reflectance values increase to the south and southeast to values greater than 4.5% R/sub o/. The most southerly wells also have reflectance depth trends which show a break in gradient within Wolfcamp sediments (9000-10,000 ft, 2700-3000 m). The change in gradient suggests a thermal event contemporaneous with the basin's rapid downwarping and Wolfcamp deposition. Any exploration in the basin, therefore, must recognize the unique relationships between structural timing, structural position, depth of burial, thermal pulses, and hydrocarbon mobility for a large portion of Val Verde basin.

  9. Western Gas Sands Project: stratigrapy of the Piceance Basin

    SciTech Connect (OSTI)

    Anderson, S.

    1980-08-01

    The Western Gas Sands Project Core Program was initiated by US DOE to investigate various low permeability, gas bearing sandstones. Research to gain a better geological understanding of these sandstones and improve evaluation and stimulation techniques is being conducted. Tight gas sands are located in several mid-continent and western basins. This report deals with the Piceance Basin in northwestern Colorado. This discussion is an attempt to provide a general overview of the Piceance Basin stratigraphy and to be a useful reference of stratigraphic units and accompanying descriptions.

  10. Oil and gas resources remaining in the Permian Basin

    SciTech Connect (OSTI)

    Not Available

    1989-01-01

    In this book the authors present a reevaluation of the oil and gas resource base remaining in existing Permian Basin reservoirs. The Permian Basin is one of the nation's premier sources of oil production, accounting for almost one quarter of the total domestic oil resource. The distribution and magnitude of oil and gas resources discovered in the basin are documented at the play and reservoir levels. Data on reservoir geology and volumetric analysis come from the oil and gas atlases published by the Bureau of Economic Geology, the Bureau's oil-reservoir data base, and NRG Associates Significant Oil and Gas Fields of the United States.

  11. BASIN ANALYSIS AND PETROLEUM SYSTEM CHARACTERIZATION AND MODELING, INTERIOR SALT BASINS, CENTRAL AND EASTERN GULF OF MEXICO

    SciTech Connect (OSTI)

    Ernest A. Mancini; Donald A. Goddard; Ronald K. Zimmerman

    2005-05-10

    The principal research effort for Year 2 of the project has been data compilation and the determination of the burial and thermal maturation histories of the North Louisiana Salt Basin and basin modeling and petroleum system identification. In the first nine (9) months of Year 2, the research focus was on the determination of the burial and thermal maturation histories, and during the remainder of the year the emphasis has basin modeling and petroleum system identification. Existing information on the North Louisiana Salt Basin has been evaluated, an electronic database has been developed, regional cross sections have been prepared, structure and isopach maps have been constructed, and burial history, thermal maturation history and hydrocarbon expulsion profiles have been prepared. Seismic data, cross sections, subsurface maps and related profiles have been used in evaluating the tectonic, depositional, burial and thermal maturation histories of the basin. Oil and gas reservoirs have been found to be associated with salt-supported anticlinal and domal features (salt pillows, turtle structures and piercement domes); with normal faulting associated with the northern basin margin and listric down-to-the-basin faults (state-line fault complex) and faulted salt features; and with combination structural and stratigraphic features (Sabine and Monroe Uplifts) and monoclinal features with lithologic variations. Petroleum reservoirs are mainly Upper Jurassic and Lower Cretaceous fluvial-deltaic sandstone facies and Lower Cretaceous and Upper Cretaceous shoreline, marine bar and shallow shelf sandstone facies. Cretaceous unconformities significantly contribute to the hydrocarbon trapping mechanism capacity in the North Louisiana Salt Basin. The chief petroleum source rock in this basin is Upper Jurassic Smackover lime mudstone beds. The generation of hydrocarbons from Smackover lime mudstone was initiated during the Early Cretaceous and continued into the Tertiary

  12. Regional basinal sandstone depositional patterns during the Guadalupian (Late Permian), Delaware basin, west Texas-New Mexico

    SciTech Connect (OSTI)

    Geisen, J.H.; Scholle, P.A. )

    1990-05-01

    Examination of well logs from more than 300 Delaware basin wells penetrating the Bell Canyon and Brushy Canyon formations has allowed definition of regional depositional patterns during the Late Permian (Guadalupian). Characteristic gamma-ray hot-kicks mark thin but widespread calcareous shales or limestones representing starved basin sedimentation during sea level highstands. Correlation of such markers along three strike and ten dip lines permitted isopaching of intervening lowstand clastic wedges. The low-stand wedges typically thin significantly from basin margin to basin center and are marked by a prominent linearity oriented perpendicular to the margin. These lineations probably represent channelized turbidite and grain-flow deposits. Most intervals show dozens of such lineations indicating multiple input points for terrigenous detritus rather than just a few major point sources of debris. The resulting deposits appear to be more apron-like than fan-like and coalesce into broad, sheetlike deposits toward the basin center. Isopach thicks vary in position through time, but terrigenous sediment transport is predominantly from northerly directions throughout the analyzed interval. Thus, the filling of the Midland basin at the close of Cherry Canyon deposition did not result in a major new source of terrigenous debris from the east (Central Basin platform). The well-sorted nature of the basinal sands, their widely distributed input points, apron-like geometry, and other factors argue for migration of eolian dunes to the shelf margin during sea level lowstands. Transport of these well-sorted, unconsolidated sands into the basin was not however, mainly by direct eolian processes as has been proposed recently, but must have involved submarine current mechanisms.

  13. Permian evolution of sandstone composition in a complex back-arc extensional to foreland basin: The Bowen Basin, eastern Australia

    SciTech Connect (OSTI)

    Baker, J.C. . Centre for Microscopy and Microanalysis); Fielding, C.R. . Dept. of Earth Sciences); Caritat, P de . Dept. of Geology); Wilkinson, M.M. )

    1993-09-01

    The Bowen Basin is a Permo-Triassic, back-arc extensional to foreland basin that developed landward of an intermittently active continental volcanic arc associated with the eastern Australian convergent plate margin. The basin has a complex, polyphase tectonic history that began with limited back-arc crustal extension during the Early Permian. This created a series of north-trending grabens and half grabens which, in the west, accommodated quartz-rich sediment derived locally from surrounding, uplifted continental basement. In the east, coeval calc-alkaline, volcanolithic-rich, and volcaniclastic sediment was derived from the active volcanic arc. This early extensional episode was followed by a phase of passive thermal subsidence accompanied by episodic compression during the late Early Permian to early Late Permian, with little contemporaneous volcanism. In the west, quartzose sediment was shed from stable, polymictic, continental basement immediately to the west and south of the basin, whereas volcanolithic-rich sediment that entered the eastern side of the basin during this time was presumably derived from the inactive, and possibly partly submerged volcanic arc. During the late Late Permian, flexural loading and increased compression occurred along the eastern margin of the Bowen Basin, and renewed volcanism took place in the arc system to the east. Reactivation of this arc led to westward and southward spread of volcanolithic-rich sediment over the entire basin. Accordingly, areas in the west that were earlier receiving quartzose, craton-derived sediment from the west and south were overwhelmed by volcanolithic-rich, arc-derived sediment from the east and north. This transition from quartz-rich, craton-derived sediments to volcanolithic-rich, arc-derived sediments is consistent with the interpreted back-arc extensional to foreland basin origin for the Bowen Basin.

