Paul Lillis
Scientist Emeritus with the Central Energy Resources Science Center
Paul Lillis is a recently retired petroleum geochemist with the Central Energy Resources Science Center of the U.S. Geological Survey (USGS) in Denver, Colorado. He received a B.A. in geology from San Jose State University, an M.S. in geology from San Diego State University, and a Ph.D. in geochemistry from Colorado School of Mines. He was a petroleum exploration geologist with Atlantic Richfield for eight years (1978 to 1986) in Colorado, California, and Texas, and has been with the USGS in Denver since 1987. His research focuses on the application of petroleum and source-rock geochemistry to identifying, characterizing, and mapping petroleum systems.\
Science and Products
Filter Total Items: 68
Assessment of undiscovered continuous oil and gas resources in the Monterey Formation, San Joaquin Basin Province, California, 2015
Using a geology-based assessment methodology, the U.S. Geological Survey assessed mean volumes of 21 million barrels of oil (MMBO), 27 billion cubic feet of gas, and 1 million barrels of natural gas liquids in two assessment units (AUs) that may contain continuous oil resources. Mean volumes of oil for the individual assessment units are 14 MMBO in the Monterey Buttonwillow AU and 7 MMBO in the Mo
Authors
Marilyn E. Tennyson, Ronald R. Charpentier, Timothy R. Klett, Michael E. Brownfield, Janet K. Pitman, Stephanie B. Gaswirth, Sarah J. Hawkins, Paul G. Lillis, Kristen R. Marra, Tracey J. Mercier, Heidi M. Leathers, Christopher J. Schenk, Katherine J. Whidden
Asphaltene content and composition as a measure of Deepwater Horizon oil spill losses within the first 80 days
The composition and content of asphaltenes in spilled and original wellhead oils from the Deepwater Horizon (DWH) incident provide information on the amount of original oil lost and the processes most responsible for the losses within the first 80 days of the active spill. Spilled oils were collected from open waters, coastal waters and coastal sediments during the incident. Asphaltenes are the mo
Authors
M. D. Lewan, A. Warden, R.F. Dias, Z.K. Lowry, T.L. Hannah, P. G. Lillis, R.F. Kokaly, T.M. Hoefen, G.A. Swayze, C.T. Mills, S.H. Harris, G.S. Plumlee
Re-Os geochronology and Os isotope fingerprinting of petroleum sourced from a Type I lacustrine kerogen: insights from the natural Green River petroleum system in the Uinta Basin and hydrous pyrolysis experiments
Rhenium–osmium (Re–Os) geochronology of marine petroleum systems has allowed the determination of the depositional age of source rocks as well as the timing of petroleum generation. In addition, Os isotopes have been applied as a fingerprinting tool to correlate oil to its source unit. To date, only classic marine petroleum systems have been studied. Here we present Re–Os geochronology and Os isot
Authors
Vivien M. Cumming, David Selby, Paul G. Lillis, Michael D. Lewan
Geology and total petroleum systems of the Paradox Basin, Utah, Colorado, New Mexico, and Arizona
The geological model for the development of the Total Petroleum Systems (TPSs) within the Paradox Basin formed the foundation of the recent U.S. Geological Survey assessment of undiscovered, technically recoverable resources in the basin. Five TPSs were defined, of which three have known production and two are hypothetical. These TPSs are based on geologic elements of the basin and the potential d
Authors
Katherine J. Whidden, Paul G. Lillis, Lawrence O. Anna, Krystal M. Pearson, Russell F. Dubiel
Rock-Eval pyrolysis and vitrinite reflectance results from the Sheep Creek 1 well, Susitna basin, south-central Alaska
We used Rock-Eval pyrolysis and vitrinite reflectance to examine the petroleum source potential of rock samples from the Sheep Creek 1 well in the Susitna basin of south-central Alaska. The results show that Miocene nonmarine coal, carbonaceous shale, and mudstone are potential sources of hydrocarbons and are thermally immature with respect to the oil window. In the samples that we studied, coals
Authors
Richard G. Stanley, Paul G. Lillis, Mark J. Pawlewicz, Peter J. Haeussler
By
Energy and Minerals Mission Area, Energy Resources Program, Mineral Resources Program, National Laboratories Program, Science and Decisions Center, Groundwater and Streamflow Information Program, Alaska Science Center, Central Energy Resources Science Center, Geology, Minerals, Energy, and Geophysics Science Center
