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Geology topics

J. W. Schmoker

Publications and source records attributed to J. W. Schmoker.

At least 37 records · Page 2Linked to original sources
USGS1996

Gas in the Uinta Basin, Utah - Resources in continuous accumulations

Continuous-type gas plays can be envisioned as large areas within which the reservoir rock is everywhere charged with gas. As part of its 1995 National Assessment of oil and gas resources, the U.S. Geological Survey identified four continuous-type gas plays in the Uinta Basin. These occur in sandstone reservoirs of the lower Tertiary Wasatch Formation (two plays) and the underlying Upper Cretaceous Mesaverde Group (two plays). Only the play representing the eastern part of the Wasatch Formation continuous accumulation (Natural Buttes area) has been the target of appreciable drilling activity to date. The volume of undiscovered gas estimated to be recoverable from these four plays using existing technology and development practices ranges between 3.7 trillion cubic feet of gas (TCFG) (95th fractile) and 11.9 TCFG (5th fractile), and averages 7.0 TCFG. However, these are geologically based resource estimates, made without direct reference to economic viability. Economic analysis indicates that only a fraction of this assessed resource could be economically found and produced at prices less than $2.00 per thousand cubic feet of gas (MCFG), based on costs that prevailed at the beginning of 1993. Production characteristics of continuous-type gas plays vary significantly from well to well. Difficulty in identifying locations with poor production characteristics in advance of drilling contributes to the unfavorable economics of some plays. The need exists for improvements in technology and geologic understanding that increase the chances of selectively drilling the more productive locations within a continuous-type play.

Mountain Geologist↗
USGS1996

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

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 mi2 (46,100 km2) 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 wellperformance 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.

Mountain Geologist↗
USGS1993

Sedimentology of Permian upper part of the Minnelusa Formation, eastern Powder River Basin, Wyoming, and a comparison to the subsurface

Describes dolomite, gypsum, and sandstone units deposited in transgressive-regressive cycles. Three depositional cycles are partly exposed. The cycles observed in outcrop were informally labelled cycle 1, cycle 2, and cycle 3 in ascending stratigraphic order. West Mellott field represents a subsurface example of the facies and facies relationships observed in outcrop. The eolian-dune sandstone of the C cycle, which was partially reworked by the transgression of the B cycle, produces oil at West Mellott. The draping of dolomite and anhydrite of the B cycle on the eolian-dune sandstone of the C cycle is analogous to the draping gypsum on dune sand in cycle 2 in outcrop. -from Authors

Mountain Geologist↗
USGS1991

Porosity trends of the Lower Cretaceous J Sandstone, Denver Basin, Colorado

This study examines relationships between porosity and time-temperature history, and the influence of rock properties upon porosity, for the Lower Cretaceous J Sandstone in the Colorado portion of the Denver basin. The J Sandstone is classified as a quartzarenite to litharenite and was deposited in nearshore-marine, deltaic, and fluvial-estuarine (valley-fill) settings. Principal elements of its paragenetic sequence include quartz cementation and pressure solution, carbonate cementation and dissolution, dissolution of feldspar and rock fragments, and formation of authigenic clays. Porosity versus vitrinite reflectance (R 0 ) regression lines of the form Phi = A(R 0 )Beta (where B is a negative number) depicting the 10th, 25th, 50th, 75th, and 90th porosity percentiles of the J Sandstone were derived from 963 core-plug measurements representing 31 wells. The data span a thermal maturity range of R 0 = 0.41%-1.14%. Porosity distributions at different locations within the basin can be estimated as a function of thermal maturity on the basis of these regression lines. Porosity trends of the J Sandstone, if considered as a function of R 0 , are similar to those of broad, composite data sets representing sandstones in general. The petrographic factors that most affect J Sandstone porosity variability at a given level of thermal maturity are carbonate cementation and clay content. Carbonate cement, where present, reduces porosity. If previously more widespread, carbonate cement could also introduce porosity heterogeneity by temporarily preserving the pore network relative to uncemented intervals. Abundant detrital and authigenic clay reduces porosity by occupying pores. Low clay content indirectly reduces porosity because the inhibiting effects of clay upon quartz cementation and pressure solution are largely absent.

Journal of Sedimentary Petrology↗
USGS1988

Sandstone porosity as a function of thermal maturity

Sandstone porosity decreases in the subsurface as a power function of thermal maturity: ϕ = A( M ) B , where ϕ is porosity and M is a measure of thermal maturity representing integrated time-temperature history; A and B are constants for a given sandstone of homogeneous properties but vary between data sets. The commonly observed exponential dependence of sandstone porosity upon depth follows as a special case from this power-function relation when temperature increases linearly with depth. The consideration of sandstone porosity in terms of time-temperature exposure offers advantages in the comparison of porosity data from diverse geologic settings, the recognition of unusual porosity within a sandstone sequence, and the prediction of porosity ahead of the drill and at times in the geologic past.

Geology↗
USGS1988

Facies composition calculated from the sonic, neutron, and density log suite, upper part of the Minnelusa Formation, Powder River basin, Wyoming

Sandstones and dolomites of the Permian upper part of the Minnelusa Formation are treated here as four-component systems consisting of fluid-filled pore space, quartz, dolomite, and anhydrite. Response equations of sonic, neutron, and density logs form a system of four simultaneous equations. With four equations and four unknowns, the composition of upper Minnelusa facies is defined by the three-log suite and can be calculated by solving a 4 ?? 4 matrix. Such calculations of facies composition help in establishing subsurface correlations and yield information on the diagenesis and physical character of upper Minnelusa sandstones and dolomites. Applications of composition calculations are illustrated by examples drawn from the area of the West Mellott field (T52N, R68W), where the upper Minnelusa is at depths of about 7000 ft (2100m). -from Authors

Mountain Geologist↗