  14. Cenozoic volcanic geology of the Basin and Range province in...

    Open Energy Info (EERE)

    the Basin and Range province in Hidalgo County, southwestern New Mexico Authors Deal, E. G., Elston, W.E., Erb, E. E., Peterson, S. L., & Reiter and D. E. Conference 29th Field...

  15. Tularosa Basin Play Fairway Analysis: Pleistocene Lake Otero

    SciTech Connect (OSTI)

    Adam Brandt

    2015-11-15

    This submission includes a geotiff of the geographic extent of Pleistocene Lake Otero; which was used as apart of the groundwater composite risk segment in a Tularosa Basin Play Fairway Analysis.

  16. Abraham Hot Springs Geothermal Area Northern Basin and Range...

    Open Energy Info (EERE)

    br Brophy br Model br Moeck br Beardsmore br Type br Volume br Geothermal br Region Mean br Reservoir br Temp br Mean br Capacity Abraham Hot Springs Geothermal Area Northern Basin...

  17. Evaluation of Geothermal Potential of Rio Grande Rift and Basin...

    Open Energy Info (EERE)

    to: navigation, search OpenEI Reference LibraryAdd to library Report: Evaluation of Geothermal Potential of Rio Grande Rift and Basin and Range Province, New Mexico Abstract A...

  18. Oil and gas resources in the West Siberian Basin, Russia

    SciTech Connect (OSTI)

    1997-12-01

    The primary objective of this study is to assess the oil and gas potential of the West Siberian Basin of Russia. The study does not analyze the costs or technology necessary to achieve the estimates of the ultimate recoverable oil and gas. This study uses reservoir data to estimate recoverable oil and gas quantities which were aggregated to the field level. Field totals were summed to a basin total for discovered fields. An estimate of undiscovered oil and gas, from work of the US Geological Survey (USGS), was added to give a total basin resource volume. Recent production decline points out Russia`s need to continue development of its discovered recoverable oil and gas. Continued exploration is required to discover additional oil and gas that remains undiscovered in the basin.

  19. Recovery Act Workers Complete Environmental Cleanup of Coal Ash Basin

    Broader source: Energy.gov [DOE]

    The Savannah River Site (SRS) recently cleaned up a 17-acre basin containing coal ash residues from Cold War operations. The American Recovery and Reinvestment Act project was safely completed at a...

  20. Characteristics of Basin and Range Geothermal Systems with Fluid...

    Open Energy Info (EERE)

    of 150-200C have been discovered in the northern Basin and Range Province of the USA. A comparison of these high and moderate temperature systems shows considerable overlap...

  1. Tularosa Basin Play Fairway Analysis: groundawater, heat flow, relief map

    SciTech Connect (OSTI)

    Adam Brandt

    2015-11-15

    In this submission is the groundwater composite risk segment (CRS) used for play fairway analysis. Also included is a heatflow probability map, and a shaded relief map of the Tularosa Basin, NM.

  2. Adjudicated Groundwater Basins in California | Open Energy Information

    Open Energy Info (EERE)

    Basins in CaliforniaLegal Published NA Year Signed or Took Effect 2014 Legal Citation Not provided DOI Not Provided Check for DOI availability: http:crossref.org Online...

  3. Magnitude of Crustal Extension in the Southern Great Basin |...

    Open Energy Info (EERE)

    Magnitude of Crustal Extension in the Southern Great Basin Jump to: navigation, search OpenEI Reference LibraryAdd to library Journal Article: Magnitude of Crustal Extension in the...

  4. EIA - Natural Gas Pipeline Network - Natural Gas Supply Basins...

    Gasoline and Diesel Fuel Update (EIA)

    Corridors About U.S. Natural Gas Pipelines - Transporting Natural Gas based on data through 20072008 with selected updates U.S. Natural Gas Supply Basins Relative to Major Natural ...

  5. Diachroneity of Basin and Range Extension and Yellowstone Hotspot...

    Open Energy Info (EERE)

    Basin and Range Province. Authors Joseph P. Colgan, Trevor A. Dumitru and Elizabeth L. Miller Published Journal Geology, 2004 DOI 10.1130G20037.1 Online Internet link for...

  6. Basin-Scale Opportunity Assessment Initiative Background Literature Review

    SciTech Connect (OSTI)

    Saulsbury, Bo; Geerlofs, Simon H.; Cada, Glenn F; Bevelhimer, Mark S

    2010-10-01

    As called for in the March 24, 2010, Memorandum of Understanding (MOU) for Hydropower, the U.S. Department of Energy (DOE), the U.S. Department of the Interior (DOI), the U.S. Army Corps of Engineers (USACE), environmental stakeholders, and the hydropower industry are collaborating to identify opportunities to simultaneously increase electricity generation and improve environmental services in river basins of the United States. New analytical tools provide an improved ability to understand, model, and visualize environmental and hydropower systems. Efficiencies and opportunities that might not be apparent in site-by-site analyses can be revealed through assessments at the river-basin scale. Information from basin-scale assessments could lead to better coordination of existing hydropower projects, or to inform siting decisions (e.g., balancing the removal of some dams with the construction of others), in order to meet renewable energy production and environmental goals. Basin-scale opportunity assessments would inform energy and environmental planning and address the cumulative effects of hydropower development and operations on river basin environmental quality in a way that quantifies energy-environment tradeoffs. Opportunity assessments would create information products, develop scenarios, and identify specific actions that agencies, developers, and stakeholders can take to locate new sustainable hydropower projects, increase the efficiency and environmental performance of existing projects, and restore and protect environmental quality in our nation's river basins. Government agencies and non-governmental organizations (NGO) have done significant work to understand and assess opportunities for both hydropower and environmental protection at the basin scale. Some initiatives have been successful, others less so, and there is a need to better understand the legacy of work on which this current project can build. This background literature review is intended to

  7. SAVANNAH RIVER SITE R REACTOR DISASSEMBLY BASIN IN SITU DECOMMISSIONING

    SciTech Connect (OSTI)

    Langton, C.; Blankenship, J.; Griffin, W.; Serrato, M.

    2009-12-03

    The US DOE concept for facility in-situ decommissioning (ISD) is to physically stabilize and isolate in tact, structurally sound facilities that are no longer needed for their original purpose of, i.e., generating (reactor facilities), processing(isotope separation facilities) or storing radioactive materials. The 105-R Disassembly Basin is the first SRS reactor facility to undergo the in-situ decommissioning (ISD) process. This ISD process complies with the105-R Disassembly Basin project strategy as outlined in the Engineering Evaluation/Cost Analysis for the Grouting of the R-Reactor Disassembly Basin at the Savannah River Site and includes: (1) Managing residual water by solidification in-place or evaporation at another facility; (2) Filling the below grade portion of the basin with cementitious materials to physically stabilize the basin and prevent collapse of the final cap - Sludge and debris in the bottom few feet of the basin will be encapsulated between the basin floor and overlying fill material to isolate if from the environment; (3) Demolishing the above grade portion of the structure and relocating the resulting debris to another location or disposing of the debris in-place; and (4) Capping the basin area with a concrete slab which is part of an engineered cap to prevent inadvertent intrusion. The estimated total grout volume to fill the 105-R Reactor Disassembly Basin is 24,424 cubic meters or 31,945 cubic yards. Portland cement-based structural fill materials were design and tested for the reactor ISD project and a placement strategy for stabilizing the basin was developed. Based on structural engineering analyses and work flow considerations, the recommended maximum lift height is 5 feet with 24 hours between lifts. Pertinent data and information related to the SRS 105-R-Reactor Disassembly Basin in-situ decommissioning include: regulatory documentation, residual water management, area preparation activities, technology needs, fill material designs

  8. Geothermal resources of the Washakie and Great Divide basins, Wyoming

    SciTech Connect (OSTI)

    Heasler, H.P.; Buelow, K.L.

