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Collaborating Authors
Water is precious, and it is a factor in every aspect of oil production in the Permian Basin. It is used to produce the hydrocarbons, and it is produced with them. In the often-arid region of the Permian, finding a balance between water production and use can be a challenge. "Water demand is very high in the Permian because we've drilled a lot of wells and the water intensity per foot of lateral is high," said Bridget Scanlon, senior research scientist at the Jackson School of Geosciences at The University of Texas at Austin. Adding to the problem, she said, is that the primary source of water is groundwater, "which may be locally scarce."
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (24 more...)
Availability of Surface Water It is estimated that the water demands of an oil shale industry of about 1.5 million bbl/day as well as the water demands of the associated growth, could be satisfied from surface supplies without having to significantly reduce other existing or projected consumptive uses in the Upper Colorado River Basin (see fig. 1). This conclusion is premised, however, on four major qualifiers. First, surface water supplies can be made available for the development of oil shale only if:water not presently under contract is purchased from existing U.S. Bureau of Reclamation reservoirs; and/or new reservoir, pipeline, and pumping facilities are constructed in order to capture, store, and transport the water. For a 1.5 million bbl/day industry, a crude estimate of the capitalized cost of developing the necessary surface water supplies is $1 billion. This would be not more than 1 or 2 percent, if that much, of the capitalized costs of constructing and operating the oil shale facilities proper. Second, it must be recognized that the above conclusion takes into account only the projections of other consumptive uses. The increased depletions and hydrologic regulation attributable to water projects serving the oil shale industry could reduce the supply of instream recreational opportunities and the habitat available for various fish species from what they would otherwise be were there no oil shale industry. It is emphasized, however, that the existence and character of such impacts can vary substantially from one location to the next. Thus, investigations at a much greater level of detail than was possible in the study from which this paper is drawn will be necessary before any definitive conclusions can be reached. Third, the conclusion stated above takes into account only those institutional factors that are embodied in each State's water rights system and in the "Law of the River" (i.e., an international treaty, interstate compacts, U.S. Supreme Court decrees, and acts of Congress governing the operation of Colorado River reservoirs). It must be recognized that there are numerous other institutional factors, such as Federal environmental regulatory laws and programs, which may affect the timing, manner, and location of water resource developments in the Upper Basin even though they are not part of the traditional body of laws governing the use and allocation of water in and among the Upper Basin States. It is impossible to quantify the effect that these latter factors may have upon the availability of water for oil shale (or any other use for that matter). Nonetheless, it is apparent that they are part of the institutional framework within which future questions of water availability must be addressed. Fourth, and finally, the above conclusion must be qualified by the observation that the amount of oil shale development in any one Upper Basin State could be constrained by interstate compact considerations. This is because the Upper Colorado River Basin Compact allocates set percentages of the water available to the entire Upper Basin to each Upper Basin to each Upper Division State. Consequently, the level of oil shale development in any one State could be subject to limitations even though the overall size of the oil shale industry in the Upper Basin did not exceed 1.5 million bbl/day. Wyoming is the only State not likely to confront this situation given the probable siting of potential oil shale developments. Besides these four qualifications, the above conclusion is premised upon four major assumptions. The first of these assumptions concerns future runoff conditions. The conclusion assumes that the future average annual natural flow of the Colorado River at the compact point (Lee Ferry) will be 13.8 million acre-feet (maf). This was the estimated natural flow for the period 1930โ1974 (see fig. 2), which span of time also encompasses the most critical period of record (1931โ1974). The second major assumption concerns projections of depletions by non-oil shale uses.
- Geology > Rock Type > Sedimentary Rock > Organic-Rich Rock > Oil Shale (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.88)
- South America > Colombia > San Juan River Basin (0.99)
- North America > United States > Wyoming > Uinta Basin (0.99)
- North America > United States > Wyoming > Great Basin (0.99)
- (7 more...)
As Permian Basin production has grown, so too has the demand for fresh water, transport, and disposal of waste water. Bloomberg recently reported that the average Permian well pumps 7 barrels of dirty water for 1 bbl of oil and put the service cost of water disposal at about $1.50 to $2.50/bbl, driving operators to look for cost savings and improved efficiencies in the water management side of their business. The demand for water and disposal services has piqued the interest--and investments--of several companies eager to acquire existing pipeline infrastructure and SWD facilities and in some cases, expand the capacity to capitalize on the growing need. RRIG Water Solutions, a Fort Worth-based water transfer company, acquired a 475-mile pipeline located in the Eastern Delaware Basin from Oilfield Water Logistics. The pipeline has the potential to move more than 2.3 million bbl/d of fresh water for oil and gas operations located throughout the Permian Basin.
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (0.38)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (25 more...)
As Permian Basin production has grown, so too has the demand for fresh water, transport, and disposal of waste water. Bloomberg recently reported that the average Permian well pumps 7 barrels of dirty water for 1 bbl of oil and put the service cost of water disposal at about $1.50 to $2.50/bbl, driving operators to look for cost savings and improved efficiencies in the water management side of their business. The demand for water and disposal services has piqued the interest--and investments--of several companies eager to acquire existing pipeline infrastructure and SWD facilities and in some cases, expand the capacity to capitalize on the growing need. RRIG Water Solutions, a Fort Worth-based water transfer company, acquired a 475-mile pipeline located in the Eastern Delaware Basin from Oilfield Water Logistics. The pipeline has the potential to move more than 2.3 million bbl/d of fresh water for oil and gas operations located throughout the Permian Basin.
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (0.38)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (25 more...)
Abstract Recently there are practical concerns for the design of offshore basins since a new large offshore basin named "Deep Ocean Engineering Basin" is under construction by Korea Research Institute of Ships & Ocean Engineering (KRISO). It is known that this would be the world largest one at this time moment. In this paper, we present a number of design issues and modeling perspectives of offshore basin. The main focus is given to basin size and depth together with major facilities for modeling ocean environments such as wave, current, water depth and wind.