Evidence for Cambrian petroleum source rocks in the Rome trough of West Virginia and Kentucky, Appalachian basin
A 130-foot-thick Cambrian black shale sampled from a core between 11,150 and 11,195 feet in the Exxon No. 1 Smith well in Wayne County, W. Va., has been identified as a good to very good source rock. The black shale is located in the Middle Cambrian Rogersville Shale of the Conasauga Group. Total organic carbon (TOC) values of four samples that range from 1.2 to 4.4 weight percent (average 2.6 wei
Authors
Robert T. Ryder, David C. Harris, Paul Gerome, Timothy J. Hainsworth, Robert A. Burruss, Paul G. Lillis, Daniel M. Jarvie, Mark J. Pawlewicz
Evaluation of the rhenium-osmium geochronometer in the Phosphoria petroleum system, Bighorn Basin of Wyoming and Montana, USA
Rhenium-osmium (Re-Os) geochronometry is applied to crude oils derived from the Permian Phosphoria Formation of the Bighorn Basin in Wyoming and Montana to determine whether the radiogenic age reflects the timing of petroleum generation, timing of migration, age of the source rock, or the timing of thermochemical sulfate reduction (TSR). The oils selected for this study are interpreted to be deriv
Authors
Paul G. Lillis, David Selby
Input-form data for the U.S. Geological Survey assessment of the Devonian and Mississippian Bakken and Devonian Three Forks Formations of the U.S. Williston Basin Province, 2013
In 2013, the U.S. Geological Survey assessed the technically recoverable oil and gas resources of the Bakken and Three Forks Formations of the U.S. portion of the Williston Basin. The Bakken and Three Forks Formations were assessed as continuous and hypothetical conventional oil accumulations using a methodology similar to that used in the assessment of other continuous- and conventional-type asse
Authors
Stephanie B. Gaswirth, Kristen R. Marra, Troy A. Cook, Ronald R. Charpentier, Donald L. Gautier, Debra K. Higley, Timothy R. Klett, Michael D. Lewan, Paul G. Lillis, Christopher J. Schenk, Marilyn E. Tennyson, Katherine J. Whidden
Assessment of undiscovered oil resources in the Bakken and Three Forks Formations, Williston Basin Province, Montana, North Dakota, and South Dakota, 2013
Using a geology-based assessment methodology, the U.S. Geological Survey estimated mean undiscovered volumes of 7.4 billion barrels of oil, 6.7 trillion cubic feet of associated/dissolved natural gas, and 0.53 billion barrels of natural gas liquids in the Bakken and Three Forks Formations in the Williston Basin Province of Montana, North Dakota, and South Dakota.
Authors
Stephanie B. Gaswirth, Kristen R. Marra, Troy A. Cook, Ronald R. Charpentier, Donald L. Gautier, Debra K. Higley, Timothy R. Klett, Michael D. Lewan, Paul G. Lillis, Christopher J. Schenk, Marilyn E. Tennyson, Katherine J. Whidden
Hydrocarbon-bearing sandstone in the Upper Jurassic Naknek Formation on the south shore of Kamishak Bay
The presence of an active petroleum system in Kamishak Bay is demonstrated by an outcrop of hydrocarbon-bearing
sandstone in the Upper Jurassic Naknek Formation near the south shore of the bay (fig. 1). The outcrop is about 140 km
southwest of Homer on a small, unnamed island near the mouth of the Douglas River (fig. 17). The existence of this outcrop was kindly reported to us by Les Magoon (U.S
Authors
Richard G. Stanley, Trystan M. Herriott, Kenneth P. Helmold, Robert J. Gillis, Paul G. Lillis
Review of oil families and their petroleum systems of the Williston Basin
The petroleum system concept was first applied in 1974 (Dow/Williams) to identify three oil systems in the Williston Basin, and recent studies have expanded the number to at least nine. This paper reviews the petroleum geochemistry, oil-oil, and oil-source correlations of the oil systems of the Williston Basin, providing a new perspective and some new findings. Petroleum systems with a known sourc
Authors
Paul G. Lillis
Re–Os geochronology of the lacustrine Green River Formation: Insights into direct depositional dating of lacustrine successions, Re–Os systematics and paleocontinental weathering