    1985-01-01

    The geothermal resources of the Great Divide and Washakie Basins of southern Wyoming are described. Oil well bottomhole temperatures, thermal logs of wells, and heat flow data were interpreted within a framework of geologic and hydrologic constraints. It was concluded large areas in Wyoming are underlain by water hotter than 120{sup 0}F. Isolated areas with high temperature gradients exist within each basin. 68 refs., 8 figs., 7 tabs. (ACR)

  9. Repository site definition in basalt: Pasco Basin, Washington

    SciTech Connect (OSTI)

    Guzowski, R.V.; Nimick, F.B.; Muller, A.B.

    1982-03-01

    Discussion of the regional setting, geology, hydrology, and geochemistry of the Pasco Basin are included in this report. Pasco basin is a structural and topographic basin of approximately 2000 mi/sup 2/ (5180 km/sup 2/) located within the Yakima Fold Belt Subprovince of the Columbia Plateau. The stratigraphic sequence within the basin consists of an undetermined thickness of lower Miocene and younger flood basalts with interbedded and overlying sedimentary units. This sequence rests upon a basement of probably diverse rock types that may range in age from precambrian through early Tertiary. Although a large amount of information is available on the hydrology of the unconfined aquifer system, ground-water flow within the basin is, in general, poorly understood. Recharge areas for the Mabton interbed and the Saddle Mountains Formation are the highlands surrounding the basin with the flow for these units toward Gable Butte - Gable Mountain and Lake Wallula. Gable Butte - Gable Mountain probably is a ground-water sink, although the vertical flow direction in this zone is uncertain. The amount of upward vertical leakage from the Saddle Mountains Formation into the overlying sediments or to the Columbia River is unknown. Units underlying the Mabton interbed may have a flow scheme similar to those higher units or a flow scheme dominated by interbasin flow. Upward vertical leakage either throughout the basin, dominantly to the Columbia River, or dominantly to Lake Wallula has been proposed for the discharge of the lower units. None of these proposals is verified. The lateral and vertical distribution of major and minor ions in solution, Eh and pH, and ion exchange between basalt and ground-water are not well defined for the basin. Changes in the redox potential from the level of the subsurface facility to the higher stratigraphic levels along with the numerous other factors influencing K/sub d/, result in a poor understanding of the retardation process.

  10. K Basins Sludge Treatment Project Phase 1 | Department of Energy

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    Project Phase 1 K Basins Sludge Treatment Project Phase 1 Full Document and Summary Versions are available for download K Basins Sludge Treatment Project Phase 1 (2.34 MB) More Documents & Publications Compilation of TRA Summaries Independent Activity Report, Richland Operations Office - April 2011 Enterprise Assessments, Review of the Hanford Site Sludge Treatment Project Engineered Container Retrieval and Transfer System Preliminary Documented Safety Analysis, Revision 00 - April 201

  11. Geothermal regime and thermal history of the Llanos Basin, Columbia

    SciTech Connect (OSTI)

    Bachu, S.; Underschultz, J.R.; Ramon, J.C.; Villegas, M.E.

    1995-01-01

    The Llanos basin is a siliciclastic foreland sub-Andean sedimentary basin located in Columbia between the Cordillera Oriental and the Guyana Precambrian shield. Data on bottom-hole temperature, lithology, porosity, and vitrinite reflectance from all 318 wells drilled in the central and southern parts of the basin were used to analyze its geothermal regime and thermal history. Average geothermal gradients in the Llanos basin decrease generally with depth and westward toward the fold and thrust belt. The geothermal regime is controlled by a moderate, generally westward-decreasing basement heat flow, by depositional and compaction factors, and, in places, by advection by formation waters. Compaction leads to increased thermal conductivity with depth, whereas westward downdip flow in deep sandstone formations may exert a cooling effect in the central-western part of the basin. Vitrinite reflectance variation with depth shows a major discontinuity at the pre-Cretaceous unconformity. Areally, vitrinite reflectance increases southwestward in Paleozoic strata and northwestward in post-Paleozoic strata. These patterns indicate that the thermal history of the basin probably includes three thermal events that led to peaks in oil generation: a Paleozoic event in the southwest, a failed Cretaceous rifting event in the west, and an early Tertiary back-arc event in the west. Rapid cooling since the last thermal event is possibly caused by subhorizontal subduction of cold oceanic lithospheric plate.

  12. Undrilled New Ireland basin in Papua New Guinea

    SciTech Connect (OSTI)

    Exon, N.F.; Marlow, M.S.

    1986-07-01

    The arcuate, west-northwest-trending, mostly offshore New Ireland basin is 900 km long and about 160 km wide, and extends northeastward from Manus Island, New Hanover, and New Ireland. The basin formed in a forearc between a southerly Eocene to early Miocene volcanic arc, and a northerly outer-arc high bounding the Manus Trench. Its southern margin drops down to the back-arc Manus basin, which commenced spreading in the Pilocene. North of Manus Island, the New Ireland basin contains areas of deformed strata that have apparently been accreted to the Manus arc by south-dipping thrust faults. In places these strata are overlain by shallowly buried lava flows, which may represent attempted spreading. The sedimentary sequence in the eastern part of the basin is interpreted to contain thick Oligocene to early Miocene volcaniclastic sediments, overlain by 1000-2000 m of Miocene shelf carbonates, overlain by 2000 m of overburden. The presumed shelf carbonates could contain both source and reservoir rocks. The Lee line 401 revealed a flat, high-amplitude reflector or bright spot in an anticlinal core 1700 m beneath the seabed in water 2500 m deep off New Ireland, suggesting that hydrocarbons have been generated in New Ireland basin.

  13. Petroleum systems of Jianghan Basin, Hubel Province, China

    SciTech Connect (OSTI)

    Cunningham, A.E.; Schaps, S.; McGregor, D.

    1996-12-31

    The Jianghan Basin is a Cretaceous-Tertiary nonmarine rift basin superimposed on a late Precambrian to Jurassic passive margin and foreland basin succession deformed by mid-Mesozoic folding and thrusting. Hence the basin has potential for superimposed petroleum systems. Oil production is established in a Tertiary petroleum system developed in two major depocenters, the Jiangling (west) and Qianjiang (east) Depressions. Lacustrine source beds in the early Eocene Xingouzhui and late Eocene Qianjiang Formations generated hydrocarbons during local maximum basin fill in the Oligocene to present. Very early, low temperature generation of petroleum occurs where Type 1S Qianjiang Formation kerogen is present. Tertiary fluvial and deltaic sandstones form reservoirs that trap oil in highs or rollover structures formed by normal faulting and salt movement. The pre-rift section contains large folds and good source-beds, but has high exploration risk. Factors limiting effectiveness of older petroleum systems are: (1) Uplift and erosion of thrust structures; (2) Overmaturation of pre-Permian source rocks prior to folding and thrusting; (3) Limited extent of secondary maturation of Late Paleozoic and Mesozoic source beds; and (4) Disruption of older traps and seals by widespread normal faulting. Production of hydrocarbons from Permian and Triassic rocks to the west of Hubei suggests that further seismic work and drilling are merited to evaluate pre-Tertiary potential in the Jianghan Basin.

