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Note: This page contains sample records for the topic "reservoir rock carbon" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


1

Carbonation Mechanism of Reservoir Rock by Supercritical Carbon...  

Open Energy Info (EERE)

from reservoir rock formation. - Task 2: Carbonation study of minerals. - Task 3: Mechanical behaviors of carbonated minerals. - Task 4: Modeling of CO2- reservoir rock...

2

Carbonation Mechanism of Reservoir Rock by Supercritical Carbon...  

Broader source: Energy.gov (indexed) [DOE]

chemistrybutchercarbonationmechanism.pdf More Documents & Publications Synchrotron X-ray Studies of Super-critical Carbon Dioxide Reservoir Rock Interfaces Innovative...

3

Carbonation Mechanism of Reservoir Rock by Supercritical Carbon Dioxide  

Broader source: Energy.gov [DOE]

Project Objectives: Elucidate comprehensively the carbonation reaction mechanisms between supercritical carbon dioxide (scCO2) and reservoir rocks consisting of different mineralogical compositions in aqueous and non-aqueous environments at temperatures of up to 250ºC, and to develop chemical modeling of CO2-reservior rock interactions.

4

Influence of Rock Types on Seismic Monitoring of CO2 Sequestration in Carbonate Reservoirs  

E-Print Network [OSTI]

) techniques such as high pressure CO2 injection may normally be required to recover oil in place in carbonate reservoirs. This study addresses how different rock types can influence the seismic monitoring of CO2 sequestration in carbonates. This research...

Mammadova, Elnara

2012-10-19T23:59:59.000Z

5

Use of ``rock-typing`` to characterize carbonate reservoir heterogeneity. Final report  

SciTech Connect (OSTI)

The objective of the project was to apply techniques of ``rock-typing`` and quantitative formation evaluation to borehole measurements in order to identify reservoir and non-reservoir rock-types and their properties within the ``C`` zone of the Ordovician Red River carbonates in the northeast Montana and northwest North Dakota areas of the Williston Basin. Rock-typing discriminates rock units according to their pore-size distribution. Formation evaluation estimates porosities and pore fluid saturation. Rock-types were discriminated using crossplots involving three rock-typing criteria: (1) linear relationship between bulk density and porosity, (2) linear relationship between acoustic interval transit-time and porosity, and (3) linear relationship between acoustic interval transit-time and bulk density. Each rock-type was quantitatively characterized by the slopes and intercepts established for different crossplots involving the above variables, as well as porosities and fluid saturations associated with the rock-types. All the existing production was confirmed through quantitative formation evaluation. Highly porous dolomites and anhydritic dolomites contribute most of the production, and constitute the best reservoir rock-types. The results of this study can be applied in field development and in-fill drilling. Potential targets would be areas of porosity pinchouts and those areas where highly porous zones are downdip from non-porous and tight dolomites. Such areas are abundant. In order to model reservoirs for enhanced oil recovery (EOR) operations, a more localized (e.g. field scale) study, expanded to involve other rock-typing criteria, is necessary.

Ikwuakor, K.C.

1994-03-01T23:59:59.000Z

6

Mobilization and Transport of Organic Compounds from Reservoir Rock and Caprock in Geological Carbon Sequestration Sites  

SciTech Connect (OSTI)

Supercritical CO2 (scCO2) is an excellent solvent for organic compounds, including benzene, toluene, ethyl-benzene, and xylene (BTEX), phenols, and polycyclic aromatic hydrocarbons (PAHs). Monitoring results from geological carbon sequestration (GCS) field tests has shown that organic compounds are mobilized following CO2 injection. Such results have raised concerns regarding the potential for groundwater contamination by toxic organic compounds mobilized during GCS. Knowledge of the mobilization mechanism of organic compounds and their transport and fate in the subsurface is essential for assessing risks associated with GCS. Extraction tests using scCO2 and methylene chloride (CH2Cl2) were conducted to study the mobilization of volatile organic compounds (VOCs, including BTEX), the PAH naphthalene, and n-alkanes (n-C20 – n-C30) by scCO2 from representative reservoir rock and caprock obtained from depleted oil reservoirs and coal from an enhanced coal-bed methane recovery site. More VOCs and naphthalene were extractable by scCO2 compared to the CH2Cl2 extractions, while scCO2 extractable alkane concentrations were much lower than concentrations extractable by CH2Cl2. In addition, dry scCO2 was found to extract more VOCs than water saturated scCO2, but water saturated scCO2 mobilized more naphthalene than dry scCO2. In sand column experiments, moisture content was found to have an important influence on the transport of the organic compounds. In dry sand columns the majority of the compounds were retained in the column except benzene and toluene. In wet sand columns the mobility of the BTEX was much higher than that of naphthalene. Based upon results determined for the reservoir rock, caprock, and coal samples studied here, the risk to aquifers from contamination by organic compounds appears to be relatively low; however, further work is necessary to fully evaluate risks from depleted oil reservoirs.

Zhong, Lirong; Cantrell, Kirk J.; Mitroshkov, Alexandre V.; Shewell, Jesse L.

2014-05-06T23:59:59.000Z

7

MULTIDISCIPLINARY IMAGING OF ROCK PROPERTIES IN CARBONATE RESERVOIRS FOR FLOW-UNIT TARGETING  

SciTech Connect (OSTI)

Excellent progress has been made on all project objectives and goals. All tasks have been completed in the Phase 1 study area, the initial area of project focus. Primary elements of this work include the following: The stratigraphic architecture has been established through correlation of wireline logs guided by core and outcrop studies of facies and cyclicity. A porosity model has been developed that creates a basis for calculation of porosity for wells in the study area. Rock fabrics have been defined by sampling, analysis, and description of cores and used to create transforms for calculating permeability and oil saturation from porosity data. Finally, a preliminary 3-D model has been constructed that incorporates stratigraphic architecture, rock-fabric data, and petrophysical data. Reservoir volumetrics calculated from the model show that a very large fraction of the original oil in place remains.

Stephen C. Ruppel

2003-01-01T23:59:59.000Z

8

Synchrotron X-ray Studies of Super-critical Carbon Dioxide / Reservoir Rock Interfaces  

Broader source: Energy.gov [DOE]

Project obectives: Utilize synchrotron X-ray measurements, to monitor all aspects of atomic to nanoscale structural changes resulting from chemical interactions of scCO2-H2O binary fluids with rocks under environments directly relevant to EGS.

9

ADVANCED CHARACTERIZATION OF FRACTURED RESERVOIRS IN CARBONATE ROCKS: THE MICHIGAN BASIN  

SciTech Connect (OSTI)

Among the accomplishments of this past reporting period are obtaining a complete landgrid for the State of Michigan and the digital processing of the high and medium resolution DEM files. We can now extract lineations from the DEMs automatically using machine algorithms. One tentative result that may be very significant is that we may be seeing manifestations of buried structures in the DEM data. We are looking at a set of extracted lineations in the northern lower peninsula that appear to follow the trend of the pinnacle reefs (Silurian) which had relief approaching 300 feet but are now buried to greater than 3000 feet. We have also extracted the dolomite alteration data from all fields and can show that this is mainly confined to the basin center. It may be related to the paleo-rift suggested by the paleomagnetic and gravity data. As reported last time, the acquisition of a 3D seismic dataset over Stoney Point Field from Marathon Oil Company, is complete and attention is being devoted to incorporating the data into the project database and utilizing it. The surface lineation study is focusing on Stoney Point Field using the high-resolution DEM data and plotting of subsurface formation top data for the main reservoir, the Trenton (Ordovician) Formation. The fault pattern at Stoney Point is well documented by Marathon and we are looking for any manifestations on the surface. The main project database is now about as complete as it will be for this project. The main goals have been met, although the scanning of the paper records will have to continue beyond the scheduled end of the project due to the sheer number of records and the increased donations of data from companies as word spread of the project. One of the unanticipated benefits of the project has been the cooperation of gas and oil companies that are or were active in the Michigan Basin in donating material to the project. Both Michigan Tech and Western Michigan continue to receive donations at an accelerating pace. The data management software developed to handle the data, Atlas, is scheduled to undergo a 3rd revision before the project ends. The goals are to streamline access to the data by improving the display and add several new features, including the ability to turn the landgrid on and off. We may also be able to include the capability to calculate or recalculate footage calls as well. We discovered the reason that some of the 1/24,000 USGS DEM (Digital Elevation Models) for the State of Michigan contain high levels of noise and are making one last attempt to acquire a set of good files before the project ends. This will greatly improve the large-scale map (48 inches x 84 inches) that has been constructed by mosaicking of the high-resolution files. This map shows excellent ground surface detail and has drawn much comment and requests for copies at the venues where it has been displayed. Although it was generated for mapping of surface lineations the map has other uses, particularly analysis of the glacial drift in Michigan.

James R. Wood; William B. Harrison

2001-04-01T23:59:59.000Z

10

Storage capacity in hot dry rock reservoirs  

DOE Patents [OSTI]

A method is described for extracting thermal energy, in a cyclic manner, from geologic strata which may be termed hot dry rock. A reservoir comprised of hot fractured rock is established and water or other liquid is passed through the reservoir. The water is heated by the hot rock, recovered from the reservoir, cooled by extraction of heat by means of heat exchange apparatus on the surface, and then re-injected into the reservoir to be heated again. Water is added to the reservoir by means of an injection well and recovered from the reservoir by means of a production well. Water is continuously provided to the reservoir and continuously withdrawn from the reservoir at two different flow rates, a base rate and a peak rate. Increasing water flow from the base rate to the peak rate is accomplished by rapidly decreasing backpressure at the outlet of the production well in order to meet periodic needs for amounts of thermal energy greater than a baseload amount, such as to generate additional electric power to meet peak demands. The rate of flow of water provided to the hot dry rock reservoir is maintained at a value effective to prevent depletion of the liquid inventory of the reservoir. 4 figs.

Brown, D.W.

1997-11-11T23:59:59.000Z

11

Storage capacity in hot dry rock reservoirs  

DOE Patents [OSTI]

A method of extracting thermal energy, in a cyclic manner, from geologic strata which may be termed hot dry rock. A reservoir comprised of hot fractured rock is established and water or other liquid is passed through the reservoir. The water is heated by the hot rock, recovered from the reservoir, cooled by extraction of heat by means of heat exchange apparatus on the surface, and then re-injected into the reservoir to be heated again. Water is added to the reservoir by means of an injection well and recovered from the reservoir by means of a production well. Water is continuously provided to the reservoir and continuously withdrawn from the reservoir at two different flow rates, a base rate and a peak rate. Increasing water flow from the base rate to the peak rate is accomplished by rapidly decreasing backpressure at the outlet of the production well in order to meet periodic needs for amounts of thermal energy greater than a baseload amount, such as to generate additional electric power to meet peak demands. The rate of flow of water provided to the hot dry rock reservoir is maintained at a value effective to prevent depletion of the liquid

Brown, Donald W. (Los Alamos, NM)

1997-01-01T23:59:59.000Z

12

Modeling of Seismic Signatures of Carbonate Rock Types  

E-Print Network [OSTI]

Carbonate reservoirs of different rock types have wide ranges of porosity and permeability, creating zones with different reservoir quality and flow properties. This research addresses how seismic technology can be used to identify different...

Jan, Badr H.

2011-02-22T23:59:59.000Z

13

Improved characterization of reservoir behavior by integration of reservoir performances data and rock type distributions  

SciTech Connect (OSTI)

An integrated geological/petrophysical and reservoir engineering study was performed for a large, mature waterflood project (>250 wells, {approximately}80% water cut) at the North Robertson (Clear Fork) Unit, Gaines County, Texas. The primary goal of the study was to develop an integrated reservoir description for {open_quotes}targeted{close_quotes} (economic) 10-acre (4-hectare) infill drilling and future recovery operations in a low permeability, carbonate (dolomite) reservoir. Integration of the results from geological/petrophysical studies and reservoir performance analyses provide a rapid and effective method for developing a comprehensive reservoir description. This reservoir description can be used for reservoir flow simulation, performance prediction, infill targeting, waterflood management, and for optimizing well developments (patterns, completions, and stimulations). The following analyses were performed as part of this study: (1) Geological/petrophysical analyses: (core and well log data) - {open_quotes}Rock typing{close_quotes} based on qualitative and quantitative visualization of pore-scale features. Reservoir layering based on {open_quotes}rock typing {close_quotes} and hydraulic flow units. Development of a {open_quotes}core-log{close_quotes} model to estimate permeability using porosity and other properties derived from well logs. The core-log model is based on {open_quotes}rock types.{close_quotes} (2) Engineering analyses: (production and injection history, well tests) Material balance decline type curve analyses to estimate total reservoir volume, formation flow characteristics (flow capacity, skin factor, and fracture half-length), and indications of well/boundary interference. Estimated ultimate recovery analyses to yield movable oil (or injectable water) volumes, as well as indications of well and boundary interference.

Davies, D.K.; Vessell, R.K. [David K. Davies & Associates, Kingwood, TX (United States); Doublet, L.E. [Texas A& M Univ., College Station, TX (United States)] [and others

1997-08-01T23:59:59.000Z

14

Rock magnetism of remagnetized carbonate rocks: another look  

E-Print Network [OSTI]

and significance of magnetism in sedimentary rocks. Journal1997. Rock Magnetism. ¨ zdemir, O Dunlop, D. J. & Oon July 30, 2013 ROCK MAGNETISM: REMAGNETIZED CARBONATES

Jackson, M.; Swanson-Hysell, N. L

2012-01-01T23:59:59.000Z

15

SEISMIC AND ROCK PHYSICS DIAGNOSTICS OF MULTISCALE RESERVOIR TEXTURES  

SciTech Connect (OSTI)

As part of our study on ''Relationships between seismic properties and rock microstructure'', we have continued our work on analyzing well logs and microstructural constraints on seismic signatures. We report results of three studies in this report. The first one deals with fractures and faults that provide the primary control on the underground fluid flow through low permeability massive carbonate rocks. Fault cores often represent lower transmissibility whereas the surrounding damaged rocks and main slip surfaces are high transmissibility elements. We determined the physical properties of fault rocks collected in and around the fault cores of large normal faults in central Italy. After studying the P- and S-wave velocity variation during cycles of confining pressure, we conclude that a rigid pore frame characterizes the fault gouge whereas the fractured limestone comprises pores with a larger aspect ratio. The second study was to characterize the seismic properties of brine as its temperature decreases from 25 C to -21 C. The purpose was to understand how the transmitted wave changes with the onset of freezing. The main practical reason for this experiment was to use partially frozen brine as an analogue for a mixture of methane hydrate and water present in the pore space of a gas hydrate reservoir. In the third study we analyzed variations in dynamic moduli in various carbonate reservoirs. The investigations include log and laboratory data from velocity, porosity, permeability, and attenuation measurements.