Lacustrine sedimentary successions provide exceptionally high-resolution records of continental geological processes, responding to tectonic, climatic and magmatic influences. These successions are therefore essential for correlating geological and climatic phenomena across continents and furthermore the globe. Producing accurate geochronological frameworks within lacustrine strata is challenging
Authors
Vivien M. Cumming, David Selby, Paul G. Lillis
Science and Products
Filter Total Items: 68
Assessment of undiscovered continuous oil and gas resources in the Monterey Formation, San Joaquin Basin Province, California, 2015
Using a geology-based assessment methodology, the U.S. Geological Survey assessed mean volumes of 21 million barrels of oil (MMBO), 27 billion cubic feet of gas, and 1 million barrels of natural gas liquids in two assessment units (AUs) that may contain continuous oil resources. Mean volumes of oil for the individual assessment units are 14 MMBO in the Monterey Buttonwillow AU and 7 MMBO in the Mo
Authors
Marilyn E. Tennyson, Ronald R. Charpentier, Timothy R. Klett, Michael E. Brownfield, Janet K. Pitman, Stephanie B. Gaswirth, Sarah J. Hawkins, Paul G. Lillis, Kristen R. Marra, Tracey J. Mercier, Heidi M. Leathers, Christopher J. Schenk, Katherine J. Whidden
Asphaltene content and composition as a measure of Deepwater Horizon oil spill losses within the first 80 days
The composition and content of asphaltenes in spilled and original wellhead oils from the Deepwater Horizon (DWH) incident provide information on the amount of original oil lost and the processes most responsible for the losses within the first 80 days of the active spill. Spilled oils were collected from open waters, coastal waters and coastal sediments during the incident. Asphaltenes are the mo
Authors
M. D. Lewan, A. Warden, R.F. Dias, Z.K. Lowry, T.L. Hannah, P. G. Lillis, R.F. Kokaly, T.M. Hoefen, G.A. Swayze, C.T. Mills, S.H. Harris, G.S. Plumlee
Re-Os geochronology and Os isotope fingerprinting of petroleum sourced from a Type I lacustrine kerogen: insights from the natural Green River petroleum system in the Uinta Basin and hydrous pyrolysis experiments
Rhenium–osmium (Re–Os) geochronology of marine petroleum systems has allowed the determination of the depositional age of source rocks as well as the timing of petroleum generation. In addition, Os isotopes have been applied as a fingerprinting tool to correlate oil to its source unit. To date, only classic marine petroleum systems have been studied. Here we present Re–Os geochronology and Os isot
Authors
Vivien M. Cumming, David Selby, Paul G. Lillis, Michael D. Lewan
Geology and total petroleum systems of the Paradox Basin, Utah, Colorado, New Mexico, and Arizona
The geological model for the development of the Total Petroleum Systems (TPSs) within the Paradox Basin formed the foundation of the recent U.S. Geological Survey assessment of undiscovered, technically recoverable resources in the basin. Five TPSs were defined, of which three have known production and two are hypothetical. These TPSs are based on geologic elements of the basin and the potential d
Authors
Katherine J. Whidden, Paul G. Lillis, Lawrence O. Anna, Krystal M. Pearson, Russell F. Dubiel
Rock-Eval pyrolysis and vitrinite reflectance results from the Sheep Creek 1 well, Susitna basin, south-central Alaska
We used Rock-Eval pyrolysis and vitrinite reflectance to examine the petroleum source potential of rock samples from the Sheep Creek 1 well in the Susitna basin of south-central Alaska. The results show that Miocene nonmarine coal, carbonaceous shale, and mudstone are potential sources of hydrocarbons and are thermally immature with respect to the oil window. In the samples that we studied, coals
Authors
Richard G. Stanley, Paul G. Lillis, Mark J. Pawlewicz, Peter J. Haeussler
By
Energy and Minerals Mission Area, Energy Resources Program, Mineral Resources Program, National Laboratories Program, Science and Decisions Center, Groundwater and Streamflow Information Program, Alaska Science Center, Central Energy Resources Science Center, Geology, Minerals, Energy, and Geophysics Science Center
Evidence for Cambrian petroleum source rocks in the Rome trough of West Virginia and Kentucky, Appalachian basin