  14. Petroleum systems of Jianghan Basin, Hubel Province, China

    SciTech Connect (OSTI)

    Cunningham, A.E. ); Schaps, S.; McGregor, D. )

    1996-01-01

    The Jianghan Basin is a Cretaceous-Tertiary nonmarine rift basin superimposed on a late Precambrian to Jurassic passive margin and foreland basin succession deformed by mid-Mesozoic folding and thrusting. Hence the basin has potential for superimposed petroleum systems. Oil production is established in a Tertiary petroleum system developed in two major depocenters, the Jiangling (west) and Qianjiang (east) Depressions. Lacustrine source beds in the early Eocene Xingouzhui and late Eocene Qianjiang Formations generated hydrocarbons during local maximum basin fill in the Oligocene to present. Very early, low temperature generation of petroleum occurs where Type 1S Qianjiang Formation kerogen is present. Tertiary fluvial and deltaic sandstones form reservoirs that trap oil in highs or rollover structures formed by normal faulting and salt movement. The pre-rift section contains large folds and good source-beds, but has high exploration risk. Factors limiting effectiveness of older petroleum systems are: (1) Uplift and erosion of thrust structures; (2) Overmaturation of pre-Permian source rocks prior to folding and thrusting; (3) Limited extent of secondary maturation of Late Paleozoic and Mesozoic source beds; and (4) Disruption of older traps and seals by widespread normal faulting. Production of hydrocarbons from Permian and Triassic rocks to the west of Hubei suggests that further seismic work and drilling are merited to evaluate pre-Tertiary potential in the Jianghan Basin.

  15. Visayan Basin - the birthplace of Philippine petroleum exploration revisited

    SciTech Connect (OSTI)

    Rillera, F.G. ); Durkee, E.F. )

    1994-07-01

    Petroleum exploration in the Philippines has its roots in the Visayan Basin in the central Philippines. This is a Tertiary basin with up to 30,000 ft of sedimentary fill. With numerous surface oil and gas manifestations known as early as 1888, the area was the site of the first attempts to establish commercial petroleum production in the country. Over the past 100 years, more than 200 wells have been drilled in the basin. Several of these have yielded significant oil and gas shows. Production, albeit noncommercial in scale, has been demonstrated to be present in some places. A review of past exploration data reveals that many of the earlier efforts failed due to poorly located tests from both structural and stratigraphic standpoints. Poor drilling and completion technology and lack of funding compounded the problems of early explorationists. Because of this, the basin remains relatively underexplored. A recent assessment by COPLEX and E.F. Durkee and Associates demonstrates the presence of many untested prospects in the basin. These prospects may contain recoverable oil and gas potential on the order of 5 to 10 MMBO onshore and 25 to 100 MMBO offshore. With new exploration ideas, innovative development concepts, and the benefit of modern technology, commercial oil and gas production from the basin may yet be realized.

  16. Williston, Vermont: Energy Resources | Open Energy Information

    Open Energy Info (EERE)

    congressional district. 1 2 Registered Energy Companies in Williston, Vermont Phillips BioFuel Supply Co References US Census Bureau Incorporated place and minor civil...

  17. Basin Analysis of the Mississippi Interior Salt Basin and Petroleum System Modeling of the Jurassic Smackover Formation, Eastern Gulf Coastal Plain

    SciTech Connect (OSTI)

    Mancini, Ernest A.

    2003-02-06

    The project objectives are improving access to information for the Mississippi Interior Salt Basin by inventorying data files and records of the major information repositories in the region, making these inventories easily accessible in electronic format, increasing the amount of information available on domestic sedimentary basins through a comprehensive analysis of the Mississippi Interior Salt Basin, and enhancing the understanding of the petroleum systems operating in the Mississippi Interior Salt Basin.

  18. Selecting major Appalachian basin gas plays

    SciTech Connect (OSTI)

    Patchen, D.G.; Nuttall, B.C.; Baranoski, M.T.; Harper, J.A.; Schwietering, J.F.; Van Tyne, A.; Aminian, K.; Smosna, R.A.

    1992-01-01

    Under a cooperative agreement with the Morgantown Energy Technology Center (METC) the Appalachian Oil and Natural Gas Research Consortium (AONGRC) is preparing a geologic atlas of the major gas plays in the Appalachian basin, and compiling a database for all fields in each geologic play. the first obligation under this agreement was to prepare a topical report that identifies the major gas plays, briefly describes each play, and explains how the plays were selected. Four main objectives have been defined for this initial task: assign each gas reservoir to a geologic play, based on age, trap type, degree of structural control, and depositional environment; organize all plays into geologically-similar groups based on the main criteria that defines each play; prepare a topical report for METC; and transfer this technology to industry through posters and talks at regional geological and engineering meetings including the Appalachian Petroleum Geology Symposium, Northeastern Section meeting of the Geological Society of America, the METC Gas Contractors Review meeting, the Kentucky Oil and Gas Association, and the Appalachian Energy Group.

  19. Selecting major Appalachian basin gas plays

    SciTech Connect (OSTI)

    Patchen, D.G.; Nuttall, B.C.; Baranoski, M.T.; Harper, J.A.; Schwietering, J.F.; Van Tyne, A.; Aminian, K.; Smosna, R.A.

    1992-06-01

    Under a cooperative agreement with the Morgantown Energy Technology Center (METC) the Appalachian Oil and Natural Gas Research Consortium (AONGRC) is preparing a geologic atlas of the major gas plays in the Appalachian basin, and compiling a database for all fields in each geologic play. the first obligation under this agreement was to prepare a topical report that identifies the major gas plays, briefly describes each play, and explains how the plays were selected. Four main objectives have been defined for this initial task: assign each gas reservoir to a geologic play, based on age, trap type, degree of structural control, and depositional environment; organize all plays into geologically-similar groups based on the main criteria that defines each play; prepare a topical report for METC; and transfer this technology to industry through posters and talks at regional geological and engineering meetings including the Appalachian Petroleum Geology Symposium, Northeastern Section meeting of the Geological Society of America, the METC Gas Contractors Review meeting, the Kentucky Oil and Gas Association, and the Appalachian Energy Group.

  20. Greater Green River Basin Production Improvement Project

    SciTech Connect (OSTI)

    DeJarnett, B.B.; Lim, F.H.; Calogero, D.

