Browsing by Subject "exploration"
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Item Center of the periphery(2009-05) Thrond, Matthew Dale; Levack, Brian P.; Kamil, Neil, 1954-Print culture was a fundamental site in which new ideas about England’s role in world affairs were debated in the latter half of the sixteenth century. Print changed the ways in which new discoveries, proposals, grievances, and questions were assessed, and not always to the desired effect. In the face of the sphinx-like power of the press, a wide array of strategies emerged to control it. But people at many levels of the publishing process could use the rhetoric of the text, and of the printed book, to rearrange the relationships between authors and readers, to upset the thrust of a particular line of argument, to alter the aesthetic, moral, or pragmatic judgment a reader might exercise, or in a more subtle way to change the terms of the issue at hand. In view of the diversity of these possibilities, this report follows figures known to the London print world, some authors, some printers, and examines how they acted, reacted, and worked through, issues that arose from being on the cusp of England’s relationship with a wider world.Item Common risk segment mapping: Streamlining exploration for carbon storage sites, with application to coastal Texas and Louisiana(2021) Bump, Alexander P.; Hovorka, Susan D.; Meckel, Tim A.Large-scale deployment of Carbon Capture and Storage (CCS) will require a commensurately large number of sites. Efficient screening methods are needed to create investment assurance and focus efforts on the most promising sites. The problem is similar to petroleum exploration, for which there are well-developed (though seldom published) workflows, including Common Risk Segment (CRS) mapping. In brief, the process requires 1) defining the key play elements; 2) identifying candidate geologic intervals for each; 3) creating fact-based maps for those intervals; 4) determining minimum criteria for the success of each element; 5) reinterpreting the fact- based maps in terms of chance of success; and 6) combining the individual maps to form a composite, basin-scale view of prospectivity. In this paper, we adapt the CRS process to screening for CO2 storage sites. Critically, we redefine the process in terms of cost of characterization and development, rather than chance of success. For illustration, we apply the process to the example of the Lower Miocene on the Texas and Louisiana Gulf Coast. We show that the predictions are consistent with historic hydrocarbon production volumes and rates. The power of the CRS method is that it creates a systematic approach to geologic evaluation and translates complex, multidimensional analysis into clear, graphical and easily comprehended business inputs. The result highlights sweet spots and identifies critical risks, suggesting a focus for further data collection and analysis. The method developed here can be applied to both surface and subsurface factors anywhere that there is interest in geologic storage of CO2.Item Exploration and Production Program for Locating and Producing Prospective Aquifers Containing Solution Gas and Free Gas- Texas Gulf Coast(1983) Gregory, A. R. (Alvin Ray), 1915-; Lin, Zsay-Shing; Reed, Roneá S.This project was designed to locate and evaluate a prospective watered-out gas reservoir in the Texas Gulf Coast inland area. The prospective reservoir was to be suitable for application of enhanced gas recovery methods for producing the unconventional gas that remained in the reservoir after primary gas production ceased. A test well site would be located within a favorable prospect area. Previous work conducted by the Bureau of Economic Geology for the U.S. Department of Energy focused on the selection of test well sites in the Frio Formation and Wilcox Group of the Texas Gulf Coast. These studies were intended to make use of thermal energy, mechanical energy, and gas dissolved in formation waters by producing large volumes of hot water from deep, highly pressured formations. In this project, funded by the Gas Research Institute, interest shifted to locating prospective reservoirs containing significant quantities of free gas in addition to the gas dissolved in the water. Abandoned watered-out reservoirs and wet zones where large amounts of water must be produced to obtain the gas by co-production were identified. The present project, funded by the Gas Research Institute, shows their continuing interest in unconventional gas and in developing prospects that are favorable for co-production of gas and water from watered-out gas reservoirs. Guidelines used to screen gas fields along the Texas Gulf Coast resulted in the selection of the Port Arthur field, Jefferson County, Texas, as a suitable prospect for application of enhanced gas recovery methods. Several