Gary Mavko

2004-08-01T23:59:59.000Z

16

Hydromechanical interactions in a fractured carbonate reservoir inferred from hydraulic and mechanical measurements  

E-Print Network [OSTI]

Hydromechanical interactions in a fractured carbonate reservoir inferred from hydraulic, France Abstract Hydromechanical coupled processes in a shallow fractured carbonate reservoir rock were of hydraulic loading/unloading of a water reservoir in which fluid flow occurs mainly inside a heterogeneous

Paris-Sud XI, Université de

17

Hydroelectric Reservoirs -the Carbon Dioxide and Methane  

E-Print Network [OSTI]

Hydroelectric Reservoirs - the Carbon Dioxide and Methane Emissions of a "Carbon Free" Energy an overview on the greenhouse gas production of hydroelectric reservoirs. The goals are to point out the main how big the greenhouse gas emissions from hydroelectric reservoirs are compared to thermo-power plants

Fischlin, Andreas

18

Reservoir rock-property calculations from thin section measurements  

E-Print Network [OSTI]

RESERVOIR ROCK-PROPERTY CALCULATIONS FROM THIN SECTION MEASUREMENTS A Thesis by DAVID RICHARD SNEED Submitted to the Office of Graduate Studies of Texas A&M University in partial fulfillment of the requirements for the degree of MASTER... OF SCIENCE August 1988 Major Subject: Geology RESERVOIR ROCK-PROPERTY CALCULATIONS FROM THIN SECTION MEASUREMENTS A Thesis by DAVID RICHARD SNEED Approved as to style and content by: Robert R. Berg (Chair of Committee) ~ c(. Thomas T. Tieh (Member...

Sneed, David Richard

1988-01-01T23:59:59.000Z

19

Petrophysical rock classification in the Cotton Valley tight-gas sandstone reservoir with a clustering  

E-Print Network [OSTI]

Petrophysical rock classification in the Cotton Valley tight-gas sandstone reservoir classification method with field data acquired in the Cotton Valley tight-gas sandstone reservoir located

Torres-Verdín, Carlos

20

SEISMIC AND ROCK PHYSICS DIAGNOSTICS OF MULTISCALE RESERVOIR TEXTURES  

SciTech Connect (OSTI)

As part of our study on ''Relationships between seismic properties and rock microstructure'', we have (1) Studied relationships between velocity and permeability. (2) Used independent experimental methods to measure the elastic moduli of clay minerals as functions of pressure and saturation. (3) Applied different statistical methods for characterizing heterogeneity and textures from scanning acoustic microscope (SAM) images of shale microstructures. (4) Analyzed the directional dependence of velocity and attenuation in different reservoir rocks (5) Compared Vp measured under hydrostatic and non-hydrostatic stress conditions in sands. (6) Studied stratification as a source of intrinsic anisotropy in sediments using Vp and statistical methods for characterizing textures in sands.

Gary Mavko

2003-10-01T23:59:59.000Z

Note: This page contains sample records for the topic "reservoir rock carbon" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


21

Sizing of a hot dry rock reservoir from a hydraulic fracturing experiment  

SciTech Connect (OSTI)

Hot dry rock (HDR) reservoirs do not lend themselves to the standard methods of reservoir sizing developed in the petroleum industry such as the buildup/drawdown test. In a HDR reservoir the reservoir is created by the injection of fluid. This process of hydraulic fracturing of the reservoir rock usually involves injection of a large volume (5 million gallons) at high rates (40BPM). A methodology is presented for sizing the HDR reservoir created during the hydraulic fracturing process. The reservoir created during a recent fracturing experiment is sized using the techniques presented. This reservoir is then investigated for commercial potential by simulation of long term power production. 5 refs., 7 figs.

Zyvoloski, G.

1985-01-01T23:59:59.000Z

22

Manufactured caverns in carbonate rock  

DOE Patents [OSTI]

Disclosed is a process for manufacturing underground caverns suitable in one embodiment for storage of large volumes of gaseous or liquid materials. The method is an acid dissolution process that can be utilized to form caverns in carbonate rock formations. The caverns can be used to store large quantities of materials near transportation facilities or destination markets. The caverns can be used for storage of materials including fossil fuels, such as natural gas, refined products formed from fossil fuels, or waste materials, such as hazardous waste materials. The caverns can also be utilized for applications involving human access such as recreation or research. The method can also be utilized to form calcium chloride as a by-product of the cavern formation process.

Bruce, David A.; Falta, Ronald W.; Castle, James W.; Murdoch, Lawrence C.

2007-01-02T23:59:59.000Z

23

URTeC 1620617 Thermal Shock in Reservoir Rock Enhances the Hydraulic  

E-Print Network [OSTI]

URTeC 1620617 Thermal Shock in Reservoir Rock Enhances the Hydraulic Fracturing of Gas Shales Saeid through strain and stress. As the temperature diffuses from hydraulic fracture into reservoir the rock matrix beyond hydraulic fracturing stimulation by cooling down the rock. The physics

Patzek, Tadeusz W.

24

Documenting Visual Quality Controls on the Evaluation of Petroleum Reservoir-rocks through  

E-Print Network [OSTI]

) processes control the distribution of porosity and permeability within petroleum reservoir rocks and prediction of the quality (porosity, permeability) of petroleum reservoirs during their exploration and production. The description and documentation of key petrographic features is an important tool

Oliveira, Manuel M.

25

Seismic modelling of a fractured carbonate reservoir in Abu Dhabi, United Arab Emirates  

E-Print Network [OSTI]

Seismic modelling of a fractured carbonate reservoir in Abu Dhabi, United Arab Emirates Mohammed Y is required to optimize hydrocarbon production. A rock containing parallel fractures can be seismically to the seismic wavelength. Seismic anisotropy may be detectable from attributes of pre-stack 3-D seismic data

Ali, Mohammed

26

Carbon sequestration in natural gas reservoirs: Enhanced gas recovery and natural gas storage  

E-Print Network [OSTI]

gas reservoirs for carbon sequestration and enhanced gasproduction and carbon sequestration, Society of Petroleumfeasibiilty of carbon sequestration with enhanced gas

Oldenburg, Curtis M.

2003-01-01T23:59:59.000Z

27

Surfactant-enhanced spontaneous imbibition process in highly fractured carbonate reservoirs.  

E-Print Network [OSTI]

??Highly fractured carbonate reservoirs are a class of reservoirs characterized by high conductivity fractures surrounding low permeability matrix blocks. In these reservoirs, wettability alteration is… (more)

Chen, Peila

2011-01-01T23:59:59.000Z

28

EXPERIMENTAL VERIFICATION OF THE LOAD-FOLLOWING POTENTIAL OF A HOT DRY ROCK GEOTHERMAL RESERVOIR  

E-Print Network [OSTI]

EXPERIMENTAL VERIFICATION OF THE LOAD-FOLLOWING POTENTIAL OF A HOT DRY ROCK GEOTHERMAL RESERVOIR. The objective of this cyclic load-following experiment was to investigate the performance of the reservoir, this series of cyclic flow tests is referred to as the Load-Following Experiment, with the objective

29

Interaction between CO2-rich solutions and reservoir-seal rocks. Experimentation  

E-Print Network [OSTI]

coal systems 5.Use of CO2 in enhanced coal bed methane recovery 6.Other suggested options (basalts, oilInteraction between CO2-rich solutions and reservoir-seal rocks. Experimentation María García formations (after Cook, 1999). Geological Storage Options for CO2 1.Depleted oil and gas reservoirs 2.Use

Politècnica de Catalunya, Universitat

30

Rock magnetism of remagnetized carbonate rocks: another look MIKE JACKSON* & NICHOLAS L. SWANSON-HYSELL  

E-Print Network [OSTI]

Rock magnetism of remagnetized carbonate rocks: another look MIKE JACKSON* & NICHOLAS L. SWANSON-HYSELL Institute for Rock Magnetism, Winchell School of Earth Sciences, University of Minnesota, Minnesota, US, dominantly in the super- paramagnetic and stable single-domain size range, also give rise to distinctive rock-magnetic

Swanson-Hysell, Nicholas

31

Study of Acid Response of Qatar Carbonate Rocks  

E-Print Network [OSTI]

reservoirs. Recently papers published from industry discussed the techniques, planning, and optimization of acid stimulation for Qatar carbonate. To the best of author’s knowledge, no study has focused on the acid reaction to Qatar carbonates. The lack...

Wang, Zhaohong

2012-02-14T23:59:59.000Z

32

Formation and thermal evolution of insoluble reservoir bitumen in Angolan carbonate reservoirs  

E-Print Network [OSTI]

Formation and thermal evolution of insoluble reservoir bitumen in Angolan carbonate reservoirs from 98% insoluble bitumen to 45% insoluble, indicating a substantial spread of maturity. However, the discordance shown by these parameters (e.g. bitumen reflectance and bitumen solubility in DCM) indicates

Paris-Sud XI, Université de

33

The Role of Acidizing in Proppant Fracturing in Carbonate Reservoirs  

E-Print Network [OSTI]

of the most widely considered alternatives for application in carbonate reservoirs. Especially in areas that have high closure stress, the non-smoothly etched surface created by acid fracturing may not remain open upon closing, resulting in decrease...

Densirimongkol, Jurairat

2010-10-12T23:59:59.000Z

34

A manual for evaluation and exploitation of carbonate reservoirs  

E-Print Network [OSTI]

A MANUAL FOR EVALUATION AND EXPI OITATION OF CARBONATE RESERVOIRS A Thesis bv PEDRO CORDOVA Submitted to the Office of Graduate Studies of Texas ASM University In Partial fulfillment of the requiren;enis for (he dc(n. ee of MASTER OF SCIENCE.... Brimhall (Member) James E. Russell (Head of Department) December 1992 ABSTRACT A Manual for Evaluation and Exploitation of Carbonate Reservoirs. (December 1992) Pedro Luis Cordova, B. S. , Universidad del Zulia Chair of Advisory Committee: Dr. W. J...

Cordova, Pedro Luis

1992-01-01T23:59:59.000Z

35

Displacement of oil from reservoir rock using high molecular weight polymer solutions  

E-Print Network [OSTI]

underground reservoirs by the injection of water containing chemicals to increase its viscosity. Some laboratory research and field trials have been conducted to evaluate the effectiveness of viscous water in dis- placing oil from reservoir rock.... ia. Twenty-eight experiments were conducted. In twenty-two experiments oil was displaced from un- consolidated sand packs using polymers with viscosity that ranged from 160 cp to 3 cp. In five experiments crude oil was displaced. from...

Barzi, Houshang

1972-01-01T23:59:59.000Z

36

Characterization of facies and permeability patterns in carbonate reservoirs based on outcrop analogs. Final report  

SciTech Connect (OSTI)

The primary objective of this research is to develop methods for better describing the three-dimensional geometry of carbonate reservoir flow units as related to conventional or enhanced recovery of oil. San Andres and Grayburg reservoirs were selected for study because of the 13 Bbbl of remaining mobile oil and 17 Bbbl of residual oil in these reservoirs. The key data base is provided by detailed characterization of geologic facies and rock permeability in reservior-scale outcrops of the Permian San Andres Formation in the Guadalupe Mountains of New Mexico. Emphasis is placed on developing an outcrop analog for San Andres strata that can be used as (1) a guide to interpreting the regional and local geologic framework of the subsurface reservoirs (2) a data source illustrating the scales and patterns of variability of rock-fabric facies and petrophysical properties, particularly in lateral dimension, and on scales that cannot be studied during subsurface reservoir characterization. The research approach taken to achieve these objectives utilizes the integration of geologic description, geostatistical techniques, and reservoir flow simulation experiments. Results from this research show that the spatial distribution of facies relative to the waterflood direction can significantly affect how the reservoir produces. Bypassing of unswept oil occurs due to cross flow of injected water from high permeability zones into lower permeability zones were high permeability zones terminate. An area of unswept oil develops because of the slower advance of the water-injection front in the lower permeability zones. When the injection pattern is reversed, the cross-flow effect changes due to the different arrangements of rock-fabric flow units relative to the flow of injected water, and the sweep efficiency is significantly different. Flow across low-permeability mudstones occurs showing that these layers do not necessarily represent flow barriers.

Kerans, C.; Lucia, F.J.; Senger, R.K.; Fogg, G.E.; Nance, H.S.; Hovorka, S.D.

1993-07-01T23:59:59.000Z

37

Reservoir Investigations on the Hot Dry Rock Geothermal System...  

Open Energy Info (EERE)

Investigations on the Hot Dry Rock Geothermal System, Fenton Hill, New Mexico- Tracer Test Results Jump to: navigation, search OpenEI Reference LibraryAdd to library Conference...

38

Characterizing Flow in Oil Reservoir Rock Using Smooth Particle Hydrodynamics  

E-Print Network [OSTI]

In this paper, a 3D Smooth Particle Hydrodynamics (SPH) simulator for modeling grain scale fluid flow in porous rock is presented. The versatility of the SPH method has driven its use in increasingly complex areas of flow ...

Holmes, David W.

39

Stimulation of Carbonate Reservoirs Using a New Emulsified Acid System  

E-Print Network [OSTI]

of the previous studies on the emulsified acid were done using core samples that were saturated with brine or deionized water. One of the main objectives of the present work is to study in detail the effect of the presence of crude oil in the reservoir rock...

Sayed, Mohammed Ali Ibrahim

2013-05-15T23:59:59.000Z

40

Carbonation Mechanism of Reservoir Rock by Supercritical Carbon...  

Broader source: Energy.gov (indexed) [DOE]

Pressure of 2500 psi Analysis: X-ray powder diffraction (XRD) and Fourier transform infrared spectroscopy (FT-IR) 10 | US DOE Geothermal Program eere.energy.gov Scientific...