    1997-10-01

    The Greater Green River Basin (GGRB) of Wyoming has produced abundant oil and gas out of multiple reservoirs for over 60 years, and large quantities of gas remain untapped in tight gas sandstone reservoirs. Even though GGRB production has been established in formations from the Paleozoic to the Tertiary, recent activity has focused on several Cretaceous reservoirs. Two of these formations, the Ahnond and the Frontier Formations, have been classified as tight sands and are prolific producers in the GGRB. The formations typically naturally fractured and have been exploited using conventional well technology. In most cases, hydraulic fracture treatments must be performed when completing these wells to to increase gas production rates to economic levels. The objectives of the GGRB production improvement project were to apply the concept of horizontal and directional drilling to the Second Frontier Formation on the western flank of the Rock Springs Uplift and to compare production improvements by drilling, completing, and testing vertical, horizontal and directionally-drilled wellbores at a common site.

  1. Understanding Long-Term Solute Transport in Sedimentary Basins: Simulating Brine Migration in the Alberta Basin. Final Report

    SciTech Connect (OSTI)

    Alicia M. Wilson

    2009-11-30

    Mass transport in deep sedimentary basins places important controls on ore formation, petroleum migration, CO2 sequestration, and geochemical reactions that affect petroleum reservoir quality, but large-scale transport in this type of setting remains poorly understood. This lack of knowledge is highlighted in the resource-rich Alberta Basin, where geochemical and hydrogeologic studies have suggested residence times ranging from hundreds of millions of years to less than 5 My, respectively. Here we developed new hydrogeologic models that were constrained by geochemical observations to reconcile these two very different estimates. The models account for variable-density fluid flow, heat transport, solute transport, sediment deposition and erosion, sediment compressibility, and dissolution of salt deposits, including Cl/Br systematics. Prior interpretations of Cl/Br ratios in the Alberta Basin concluded that the brines were derived from evaporatively-concentrated brines that were subsequently diluted by seawater and freshwater; models presented here show that halite dissolution must have contributed strongly as well, which implies significantly greater rates of mass transport. This result confirms that Cl/Br ratios are subject to significant non-uniqueness and thus do not provide good independent indicators of the origin of brines. Salinity and Cl/Br ratios provided valuable new constraints for basin-scale models, however. Sensitivity studies revealed that permeabilities obtained from core- and field-scale tests were appropriate for basin-scale models, despite the differences in scale between the tests and the models. Simulations of groundwater age show that the residence time of porefluids in much of the basin is less than 100 My. Groundwater age increases with depth and approaches 200 My in the deepest part of the basin, but brines are significantly younger than their host rocks throughout the basin.

  2. Potiguar basin: geologic model and habitat of oil of a Brazilian equatorial basin

    SciTech Connect (OSTI)

    Falkenhein, F.U.; Barros, R.M.; Da Costa, I.G.; Cainelli, C.

    1984-04-01

    The Potiguar basin integrates the eastern part of the Brazilian equatorial Atlantic-type margin. The rifting stage of this basin occurred during the Neocomian and Aptian. The drifting stage and sea-floor spreading began in the Late Albian. The rifting stage clearly was intracratonic during the Neocomian and is recognized as a mosaic of half-grabens trending mostly northeast-southwest and filled with syntectonic lacustrine siliciclastics. The half-graben pattern exhibits rotation of beds into the major fault zone, and the preserved uplifted margins display either paleostructures of paleogeomorphic features with hydrocarbons. A regional pre-Aptian unconformity preceded the Aptian proto-oceanic rifting stage which was characterized by syntectonic fluvio-deltaic sediments. The Aptian tectonics were represented by reactivation of former lineaments superimposed by predominant east-west normal faulting. Structural highs during this stage are so far the most prolific oil accumulations. The most important source beds and reservoir rocks are both Neocomian and Aptian sediments. Geochemistry and hydrodynamics have shown that hydrocarbon migration was driven through fracture or fault zones in both Aptian or Albian plays. Lithofacies maps support this interpretation because pools occur whenever adjacent downthrown blocks present a high shale content.

  3. Reserve estimates in western basins: Unita Basin. Final report, Part III

    SciTech Connect (OSTI)

    1995-10-01

    This study characterizes an extremely large gas resource located in low permeability, sandstone reservoirs of the Mesaverde group and Wasatch formation in the Uinta Basin, Utah. Total in-place resource is estimated at 395.5 Tcf. Via application of geologic, engineering and economic criteria, the portion of this resource potentially recoverable as reserves is estimated. Those volumes estimated include probable, possible and potential categories and total 3.8 Tcf as a mean estimate of recoverable gas for all plays considered in the basin. Two plays were included in this study and each was separately analyzed in terms of its tight gas resource, established productive characteristics and future reserves potential based on a constant $2/Mcf wellhead gas price scenario. A scheme has been developed to break the overall resource estimate down into components that can be considered as differing technical and economic challenges that must be overcome in order to exploit such resources; in other words, to convert those resources to economically recoverable reserves. About 82.1% of the total evaluated resource is contained within sandstones that have extremely poor reservoir properties with permeabilities considered too low for commerciality using current frac technology.

  4. Petroleum geology of Giant oil and gas fields in Turpan Basin Xinjiang China

    SciTech Connect (OSTI)

    Boliang, Hu; Jiajing, Yang,

    1995-08-01

    Turpan Basin is the smallest and the last development basin in three big basins of Xinjiang autonomous region, P.R. China. Since April, 1989, the Shanshan oilfield was discovered, the Oinling, Wenjisang, Midang, Baka, Qiudong and North Putaogou fields were discovered. In 1994, the crude oil productivity of Turpan Basin was a Million tons, with an estimated output of 3 million tons per year by 1995; obviously a key oil productive base in the west basins of China, Tarim, Jungar, Chaidam, Hexi, Erduos and Sichuan Basins. The Turpan Basin is an intermontane basin in a eugeosyncline foldbelt of the north Tianshan Mountains. The oil and gas was produced from the payzone of the Xishanyao, Sanjianfang and Qiketai Formatiosn of the Middle Jurassic series. The geochemical characteristics of the crude oil and gas indicate they derive from the Middle to Lower Jurassic coal series, in which contains the best oil-prone source rocks in the basin.

  5. South Atlantic sag basins: new petroleum system components

    SciTech Connect (OSTI)

    Henry, S.G. Mohriak, W.U.; Mello, M.R.

    1996-08-01

    Newly discovered pre-salt source rocks, reservoirs and seals need to be included as components to the petroleum systems of both sides of the South Atlantic. These new components lie between the pre-salt rift strata and the Aptian salt layers, forming large, post-rift, thermal subsidence sag basins. These are differentiated from the older rift basins by the lack of syn-rift faulting and a reflector geometry that is parallel to the base salt regional unconformity rather than to the Precambrian basement. These basins are observed in deep water regions overlying areas where both the mantle and the crust have been involved in the extension. This mantle involvement creates post-rift subsiding depocenters in which deposition is continuous while proximal rift-phase troughs with little or no mantle involvement are bypassed and failed to accumulate potential source rocks during anoxic times. These features have been recognized in both West African Kwanza Basin and in the East Brasil Rift systems. The pre-salt source rocks that are in the West African sag basins were deposited in lacustrine brackish to saline water environment and are geochemically distinct from the older, syn-rift fresh to brackish water lakes, as well as from younger, post-salt marine anoxic environments of the drift phase. Geochemical analyses of the source rocks and their oils have shown a developing source rock system evolving from isolated deep rift lakes to shallow saline lakes, and culminating with the infill of the sag basin by large saline lakes to a marginally marine restricted gulf. Sag basin source rocks may be important in the South Atlantic petroleum system by charging deep-water prospects where syn-rift source rocks are overmature and the post-salt sequences are immature.