watered-out gas sandstones in this field have excellent reservoir characteristics. All 18 wells in the field have been plugged and abandoned by previous operators; hence, leasing problems should be simplified. Abundant shallow Miocene sands in the area are available for salt-water disposal. The "C" reservoir interval, located at an average depth of 11,130 ft, received the most extensive evaluation. Predicted gas recovery by natural flow is 5.1 billion standard cubic feet as reservoir pressure declines from 6,632 to 4,309 psig. A sample economic analysis showed a net present worth of $968,000 and a payout time of 3 years. This prospect has the potential to be economically profitable in addition to being a good research and development test for evaluating co-production techniques. It is recommended that a co-production well be drilled and tested on a site near the Meredith No. 2 Doornbos (Well 14).Item Geologic Analysis of Primary and Secondary Tight Gas Sand Objectives, Phase C(1984) Finley, Robert J.; Dutton, Shirley P.; Lin, Zsay-Shing; Saucier, A. E.; Baumgardner, Jr., Robert W.Previous assessments of blanket-geometry tight gas sandstones led to the selection of the Travis Peak Formation of the East Texas and North Louisiana Basins and the Corcoran and Cozzette Sandstones of the Piceance Creek Basin as major research objectives. The anticipated outcomes of this study include increased availability of tight gas resources and advancements in technology with high transferability. The work reported here encompasses all aspects of the depositional systems and reservoir geology of these units as fundamental components of resource characterization, with an emphasis on understanding controls on reservoir facies distribution and their relevance to low-permeability reservoir development. Six lithofacies of the Travis Peak (Hosston) Formation in East Texas and North Louisiana have been identified using electric logs. These facies comprise sand-rich fluvial-deltaic, silt-rich delta-front, clay- and carbonate-rich shelf, carbonate reef, and clay-rich open marine facies. The most well-developed facies in the East Texas area are the fluvial-deltaic and delta-front facies. Travis Peak rocks from the Clayton Williams #11 Sam Hughes well, Panola County, Texas, were primarily deposited in a fluvial environment within a coastal plain setting. Porosity and permeability control in the clean sandstones are primarily attributed to quartz overgrowths, chlorite cement, and solid organic matter, with approximately half of the remaining porosity being secondary, resulting from framework grain dissolution. Studies of Travis Peak gas production at Pinehill Southeast and Percy-Wheeler fields indicate an average permeability-thickness product of about 10 md-ft, with a range of 0.7 to 35 md-ft, indicating dry gas reservoirs. Well logs, core, and mud logs from Chapel Hill field in Smith County, Texas, were examined in preparation for a complete cooperative well program in the ARCO #11 Phillips well on the western margin of that field. Field studies of Corcoran-Cozzette Sandstones near Grand Junction, Colorado, suggest that the depositional environments of the Corcoran evolved from marine upper shoreface to non-marine, while the Cozzette sequence evolved from lower to upper shoreface. Porosity and water saturation calculations have been conducted by computer for seven Corcoran and Cozzette depositional units. A comparison of calculated water saturation with core-derived porosity and permeability indicates a fair to very good correlation of reservoir properties with clay content measured by gamma-ray log.Item Geologic Anaylsis of Primary and Secondary Tight Gas Sand Objectives Phase A&B(1983) Finley, Robert J.; Garrett, C. M., Jr.; Han, Jong H.Finley (1982) listed geologic and engineering characteristics of over 30 blanket-geometry tight gas sandstones in a survey of 16 sedimentary basins. Emphasis was placed on defining elastic depositional systems and on using constituent facies as a method of evaluating the common features of stratigraphic units of different ages in diverse sedimentary and structural settings. Blanket-geometry tight gas sandstones considered suitable for future research by the Gas Research Institute were found to occur primarily within deltaic and barrier-strandplain depositional systems. An assessment of expected transferability of research results (extrapolation potential) was made between stratigraphic units, and more detailed study of six formations was recommended. The Corcoran and Cozzette Sandstones of the Piceance Creek Basin and the Travis Peak Formation of the East Texas Basin and North Louisiana Salt Basin were recommended for research by the Gas Research Institute on blanket-geometry tight gas sandstones, and initial studies of depositional systems were begun. The Corcoran and Cozzette represent the