Note: This page contains sample records for the topic "reservoir rock carbon" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


41

Carbonation Mechanism of Reservoir Rock by Supercritical Carbon Dioxide  

Open Energy Info (EERE)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data Center Home5b9fcbce19 NoPublic Utilities Address: 160Benin: EnergyBostonFacility | OpenCarboPur TechnologiesGeothermal Lab Call Project |

42

SEISMIC AND ROCK PHYSICS DIAGNOSTICS OF MULTISCALE RESERVOIR TEXTURES  

SciTech Connect (OSTI)

As part of our study on ''Relationships between seismic properties and rock microstructure'', we have studied (1) Methods for detection of stress-induced velocity anisotropy in sands. (2) We have initiated efforts for velocity upscaling to quantify long-wavelength and short-wavelength velocity behavior and the scale-dependent dispersion caused by sediment variability in different depositional environments.

Gary Mavko

2003-06-30T23:59:59.000Z

43

INTEGRATED OUTCROP AND SUBSURFACE STUDIES OF THE INTERWELL ENVIRONMENT OF CARBONATE RESERVOIRS: CLEAR FORK (LEONARDIAN-AGE) RESERVOIRS, WEST TEXAS AND NEW MEXICO  

SciTech Connect (OSTI)

This is the final report of the project ''Integrated Outcrop and Subsurface Studies of the Interwell Environment of Carbonate Reservoirs: Clear Fork (Leonardian-Age) Reservoirs, West Texas and New Mexico'', Department of Energy contract no. DE-AC26-98BC15105 and is the third in a series of similar projects funded jointly by the U.S. Department of Energy and The University of Texas at Austin, Bureau of Economic Geology, Reservoir Characterization Research Laboratory for Carbonates. All three projects focus on the integration of outcrop and subsurface data for the purpose of developing improved methods for modeling petrophysical properties in the interwell environment. The first project, funded by contract no. DE-AC22-89BC14470, was a study of San Andres outcrops in the Algerita Escarpment, Guadalupe Mountains, Texas and New Mexico, and the Seminole San Andres reservoir, Permian Basin. This study established the basic concepts for constructing a reservoir model using sequence-stratigraphic principles and rock-fabric, petrophysical relationships. The second project, funded by contract no. DE-AC22-93BC14895, was a study of Grayburg outcrops in the Brokeoff Mountains, New Mexico, and the South Cowden Grayburg reservoir, Permian Basin. This study developed a sequence-stratigraphic succession for the Grayburg and improved methods for locating remaining hydrocarbons in carbonate ramp reservoirs. The current study is of the Clear Fork Group in Apache Canyon, Sierra Diablo Mountains, West Texas, and the South Wasson Clear Fork reservoir, Permian Basin. The focus was on scales of heterogeneity, imaging high- and low-permeability layers, and the impact of fractures on reservoir performance. In this study (1) the Clear Fork cycle stratigraphy is defined, (2) important scales of petrophysical variability are confirmed, (3) a unique rock-fabric, petrophysical relationship is defined, (4) a porosity method for correlating high-frequency cycles and defining rock-fabric flow layers is described, (5) Clear Fork fractures are described and geomechanical modeling of fractures is investigated, and (6) most importantly, new statistical methods are developed for scaleup of petrophysical properties from the core to the layer scale and for retaining stratigraphic layering in simulation models.

F. Jerry Lucia

2002-01-31T23:59:59.000Z

44

Exploration model for shallow Silurian (Kankakee) carbonate reservoirs in western Illinois  

SciTech Connect (OSTI)

Reservoirs in shallow (600-650 ft deep) basal Silurian Kankakee carbonates at Buckhorn consolidated, Siloam, and Kellerville oil fields in western Illinois have produced nearly 2 million bbl of oil, but were developed essentially by random drilling. A new exploration model that combines lithologic studies and isopach mapping has been developed at the Illinois State Geological Survey. Isopach mapping of Silurian and Devonian rocks between an organic facies in the Mississippian-Devonian New Albany Shale and the top of the Ordovician Maquoketa Shale reveals thickened sequences that coincide with most of the oil fields. These thickened intervals apparently reflect subtle paleovalleys eroded into the Maquoketa shale during the Ordovician-Silurian hiatus. During the initial Silurian marine transgression, these paleovalleys at the base of the Kankakee were filled with carbonates to form the thickened sequences. Differential erosion at the top of the Kankakee does not satisfactorily explain the locally thickened sequences in the Kankakee. Lithologic studies suggest that subsurface fluid flows concentrated along these paleovalleys contributed to subsequent diagenesis of valleyfill carbonates. Diagenetic alteration of these carbonates resulted in development of basal Kankakee reservoirs within the paleovalleys. This concept of Kankakee reservoirs occurring within paleovalleys at the Ordovician-Silurian unconformity is a new exploration model that can aid in the search for similar traps in western Illinois.

Crockett, J.E.; Seyler, B.J.; Whitaker, S.

1987-09-01T23:59:59.000Z

45

SCREENING METHODS FOR SELECTION OF SURFACTANT FORMULATIONS FOR IOR FROM FRACTURED CARBONATE RESERVOIRS  

SciTech Connect (OSTI)

This topical report presents details of the laboratory work performed to complete Task 1 of this project; developing rapid screening methods to assess surfactant performance for IOR (Improved Oil Recovery) from fractured carbonate reservoirs. The desired outcome is to identify surfactant formulations that increase the rate and amount of aqueous phase imbibition into oil-rich, oil-wet carbonate reservoir rock. Changing the wettability from oil-wet to water-wet is one key to enhancing this water-phase imbibition process that in turn recovers additional oil from the matrix portion of a carbonate reservoir. The common laboratory test to evaluate candidate surfactant formulations is to measure directly the aqueous imbibition rate and oil recovery from small outcrop or reservoir cores, but this procedure typically requires several weeks. Two methods are presented here for the rapid screening of candidate surfactant formulations for their potential IOR performance in carbonate reservoirs. One promising surfactant screening protocol is based on the ability of a surfactant solution to remove aged crude oil that coats a clear calcite crystal (Iceland Spar). Good surfactant candidate solutions remove the most oil the quickest from the chips, plus change the apparent contact angle of the remaining oil droplets on the surface that thereby indicate increased water-wetting. The other fast surfactant screening method is based on the flotation behavior of powdered calcite in water. In this test protocol, first the calcite power is pre-treated to make the surface oil-wet. The next step is to add the pre-treated powder to a test tube and add a candidate aqueous surfactant formulation; the greater the percentage of the calcite that now sinks to the bottom rather than floats, the more effective the surfactant is in changing the solids to become now preferentially water-wet. Results from the screening test generally are consistent with surfactant performance reported in the literature.

William A. Goddard III; Yongchun Tang; Patrick Shuler; Mario Blanco; Yongfu Wu; Seung Soon Jang

2005-07-01T23:59:59.000Z

46

Electrolyte reservoir for carbonate fuel cells  

DOE Patents [OSTI]

An electrode for a carbonate fuel cell and method of making same are described wherein a substantially uniform mixture of an electrode-active powder and porous ceramic particles suitable for a carbonate fuel cell are formed into an electrode with the porous ceramic particles having pores in the range of from about 1 micron to about 3 microns, and a carbonate electrolyte is in the pores of the ceramic particles.

Iacovangelo, C.D.; Shores, D.A.

1984-05-23T23:59:59.000Z

47

Multi-Attribute Seismic/Rock Physics Approach to Characterizing Fractured Reservoirs  

SciTech Connect (OSTI)

Most current seismic methods to seismically characterize fractures in tight reservoirs depend on a few anisotropic wave propagation signatures that can arise from aligned fractures. While seismic anisotropy can be a powerful fracture diagnostic, a number of situations can lessen its usefulness or introduce interpretation ambiguities. Fortunately, laboratory and theoretical work in rock physics indicates that a much broader spectrum of fracture seismic signatures can occur, including a decrease in P- and S-wave velocities, a change in Poisson's ratio, an increase in velocity dispersion and wave attenuation, as well as well as indirect images of structural features that can control fracture occurrence. The goal of this project was to demonstrate a practical interpretation and integration strategy for detecting and characterizing natural fractures in rocks. The approach was to exploit as many sources of information as possible, and to use the principles of rock physics as the link among seismic, geologic, and log data. Since no single seismic attribute is a reliable fracture indicator in all situations, the focus was to develop a quantitative scheme for integrating the diverse sources of information. The integrated study incorporated three key elements: The first element was establishing prior constraints on fracture occurrence, based on laboratory data, previous field observations, and geologic patterns of fracturing. The geologic aspects include analysis of the stratigraphic, structural, and tectonic environments of the field sites. Field observations and geomechanical analysis indicates that fractures tend to occur in the more brittle facies, for example, in tight sands and carbonates. In contrast, strain in shale is more likely to be accommodated by ductile flow. Hence, prior knowledge of bed thickness and facies architecture, calibrated to outcrops, are powerful constraints on the interpreted fracture distribution. Another important constraint is that fracturing is likely to be more intense near faults--sometimes referred to as the damaged zone. Yet another constraint, based on world-wide observations, is that the maximum likely fracture density increases with depth in a well-defined way. Defining these prior constrains has several benefits: they lead to a priori probability distributions of fractures, that are important for objective statistical integration; they limit the number of geologic hypotheses that need to be theoretically modeled; they provide plausible models for fracture distributions below the seismic resolution. The second element was theoretical rock physics modeling of optimal seismic attributes, including offset and azimuth dependence of traveltime, amplitude, and impedance signatures of anisotropic fractured rocks. The suggested workflow is to begin with an elastic earth model, based on well logs, theoretically add fractures to the likely facies as defined by the geologic prior information, and then compute synthetic seismic traces and attributes, including variations in P and S-wave velocities, Poisson's ratio, reflectivity, travel time, attenuation, and anisotropies of these parameters. This workflow is done in a Monte-Carlo fashion, yielding ranges of expected fracture signatures, and allowing realistic assessments of uncertainty to be honored. The third element was statistical integration of the geophysical data and prior constraints to map fracture intensity and orientations, along with uncertainties. A Bayesian framework was developed that allowed systematic integration of the prior constraints, the theoretical relations between fractures and their seismic signatures, and the various observed seismic observations. The integration scheme was successfully applied on an East Texas field site. The primary benefit from the study was the optimization and refinement of practical workflows for improved geophysical characterization of natural fractures and for quantifying the uncertainty of these interpretations. By presenting a methodology for integrating various types of information, the workflow will

Gary Mavko

2004-11-30T23:59:59.000Z

48

A quantitative evaluation of effective shale content and its influence on electrical resistivity and permeability of reservoir rocks  

E-Print Network [OSTI]

A QUANTITATIVE EVALUATION OF EFFECTIVE SHALE CONTENT AND ITS INFLUENCE ON ELECTRICAL RESISTIVITY AND PERMEABILITY OF RESERVOIR ROCKS A Thesis By PARAYATH E. B. MENON Submitted to the Graduate College of Texas ASM University in Partial... fulfillment of the Requirements for the Degree of MASTER OF SCIENCE January, f965 Major Subject: Petroleum Engineering A QUANTITATIVE EVALUATION OF EFFECTIVE SHALE CONTENT AND ITS INFLUENCE ON ELECTRICAL RESISTIVITY AND PERMEABILITY OF RESERVOIR ROCKS...

Menon, Parayath Eravi Bhaskara

1965-01-01T23:59:59.000Z

49

Exploring an Unstructured Lattice Representation for Carbonate Reservoir Characterization  

E-Print Network [OSTI]

carbonates via a lattice-network of pore-volumes connected in space in directions and connectivity properties driven by the rock fabric, as opposed to being limited by the rigid geometry of grid-blocks. With this goal in mind, some aspects related to a...

Pasumarti, Lakshmi

2014-05-19T23:59:59.000Z

50

Mining earth's heat: development of hot-dry-rock geothermal reservoirs  

SciTech Connect (OSTI)

The energy-extraction concept of the Hot Dry Rock (HDR) Geothermal Program, as initially developed by the Los Alamos National Laboratory, is to mine this heat by creating a man-made reservoir in low-permeability, hot basement rock. This concept has been successfully proven at Fenton Hill in northern New Mexico by drilling two holes to a depth of approximately 3 km (10,000 ft) and a bottom temperature of 200/sup 0/C (392/sup 0/F), then connecting the boreholes with a large-diametervertical hydraulic fracture. Water is circulated down one borehole, heated by the hot rock, and rises up the second borehole to the surface where the heat is extracted and the cooled water is reinjected into the underground circulation loop. This system has operated for a cumulative 416 days during engineering and reservoir testing. An energy equivalent of 3 to 5 MW(t) was produced without adverse environmental problems. During one test, a generator was installed in the circulation loop and produced 60 kW of electricity. A second-generation system, recently drilled to 4.5 km (15,000 ft) and temperatures of 320/sup 0/C (608/sup 0/F), entails creating multiple, parallel fractures between a pair of inclined boreholes. This system should produce 5 to 10 MW(e) for 20 years. Significant contributions to underground technology have been made through the development of the program.

Pettitt, R.A.; Becker, N.M.

1983-01-01T23:59:59.000Z

51

Application of Reservoir Characterization and Advanced Technology to Improve Recovery and Economics in a Lower Quality Shallow Shelf Carbonate Reservoir  

SciTech Connect (OSTI)

The Class 2 Project at West Welch was designed to demonstrate the use of advanced technologies to enhance the economics of improved oil recovery (IOR) projects in lower quality Shallow Shelf Carbonate (SSC) reservoirs, resulting in recovery of additional oil that would otherwise be left in the reservoir at project abandonment. Accurate reservoir description is critical to the effective evaluation and efficient design of IOR projects in the heterogeneous SSC reservoirs. Therefore, the majority of Budget Period 1 was devoted to reservoir characterization. Technologies being demonstrated include: (1) Advanced petrophysics; (2) Three dimensional (3-D) seismic; (3) Cross-well bore tomography; (4) Advanced reservoir simulation; (5) Carbon dioxide (CO{sub 2}) stimulation treatments; (6) Hydraulic fracturing design and monitoring; and (7) Mobility control agents.

Taylor, Archie R.