  6. Tectonic evolution of Brazilian equatorial continental margin basins

    SciTech Connect (OSTI)

    Azevedo, R.P. )

    1993-02-01

    The structural style and stratigraphic relationships of sedimentary basins along the Brazilian Equatorial Atlantic Continental Margin were used to construct an empirical tectonic model for the development of ancient transform margins. The model is constrained by detailed structural and subsidence analyses of several basins along the margin. The structural framework of the basins was defined at shallow and deep levels by the integration of many geophysical and geological data sets. The Barreirinhas and Para-Maranhao Basins were divided in three tectonic domains: the Tutoia, Caete, and Tromai subbasins. The Caete area is characterized by northwest-southeast striking and northeast-dipping normal faults. A pure shear mechanism of basin formation is suggested for its development. The structure of the Tutoia and Tromai subbasins are more complex and indicative of a major strike-slip component with dextral sense of displacement, during early stages of basin evolution. These two later subbasins were developed on a lithosphere characterized by an abrupt transition (<50 km wide) from an unstretched continent to an oceanic lithosphere. The subsidence history of these basins do not comply with the classical models developed for passive margins or continental rifting. The thermo-mechanical model proposed for the Brazilian equatorial margin includes heterogeneous stretching combined with shearing at the plate margin. The tectonic history comprises: (1) Triassic-Jurassic limited extension associated with the Central Atlantic evolution; (2) Neocomian intraplate deformation consisting of strike-slip reactivation of preexisting shear zones; (3) Aptian-Cenomanian two-phase period of dextral shearing; and (4) Late Cretaceous-Cenozoic sea-floor spreading.

  7. Spatial design principles for sustainable hydropower development in river basins

    SciTech Connect (OSTI)

    Jager, Henriëtte I.; Efroymson, Rebecca A.; Opperman, Jeff J.; Kelly, Michael R.

    2015-02-27

    How can dams be arranged within a river basin such that they benefit society? Recent interest in this question has grown in response to the worldwide trend toward developing hydropower as a source of renewable energy in Asia and South America, and the movement toward removing unnecessary dams in the US. Environmental and energy sustainability are important practical concerns, and yet river development has rarely been planned with the goal of providing society with a portfolio of ecosystem services into the future. We organized a review and synthesis of the growing research in sustainable river basin design around four spatial decisions: Is it better to build fewer mainstem dams or more tributary dams? Should dams be clustered or distributed among distant subbasins? Where should dams be placed along a river? At what spatial scale should decisions be made? We came up with the following design principles for increasing ecological sustainability: (i) concentrate dams within a subset of tributary watersheds and avoid downstream mainstems of rivers, (ii) disperse freshwater reserves among the remaining tributary catchments, (iii) ensure that habitat provided between dams will support reproduction and retain offspring, and (iv) formulate spatial decision problems at the scale of large river basins. Based on our review, we discuss trade-offs between hydropower and ecological objectives when planning river basin development. We hope that future testing and refinement of principles extracted from our review will define a path toward sustainable river basin design.

  8. Spatial design principles for sustainable hydropower development in river basins

    DOE Public Access Gateway for Energy & Science Beta (PAGES Beta)

    Jager, Henriëtte I.; Efroymson, Rebecca A.; Opperman, Jeff J.; Kelly, Michael R.

    2015-02-27

    How can dams be arranged within a river basin such that they benefit society? Recent interest in this question has grown in response to the worldwide trend toward developing hydropower as a source of renewable energy in Asia and South America, and the movement toward removing unnecessary dams in the US. Environmental and energy sustainability are important practical concerns, and yet river development has rarely been planned with the goal of providing society with a portfolio of ecosystem services into the future. We organized a review and synthesis of the growing research in sustainable river basin design around four spatialmore » decisions: Is it better to build fewer mainstem dams or more tributary dams? Should dams be clustered or distributed among distant subbasins? Where should dams be placed along a river? At what spatial scale should decisions be made? We came up with the following design principles for increasing ecological sustainability: (i) concentrate dams within a subset of tributary watersheds and avoid downstream mainstems of rivers, (ii) disperse freshwater reserves among the remaining tributary catchments, (iii) ensure that habitat provided between dams will support reproduction and retain offspring, and (iv) formulate spatial decision problems at the scale of large river basins. Based on our review, we discuss trade-offs between hydropower and ecological objectives when planning river basin development. We hope that future testing and refinement of principles extracted from our review will define a path toward sustainable river basin design.« less

  9. Grande Ronde Basin Supplementation Program; Lostine River, 2000 Annual Report.

    SciTech Connect (OSTI)

    Onjukka, Sam T.; Harbeck, Jim

    2003-03-01

    The Northwest Power Planning Council (NPPC) identified supplementation as a high priority to achieve its goal of increasing runs of anadromous fish in the Columbia Basin. Supplementation activities in the Lostine River and associated monitoring and evaluation conducted by the Nez Perce Tribe relate directly to the needs addressed in the Columbia River Basin Fish and Wildlife Program (NPPC 1994). Measure 7.4L.1 of the Program mandates that appropriate research accompany any proposed supplementation. In addition, measure 7.3B.2 of the Program stresses the need for evaluating supplementation projects to assess their ability to increase production. Finally, Section 7.4D.3 encourages the study of hatchery rearing and release strategies to improve survival and adaptation of cultured fish. In 1997, Oregon Department of Fisheries and Wildlife (ODFW) requested a modification of Permit 1011 to allow the take of adult spring chinook salmon. In 1998, the Nez Perce Tribe also requested a permit specific to activities on Lostine River. The permit was issued in 2000. A special condition in the permits required the development of a long term management plan for the spring chinook salmon of the Grande Ronde Basin. The Nez Perce Tribe, ODFW, and the Confederated Tribes of the Umatilla Indian Reservation (CTUIR) completed a formal long range plan entitled ''Grande Ronde Basin Endemic Spring Chinook Salmon Supplementation Program''. The program proposes to increase the survival of spring chinook salmon in the Grand Ronde Basin through hatchery intervention. Adult salmon from the Lostine River, Catherine Creek, and the Upper Grande Ronde River are used for a conventional supplementation program in the basin. The Nez Perce program currently operates under the ESA Section 10 Permit 1149.