barrier-strandplain system and contain barrier, offshore bar, and associated marginal-marine facies. Detailed studies of the Corcoran-Cozzette in Shire Gulch and Plateau Fields show shoreface sequences common to the lower parts of both units, and bay-lagoon and deltaic facies occur in the upper parts. The Travis Peak Formation represents a deltaic system, having a lower subdivision of progradational deltaic facies, a thick middle subdivision of braided alluvial deposits, and an upper subdivision of marginal marine deposits influenced by marine transgression. Sands greater than 50 ft thick are prominent in the middle subdivision in areas on the west flank of the Sabine Uplift. The Frontier Formation and the upper Almond Formation of the Greater Green River Basin and the Olmos Formation of the Maverick Basin are not recommended for further research, but should be considered when the need arises to test barrier, offshore bar, and possibly deltaic facies outside the two main research areas. The estimated gas resources associated with the Corcoran-Cozzette and the Travis Peak in Texas are 3.7 and 17.3 Tcf respectively. The Mancos "B" of the Piceance Creek Basin is not recommended for any additional research because its unique distribution of lithologies limits its extrapolation to a small group of shelf deposits, some of which have already been investigated. The extrapolation potential of the Travis Peak is largely to itself over a wide area of East Texas and North Louisiana. Extrapolation potential of the Corcoran and Cozzette extends to a large number of stratigraphic units, mostly within the Upper Cretaceous of the Rocky Mountain Region.Item Geologic Challenges and Opportunites of the Cherokee Group Play (Pennsylvanian): Anadarko Basin, Oklahoma(1993) Hentz, Tucker F.The Middle Pennsylvanian Cherokee Group composes one of the most active natural gas plays in the Anadarko Basin of Oklahoma, having produced more than 1.2 Tcf from major (> 10 Bcf cumulative production) Cherokee reservoirs in Beckham, Custer, Roger Mills, and Washita Counties, the area currently experiencing the most active Cherokee development activity. Preliminary geologic study and telephone survey of 15 Cherokee operators satisfied three primary project objectives: (1) to summarize both the geologic characteristics of the Cherokee Group and the production highlights in the four-county area of current activity; (2) to summarize what current Cherokee producing companies perceive to be the primary geologic challenges they face in developing the Cherokee play; and (3) to suggest geologic strategies to help respond to these challenges. Geologic questions related to Cherokee gas-production enhancement are fundamental, and answers to these questions have the potential to alter current production strategies, reduce risk, and ultimately to increase natural gas reserves. Most of the surveyed Cherokee operators acknowledge that they have only a partial understanding of regional facies relations within the Cherokee depositional systems tracts. Moreover, there is no clear and integrated perspective of depositional systems, reservoir geometry, and diagenesis among all Cherokee fields in the play area. Reservoir geometry is complex and not readily predictable; therefore, drilling of infill wells, which characterizes the current development strategy of the Cherokee play, is fraught with uncertainty. The high degree of variation in porosity and permeability cannot be predicted from current knowledge of reservoir-quality patterns. A limited per-well drainage area suggests internal compartmentalization of sandstone reservoirs. Investigations at several scales can provide needed information. Improved and more precise modeling of (1) the regional spectra of Cherokee depositional settings at the play scale, (2) depositional facies and geometry at the field scale, and (3) facies architecture, diagenesis, and fracture distribution at the reservoir scale would aid the efficient exploitation of the remaining natural gas resources in the Cherokee play.Item Geothermal Potential along the Balcones/Ouachita Trend, Central Texas--Ongoing Assessment and Selected Case Studies(1984) Woodruff, Jr., C. M.; McPherson, G. L.; Gever, Christine; Caran, S. Christopher; El Shazly, Ahmed G.Numerous wells produce warm groundwater from several Cretaceous aquifers located beneath the innermost part of the Texas Gulf Coastal Plain. The changes in landscape between the Coastal Plain and the uplands farther west result from a major geologic break. Texas is bisected along this trend by the Texas Craton, a hinge zone that separates the downwarping Gulf Coast Basin from the more stable continental interior. At depth, this hinge is defined by the subsided Ouachita Mountains; at the surface, the geologic break is expressed by the Balcones and Luling-Mexia-Talco Fault Zones. The geologic hinge