1996-07-01T23:59:59.000Z

52

Estimating rock properties in two phase petroleum reservoirs: an error analysis  

E-Print Network [OSTI]

. 60x10 1. 16x10 4. 16x10 1. 01 9. 13x10 1. 51 2. 07%10 6. 51x10 5. 42x10 8. 18 3. 16x10 26 function approximated in the tt parameter space gives a mean prediction error which is essentially zero. However, using the permeability estimates obtained.... G ver (Mem er) . L. Curry . D. Ho land ( d of Department) December 1983 ABSTRACT Estimating Rock Properties In Two Phase Petroleum Reservoirs: An Error Analysis. (December 1983) Anthony Ian Paul B. Sc. , Imperial College, London University...

Paul, Anthony Ian

1983-01-01T23:59:59.000Z

53

Study of dissolved organic matter in peatlands: molecular characterisation of a dynamic carbon reservoir   

E-Print Network [OSTI]

Northern peatlands represent a significant carbon reservoir, containing approximately a third of the terrestrial carbon pool. The stability of these carbon stores is poorly understood, and processes of accumulation and ...

Ridley, Luke McDonald

2014-06-30T23:59:59.000Z

54

WETTABILITY ALTERATION OF CARBONATE ROCK MEDIATED BY BIOSURFACTANT PRODUCED FROM HIGH-STARCH AGRICULTURAL EFFLUENTS  

SciTech Connect (OSTI)

Surfactants can be used to alter wettability of reservoir rock, increasing spontaneous imbibition and thus improving oil yields. Commercial synthetic surfactants are often prohibitively expensive and so a crude preparation of the anionic biosurfactant, surfactin, from Bacillus subtilis grown on high-starch industrial and agricultural effluents has been proposed as an economical alternative. To assess the effectiveness of the surfactin, it is compared to commercially available surfactants. In selecting a suitable benchmark surfactant, two metrics are examined: the ability of the surfactants to alter wettability at low concentrations, and the degree to which they are absorbed onto reservoir matrix. We review the literature to survey the adsorption models that have been developed to describe surfactant adsorption in porous media. These models are evaluated using the experimental data from this study. Crushed carbonate rock samples are cleaned and aged in crude oil. The wettability change mediated by dilute solutions of commercial anionic surfactants and surfactin is assessed using a two-phase separation; and surfactant loss due to retention and adsorption the rock is determined.

Mehdi Salehi; Stephen Johnson; Gregory Bala; Jenn-Tai Liang

2006-09-01T23:59:59.000Z

55

Fracture Dissolution of Carbonate Rock: An Innovative Process for Gas Storage  

SciTech Connect (OSTI)

The goal of the project is to develop and assess the feasibility and economic viability of an innovative concept that may lead to commercialization of new gas-storage capacity near major markets. The investigation involves a new approach to developing underground gas storage in carbonate rock, which is present near major markets in many areas of the United States. Because of the lack of conventional gas storage and the projected growth in demand for storage capacity, many of these areas are likely to experience shortfalls in gas deliverability. Since depleted gas reservoirs and salt formations are nearly non-existent in many areas, alternatives to conventional methods of gas storage are required. The need for improved methods of gas storage, particularly for ways to meet peak demand, is increasing. Gas-market conditions are driving the need for higher deliverability and more flexibility in injection/withdrawal cycling. In order to meet these needs, the project involves an innovative approach to developing underground storage capacity by creating caverns in carbonate rock formations by acid dissolution. The basic concept of the acid-dissolution method is to drill to depth, fracture the carbonate rock layer as needed, and then create a cavern using an aqueous acid to dissolve the carbonate rock. Assessing feasibility of the acid-dissolution method included a regional geologic investigation. Data were compiled and analyzed from carbonate formations in six states: Indiana, Ohio, Kentucky, West Virginia, Pennsylvania, and New York. To analyze the requirements for creating storage volume, the following aspects of the dissolution process were examined: weight and volume of rock to be dissolved; gas storage pressure, temperature, and volume at depth; rock solubility; and acid costs. Hydrochloric acid was determined to be the best acid to use because of low cost, high acid solubility, fast reaction rates with carbonate rock, and highly soluble products (calcium chloride) that allow for the easy removal of calcium waste from the well. Physical and chemical analysis of core samples taken from prospective geologic formations for the acid dissolution process confirmed that many of the limestone samples readily dissolved in concentrated hydrochloric acid. Further, some samples contained oily residues that may help to seal the walls of the final cavern structure. These results suggest that there exist carbonate rock formations well suited for the dissolution technology and that the presence of inert impurities had no noticeable effect on the dissolution rate for the carbonate rock. A sensitivity analysis was performed for characteristics of hydraulic fractures induced in carbonate formations to enhance the dissolution process. Multiple fracture simulations were conducted using modeling software that has a fully 3-D fracture geometry package. The simulations, which predict the distribution of fracture geometry and fracture conductivity, show that the stress difference between adjacent beds is the physical property of the formations that has the greatest influence on fracture characteristics by restricting vertical growth. The results indicate that by modifying the fracturing fluid, proppant type, or pumping rate, a fracture can be created with characteristics within a predictable range, which contributes to predicting the geometry of storage caverns created by acid dissolution of carbonate formations. A series of three-dimensional simulations of cavern formation were used to investigate three different configurations of the acid-dissolution process: (a) injection into an open borehole with production from that same borehole and no fracture; (b) injection into an open borehole with production from that same borehole, with an open fracture; and (c) injection into an open borehole connected by a fracture to an adjacent borehole from which the fluids are produced. The two-well configuration maximizes the overall mass transfer from the rock to the fluid, but it results in a complex cavern shape. Numerical simulations were performed to evalua

James W. Castle; Ronald W. Falta; David Bruce; Larry Murdoch; Scott E. Brame; Donald Brooks

2006-10-31T23:59:59.000Z

56

Extreme organic carbon burial fuels intense methane bubbling in a temperate reservoir  

E-Print Network [OSTI]

Extreme organic carbon burial fuels intense methane bubbling in a temperate reservoir Sebastian. Wehrli (2012), Extreme organic carbon burial fuels intense methane bubbling in a temperate reservoir; revised 25 November 2011; accepted 30 November 2011; published 4 January 2012. [1] Organic carbon (OC

Wehrli, Bernhard

57

Carbon sequestration in leaky reservoirs Alain Jean-Marie, INRIA and UMR LIRMM  

E-Print Network [OSTI]

Carbon sequestration in leaky reservoirs Alain Jean-Marie, INRIA and UMR LIRMM Michel Moreaux, February 2, 2011 Abstract We propose in this paper a model of optimal Carbon Capture and Storage in which the reservoir of sequestered carbon is leaky, and pollution eventually is released into the atmosphere. We

Boyer, Edmond

58

Tracer Fluid Flow through Porous Media: Theory Applied to Acid Stimulation Treatments in Carbonate Rocks  

E-Print Network [OSTI]

Most carbonate rocks are heterogeneous at multiple length scales. These heterogeneities strongly influence the outcome of the acid stimulation treatments which are routinely performed to improve well productivity. At the pore scale, carbonate rocks...

Zakaria Mohamed Reda, Ahmed

2014-07-29T23:59:59.000Z

59

A comparison of two heat transfer models for estimating thermal drawdown in Hot Dry Rock reservoirs  

SciTech Connect (OSTI)

Estimates of thermal drawdown in Hot Dry Rock geothermal systems have been made with two different models of heat transfer from hydraulically fractured reservoir rock blocks to water circulated through the fracture permeability. One model is based on deconvolution of experimental tracer response curves into a network of flowpaths connected in parallel with heat transfer calculated individually in each flowpath. The second model is based on one-dimensional flow through the rock with a block size distribution described as a group of equivalent-radius spheres for which the heat transfer equations can be solved analytically. The two models were applied to the planned Phase II long-term thermal drawdown experiment at Fenton Hill, NM. The results show good agreement between the two models, with estimates of temperature cooldown from 240ºC to 150ºC in a few years depending on selected operation parameters, but with somewhat differing cooldown curve characteristic shapes. Data from the long-term experiment will be helpful in improving the two models.

Robinson, Bruce A.; Kruger, Paul

1988-01-01T23:59:59.000Z

60

Impact of carbon dioxide sequestration in depleted gas-condensate reservoirs.  

E-Print Network [OSTI]

??Depleted gas-condensate reservoirs are becoming important targets for carbon dioxide sequestration. Since depleted below the dew point, retrograde condensate has been deposited in the pore… (more)

Ramharack, Richard M.

2010-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "reservoir rock carbon" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


61

Mathematical and Statistical Investigation of Steamflooding in Naturally Fractured Carbonate Heavy Oil Reservoirs.  

E-Print Network [OSTI]

??A significant amount of Viscous Oil (e.g., heavy oil, extra heavy oil, and bitumen) is trapped in Naturally Fractured Carbonate Reservoirs also known as NFCRs.… (more)

Shafiei, Ali

2013-01-01T23:59:59.000Z

62

Actualistic and Geochemical Modeling of Reservoir Rock, CO2 and Formation Fluid Interaction, Citronelle Oil Field, Alabama  

SciTech Connect (OSTI)

This report includes description of the Citronelle field study area and the work carried out in the project to characterize the geology and composition of reservoir rock material and to collect an analyze the geochemical composition of produced fluid waters from the Citronelle field. Reservoir rock samples collected from well bore core were made into thin-sections and assessed for textural properties, including pore types and porosity distribution. Compositional framework grain modal data were collected via point-counting, and grain and cement mineralogy was assessed using SEM-EDS. Geochemistry of fluid samples is described and modeled using PHREEQC. Composition of rock and produced fluids were used as inputs for TOUGHREACT reactive transport modeling, which determined the rock-fluid system was in disequilibrium.

Weislogel, Amy

2014-01-31T23:59:59.000Z

63

Supercritical Carbon Dioxide / Reservoir Rock Chemical Interactions | Open  

Open Energy Info (EERE)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data CenterFranconia, Virginia:FAQ < RAPID Jump to:Seadov Pty LtdSteen, Minnesota:36052°,Sunfield,Farms BiomassSunwattEnergy Information

64

PUBLISHED ONLINE: 31 JULY 2011 | DOI: 10.1038/NGEO1211 Carbon emission from hydroelectric reservoirs  

E-Print Network [OSTI]

LETTERS PUBLISHED ONLINE: 31 JULY 2011 | DOI: 10.1038/NGEO1211 Carbon emission from hydroelectric * Hydroelectric reservoirs cover an area of 3.4 Ã? 105 km2 and comprise about 20% of all reservoirs. In addition dioxide and methane from hydroelectric reservoirs, on the basis of data from 85 globally distributed

65

Rock failure during massive hydraulic stimulation of the Baca location geothermal reservoir  

SciTech Connect (OSTI)

The analyses of microearthquake signals occurring during hydraulic stimulation provide an estimate of the size and location of the fractures thus produced. Studies of microearthquakes occurring during two large (> 10/sup 3/m/sup 3/) hydraulic stimulations of the hydrothermal reservoir at the Baca Location in the Jemez Mountains of northeastern New Mexico are reported. Both stimulations consisted of water, viscosity enhancer, and proppant. The microearthquake event rate was low but variable throughout most of the treatment. Rock failure as indicated by the distribution of the microearthquakes' foci appeared restricted to a nearly vertical NE striking zone. This orientation is in good agreement with the local earth stresses inferred from geological considerations. The second stimulation which occurred in a neighboring well was similar to the first except for a larger injected volume. The lateral extent of the detected fracture system was 600 m in both stimulations.

Pearson, C.; Keppler, H.; Albright, J.; Potter, R.

1982-01-01T23:59:59.000Z

66

Development of Chemical Model to Predict the Interactions between Supercritical CO2and Fluid, and Rocks in EGS Reservoirs  

Broader source: Energy.gov [DOE]

This project will develop a chemical model, based on existing models and databases, that is capable of simulating chemical reactions between supercritical (SC) CO2 and Enhanced Geothermal System (EGS) reservoir rocks of various compositions in aqueous, non-aqueous and 2-phase environments.

67

Reservoir Simulation and Evaluation of the Upper Jurassic Smackover Microbial Carbonate and Grainstone-Packstone Reservoirs in Little Cedar Creek Field, Conecuh County, Alabama  

E-Print Network [OSTI]

This thesis presents an integrated study of mature carbonate oil reservoirs (Upper Jurassic Smackover Formation) undergoing gas injection in the Little Cedar Creek Field located in Conecuh County, Alabama. This field produces from two reservoirs...

Mostafa, Moetaz Y

2013-04-25T23:59:59.000Z

68

Modeling wettability alteration in naturally fractured carbonate reservoirs.  

E-Print Network [OSTI]

??The demand for energy and new oil reservoirs around the world has increased rapidly while oil recovery from depleted reservoirs has become more difficult. Oil… (more)

Goudarzi, Ali

2012-01-01T23:59:59.000Z

69

The net carbon footprint of a newly created boreal hydroelectric reservoir  

E-Print Network [OSTI]

The net carbon footprint of a newly created boreal hydroelectric reservoir Cristian R. Teodoru,1 of a boreal hydroelectric reservoir (Eastmain-1 in northern Québec, Canada). This is the result of a large. Citation: Teodoru, C. R., et al. (2012), The net carbon footprint of a newly created boreal hydroelectric

Long, Bernard

70

Geological controls on gas accumulation in a unique Zechstein carbonate reservoir  

E-Print Network [OSTI]

potentially contribute and combine favourably to Wissey's reservoir quality and gas reserves. It is nowGeological controls on gas accumulation in a unique Zechstein carbonate reservoir Craig Duguid, The King's Buildings, West Mains Road, Edinburgh, EH9 3JW, Scotland, UK Email: S0567834@sms.ed.ac.uk Gas

71

Integrated Analysis and Application of Reservoir Models to Early Permian Detrital Carbonate Deposits, Midland Basin, Texas  

E-Print Network [OSTI]

A 3-D seismic volume, wireline logs and core data were integrated to determine the spatial distribution of porous reservoirs within the Wolfcampian-Leonardian detrital carbonate slope and basin strata in Glasscock County, Texas. A 3-D seismic...

Johnston, Travis Wayne 1987-

2012-11-01T23:59:59.000Z

72

Experimental and simulation studies of sequestration of supercritical carbon dioxide in depleted gas reservoirs  

E-Print Network [OSTI]

he feasibility of sequestering supercritical CO2 in depleted gas reservoirs. The experimental runs involved the following steps. First, the 1 ft long by 1 in. diameter carbonate core is inserted into a viton Hassler sleeve and placed inside...