A 130-foot-thick Cambrian black shale sampled from a core between 11,150 and 11,195 feet in the Exxon No. 1 Smith well in Wayne County, W. Va., has been identified as a good to very good source rock. The black shale is located in the Middle Cambrian Rogersville Shale of the Conasauga Group. Total organic carbon (TOC) values of four samples that range from 1.2 to 4.4 weight percent (average 2.6 wei
Authors
Robert T. Ryder, David C. Harris, Paul Gerome, Timothy J. Hainsworth, Robert A. Burruss, Paul G. Lillis, Daniel M. Jarvie, Mark J. Pawlewicz
Evaluation of the rhenium-osmium geochronometer in the Phosphoria petroleum system, Bighorn Basin of Wyoming and Montana, USA
Rhenium-osmium (Re-Os) geochronometry is applied to crude oils derived from the Permian Phosphoria Formation of the Bighorn Basin in Wyoming and Montana to determine whether the radiogenic age reflects the timing of petroleum generation, timing of migration, age of the source rock, or the timing of thermochemical sulfate reduction (TSR). The oils selected for this study are interpreted to be deriv
Authors
Paul G. Lillis, David Selby
Input-form data for the U.S. Geological Survey assessment of the Devonian and Mississippian Bakken and Devonian Three Forks Formations of the U.S. Williston Basin Province, 2013
In 2013, the U.S. Geological Survey assessed the technically recoverable oil and gas resources of the Bakken and Three Forks Formations of the U.S. portion of the Williston Basin. The Bakken and Three Forks Formations were assessed as continuous and hypothetical conventional oil accumulations using a methodology similar to that used in the assessment of other continuous- and conventional-type asse
Authors
Stephanie B. Gaswirth, Kristen R. Marra, Troy A. Cook, Ronald R. Charpentier, Donald L. Gautier, Debra K. Higley, Timothy R. Klett, Michael D. Lewan, Paul G. Lillis, Christopher J. Schenk, Marilyn E. Tennyson, Katherine J. Whidden
Assessment of undiscovered oil resources in the Bakken and Three Forks Formations, Williston Basin Province, Montana, North Dakota, and South Dakota, 2013
Using a geology-based assessment methodology, the U.S. Geological Survey estimated mean undiscovered volumes of 7.4 billion barrels of oil, 6.7 trillion cubic feet of associated/dissolved natural gas, and 0.53 billion barrels of natural gas liquids in the Bakken and Three Forks Formations in the Williston Basin Province of Montana, North Dakota, and South Dakota.
Authors
Stephanie B. Gaswirth, Kristen R. Marra, Troy A. Cook, Ronald R. Charpentier, Donald L. Gautier, Debra K. Higley, Timothy R. Klett, Michael D. Lewan, Paul G. Lillis, Christopher J. Schenk, Marilyn E. Tennyson, Katherine J. Whidden
Hydrocarbon-bearing sandstone in the Upper Jurassic Naknek Formation on the south shore of Kamishak Bay
The presence of an active petroleum system in Kamishak Bay is demonstrated by an outcrop of hydrocarbon-bearing
sandstone in the Upper Jurassic Naknek Formation near the south shore of the bay (fig. 1). The outcrop is about 140 km
southwest of Homer on a small, unnamed island near the mouth of the Douglas River (fig. 17). The existence of this outcrop was kindly reported to us by Les Magoon (U.S
Authors
Richard G. Stanley, Trystan M. Herriott, Kenneth P. Helmold, Robert J. Gillis, Paul G. Lillis
Review of oil families and their petroleum systems of the Williston Basin
The petroleum system concept was first applied in 1974 (Dow/Williams) to identify three oil systems in the Williston Basin, and recent studies have expanded the number to at least nine. This paper reviews the petroleum geochemistry, oil-oil, and oil-source correlations of the oil systems of the Williston Basin, providing a new perspective and some new findings. Petroleum systems with a known sourc
Authors
Paul G. Lillis
Re–Os geochronology of the lacustrine Green River Formation: Insights into direct depositional dating of lacustrine successions, Re–Os systematics and paleocontinental weathering
Lacustrine sedimentary successions provide exceptionally high-resolution records of continental geological processes, responding to tectonic, climatic and magmatic influences. These successions are therefore essential for correlating geological and climatic phenomena across continents and furthermore the globe. Producing accurate geochronological frameworks within lacustrine strata is challenging
Authors
Vivien M. Cumming, David Selby, Paul G. Lillis