zone has clearly affected the physiography of the region. These effects include abrupt changes in terrain, climate, soils, vegetation, and availability of groundwater across the hinge. These changes have, in turn, influenced human settlement patterns (Bybee, 1952). The Balcones/Ouachita hinge is a geocultural break similar in cause and comparable in effect to the Fall Line of the Eastern United States (Woodruff, 1980). Both trends are the loci of cities. The towns and cities along the Balcones/Ouachita trend might use the thermal resources; at some localities, the warm water is already used although as drinking water and not generally for its energy content. Studies at the Bureau of Economic Geology have documented geothermal waters in many places across Texas (Henry, 1979; Henry and Gluck, 1981; Woodruff and others, 1982). Locally, these waters may be hotter or more abundant than along the Balcones/Ouachita trend, but considering both geologic and socioeconomic aspects, Central Texas is probably the region with the greatest potential for developing a cost-effective energy resource from low-temperature geothermal waters. The cities along the Balcones/Ouachita trend constitute a market for the geothermal energy resource.Item Hydrocarbon Production and Potential of the Distal Frio Formation, Texas Coastal Zone and Shelf(1987) Hamlin, H. ScottThe distal Frio Formation along the Texas Coastal Zone and offshore has yielded 680.85 million barrels of oil and 6.54 trillion ft3 of gas from 153 fields that range in size from 1 to 140 million barrels of oil equivalent. To evaluate the exploration potential of the distal Frio extending deep beneath the Federal Outer Continental Shelf, petroleum production data, regional reservoir-quality and temperature/pressure conditions, and characterization of typical fields were integrated with Galloway's (1986) description of stratigraphy, depositional systems, and structural framework. The most prospective locations for distal Frio exploration are in the Mustang Island and northeastern Galveston offshore areas, extending as far as 15 mi (24 km) seaward of the 3-league line (Outer Continental Shelf boundary). The North Padre Island offshore area has moderate exploration potential. Significant new discoveries will be deep (9,000 to 16,000 ft [2,740 to 4,880 m]), high-pressure, dry-gas-dominated reservoirs in thin, distal deltaic, strike-reworked delta-margin and distal shoreface/shelf sandstones that will potentially yield 1 to 100 billion ft3 of gas annually for as long as 10 years.Item Identifying Structural Variation in Haploid Microbial Genomes from Short-Read Resequencing Data Using Breseq(2014-11) Barrick, Jeffrey E.; Colburn, Geoffrey; Deatherage, Daniel E.; Traverse, Charles C.; Strand, Matthew D.; Borges, Jordan J.; Knoester, David B.; Reba, Aaron; Meyer, Austin G.; Barrick, Jeffrey E.; Colburn, Geoffrey; Deatherage, Daniel E.; Traverse, Charles C.; Strand, Matthew D.; Borges, Jordan J.; Reba, Aaron; Meyer, Austin G.Mutations that alter chromosomal structure play critical roles in evolution and disease, including in the origin of new lifestyles and pathogenic traits in microbes. Large-scale rearrangements in genomes are often mediated by recombination events involving new or existing copies of mobile genetic elements, recently duplicated genes, or other repetitive sequences. Most current software programs for predicting structural variation from short-read DNA resequencing data are intended primarily for use on human genomes. They typically disregard information in reads mapping to repeat sequences, and significant post-processing and manual examination of their output is often required to rule out false-positive predictions and precisely describe mutational events. Results: We have implemented an algorithm for identifying structural variation from DNA resequencing data as part of the breseq computational pipeline for predicting mutations in haploid microbial genomes. Our method evaluates the support for new sequence junctions present in a clonal sample from split-read alignments to a reference genome, including matches to repeat sequences. Then, it uses a statistical model of read coverage evenness to accept or reject these predictions. Finally, breseq combines predictions of new junctions and deleted chromosomal regions to output biologically relevant descriptions of mutations and their effects on genes. We demonstrate the performance of breseq on simulated Escherichia coli genomes with deletions generating unique breakpoint sequences, new insertions of mobile genetic elements, and deletions mediated by mobile elements. Then, we reanalyze data from an E. coli K-12 mutation accumulation evolution experiment in which structural variation was not previously identified. Transposon insertions and large-scale chromosomal changes detected by breseq account for similar to 