Seo, Jeong Gyu

2004-09-30T23:59:59.000Z

73

Electrical vs. Hydraulic Rock Types in Clastic Reservoirs: Pore-Scale Understanding Verified with Field Observations in the Gulf of Mexico, U.S.  

E-Print Network [OSTI]

with Field Observations in the Gulf of Mexico, U.S. Chicheng Xu*, Carlos Torres-Verdín, and Shuang Gao of turbidite oil reservoir in the Gulf of Mexico shows that inclusion of resistivity logs in the classification oil reservoir in the Gulf of Mexico, US. Electrical and Hydraulic Conductivity Models In a porous rock

Torres-Verdín, Carlos

74

Reservoir condition special core analyses and relative permeability measurements on Almond formation and Fontainebleu sandstone rocks  

SciTech Connect (OSTI)

This report describes the results from special core analyses and relative permeability measurements conducted on Almond formation and Fontainebleu sandstone plugs. Almond formation plug tests were performed to evaluate multiphase, steady-state,reservoir-condition relative permeability measurement techniques and to examine the effect of temperature on relative permeability characteristics. Some conclusions from this project are as follows: An increase in temperature appeared to cause an increase in brine relative permeability results for an Almond formation plug compared to room temperature results. The plug was tested using steady-state oil/brine methods. The oil was a low-viscosity, isoparaffinic refined oil. Fontainebleu sandstone rock and fluid flow characteristics were measured and are reported. Most of the relative permeability versus saturation results could be represented by one of two trends -- either a k{sub rx} versus S{sub x} or k{sub rx} versus Sy trend where x and y are fluid phases (gas, oil, or brine). An oil/surfactant-brine steady-state relative permeability test was performed to examine changes in oil/brine relative permeability characteristics from changes in fluid IFTS. It appeared that, while low interfacial tension increased the aqueous phase relative permeability, it had no effect on the oil relative permeability. The BOAST simulator was modified for coreflood simulation. The simulator was useful for examining effects of variations in relative permeability and capillary pressure functions. Coreflood production monitoring and separator interface level measurement techniques were developed using X-ray absorption, weight methods, and RF admittance technologies. The three types of separators should be useful for routine and specialized core analysis applications.

Maloney, D.

1993-11-01T23:59:59.000Z

75

The Effect of Acid Additives on Carbonate Rock Wettability and Spent Acid Recovery in Low Permeability Gas Carbonates  

E-Print Network [OSTI]

Spent acid retention in the near-wellbore region causes reduction of relative permeability to gas and eventually curtailed gas production. In low-permeability gas carbonate reservoirs, capillary forces are the key parameters that affect the trapping...

Saneifar, Mehrnoosh

2012-10-19T23:59:59.000Z

76

Geophysical and transport properties of reservoir rocks. Final report for task 4: Measurements and analysis of seismic properties  

SciTech Connect (OSTI)

The principal objective of research on the seismic properties of reservoir rocks is to develop a basic understanding of the effects of rock microstructure and its contained pore fluids on seismic velocities and attenuation. Ultimately, this knowledge would be used to extract reservoir properties information such as the porosity, permeability, clay content, fluid saturation, and fluid type from borehole, cross-borehole, and surface seismic measurements to improve the planning and control of oil and gas recovery. This thesis presents laboratory ultrasonic measurements for three granular materials and attempts to relate the microstructural properties and the properties of the pore fluids to P- and S-wave velocities and attenuation. These experimental results show that artificial porous materials with sintered grains and a sandstone with partially cemented grains exhibit complexities in P- and S-wave attenuation that cannot be adequately explained by existing micromechanical theories. It is likely that some of the complexity observed in the seismic attenuation is controlled by details of the rock microstructure, such as the grain contact area and grain shape, and by the arrangement of the grain packing. To examine these effects, a numerical method was developed for analyzing wave propagation in a grain packing. The method is based on a dynamic boundary integral equation and incorporates generalized stiffness boundary conditions between individual grains to account for viscous losses and grain contact scattering.

Cook, N.G.W.

1993-05-01T23:59:59.000Z

77

Geochemistry of silicate-rich rocks can curtail spreading of carbon dioxide in subsurface aquifers  

E-Print Network [OSTI]

of carbon sequestration and dissolution rates in the subsurface, suggesting that pooled carbon dioxide may remain in the shallower regions of the formation for hundreds to thousands of years. The deeper regions of the reservoir can remain virtually carbon... interests. References 1. Marini, L. Geochemical Sequestration of Carbon Dioxide. (Elsevier 2007). 2. IPCC Special Report on Carbon Dioxide Capture and Storage, edited by Metz B. et al. (Cambridge University Press, UK and New York, USA, 2005). 3. Falkowski...

Cardoso, S. S. S.; Andres, J. T. H.

2014-12-11T23:59:59.000Z

78

IMPROVED OIL RECOVERY IN MISSISSIPPIAN CARBONATE RESERVOIRS OF KANSAS - NEAR TERM - CLASS 2  

SciTech Connect (OSTI)

This annual report describes progress during the final year of the project entitled ''Improved Oil Recovery in Mississippian Carbonate Reservoirs in Kansas''. This project funded under the Department of Energy's Class 2 program targets improving the reservoir performance of mature oil fields located in shallow shelf carbonate reservoirs. The focus of the project was development and demonstration of cost-effective reservoir description and management technologies to extend the economic life of mature reservoirs in Kansas and the mid-continent. As part of the project, tools and techniques for reservoir description and management were developed, modified and demonstrated, including PfEFFER spreadsheet log analysis software. The world-wide-web was used to provide rapid and flexible dissemination of the project results through the Internet. A summary of demonstration phase at the Schaben and Ness City North sites demonstrates the effectiveness of the proposed reservoir management strategies and technologies. At the Schaben Field, a total of 22 additional locations were evaluated based on the reservoir characterization and simulation studies and resulted in a significant incremental production increase. At Ness City North Field, a horizontal infill well (Mull Ummel No.4H) was planned and drilled based on the results of reservoir characterization and simulation studies to optimize the location and length. The well produced excellent and predicted oil rates for the first two months. Unexpected presence of vertical shale intervals in the lateral resulted in loss of the hole. While the horizontal well was not economically successful, the technology was demonstrated to have potential to recover significant additional reserves in Kansas and the Midcontinent. Several low-cost approaches were developed to evaluate candidate reservoirs for potential horizontal well applications at the field scale, lease level, and well level, and enable the small independent producer to identify efficiently candidate reservoirs and also to predict the performance of horizontal well applications.

Timothy R. Carr; Don W. Green; G. Paul Willhite

2000-04-30T23:59:59.000Z

79

Determination of the Effect of Geological Reservoir Variability on Carbon Dioxide Storage  

E-Print Network [OSTI]

Determination of the Effect of Geological Reservoir Variability on Carbon Dioxide Storage Using'expériences -- Dans le contexte de l'étude du stockage géologique du dioxyde de carbone dans les réservoirs al. (2007) Energy Convers. Manage. 48, 1782-1797; Gunter et al. (1999) Appl. Geochem. 4, 1

Paris-Sud XI, Université de

80

Non-parametric regression and neural-network inll drilling recovery models for carbonate reservoirs  

E-Print Network [OSTI]

, and operations e- ciency. Consequent to the primary recovery, water- ¯ood is often used as a secondary recoveryNon-parametric regression and neural-network in®ll drilling recovery models for carbonate ultimate oil recovery from reservoirs in San Andres and Clearfork carbonate formations in West Texas

Valkó, Peter

Note: This page contains sample records for the topic "reservoir rock carbon" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


81

Well Productivity Enhancement of High Temperature Heterogeneous Carbonate Reservoirs  

E-Print Network [OSTI]

Acidizing is one of the most popular techniques for well productivity enhancement during oil and gas production. However, the treatment method is not very effective when the wellbore penetrates through multiple layers of heterogeneous reservoirs...

Wang, Guanqun

2014-05-08T23:59:59.000Z

82

Using Biosurfactants Produced from Agriculture Process Waste Streams to Improve Oil Recovery in Fractured Carbonate Reservoirs  

SciTech Connect (OSTI)

This report describes the progress of our research during the first 30 months (10/01/2004 to 03/31/2007) of the original three-year project cycle. The project was terminated early due to DOE budget cuts. This was a joint project between the Tertiary Oil Recovery Project (TORP) at the University of Kansas and the Idaho National Laboratory (INL). The objective was to evaluate the use of low-cost biosurfactants produced from agriculture process waste streams to improve oil recovery in fractured carbonate reservoirs through wettability mediation. Biosurfactant for this project was produced using Bacillus subtilis 21332 and purified potato starch as the growth medium. The INL team produced the biosurfactant and characterized it as surfactin. INL supplied surfactin as required for the tests at KU as well as providing other microbiological services. Interfacial tension (IFT) between Soltrol 130 and both potential benchmark chemical surfactants and crude surfactin was measured over a range of concentrations. The performance of the crude surfactin preparation in reducing IFT was greater than any of the synthetic compounds throughout the concentration range studied but at low concentrations, sodium laureth sulfate (SLS) was closest to the surfactin, and was used as the benchmark in subsequent studies. Core characterization was carried out using both traditional flooding techniques to find porosity and permeability; and NMR/MRI to image cores and identify pore architecture and degree of heterogeneity. A cleaning regime was identified and developed to remove organic materials from cores and crushed carbonate rock. This allowed cores to be fully characterized and returned to a reproducible wettability state when coupled with a crude-oil aging regime. Rapid wettability assessments for crushed matrix material were developed, and used to inform slower Amott wettability tests. Initial static absorption experiments exposed limitations in the use of HPLC and TOC to determine surfactant concentrations. To reliably quantify both benchmark surfactants and surfactin, a surfactant ion-selective electrode was used as an indicator in the potentiometric titration of the anionic surfactants with Hyamine 1622. The wettability change mediated by dilute solutions of a commercial preparation of SLS (STEOL CS-330) and surfactin was assessed using two-phase separation, and water flotation techniques; and surfactant loss due to retention and adsorption on the rock was determined. Qualitative tests indicated that on a molar basis, surfactin is more effective than STEOL CS-330 in altering wettability of crushed Lansing-Kansas City carbonates from oil-wet to water-wet state. Adsorption isotherms of STEOL CS-330 and surfactin on crushed Lansing-Kansas City outcrop and reservoir material showed that surfactin has higher specific adsorption on these oomoldic carbonates. Amott wettability studies confirmed that cleaned cores are mixed-wet, and that the aging procedure renders them oil-wet. Tests of aged cores with no initial water saturation resulted in very little spontaneous oil production, suggesting that water-wet pathways into the matrix are required for wettability change to occur. Further investigation of spontaneous imbibition and forced imbibition of water and surfactant solutions into LKC cores under a variety of conditions--cleaned vs. crude oil-aged; oil saturated vs. initial water saturation; flooded with surfactant vs. not flooded--indicated that in water-wet or intermediate wet cores, sodium laureth sulfate is more effective at enhancing spontaneous imbibition through wettability change. However, in more oil-wet systems, surfactin at the same concentration performs significantly better.

Stephen Johnson; Mehdi Salehi; Karl Eisert; Sandra Fox

2009-01-07T23:59:59.000Z

83

INTEGRATED GEOLOGIC-ENGINEERING MODEL FOR REEF AND CARBONATE SHOAL RESERVOIRS ASSOCIATED WITH PALEOHIGHS: UPPER JURASSIC SMACKOVER FORMATION, NORTHEASTERN GULF OF MEXICO  

SciTech Connect (OSTI)

The University of Alabama, in cooperation with Texas A&M University, McGill University, Longleaf Energy Group, Strago Petroleum Corporation, and Paramount Petroleum Company, has undertaken an integrated, interdisciplinary geoscientific and engineering research project. The project is designed to characterize and model reservoir architecture, pore systems and rock-fluid interactions at the pore to field scale in Upper Jurassic Smackover reef and carbonate shoal reservoirs associated with varying degrees of relief on pre-Mesozoic basement paleohighs in the northeastern Gulf of Mexico. The project effort includes the prediction of fluid flow in carbonate reservoirs through reservoir simulation modeling which utilizes geologic reservoir characterization and modeling and the prediction of carbonate reservoir architecture, heterogeneity and quality through seismic imaging. The primary goal of the project is to increase the profitability, producibility and efficiency of recovery of oil from existing and undiscovered Upper Jurassic fields characterized by reef and carbonate shoals associated with pre-Mesozoic basement paleohighs. Geoscientific reservoir property, geophysical seismic attribute, petrophysical property, and engineering property characterization has shown that reef (thrombolite) and shoal reservoir lithofacies developed on the flanks of high-relief crystalline basement paleohighs (Vocation Field example) and on the crest and flanks of low-relief crystalline basement paleohighs (Appleton Field example). The reef thrombolite lithofacies have higher reservoir quality than the shoal lithofacies due to overall higher permeabilities and greater interconnectivity. Thrombolite dolostone flow units, which are dominated by dolomite intercrystalline and vuggy pores, are characterized by a pore system comprised of a higher percentage of large-sized pores and larger pore throats. Rock-fluid interactions (diagenesis) studies have shown that although the primary control on reservoir architecture and geographic distribution of Smackover reservoirs is the fabric and texture of the depositional lithofacies, diagenesis (chiefly dolomitization) is a significant factor that preserves and enhances reservoir quality. The evaporative pumping mechanism is favored to explain the dolomitization of the thrombolite doloboundstone and dolostone reservoir flow units at Appleton and Vocation Fields. Geologic modeling, reservoir simulation, and the testing and applying the resulting integrated geologic-engineering models have shown that little oil remains to be recovered at Appleton Field and a significant amount of oil remains to be recovered at Vocation Field through a strategic infill drilling program. The drive mechanisms for primary production in Appleton and Vocation Fields remain effective; therefore, the initiation of a pressure maintenance program or enhanced recovery project is not required at this time. The integrated geologic-engineering model developed for a low-relief paleohigh (Appleton Field) was tested for three scenarios involving the variables of present-day structural elevation and the presence/absence of potential reef thrombolite lithofacies. In each case, the predictions based upon the model were correct. From this modeling, the characteristics of the ideal prospect in the basement ridge play include a low-relief paleohigh associated with dendroidal/chaotic thrombolite doloboundstone and dolostone that has sufficient present-day structural relief so that these carbonates rest above the oil-water contact. Such a prospect was identified from the modeling, and it is located northwest of well Permit No. 3854B (Appleton Field) and south of well No. Permit No.11030B (Northwest Appleton Field).