  10. Grande Ronde Basin Supplementation Program; Lostine River, 2001 Annual Report.

    SciTech Connect (OSTI)

    Onjukka, Sam T.; Harbeck, Jim

    2003-03-01

    The Northwest Power Planning Council (NPPC) identified supplementation as a high priority to achieve its goal of increasing runs of anadromous fish in the Columbia Basin. Supplementation activities in the Lostine River and associated monitoring and evaluation conducted by the Nez Perce Tribe relate directly to the needs addressed in the Columbia River Basin Fish and Wildlife Program (NPPC 1994). Measure 7.4L.1 of the Program mandates that appropriate research accompany any proposed supplementation. In addition, measure 7.3B.2 of the Program stresses the need for evaluating supplementation projects to assess their ability to increase production. Finally, Section 7.4D.3 encourages the study of hatchery rearing and release strategies to improve survival and adaptation of cultured fish. In 1997, Oregon Department of Fisheries and Wildlife (ODFW) requested a modification of Permit 1011 to allow the take of adult spring chinook salmon. In 1998, the Nez Perce Tribe also requested a permit specific to activities on Lostine River. The permit was issued in 2000. A special condition in the permits required the development of a long term management plan for the spring chinook salmon of the Grande Ronde Basin. The Nez Perce Tribe, ODFW, and the Confederated Tribes of the Umatilla Indian Reservation (CTUIR) completed a formal long range plan entitled ''Grande Ronde Basin Endemic Spring Chinook Salmon Supplementation Program''. The program proposes to increase the survival of spring chinook salmon in the Grand Ronde Basin through hatchery intervention. Adult salmon from the Lostine River, Catherine Creek, and the Upper Grande Ronde River are used for a conventional supplementation program in the basin. The Nez Perce program currently operates under the ESA Section 10 Permit 1149.

  11. MCNP model for the many KE-Basin radiation sources

    SciTech Connect (OSTI)

    Rittmann, P.D.

    1997-05-21

    This document presents a model for the location and strength of radiation sources in the accessible areas of KE-Basin which agrees well with data taken on a regular grid in September of 1996. This modelling work was requested to support dose rate reduction efforts in KE-Basin. Anticipated fuel removal activities require lower dose rates to minimize annual dose to workers. With this model, the effects of component cleanup or removal can be estimated in advance to evaluate their effectiveness. In addition, the sources contributing most to the radiation fields in a given location can be identified and dealt with.

  12. Tularosa Basin Play Fairway: Weights of Evidence Models

    DOE Data Explorer [Office of Scientific and Technical Information (OSTI)]

    Adam Brandt

    2015-12-01

    These models are related to weights of evidence play fairway anlaysis of the Tularosa Basin, New Mexico and Texas. They were created through Spatial Data Modeler: ArcMAP 9.3 geoprocessing tools for spatial data modeling using weights of evidence, logistic regression, fuzzy logic and neural networks. It used to identify high values for potential geothermal plays and low values. The results are relative not only within the Tularosa Basin, but also throughout New Mexico, Utah, Nevada, and other places where high to moderate enthalpy geothermal systems are present (training sites).

  13. What happened in the Permian basin in the 1980s

    SciTech Connect (OSTI)

    Lewis, C.J. )

    1992-04-01

    Using an established and well-recognized database of significant oil and gas fields, changes in exploration patterns are tracked on a play basis through the 1980s and compared to those of previous decades. The Permian basin is here considered to contain a total of 71 producing trends (plays) and approximately 1500 significant oil and gas fields (with reserves over 1 million bbl of oil equivalent). Changes in the field characteristics that are examined include discovery and growth rates, trap type, field size, dominant formations and lithologies, reservoir type, and depth to production. Significant conclusions may help direct future exploration strategy in the basin.

  14. Shale Gas Development in the Susquehanna River Basin

    U.S. Energy Information Administration (EIA) Indexed Site

    Water Resource Challenges From Energy Production Major Types of Power Generation in SRB - Total 15,300 Megawatts - 37.5% 4.0% 12.0% 15.5% 31.0% Nuclear Coal Natural Gas Hydroelectric Other Marcellus Shale Gas Development in the Susquehanna River Basin The Basin: * 27,510-square-mile watershed * Comprises 43 percent of the Chesapeake Bay watershed * 4.2 million population * 60 percent forested * 32,000+ miles of waterways The Susquehanna River: * 444 miles, largest tributary to the Chesapeake Bay

  15. ,"Calif--Los Angeles Basin Onshore Crude Oil Reserves in Nonproducing...

    U.S. Energy Information Administration (EIA) Indexed Site

    Data for" ,"Data 1","Calif--Los Angeles Basin Onshore Crude Oil Reserves in ... PM" "Back to Contents","Data 1: Calif--Los Angeles Basin Onshore Crude Oil Reserves in ...

  16. Heat flow in the northern Basin and Range province | Open Energy...

    Open Energy Info (EERE)

    to: navigation, search OpenEI Reference LibraryAdd to library Journal Article: Heat flow in the northern Basin and Range province Abstract The heat flow in the Basin and Range...

  17. Functions and requirements for 105-KE Basin sludge retrieval and packaging

    SciTech Connect (OSTI)

    Feigenbutz, L.V.

    1994-12-16

    Sludge, and the clouding due to sludge, interferes with basin operation and maintenance activities. This document defines the overall functions and requirements for sludge retrieval and packaging activities to be performed in the 105-KE Basin.

  18. Savannah River Site - D-Area Oil Seepage Basin | Department of...

    Energy Savers [EERE]

    - D-Area Oil Seepage Basin Savannah River Site - D-Area Oil Seepage Basin January 1, 2014 ... InstallationName, State: Savannah River Site, SC Responsible DOE Office: Savannah River ...

  19. BASIN VER DE GREAT ER ANETH BU G BAR KER DOME HOR SESH OE UTE...

    U.S. Energy Information Administration (EIA) Indexed Site

    Unnamed fields and fields generically named "wildcat" were renamed to a concatenate of their basin and state of occurrence, e.g. UPUT (Uinta-Piceance Basin and Utah). Map created ...

  20. Audit of the Western Area Power Administration's Contract with Basin Electric Power Cooperative, IG-0409

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    June 25, 1997 MEMORANDUM FOR THE SECRETARY FROM: John C. Layton Inspector General SUBJECT: INFORMATION: Report on "Audit of the Western Area Power Administration's Contract with Basin Electric Power Cooperative" BACKGROUND: At the request of the Western Area Power Administration (Western), we conducted an audit of charges to Western made by Basin Electric Power Cooperative (Basin), under Contract No. DE- MP65-82WP-19001. The contract for Westernms purchase of electric power from Basin

  1. K Basins Groundwater Monitoring Task, Spent Nuclear Fuels Project: Report for April, May, and June 2006

    SciTech Connect (OSTI)

    Peterson, Robert E.

    2006-08-30

    This report provides a summary of groundwater monitoring at the K Basins during April, May, and June 2006

  2. Gas/liquid sampler for closed canisters in KW Basin - test report

    SciTech Connect (OSTI)

    Pitkoff, C.C.

    1995-01-23

    Test report for the gas/liquid sampler designed and developed for sampling closed canisters in the KW Basin.

  3. Independent Oversight Review, Hanford K Basin and Cold Vacuum Drying Facility- August 2012

    Broader source: Energy.gov [DOE]

    Review of Hanford K Basin and Cold Vacuum Drying Facility Found Fuel Multi-Canister Overpack Operations

  4. The petroleum geologic characteristics of Sichuan basin, central China

    SciTech Connect (OSTI)

    Sheng, Li De )

    1991-03-01

    Sichuan basin is the main gas producer of China. It covers an area of 230,000 km{sup 2}. The evolution of this basin since Meso-Cenozoic was influenced by both trans-Eurasia Tethys tectonism from the west and the circum-Pacific tectonism from the east. So it has dual characteristics, compressional and tensional. The northward-moving Indian Plate resulted in a series of thrust fault zones along the Longmenshan western margin of Sichuan basin. Jurassic oil pools and Triassic, Permian, Carboniferous, and Sinian gas pools are present, where a series of box-like anticlines, comblike anticlines, and gentle slope dome anticlines, and gentle slope dome anticline, carbonate reef buildups are the main trap types. Significant role of fractures and caves of carbonate reservoir formations in Sichuan basin affects the production capacity of gas/oil wells and abundances of gas/oil reserves. Three-dimensional seismic methods are used to predict the unconformities and the paleokarst and fracture zones. Acidizing treatments were used for well completions.