25% of spontaneous mutations in this strain. In all cases, we find that breseq is able to reliably predict structural variation with modest read-depth coverage of the reference genome (>40-fold). Conclusions: Using breseq to predict structural variation should be useful for studies of microbial epidemiology, experimental evolution, synthetic biology, and genetics when a reference genome for a closely related strain is available. In these cases, breseq can discover mutations that may be responsible for important or unintended changes in genomes that might otherwise go undetected.Item Improved Resource Characterization Technology(1996) Laubach, Stephen E. (Stephen Ernest), 1955-ÂTo enhance the application of research results by industry, this report provides a guide to the results of research carried out by the Bureau of Economic Geology in the Geological Analysis of Primary and Secondary Tight Gas Sands Objectives Project as part of the Gas Research Institute (GRI) Tight Gas Sands Research Program in the period 1982-1995. The Gas Research Institute (GRI) has supported geological investigations designed to develop the knowledge necessary to produce gas from low-permeability sandstones efficiently. As part of that program, the Bureau of Economic Geology has conducted in-depth research on most of the important low-permeability sandstones in the lower 48. Another objective was to develop advanced technologies, verified in the field, which are necessary for continued cost-competitive production from low-permeability reservoirs. An extensive body of knowledge about many aspects of the geology and engineering attributes of low-permeability sandstones has been developed. We review some of the key findings of the geologic studies published in GRI topical reports and Bureau of Economic Geology monographs, refereed journal papers, contributions to other GRI reports, and papers and abstracts in meeting transaction volumes.Item Letter to A.C. Wright from H.B. Stenzel on 1952-07-21(1952-07-21) Stenzel, Henryk B.Item Letter to H.B. Stenzel from Bramlette McClelland on 1953-04-23(1953-04-23) McClelland, BramletteItem Letter to H.B. Stenzel from John T. Lonsdale on 1945-06-14(1945-06-14) Lonsdale, John T.Item Letter to H.B. Stenzel from R.E. McAdams on Undated(0000-00-00) McAdams, R.E.Item Letter to H.B. Stenzel from Raymond L. Artusy on 1958-10-14(1958-10-14) Artusy, Raymond L.Item Letter to Unknown from R.E. McAdams on 1959-06-09(1959-06-09) McAdams, R.E.Item Overview Of The SDSS-IV Manga Survey: Mapping Nearby Galaxies At Apache Point Observatory(2015-01) Bundy, Kevin; Bershady, Matthew A.; Law, David R.; Yan, Renbin; Drory, Niv; MacDonald, Nicholas; Wake, David A.; Cherinka, Brian; Sanchez-Gallego, Jose R.; Weijmans, Anne-Marie; Thomas, Daniel; Tremonti, Christy; Masters, Karen; Coccato, Lodovico; Diamond-Stanic, Aleksandar M.; Aragon-Salamanca, Alfonso; Avila-Reese, Vladimir; Badenes, Carles; Falcon-Barroso, Jesus; Belfiore, Francesco; Bizyaev, Dmitry; Blanc, Guillermo A.; Bland-Hawthorn, Joss; Blanton, Michael R.; Brownstein, Joel R.; Byler, Nell; Cappellari, Michele; Conroy, Charlie; Dutton, Aaron A.; Emsellem, Eric; Etherington, James; Frinchaboy, Peter M.; Fu, Hai; Gunn, James E.; Harding, Paul; Johnston, Evelyn J.; Kauffmann, Guinevere; Kinemuchi, Karen; Klaene, Mark A.; Knapen, Johan H.; Leauthaud, Alexie; Li, Cheng; Lin, Lihwai; Maiolino, Roberto; Malanushenko, Viktor; Malanushenko, Elena; Mao, Shude; Maraston, Claudia; McDermid, Richard M.; Merrifield, Michael R.; Nichol, Robert C.; Oravetz, Daniel; Pan, Kaike; Parejko, John K.; Sanchez, Sebastian F.; Schlegel, David; Simmons, Audrey; Steele, Oliver; Steinmetz, Matthias; Thanjavur, Karun; Thompson, Benjamin A.; Tinker, Jeremy L.; van den Bosch, Remco C. E.; Westfall, Kyle B.; Wilkinson, David; Wright, Shelley; Xiao, Ting; Zhang, Kai; Drory, NivWe present an overview of a new integral field spectroscopic survey called MaNGA (Mapping Nearby Galaxies at Apache Point Observatory), one of three core programs in the fourth-generation Sloan Digital Sky Survey (SDSS-IV) that began on 2014 July 1. MaNGA will investigate the internal kinematic structure and composition of gas and stars in an unprecedented sample of 10,000 nearby galaxies. We summarize essential characteristics of the instrument and survey design in the context of MaNGA's key science goals and present prototype observations to demonstrate MaNGA's scientific potential. MaNGA employs dithered observations with 17 fiber-bundle integral field units that vary in diameter from 12 '' (19 fibers) to 32 '' (127 fibers). Two dual-channel spectrographs provide simultaneous wavelength coverage over 3600-10300 angstrom at R similar to 2000. With a typical integration time of 3 hr, MaNGA reaches a target r-band signal-to-noise ratio of 4-8 (angstrom(-1) per 2 '' fiber) at 23 AB mag arcsec(-2), which is typical for