Ernest A. Mancini

2004-02-25T23:59:59.000Z

84

Petrography and prediction of reservoir rock properties in the Sussex Sandstone, Powder River Basin, Wyoming  

E-Print Network [OSTI]

to determine rock composition and texture. Composition was established by point count of 100 grains. Framework grains were identified and counted as monocrystalline quartz, polycrystalline quartz, volcanic rock fragments, potassium feldspar, plagioclase... and quiet water deposition of shale was resumed. The sandstone is classified as a volcanic aronite based on a det: ital composition averaging 59 percent quartz, including both monccrystalline and polycrystalline varieties, 18 percent rock frag- ments...

Shirley, Richard Hoyt

1977-01-01T23:59:59.000Z

85

The environment of deposition and reservoir characterization of the Simpson Rocks (Middle Ordovician) at the Scully Field, Marion County, Kansas  

E-Print Network [OSTI]

undnf Sll undlh Ma uaketo m Galena Gp. Deep ah Shale a mr i lii. nwaod Fm St Peter Sandstone Shalmpee Fm Jordan/sl Lawrence Fms Doris Ffn wiwtteiYe Fm Mt Simoh Salldshwie 7 Figure 4. Generalized correlation chart of the Paleozoic... for individual wells. 80 INTRODUCIlON The lower Paleozoic rocks in the cratonic interior of North America are characterized by relatively thick sections of carbonate rocks separated by thin sections of quartzose sheet sandstones and rarely shales. The facies...

McRae, Martha Fay

1991-01-01T23:59:59.000Z

86

Sources and fluxes of carbon in a large boreal hydroelectric reservoir of eastern Canada: an isotopic approach  

E-Print Network [OSTI]

Sources and fluxes of carbon in a large boreal hydroelectric reservoir of eastern Canada Hydroelectric reservoirs emit greenhouse gases (GHGs). Although a few hypothesis have been put forward at the surface of a large boreal hydroelectric reservoir of eastern Canada (Robert-Bourassa) as well

Long, Bernard

87

Direct Prediction of the Absolute Permeability of Unconsolidated and Consolidated Reservoir Rock  

E-Print Network [OSTI]

SPE 90084 Direct Prediction of the Absolute Permeability of Unconsolidated and Consolidated unconsolidated rocks whose micro-tomographic images cannot be obtained. The lattice-Boltzmann method is used

Patzek, Tadeusz W.

88

Organic carbon sources and transformations in mangrove sediments: A Rock-Eval pyrolysis approach  

E-Print Network [OSTI]

Organic carbon sources and transformations in mangrove sediments: A Rock-Eval pyrolysis approach C'Orléans, CNRS/INSU, Université d'Orléans, 1A rue de la Férollerie, 45071 Orléans, France Abstract A Rock cycling in this specific environment using a method that allows monitoring the depth evolution of sources

Paris-Sud XI, Université de

89

Crosswell Seismic Amplitude-Versus-Offset for Detailed Imaging of Facies and Fluid Distribution within Carbonate Oil Reservoirs  

E-Print Network [OSTI]

Crosswell Seismic Amplitude-Versus-Offset for Detailed Imaging of Facies and Fluid Distribution within Carbonate Oil Reservoirs DOE Award Number: DE-FC26-04NT15508 Oct 2004 - Sep 2007 Michigan in carbonate reef reservoirs that are currently under production. This project will develop, test

90

Volumetric Curvature and Coherency Assisted Fault Mapping and Fracture Prediction of Carbonate Reservoir Huabei Field, North China  

E-Print Network [OSTI]

in carbonates, and are thus the focus of my investigation. With a 3D dataset and well data from the Huabei Field in North China, a carbonate reservoir is identified and interpreted through the field. We use the reservoir top depth to narrow our window...

Li, Allen

2014-08-10T23:59:59.000Z

91

Reservoir characters of the Ypresian carbonates, Western Libyan Offshore, Central Mediterranean Sea  

SciTech Connect (OSTI)

Significant hydrocarbon accumulations have been discovered in Western Libyan offshore in the Ypresian carbonate reservoirs of Jdeir Formation and Jirani Dolomite. The discoveries of hydrocarbons are mainly in structural traps where the Jdeir nummulitic facies and Jirani dolomitic facies B have been structured by salt domes or underlying positive fault blocks. This study investigates the relationship between environments of deposition, diagenesis and reservoir characters of the two main hydrocarbon producing units of the Jdeir and Jirani formations. Petrographic and petrophysical studies indicate that porosity in the Jirani Dolomite is related to diagenesis in meteoric environments, while in the Jdeir reservoir is the result of the environment of deposition and diagenesis. Excellent reservoir porosity of Jdeir nummulitic facies and Jirani dolomitic facies B is related to diagenesis in meteoric water during exposure to subaerial conditions which is considered to be due to lowering of sea level and possibly local uplifting.

Mriheel, I.Y. [Petroleum Research Centre, Tripoli (Libyan Arab Jamahiriya)

1995-08-01T23:59:59.000Z

92

Integration of Geology, Rock-Physics, Logs, and Pre-stack Seismic for Reservoir Porosity Estimation  

E-Print Network [OSTI]

The main objective of this paper is to obtain reservoir properties, such as porosity, both at the well locations and in the inter-well regions from seismic data and well logs. The seismic and well-log datasets are from an ...

Al Muhaidib, Abdulaziz

2011-01-01T23:59:59.000Z

93

3D multi-scale imaging of experimental fracture generation in shale gas reservoirs.  

E-Print Network [OSTI]

in research and shale unconventional reservoirs that will provide you with the skills to enter the oil and gas3D multi-scale imaging of experimental fracture generation in shale gas reservoirs. Supervisory-grained organic carbon-rich rocks (shales) are increasingly being targeted as shale gas "reservoirs". Due

Henderson, Gideon

94

Reservoir Characterization, Formation Evaluation, and 3D Geologic Modeling of the Upper Jurassic Smackover Microbial Carbonate Reservoir and Associated Reservoir Facies at Little Cedar Creek Field, Northeastern Gulf of Mexico  

E-Print Network [OSTI]

characterization, formation evaluation, and 3D geologic modeling provides a sound framework in the establishment of a field/reservoir-wide development plan for optimal primary and enhanced recovery for these Upper Jurassic microbial carbonate and associated...

Al Haddad, Sharbel

2012-10-19T23:59:59.000Z

95

Cost Effective Surfactant Formulations for Improved Oil Recovery in Carbonate Reservoirs  

SciTech Connect (OSTI)

This report summarizes work during the 30 month time period of this project. This was planned originally for 3-years duration, but due to its financial limitations, DOE halted funding after 2 years. The California Institute of Technology continued working on this project for an additional 6 months based on a no-cost extension granted by DOE. The objective of this project is to improve the performance of aqueous phase formulations that are designed to increase oil recovery from fractured, oil-wet carbonate reservoir rock. This process works by increasing the rate and extent of aqueous phase imbibition into the matrix blocks in the reservoir and thereby displacing crude oil normally not recovered in a conventional waterflood operation. The project had three major components: (1) developing methods for the rapid screening of surfactant formulations towards identifying candidates suitable for more detailed evaluation, (2) more fundamental studies to relate the chemical structure of acid components of an oil and surfactants in aqueous solution as relates to their tendency to wet a carbonate surface by oil or water, and (3) a more applied study where aqueous solutions of different commercial surfactants are examined for their ability to recover a West Texas crude oil from a limestone core via an imbibition process. The first item, regarding rapid screening methods for suitable surfactants has been summarized as a Topical Report. One promising surfactant screening protocol is based on the ability of a surfactant solution to remove aged crude oil that coats a clear calcite crystal (Iceland Spar). Good surfactant candidate solutions remove the most oil the quickest from the surface of these chips, plus change the apparent contact angle of the remaining oil droplets on the surface that thereby indicate increased water-wetting. The other fast surfactant screening method is based on the flotation behavior of powdered calcite in water. In this test protocol, first the calcite power is pre-treated to make the surface oil-wet. The next step is to add the pre-treated powder to a test tube and add a candidate aqueous surfactant formulation; the greater the percentage of the calcite that now sinks to the bottom rather than floats, the more effective the surfactant is in changing the solids to become now preferentially water-wet. Results from the screening test generally are consistent with surfactant oil recovery performance reported in the literature. The second effort is a more fundamental study. It considers the effect of chemical structures of different naphthenic acids (NA) dissolved in decane as model oils that render calcite surfaces oil-wet to a different degree. NAs are common to crude oil and are at least partially responsible for the frequent observation that carbonate reservoirs are oil-wet. Because pure NA compounds are used, trends in wetting behavior can be related to NA molecular structure as measured by solid adsorption, contact angle and our novel, simple flotation test with calcite. Experiments with different surfactants and NA-treated calcite powder provide information about mechanisms responsible for sought after reversal to a water-wet state. Key findings include: (1) more hydrophobic NA's are more prone to induce oil-wetting, and (2) recovery of the model oil from limestone core was better with cationic surfactants, but one nonionic surfactant, Igepal CO-530, also had favorable results. This portion of the project included theoretical calculations to investigate key basic properties of several NAs such as their acidic strength and their relative water/oil solubility, and relate this to their chemical structure. The third category of this project focused on the recovery of a light crude oil from West Texas (McElroy Field) from a carbonate rock (limestone outcrop). For this effort, the first item was to establish a suite of surfactants that would be compatible with the McElroy Field brine. Those were examined further for their ability to recover oil by imbibition. Results demonstrate several types of promising candida

William A. Goddard; Yongchun Tang; Patrick Shuler; Mario Blanco; Yongfu Wu

2007-09-30T23:59:59.000Z

96

The Effect of Heterogeneity on Matrix Acidizing of Carbonate Rocks  

E-Print Network [OSTI]

In matrix acidizing, the goal is to dissolve minerals in the rock to increase well productivity. This is accomplished by injecting an application-specific solution of acid into the formation at a pressure between the pore pressure and fracture...

Keys, Ryan S.

2010-07-14T23:59:59.000Z

97

Rocks  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE:1 First Use of Energy for All Purposes (Fuel and Nonfuel),Feet) Year Jan Feb Mar Apr May JunDatastreamsmmcrcalgovInstrumentsrucLas ConchasPassive Solar HomePromisingStories »SubmitterJ. NorbyN.Rocks Rocks Rocks have been

98

Experimental Study of Carbon Sequestration Reactions Controlled  

E-Print Network [OSTI]

Experimental Study of Carbon Sequestration Reactions Controlled by the Percolation of CO2-Rich. Carbonation of ultramafic rocks in geological reservoirs is, in theory, the most efficient way to trap CO2 irreversibly; however, possible feedback effects between carbonation reactions and changes in the reservoir

Demouchy, Sylvie

99

Tests of US rock salt for long-term stability of CAES reservoirs  

SciTech Connect (OSTI)

This is a report on laboratory tests to assess the effects of compressed air energy storage (CAES) on rock salt within the US. The project included a conventional laboratory test phase, with triaxial test machines, and a bench-scale test phase performed in salt mines in southern Louisiana. Limited numerical modeling also was performed to serve as a guide in selecting test layouts and for interpreting test data.

Gehle, R.M.; Thoms, R.L.

1986-01-01T23:59:59.000Z

100

Displacement of oil from reservoir rock using graded-viscosity water  

E-Print Network [OSTI]

of reservoir conditions. The objective of this paper was to investigate, in the dis- placement processes the effect on oil recovery of 1) A graded- viscosity bank as compared to that of a constant-viscosity bank. The two banks used had the same mass...- cosity. He compared his results with a constant-viscosity slug, having the same mass of polymer and found increased oil recov- eries from the graded-viscosity slug, in the displacement process. His concentration of polymer, however, were too high...

Al-Atigi, Yosef A

1974-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "reservoir rock carbon" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


101

Depositional and diagenetic history of some Jurassic carbonates, Indian Rock-Gilmer Field, Upshur County, Texas  

E-Print Network [OSTI]

that the origin of the paleostructure which pro- duced the shallow marine environments during Cotton Valley/Haynesvi lie deposition was a Paleozoic high. The Indian Rock-Gilmer Field was a shallow area in the Jurassic Cotton Valley/Haynesville sea situated...~ ~ ~ 0 '''j DEPOSITIONAL AND DIAGENETIC HISTORY OF SOME JURASSIC CARBONATES, INDIAN ROCK-GILMER FIELD, UPSHUR COUNTY, TEXAS A Thesis by STEVEN ANTHONY FALL Submitted to the Graduate College of Texas ASM University in partial fulfillment...

Fall, Steven Anthony

1974-01-01T23:59:59.000Z

102

A Rock Physics Based Investigation of Pore Structure Variations Associated with a CO2 Flood in a Clastic Reservoir, Delhi, LA  

E-Print Network [OSTI]

3-D seismic which spans the entire field (Figure 7). Since both Sun (2004) and Aveseth?s (2011) models correlate dry bulk modulus with the pore structure of a reservoir, possibly the Sun (2004) model maybe applicable to the 3-D range as well... ................................................................................................................. 85 5.1 Wells 159-2 and 169-5 Variability in Lithology, Porosity and Permeability ........ 86 5.2 Velocity Estimation Rock Physic Models .............................................................. 89 5.3 Variability in Bulk and Shear Modulus...

Davidson, Daniel

2013-08-14T23:59:59.000Z

103

A Simple Hydromechanical Modeling of Carbon Sequestration in Sedimentary Rocks  

E-Print Network [OSTI]

In this study, over different scenarios we will simulate a week coupling of hydromechanical loads in a long term CO2 injection with a hypothetical reservoir while the effect of pore water pressure and then multi-phase flow procedure has been ignored. In the first basic case the homogenous case has been considered when the theory of poroelasticity was employed. Second case covers the effects of directional heterogeneity, constructed by random faults, on the flow paths of gas and other attributes of the system. Also, in the latter case the impact of stress state as an active loads (body loads) has been regarded. Thanks to multiple directional heterogeneity, which induces only one heterogenic parameter (intrinsic permeability), distinguishable flow paths can be recognized. In another process, the failure ability of system regard to Mohr-Columb criterion is measured as well as options that, presumably, the system has continuum faults (zero cohesion). The results over different cases shows absedince of ground surf...