  5. Peru onshore-deepwater basins should have large potential

    SciTech Connect (OSTI)

    Zuniga-Rivero, F.; Keeling, J.A.; Hay-Roe, H.

    1998-10-19

    Perupetro`s recent announcement that 13 offshore exploration blocks of nearly 1 million acres each will be offered for bids in the fourth quarter of 1998 has reawakened interest in this extensive, largely unexplored area. The new government policy, combined with the results of modern, deep-probing seismic surveys, has already led to a stepped-up search for oil and gas that will probably escalate. Most of Peru`s ten coastal basins are entirely offshore, but at both ends of the 1,500-mile coastline the sedimentary basins stretch from onshore across the continental shelf and down the continental slope. Two of these basin areas, both in the north, have commercial production. The third, straddling the country`s southern border, has never been drilled either on land or offshore. The Peruvian sectors of these three basins total roughly 50,000 sq miles in area, 75% offshore. All have major oil and gas potential. They are described individually in this article, an update in the ongoing studies last reported at the 1998 Offshore Technology Conference and in the first article of this series.

  6. Geothermal resources of the Southern Powder River Basin, Wyoming

    SciTech Connect (OSTI)

    Heasler, H.P.; Buelow, K.L.; Hinckley, B.S.

    1985-06-13

    This report describes the geothermal resources of the Southern Powder River Basin. The report contains a discussion of the hydrology as it relates to the movement of heated water, a description and interpretation of the thermal regime, and four maps: a generalized geological map, a structure contour map, a thermal gradient contour map, and a ground water temperature map. 10 figs. (ACR)

  7. Geological model for oil gravity variations in Oriente Basin, Ecuador

    SciTech Connect (OSTI)

    Dashwood, M.F.; Abbotts, I.L.

    1988-01-01

    The Oriente basin is one of the major productive Subandean basins. Most of the fields produce 29/sup 0/-33/sup 0/ API paraffinic oils, but oils have been discovered with gravities ranging from 10/sup 0/to 35/sup 0/ API. All the oils have been recovered from multiple middle to Late Cretaceous sandstone reservoirs (Hollin and Napo Formations). Wells display a variety of oil gravities by reservoir. The origin of the Oriente oils is problematical and controversial, but structural, geochemical, and well evidence suggest a vast oil kitchen west of the present Andean foothills that was mature for oil generation by at least early Tertiary. Oil analyses indicate a single family of oils is present. Oil gravity variations can be explained systematically in terms of the various alteration processes suffered by the oil in each reservoir. Intermittent early Andean uplift (latest Cretaceous to Mid-Eocene) resulted in biodegradation and water-washing of oils, particularly in the uppermost Napo reservoirs. The main Andean orogeny (Pliocene) uplifted the Hollin reservoir to outcrop in the west, and tilted the basin down to the south. This movement resulted in water washing or flushing of the Hollin aquifer and a phase of northward remigration of oil. Late Andean structures postdated primary oil migration. Almost all structures displaying growth during the Late Cretaceous to early Eocene have been oil bearing, but some, particularly those located on the present-day basin flanks, were later severely biodegraded or breached.

  8. GAMA-LLNL Alpine Basin Special Study: Scope of Work

    SciTech Connect (OSTI)

    Singleton, M J; Visser, A; Esser, B K; Moran, J E

    2011-12-12

    For this task LLNL will examine the vulnerability of drinking water supplies in foothills and higher elevation areas to climate change impacts on recharge. Recharge locations and vulnerability will be determined through examination of groundwater ages and noble gas recharge temperatures in high elevation basins. LLNL will determine whether short residence times are common in one or more subalpine basin. LLNL will measure groundwater ages, recharge temperatures, hydrogen and oxygen isotopes, major anions and carbon isotope compositions on up to 60 samples from monitoring wells and production wells in these basins. In addition, a small number of carbon isotope analyses will be performed on surface water samples. The deliverable for this task will be a technical report that provides the measured data and an interpretation of the data from one or more subalpine basins. Data interpretation will: (1) Consider climate change impacts to recharge and its impact on water quality; (2) Determine primary recharge locations and their vulnerability to climate change; and (3) Delineate the most vulnerable areas and describe the likely impacts to recharge.

  9. New basins invigorate U.S. gas shales play

    SciTech Connect (OSTI)

    Reeves, S.R.; Kuuskraa, V.A.; Hill, D.G.

    1996-01-22

    While actually the first and oldest of unconventional gas plays, gas shales have lagged the other main unconventional gas resources--tight gas and coalbed methane--in production and proved reserves. Recently, however, with active drilling of the Antrim shales in Michigan and promising results from the Barnett shales of North Texas, this gas play is growing in importance. While once thought of as only an Appalachian basin Devonian-age Ohio shales play and the exclusive domain of regional independents, development of gas shales has expanded to new basins and has began to attract larger E and P firms. Companies such as Amoco, Chevron, and Shell in the Michigan basin and Mitchell Energy and Development and Anadarko Petroleum Corporation in the Fort Worth basin are aggressively pursuing this gas resource. This report, the third of a four part series assessing unconventional gas development in the US, examines the state of the gas shales industry following the 1992 expiration of the Sec. 29 Nonconventional Fuels Tax Credit. The main questions being addressed are first, to what extent are these gas sources viable without the tax credit, and second, what advances in understanding of these reservoirs and what progress in extraction technologies have changed the outlook for this large but complex gas resource?

  10. 488-D Ash Basin Vegetative Cover Treatibility Study

    SciTech Connect (OSTI)

    Barton, Christopher; Marx, Don; Blake, John; Adriano, Domy; Koo, Bon-Jun; Czapka, Stephen

    2003-01-01

    The 488-D Ash Basin is an unlined containment basin that received ash and coal reject material from the operation of a powerhouse at the USDOE's Savannah River Site, SC. They pyretic nature of the coal rejects has resulted in the formation of acidic drainage (AD), which has contributed to groundwater deterioration and threatens biota in down gradient wetlands. Establishment of a vegetative cover was examined as a remedial alternative for reducing AD generation within this system by enhanced utilization of rainwater and subsequent non-point source water pollution control. The low nutrient content, high acidity, and high salinity of the basin material, however, was deleterious to plant survivability. As such, studies to identify suitable plant species and potential adaptations, and pretreatment techniques in the form of amendments, tilling, and/or chemical stabilization were needed. A randomized block design consisting of three subsurface treatments (blocks) and five duplicated surface amendments (treatments) was developed. One hundred inoculated pine trees were planted on each plot. Herbaceous species were also planted on half of the plots in duplicated 1-m2 beds. After two growing seasons, deep ripping, subsurface amendments and surface covers were shown to be essential for the successful establishment of vegetation on the basin. This is the final report of the study.