the outskirts of MaNGA galaxies. Targets are selected with M* greater than or similar to 10(9) M-circle dot using SDSS-I redshifts and i-band luminosity to achieve uniform radial coverage in terms of the effective radius, an approximately flat distribution in stellar mass, and a sample spanning a wide range of environments. Analysis of our prototype observations demonstrates MaNGA's ability to probe gas ionization, shed light on recent star formation and quenching, enable dynamical modeling, decompose constituent components, and map the composition of stellar populations. MaNGA's spatially resolved spectra will enable an unprecedented study of the astrophysics of nearby galaxies in the coming 6 yr.Item Petroleum Potential in Texas State Submerged Lands, Frio and Lower Miocene Depositional Episodes(1987) Seni, Steven J.; Hamlin, H. Scott; Walter, T. G.The historical trend of annual oil and gas production from State submerged lands along the Texas Coastal Zone has been one of decline. However, this decline rate can be moderated, and production rates stabilized, through proper incentives, innovative exploration and development strategies, and enhanced recovery programs. In the 1980s, the rate of decline in Texas oil and gas production slowed down, with a maximum decline of 4.6 percent in the Texas Gulf area, following a relatively rapid decline in the 1970s (maximum 6.5 percent decline in the Texas Gulf area). Fisher and Finley (1986) outlined two main drilling strategies that helped arrest the rate of production decline and added to reserves: (1) infill drilling and field extension, and (2) new field wildcats. The majority of additional reserves came from infill and extension drilling, as well as new pool discoveries. Statistics from Fisher and Finley (1986) and Fisher (1987) illustrate that between 1973 and 1982, extension and infill drilling contributed more reserves (4.38 billion bbl) compared to new field discoveries (0.65 billion bbl), new pool discoveries (0.60 billion bbl), tertiary projects (0.25 billion bbl), and delayed abandonments (0.14 billion bbl). To maximize hydrocarbon recovery from State submerged lands, it is essential to improve recovery from known reservoirs and actively seek out small and moderate-sized new fields. By implementing secondary recovery techniques and gaining fresh insights through exploration efforts, significant new hydrocarbon resources can be discovered in State lands. This potential is supported by the historical productivity of the Frio trend in onshore State waters and the relative immaturity of the Frio and lower Miocene trends in State offshore waters.Item Potential for Petroleum Resources in the Palo Duro Basin Area, Texas Panhandle(1984) Ruppel, Stephen C.; Dutton, Shirley P.Investigations of the petroleum potential of the Palo Duro Basin have been underway since 1978. This report contains the results of studies carried out during the 1983-84 fiscal year, which have not yet been published. The section of this report dealing with pre-Pennsylvanian units in the basin represents the final results of work done on these rocks. Work is continuing on Pennsylvanian and younger strata as further data become available. The second part of this report presents additional data recently gathered on these units.Item Review of the Rose Run Sandstone Play of Ohio: Geological Framework and Exploration/Production Techniques, Challenges, and Opportunities - Topical Report (April 1993-June 1993)(1993) Burn, Mark J.The Upper Cambrian Rose Run sandstone of Ohio currently forms the most active exploratory hydrocarbon play in the Appalachian Basin. The Rose Run comprises a 125-ft-thick, interstratified siliciclastic/carbonate unit that was deposited in peritidal to shallow-subtidal marine environments. Deep-seated faults and folds influenced both Rose Run deposition and diagenesis. Rose Run reservoirs consist of sandstone bodies, 10 to 30 ft thick. Dolomite forms the predominant sandstone cement. The most important feature controlling the distribution of Rose Run reservoirs is the Knox unconformity. Remnants of Rose Run strata overlain by Beekmantown dolomite form the primary targets for exploration, and 2-D seismic data play a critical role in their identification. Other exploration techniques include mapping thickness variations of the shallower Packer Shell and Wells Creek intervals. Drilling depths for the play range from 3,200 to 7,000 ft, and drilling, completion, and pipeline hookup costs range from $200,000 to $300,000 per well. Average well-deliverability rates are 500 Mcf per day, and average cumulative production per well is estimated at 1 Bcf. Challenges facing Rose Run operators include seismic interpretation and successful completion and cement operations. Research opportunities include evaluating external reservoir geometry and intra-reservoir permeability variation.