Ghaffari, Hamed O

2009-01-01T23:59:59.000Z

104

Design and Implementation of a CO(2) Flood Utilizing Advanced Reservoir Characterization and Horizontal Injection Wells in Shallow Shelf Carbonate Approaching Waterflood Depletion  

SciTech Connect (OSTI)

The work reported herein covers select tasks in Budget Phase 11. The principle Task in Budget Phase 11 included in this report is Field Demonstration. Completion of many of the Field Demonstration tasks during the last report period enabled an optimum carbon dioxide (CO{sub 2}) flood project to be designed, economically evaluated, and implemented in the field. Field implementation of the project commenced during late 1995, with actual C0{sub 2} injection commencing in mid-July, 1996. This report summarizes activities incurred following initial project start-up, towards the goal of optimizing project performance. The current project has focused on reducing initial investment cost by utilizing horizontal injection wells and concentrating the project in the best productivity area of the field. An innovative C0{sub 2} purchase agreement (no take-or-pay provisions, C0{sub 2} purchase price tied to West Texas Intermediate (WTI) crude oil price) and gas recycle agreement (expensing costs as opposed to a large upfront capital investment for compression) were negotiated to further improve the project economics. The Grayburg-San Andres section had previously been divided into multiple zones based on the core study and gamma ray markers that correlate wells within the Unit. Each zone was mapped as continuous across the field. Previous core studies concluded that the reservoir quality in the South Cowden Unit (SCU) is controlled primarily by the distribution of a bioturbated and diagenetically-altered rock type with a distinctive chaotic texture. The chaotic modifier is derived from the visual effect of pervasive, small-scale intermixing of tan oil-stained reservoir rock with tight gray non- reservoir rock. The chaotic reservoir rock extends from Zone C (4780`-4800`) to the lower part of Zone F (4640`-4680`). Zones D (4755`-4780`) and E (4680`-4755`) are considered the main floodable zones, though Zone F is also productive and Zone C is productive above the oil- water contact. During Budget Phase 1, the Stratamodel computer program was utilized as the primary tool to integrate the diverse geologic, petrophysical, and seismic data into a coherent three dimensional (3-D) model. The basic porosity model having been constructed, critiqued and modified based on field production and detailed cross-section displays, permeability data was imported into the model, and a 3-D interpolation of the permeability was completed.

NONE

1997-12-31T23:59:59.000Z

105

CO2 Huff-n-Puff Process in a Light Oil Shallow Shelf Carbonate Reservoir  

SciTech Connect (OSTI)

The application cyclic CO2, often referred to as the CO2 Huff-n-Puff process, may find its niche in the maturing waterfloods of the Permian Basin. Coupling the CO2 Huff-n-Puff process to miscible flooding applications could provide the needed revenue to sufficiently mitigate near-term negative cash flow concerns in capital-intensive miscible projects. Texaco Exploration and Production Inc. and the US Department of Energy have teamed up in a attempt to develop the CO2 Huff-n-Puff process in the Grayburg and San Andres formations which are light oil, shallow shelf carbonate reservoirs that exist throughout the Permian Basin. This cost-shared effort is intended to demonstrate the viability of this underutilized technology in a specific class of domestic reservoir.

Boomer, R.J.; Cole, R.; Kovar, M.; Prieditis, J.; Vogt, J.; Wehner, S.

1999-02-24T23:59:59.000Z

106

CO2 Huff-n-Puff Process in a Light Oil Shallow Shelf Carbonate Reservoir  

SciTech Connect (OSTI)

The application of cyclic CO2, often referred to as the CO2 Huff-n-Puff process, may find its niche in the maturing waterfloods of the Permian Basin. Coupling the CO2 Huff-n-Puff process to miscible flooding applications could provide the needed revenue to sufficiently mitigate near-term negative cash flow concerns in the capital-intensive miscible projects. Texaco Exploration & Production Inc. and the U. S. Department of Energy have teamed up in an attempt to develop the CO2 Huff-n-Puff process in the Grayburg and San Andres formations which are light oil, shallow shelf carbonate reservoirs that exist throughout the Permian Basin. This cost-shared effort is intended to demonstrate the viability of this underutilized technology in a specific class of domestic reservoir. A significant amount of oil reserves are located in carbonate reservoirs. Specifically, the carbonates deposited in shallow shelf (SSC) environments make up the largest percentage of known reservoirs within the Permian Basin of North America. Many of these known resources have been under waterflooding operations for decades and are at risk of abandonment if crude oil recoveries cannot be economically enhanced 1,2 . The selected sites for this demonstration project are the Central Vacuum Unit waterflood in Lea County, New Mexico and the Sundown Slaughter Field in Hockley County, Texas. Miscible CO2 flooding is the process of choice for enhancing recovery of light oils 3 and already accounts for over 12% of the Permian Basin?s daily production.4 There are significant probable reserves associated with future miscible CO2 projects. However, many are marginally economic at current market conditions due to large up-front capital commitments for a peak response, which may be several years in the future. The resulting negative cash-flow is sometimes too much for an operator to absorb. The CO2 Huff-n-Puff process is being investigated as a near-term option to mitigate the negative cash-flow situation--allowing acceleration of inventoried miscible CO2 projects when coupled together. The CO2 Huff-n-Puff process is a proven enhanced oil recovery technology in Louisiana-Texas Gulf-coast sandstone reservoirs 5,6 . Application seems to mostly confine itself to low pressure sandstone reservoirs 7 . The process has even been shown to be moderately effective in conjunction with steam on heavy California crude oils 8,9 . A review of earlier literature 5,10,11 provides an excellent discussion on the theory, mechanics of the process, and several case histories. Although the technology is proven in light oil sandstones, it continues to be a very underutilized enhanced recovery option for carbonates. However, the theories associated with the CO2 Huff-n-Puff process are not lithology dependent. It was anticipated that this project would show that the application of the CO2 Huff-n-Puff process in shallow shelf carbonates could be economically implemented to recover appreciable volumes of light oil. The goals of the project were the development of guidelines for cost-effective selection of candidate reservoirs and wells, along with estimating recovery potential.

Mark Kovar; Scott Wehner

1998-01-13T23:59:59.000Z

107

Layer definition and pressure buildup case histories in a carbonate reservoir  

SciTech Connect (OSTI)

This paper presents case histories of pressure buildup analysis in a layered carbonate reservoir (Zella/Aswad Fields in the Socialist People's Libyan Arab Jamahiria). The productive formation consists of several dolomite and limestone layers separated by thin tight streaks. Lack of pressure communication between layers has been determined by pressure measurements in the individual layers using the Repeat Formation Tester (RFT). Results of the two-dimensional radial model simulated pressure buildup performance are compared to the actual measured pressure buildup data. 14 refs.

Vadgama, U.N.; Arifi, N.A.

1981-01-01T23:59:59.000Z

108

Maximizing Storage Rate and Capacity and Insuring the Environmental Integrity of Carbon Dioxide Sequestration in Geological Reservoirs  

SciTech Connect (OSTI)

Maximizing Storage Rate and Capacity and Insuring the Environmental Integrity of Carbon Dioxide Sequestration in Geological Formations The U.S. and other countries may enter into an agreement that will require a significant reduction in CO2 emissions in the medium to long term. In order to achieve such goals without drastic reductions in fossil fuel usage, CO2 must be removed from the atmosphere and be stored in acceptable reservoirs. The research outlined in this proposal deals with developing a methodology to determine the suitability of a particular geologic formation for the long-term storage of CO2 and technologies for the economical transfer and storage of CO2 in these formations. A novel well-logging technique using nuclear-magnetic resonance (NMR) will be developed to characterize the geologic formation including the integrity and quality of the reservoir seal (cap rock). Well-logging using NMR does not require coring, and hence, can be performed much more quickly and efficiently. The key element in the economical transfer and storage of the CO2 is hydraulic fracturing the formation to achieve greater lateral spreads and higher throughputs of CO2. Transport, compression, and drilling represent the main costs in CO2 sequestration. The combination of well-logging and hydraulic fracturing has the potential of minimizing these costs. It is possible through hydraulic fracturing to reduce the number of injection wells by an order of magnitude. Many issues will be addressed as part of the proposed research to maximize the storage rate and capacity and insure the environmental integrity of CO2 sequestration in geological formations. First, correlations between formation properties and NMR relaxation times will be firmly established. A detailed experimental program will be conducted to determine these correlations. Second, improved hydraulic fracturing models will be developed which are suitable for CO2 sequestration as opposed to enhanced oil recovery (EOR). Although models that simulate the fracturing process exist, they can be significantly improved by extending the models to account for nonsymmetric, nonplanar fractures, coupling the models to more realistic reservoir simulators, and implementing advanced multiphase flow models for the transport of proppant. Third, it may be possible to deviate from current hydraulic fracturing technology by using different proppants (possibly waste materials that need to be disposed of, e.g., asbestos) combined with different hydraulic fracturing carrier fluids (possibly supercritical CO2 itself). Because current technology is mainly aimed at enhanced oil recovery, it may not be ideally suited for the injection and storage of CO2. Finally, advanced concepts such as increasing the injectivity of the fractured geologic formations through acidization with carbonated water will be investigated. Saline formations are located through most of the continental United States. Generally, where saline formations are scarce, oil and gas reservoirs and coal beds abound. By developing the technology outlined here, it will be possible to remove CO2 at the source (power plants, industry) and inject it directly into nearby geological formations, without releasing it into the atmosphere. The goal of the proposed research is to develop a technology capable of sequestering CO2 in geologic formations at a cost of US $10 per ton.

L.A. Davis; A.L. Graham; H.W. Parker; J.R. Abbott; M.S. Ingber; A.A. Mammoli; L.A. Mondy; Quanxin Guo; Ahmed Abou-Sayed

2005-12-07T23:59:59.000Z

109

EUROCK 2006 Multiphysics Coupling and Long Term Behaviour in Rock Mechanics Van Cotthem, Charlier, Thimus & Tshibangu (eds)  

E-Print Network [OSTI]

observations of stress-aligned shear- wave splitting (seismic birefringence) in hydro-carbon reservoirs-WAVE SPLITTING The key phenomenon for observing the internal micro- cracked structure of rocks is stress

110

Pressure transient test analysis of vuggy naturally fractured carbonate reservoir: field case study  

E-Print Network [OSTI]

Well pressure transient analysis is widely used in reservoir management to obtain reservoir information needed for reservoir simulation, damage identification, well optimization and stimulation evaluation. The main objective of this project...

Ajayi, Babatunde Tolulope

2009-06-02T23:59:59.000Z

111

Identification of pore type and origin in a Lower Cretaceous carbonate reservoir using NMR T2 relaxation times  

E-Print Network [OSTI]

IDENTIFICATION OF PORE TYPE AND ORIGIN IN A LOWER CRETACEOUS CARBONATE RESERVOIR USING NMR T 2 RELAXATION TIMES A Thesis by DOMENICO LODOLA Submitted to the Office of Graduate Studies of Texas A&M University in partial fulfillment... of the requirements for the degree of MASTER OF SCIENCE May 2004 Major Subject: Geology IDENTIFICATION OF PORE TYPE AND ORIGIN IN A LOWER CRETACEOUS CARBONATE RESERVOIR USING NMR T2 RELAXATION TIMES A Thesis by DOMENICO LODOLA Submitted to Texas A&M University...

Lodola, Domenico Domenico

2004-09-30T23:59:59.000Z

112

Design and Implementation of a CO2 Flood Utilizing Advanced Reservoir Characterization and Horizontal Injection Wells In a Shallow Shelf Carbonate Approaching Waterflood Depletion, Class II  

SciTech Connect (OSTI)

The principle objective of this project is to demonstrate the economic viability and widespread applicability of an innovative reservoir management and carbon dioxide (CO2) flood project development approach for improving CO2 flood project economics in shallow shelf carbonate (SSC) reservoirs.

Czirr, K.L.; Gaddis, M.P.; Moshell, M.K.

2002-02-21T23:59:59.000Z

113

A parametric study of factors affecting oil recovery efficiency from carbon dioxide injection using a compositional reservoir model  

E-Print Network [OSTI]

Factors Affecting Oil Recovery Estimating Oil Recovery From Carbon Dioxide Flooding 15 33 CHAPTER III ? FIELD CASE ANALYSIS 38 3. 1 3. 2 3. 3 3. 4 Background Laboratory Analysis Reservoir Analysis Estimates of Injection Recovery and Project... to estimate the recovery of oil from continuous injection of carbon dioxide. Finally, the results of the sensitivity analysis were compared to published laboratory and theoretical models and documented field results to test the correlation model. CHAPTER...

Barnes, Gregory Allen.

1991-01-01T23:59:59.000Z

114

Advanced Characterization of Fractured Reservoirs in Carbonate Rocks: The Michigan Basin  

SciTech Connect (OSTI)

The purpose of the study was to collect and analyze existing data on the Michigan Basin for fracture patterns on scales ranging form thin section to basin. The data acquisition phase has been successfully concluded with the compilation of several large digital databases containing nearly all the existing information on formation tops, lithology and hydrocarbon production over the entire Michigan Basin. These databases represent the cumulative result of over 80 years of drilling and exploration.

Wood, James R.; Harrison, William B.

2002-12-02T23:59:59.000Z

115

ADVANCED CHARACTERIZATION OF FRACTURED RESERVOIRS IN CARBONATE ROCKS: THE MICHIGAN BASIN  

SciTech Connect (OSTI)

Progress in year 2 of this project is highlighted by the completing of the writing and testing of the project database, ''Atlas'', and populating it with all the project data gathered to date. This includes digitization of 17,000+ original Scout Tickets for the Michigan Basin. Work continues on the Driller's Reports, where they have scanned about 50,000 pages out of an estimated 300,000 pages. All of the scanned images have been attached to ''Atlas'', the visual database viewer developed for this project. A complete set of the 1/24,000 USGS DEM (Digital Elevation Models) for the State of Michigan has been downloaded from the USGS Web sites, decompressed and converted to ArcView Grid files. A large-scale map (48 inches x 84 inches) has been constructed by mosaicking of the high-resolution files. This map shows excellent ground surface detail and has drawn much comment and requests for copies at the venues where it has been displayed. Although it was generated for mapping of surface lineations the map has other uses, particularly analysis of the glacial drift in Michigan. It presents unusual problems due to its size and they are working with vendors on compression and display algorithms (e.g. MrSID{copyright}) in an attempt to make it available over the Internet, both for viewing and download. A set of aeromagnetic data for the Michigan Basin has been acquired and is being incorporated into the study. As reported previously, the general fracture picture in the Michigan Basin is a dominant NW-SE trend with a conjugate NE-SW trend. Subsurface, DEM and gravity data support the interpretation of a graben-type deep basement structural trend coincident with the Michigan Basin Gravity High. They plan to incorporate the aeromagnetic data into this interpretation as well.

