No description available.

No description available.

The Mississippian Newman Limestone (0-30 m thick) in eastern Kentucky contains pink-staining, aquifer-related cements (up to 750 ppm Mn+2); up to 1000 ppm Fe+2; δ¹⁸ -7.5 to -6.8 per mil; δ¹³C 1.7 to -6.8) that is non-luminescent (low Fe and Mn) in the recharge area, but becomes uniformly dully luminescent downdip. This aquifer developed toward the end of Newman limestone deposition during two major regressions (Late Mississippian and Mississippian-Pennsylvanian time). Shallow burial cementation was less common to the south-east into the Appalachian Basin, where the Mississippian limestone is up to 1000 m thick. Here, phreatic meteoric diagenesis in more distal parts of the aquifer caused high-Mg calcite and aragonite grains to be leached, while isotopically light, fine dolomite (δ¹⁸O -1.7 to -6.7 per mil; δ¹³C 2.7 to -5.3 per mil) replaced muddy carbonates in a paleomixing zone. As the aquifer evolved, low-iron, dully luminescent calcite was precipitated from reducing pore waters. With increasing burial, compaction caused spalling of ooid cortices; iron rich saddle dolomite (δ¹⁸O -5.5 to -11.2 per mil; δ¹³C 0.9 to 1.4 per mil), and moderately ferroan (purple-staining) calcite cement (0-1200 ppm Mn2+; 1000-3000 ppm Fe2+; δ¹⁸O -4.6 to -10.6 per mil; δ¹³C 2.7 to -6 per mil) precipitated in pores and fractures from waters that were increasingly dominated by warm, basinal, oil-bearing fluids expelled from dewatering Paleozoic shales. These coarse dolomites overgrew early fine dolomite of reservoirs, while the purple staining calcite filled intercrystal porosity outside of the reservoirs. At or near deepest burial, Fe-rich (blue-staining) calcite (up to 1200 ppm Mn2+; 3000-7000 ppm Fe2+; δ¹⁸O -3. 8 to -7. 8 per mil; δ¹³C 1. 8 to -1. 5 per mil) precipitated in much of the remaining void space in the limestones. During uplift of the sequence late calcite cements with decreasing Fe contents were precipitated from increasingly oxidizing fluids that penetrated the section through fractures and remaining pore spaces. / M.S.

Typescript (photocopy). / Digitized by Kansas State University Libraries

The Waltersburg sandstone produces oil from isolated sand bodies and has produced nearly eight million barrels of oil from those of the Rochester, Mounts, and Fleener Fields. From the overlying "little Menard" Limestone to the Vienna Limestone below, the Waltersburg interval is most commonly 70 feet thick, but ranges from 14 feet in the north to 116 feet in the south. Increasing interval thickness is strongly correlated with increasing sand percentage. The maximum sand accumulation occurs in elongate sand bodies up to 100 feet thick,one-fourth to one mile wide, and two to five miles long. Elongate sand bodies are commonly oriented northeast-southwest, nearly perpendicular to strike. Sheet sand bodies are less than half as thick and usually produce only from small structural highs.Structure contour maps of the Vienna and "little Msnard" Limestones show that a 16 square mile plunging anticline bearing N30E exists along with other minor folds on a regional slope dipping about 40 feet per mile into the Illinois Basin. The structure of the "little Menard" may be associated with structural features of the Vienna, with isolated thick sand bodies or both where they occur together. Structural features of the "little Menard" that are not seen on the Vienna are usually attributed to differential compaction over sand bodies. The overall similarity in folding of both limestones suggests that deformation occurred after Waltersburg deposition as a result of differential compaction over older sediments combined with regional tilting as sediments subsided into the Illinois Basin.Oil production occurs in sands 10 to 60 feet thick that are structurally high. Structural elevation is therefore more important to production than sand thickness. Since most structural traps have been exploited, the most favorable locations for potential production are where thick elongate sands thin up-dip to form stratigraphic traps. Although a few locations for possible stratigraphic traps exist within the study area, extending exploration in recommended places may lead to more promising production outside the study area.On the basis of petrography, subsurface geometry, and log signatures of the Waltersburg sandstone, the depositional environment is suggested as being a fluvial dominated delta plain facies. The various types of thick elongate sand bodies are attributed to fluvial distributary channels. The interdistributary area is represented by mostly shale and silt, with crevasse-splay sands and possible minor mouth bar/crevasse-splay couplets.

The Elliot Oil Field lies in the northeast corner of Vanderburgh County, Indiana. Elliot Field produces from the Cypress Formation that is a sandstone reservoir.The West Baden Group is the lowermost group of the Chesterian Series of late Mississippian age in the Indiana portion of the Illinois Basin. The West Baden Group encompasses, in descending order: Cypress Formation, Reelsville Limestone, Sample Formation, Beaver Bend Limestone, and Bethel Formation.Within the study area, the West Baden Group was mapped with emphasis on the distribution of the sandstones and clarification and correlation of intervening limestone units. The West Baden has been mapped between the overlying Beech Creek Limestone and the underlying Renault Formation. Both upper and lower contacts of the West Baden appear to be sharp. The maps for this report show: structure on top and bottom of the West Baden, isopach of the West Baden, sandstone thickness and percentage in the West Baden and sandstone thickness in the Bethel, Sample and Cypress Formations.in the study area, the West Baden Group ranges from 180 to 235 feet in thickness. The irregularities in thickness of the West Baden result predominantly from variation in the percentage of sandstone. The regional dip of the West Baden beds is to the southwest at a rate of approximately 45 feet per mile. The top of the West Baden lies 1275 feet below sea level within the northeast portion of the study area.The Reelsville Limestone is absent within the study area and the Beaver Bend Limestone is only present in the northwest portion. The deposition of the Beaver Bend is most likely controlled by development of underlying sandstone of the Bethel Formation and by the amount of compaction. The presence of Beaver Bend in the northwest portion of the study area precludes the concept that only a single clastic cycle is represented during the West Baden interval.Sedimentation of the West Baden interval is dominated by the clastic dispersal system of the ancient Michigan River with a predominantly southwesterly trend. The lateral gradation of sandstone bodies into a marine section is evidence for the deltaic origin of West Baden deposits. The intervening limestone units of the West Baden interval can best be explained by the sporadic transgression and regression of a shallow epicontinental sea.Elliot Field has produced more than 640,000 barrels of oil, mostly within the last 30 years. The trapping mechanism is related to a point-bar sand with an updip permeability barrier provided by fine-grained prechannel deposits.

No description available.

The Wheatonvilie Consolidated Oil Field lies in Onion and Barton Townships of Gibson County, Indiana. Oil is produced from a sandstone reservoir commonly referred to the "Jackson Sand". The Jackson Sandstone is here informally adopted as member rank of Big Clifty Formation. The Stephen sport Group includes the Big Clifty and is Late Mississippian (Chesterian) in age.Within the area of the field, the Big Clifty Formation has been mapped between the underlying Beech Creek Limestone and the overlying Harvey Limestone. The lower contact of the Big Clifty appears to be sharp. The upper contact of the Big Clifty intergrades with at least one thin limestone tongue of Haney which pinches out laterally into the uppermost shales of the Big Clifty.The Big Clifty Formation includes sandstone, siltstone, shale, and mudstone with minor amounts of sandy limestone. A typical sequence from top to bottom includes:dark gray shale; thin red mudstone; gray shale; limey siltstone; very fine-grained white sandstone interbedded with gray shale; well sorted, fine-grained, white sandstone; and thin black shale. The percentage of sandstone within the Big Clifty Formation varies laterally significantly.The thickness of the Big Clifty Formation ranges from 64 feet to 97 feet. The formation dips to the southwest at a rate of approximately 29 feet per mile and lies 940 feet below the surface within the northeast portion of the study area.The areas containing high concentrations of sandstone form two elongated trends. The sandstone trends strike N35°E. The axes of the trends lie approximately 1 mile apart. The sandstone bodies are approximately 3/4 of a mile across and 5 miles long. These sand bodies range in thickness from 20 feet to 64 feet.The sandstone bodies may represent tidally influenced shallow marine offshore bars. Cross laminations and very fine grained clastics indicate a low velocity aqueous environment. The elongate shape of the sands indicate bar deposits and the sandy limestones indicate a marine environment.

In this paper, I will determine the subsurface structure of the Spencer Consolidated Oil Field occupying Sections 1, 2, 11-15, 22, 26, and 27 of Township 8 South, Range 14 West, Posey County, Indiana (Uniontown 7 1/2" Quadrangle).Oil production in the Spencer Consolidated is from three principal formations. These are, in descending stratigraphic order, the Renault Formation, Aux Vases Sandstone, and Ste. Genevieve Limestone, in which the producing zones are referred to as either McClosky sands or oolitic bodies. Mapping the configuration of the oilbearing rocks and defining the distribution of these rocks will be my main concern.Structure contour maps of these three formations were prepared, as were isopach maps of the base of the lower Renault limestone and the Aux Vases Sandstone. There are insufficient data points defining the Ste. Genevieve.For the possible recovery of new hydrocarbons within the Spencer Consolidated and the exploration of existing traps, electric log correlation sections, both transverse and parallel to the surrounding faults, were made. For reliability and consistency, only those wells with electric logs were used.

The Lower Mississippian Lodgepole/lower Madison Formations (20-225 m thick) developed along a broad (>700 km) stormdominated cratonic ramp. Three types of shallowing-upward cycles (5th order) are recognized across the ramp-to-basin transition. Peritidal cycles consist of very shallow subtidal facies overlain by algal-laminated tidal flat deposits, which are rarely capped by paleosol/breccia layers. Shallow subtidal cycles consist of stacked ooid grainstone shoal deposits or deeper subtidal facies overlain by ooid-skeletal grainstone caps. Deep subtidal cycles occur along the outer ramp and ramp-slope and consist of sub-storm wave base limestone-argillite, overlain by graded limestone, and are capped by storm-deposited skeletal-ooid grainstone. They pass downslope into rhythmically interbedded limestone and argillite with local deepwater mud mounds; no shallowing-upward cycles occur within the ramp-slope facies. Average cycle periods calculated along the outer ramp range from 30-110 k.y. The cycles likely formed in response to 5th order (20-100 k.y.) sea level oscillations. The cycles are stacked to form three 3rd to 4th order depositional sequences which are defined by regional transgressive-regressive facies trends. The ramp margin wedge (RMW) developed during long-term sea level fall lowstand conditions and consists of cyclic crinoidal bank and oolitic shoal facies which pass downdip into deep subtidal cycles. The transgressive systems tract (TST),which onlapped the ramp during long-term sea level rise, includes thick deep and shallow subtidal cycles; peritidal cycles are restricted to the inner ramp. The highstand systems tract (HST) developed during long-term sea level highstand and fall, and along the ramp is composed of early HST shallow subtidal cycles which are overlain by late HST peritidal cycles; shallow through deep subtidal cycles composed the HST along the ramp-slope. / Ph. D.