James R. Wood; William B. Harrison

2000-04-01T23:59:59.000Z

116

Rock Physics-Based Carbonate Reservoir Pore Type Evaluation by Combining Geological, Petrophysical and Seismic Data  

E-Print Network [OSTI]

OF FIGURES ....................................................................................................... x CHAPTER I INTRODUCTION ........................................................................................ 1... Significance of Research ......................................................................... 1 Objectives ................................................................................................. 4 Literature Review...

Dou, Qifeng

2012-07-16T23:59:59.000Z

117

Design and implementation of a CO{sub 2} flood utilizing advanced reservoir characterization and horizontal injection wells in a shallow shelf carbonate approaching waterflood depletion. Annual Report, July 1, 1995--June 30, 1996  

SciTech Connect (OSTI)

The work reported herein covers select tasks remaining in Budget Phase I and many of the tasks of Budget Phase II. The principal Tasks in Budget Phase I included in this report are Reservoir Analysis and Characterization; Advanced Technical Studies; and Technology Transfer, Reporting and Project Management Activities for Budget Phase I. The principle Task in Budget Phase II included in this report is Field Demonstration. Completion of these tasks has enabled an optimum carbon dioxide (CO{sub 2}) flood project to be designed, economically evaluated, and implemented in the field. Field implementation of the project commenced during late 1995, with actual CO{sub 2} injection scheduled for start-up in mid-July, 1996. The current project has focused on reducing initial investment cost by utilizing horizontal injection wells and concentrating the project in the best productivity area of the field. An innovative CO{sub 2} purchase agreement (no take-or-pay provisions, CO{sub 2} purchase price tied to West Texas Intermediate (WTI) crude oil price) and gas recycle agreements (expensing costs as opposed to a large upfront capital investment for compression) were negotiated to further improve the project economics. The Grayburg-San Andres section had previously been divided into multiple zones based on the core study and gamma ray markers that correlate wells within the Unit. Each zone was mapped as continuous across the field. Previous core studies concluded that the reservoir quality in the South Cowden Unit (SCU) is controlled primarily by the distribution of a bioturbated and diagenetically-altered rock type with a distinctive {open_quotes}chaotic{close_quotes} texture. The {open_quotes}chaotic{close_quotes} modifier is derived from the visual effect of pervasive, small-scale intermixing of tan oil-stained reservoir rock with tight gray non-reservoir rock.

Chimahusky, J.S.; Hallenbeck, L.D.; Harpole, K.J.; Dollens, K.B.

1997-05-01T23:59:59.000Z

118

T2Well/ECO2N Version 1.0: Multiphase and Non-Isothermal Model for Coupled Wellbore-Reservoir Flow of Carbon Dioxide and Variable Salinity Water  

SciTech Connect (OSTI)

At its most basic level, the injection of CO{sub 2} into geologic CO{sub 2} storage sites involves a system comprising the wellbore and the target reservoir. The wellbore is the only conduit available to emplace CO{sub 2} into reservoirs for long-term storage. At the same time, wellbores in general have been identified as the most likely conduit for CO{sub 2} and brine leakage from geologic carbon sequestration (GCS) sites, especially those in sedimentary basins with historical hydrocarbon production. We have developed a coupled wellbore and reservoir model for simulating the dynamics of CO{sub 2} injection and leakage through wellbores. The model describes the following processes: (1) upward or downward wellbore flow of CO{sub 2} and variable salinity water with transition from supercritical to gaseous CO{sub 2} including Joule-Thomson cooling, (2) exsolution of CO{sub 2} from the aqueous phase as pressure drops, and (3) cross flow into or interaction with layers of surrounding rock (reservoirs). We use the Drift-Flux Model and related conservation equations for describing transient two-phase non-isothermal wellbore flow of CO{sub 2}-water mixtures under different flow regimes and interacting with surrounding rock. The mass and thermal energy balance equations are solved numerically by a finite difference scheme with wellbore heat transmission to the surrounding rock handled either semi-analytically or numerically. The momentum balance equation for the flow in the wellbore is solved numerically with a semi-explicit scheme. This manual provides instructions for compilation and use of the new model, and presents some example problems to demonstrate its use.

Pan, L.; Oldenburg, C.M.; Wu, Y.-S.; Pruess, K.

2011-02-14T23:59:59.000Z

119

Modeling brine-rock interactions in an enhanced geothermal systemdeep fractured reservoir at Soultz-Sous-Forets (France): a joint approachusing two geochemical codes: frachem and toughreact  

SciTech Connect (OSTI)

The modeling of coupled thermal, hydrological, and chemical (THC) processes in geothermal systems is complicated by reservoir conditions such as high temperatures, elevated pressures and sometimes the high salinity of the formation fluid. Coupled THC models have been developed and applied to the study of enhanced geothermal systems (EGS) to forecast the long-term evolution of reservoir properties and to determine how fluid circulation within a fractured reservoir can modify its rock properties. In this study, two simulators, FRACHEM and TOUGHREACT, specifically developed to investigate EGS, were applied to model the same geothermal reservoir and to forecast reservoir evolution using their respective thermodynamic and kinetic input data. First, we report the specifics of each of these two codes regarding the calculation of activity coefficients, equilibrium constants and mineral reaction rates. Comparisons of simulation results are then made for a Soultz-type geothermal fluid (ionic strength {approx}1.8 molal), with a recent (unreleased) version of TOUGHREACT using either an extended Debye-Hueckel or Pitzer model for calculating activity coefficients, and FRACHEM using the Pitzer model as well. Despite somewhat different calculation approaches and methodologies, we observe a reasonably good agreement for most of the investigated factors. Differences in the calculation schemes typically produce less difference in model outputs than differences in input thermodynamic and kinetic data, with model results being particularly sensitive to differences in ion-interaction parameters for activity coefficient models. Differences in input thermodynamic equilibrium constants, activity coefficients, and kinetics data yield differences in calculated pH and in predicted mineral precipitation behavior and reservoir-porosity evolution. When numerically cooling a Soultz-type geothermal fluid from 200 C (initially equilibrated with calcite at pH 4.9) to 20 C and suppressing mineral precipitation, pH values calculated with FRACHEM and TOUGHREACT/Debye-Hueckel decrease by up to half a pH unit, whereas pH values calculated with TOUGHREACT/Pitzer increase by a similar amount. As a result of these differences, calcite solubilities computed using the Pitzer formalism (the more accurate approach) are up to about 1.5 orders of magnitude lower. Because of differences in Pitzer ion-interaction parameters, the calcite solubility computed with TOUGHREACT/Pitzer is also typically about 0.5 orders of magnitude lower than that computed with FRACHEM, with the latter expected to be most accurate. In a second part of this investigation, both models were applied to model the evolution of a Soultz-type geothermal reservoir under high pressure and temperature conditions. By specifying initial conditions reflecting a reservoir fluid saturated with respect to calcite (a reasonable assumption based on field data), we found that THC reservoir simulations with the three models yield similar results, including similar trends and amounts of reservoir porosity decrease over time, thus pointing to the importance of model conceptualization. This study also highlights the critical effect of input thermodynamic data on the results of reactive transport simulations, most particularly for systems involving brines.

Andre, Laurent; Spycher, Nicolas; Xu, Tianfu; Vuataz,Francois-D.; Pruess, Karsten.

2006-12-31T23:59:59.000Z

120

Establishing the Relationship between Fracture-Related Dolomite and Primary Rock Fabric on the Distribution of Reservoirs in the Michigan Basin  

SciTech Connect (OSTI)

This topical report covers the year 2 of the subject 3-year grant, evaluating the relationship between fracture-related dolomite and dolomite constrained by primary rock fabric in the 3 most prolific reservoir intervals in the Michigan Basin (Ordovician Trenton-Black River Formations; Silurian Niagara Group; and the Devonian Dundee Formation). The characterization of select dolomite reservoirs has been the major focus of our efforts in Phase II/Year 2. Fields have been prioritized based upon the availability of rock data for interpretation of depositional environments, fracture density and distribution as well as thin section, geochemical, and petrophysical analyses. Structural mapping and log analysis in the Dundee (Devonian) and Trenton/Black River (Ordovician) suggest a close spatial relationship among gross dolomite distribution and regional-scale, wrench fault related NW-SE and NE-SW structural trends. A high temperature origin for much of the dolomite in the 3 studied intervals (based upon initial fluid inclusion homogenization temperatures and stable isotopic analyses,) coupled with persistent association of this dolomite in reservoirs coincident with wrench fault-related features, is strong evidence for these reservoirs being influenced by hydrothermal dolomitization. For the Niagaran (Silurian), a comprehensive high resolution sequence stratigraphic framework has been developed for a pinnacle reef in the northern reef trend where we had 100% core coverage throughout the reef section. Major findings to date are that facies types, when analyzed at a detailed level, have direct links to reservoir porosity and permeability in these dolomites. This pattern is consistent with our original hypothesis of primary facies control on dolomitization and resulting reservoir quality at some level. The identification of distinct and predictable vertical stacking patterns within a hierarchical sequence and cycle framework provides a high degree of confidence at this point that results will be exportable throughout the basin. Ten petrophysically significant facies have been described in the northern reef trend, providing significantly more resolution than the standard 4-6 that are used most often in the basin (e.g. Gill, 1977). Initial petrophysical characterization (sonic velocity analysis under confining pressures) shows a clear pattern that is dependent upon facies and resulting pore architecture. Primary facies is a key factor in the ultimate diagenetic modification of the rock and the resulting pore architecture. Facies with good porosity and permeability clearly show relatively slow velocity values as would be expected, and low porosity and permeability samples exhibit fast sonic velocity values, again as expected. What is significant is that some facies that have high porosity values, either measured directly or from wireline logs, also have very fast sonic velocity values. This is due to these facies having a pore architecture characterized by more localized pores (vugs, molds or fractures) that are not in communication.

G. Michael Grammer

2006-09-30T23:59:59.000Z

Note: This page contains sample records for the topic "reservoir rock carbon" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


121

Improved Oil Recovery in Mississippian Carbonate Reservoirs of Kansas - Near-Term, Class II  

SciTech Connect (OSTI)

The focus of this project was development and demonstration of cost-effective reservoir description and management technologies to extend the economic life of mature reservoirs in Kansas and the mid-continent.

Carr, Timothy R.; Green, Don W.; Willhite, G. Paul

2001-10-30T23:59:59.000Z

122

Finite Element Solution of Nonlinear Transient Rock Damage with Application in Geomechanics of Oil and Gas Reservoirs  

E-Print Network [OSTI]

, Damage diffusion, Reservoir geo-mechanics, Brittle fracture. 1. Introduction Solid mechanics and strength of materials are two of the oldest engineering mechanics problems. The fundamental works of Galileo [1 such as diatomite oilfield or gas shale [3]. Continuum damage mechanics (CDM) is a branch of solid mechanics which

Patzek, Tadeusz W.

123

Estimates of incremental oil recoverable by carbon dioxide flooding and related carbon dioxide supply requirements for flooding major carbonate reservoirs in the Permian, Williston, and other Rocky Mountain basins  

SciTech Connect (OSTI)

The objective of the work was to build a solid engineering foundation (in) carbonate reservoirs for the purpose of extending the technology base in carbon dioxide miscible flooding. This report presents estimates of incremental oil recovery and related carbon dioxide supply requirements for selected carbonate reservoirs in the Permian, Williston, and Rocky Mountain Basins. The estimates presented here are based on calculations using a volumetric model derived and described in this report. The calculations utilized data developed in previous work. Calculations were made for a total of 279 reservoirs in the Permian, Williston, and several smaller Rocky Mountain Basins. Results show that the carbonate reservoirs of the Permian Basin constitute an order of magnitude larger target for carbon dioxide flooding than do all the carbonate reservoirs of the Williston and Rocky Mountain intermontane basins combined. Review of the calculated data in comparison with information from earlier work indicates that the figures given here are probably optimistic in that incremental oil volumes may be biased toward the high side while carbon dioxide supply requirements may be biased toward the low side. However, the information available would not permit further practical refinement of the calculations. Use of the incremental oil figures given for individual reservoirs as an official estimate is not recommended because of various uncertainties in individual field data. Further study and compilation of data for field projects as they develop appears warranted to better calibrate the calculation procedures and thus to develop more refined estimates of incremental oil potential and carbon dioxide supply requirements. 11 figures, 16 tables.

Goodrich, J.H.

1982-12-01T23:59:59.000Z

124

Characterization of Rodessa Formation Reservoir (Lower Cretaceous) in Van Field, Van Zandt County, Texas  

E-Print Network [OSTI]

(Wescott and Hood, 1994). Those authors also stated that the hydrocarbons in the Rodessa Formation and other Lower Cretaceous formations are typical of oil identified to have originated in Jurassic source rocks owing to their carbon isotopic and sulfur...?to-nitrogen ratio analysis. Oil to source rock correlation suggests that much of Smackover oil was sourced by Jurassic rocks. The most reasonable way to bring Jurassic oil into a Cretaceous reservoir is by vertical migration along the faults (Burgess, 1990...

Triyana, Yanyan

2004-09-30T23:59:59.000Z

125

An investigation of parameters affecting oil recovery efficiency of carbon dioxide flooding in cross-sectional reservoirs  

SciTech Connect (OSTI)

Low oil recovery efficiency is attributed to low vertical and areal sweep efficiency. The major causes of the low recovery efficiencies may be classified into three categories: (1) gravity segregation, (2) reservoir heterogeneity, and (3) unstable viscous fingering. Water alternate with gas (WAG) injection processes have been employed in field operations to improve the recovery efficiency and cut the cost of gas injection. The purpose of this study is to investigate the effects of reservoir and process parameters on the oil recovery efficiency of carbon dioxide WAG processes in cross-sectional reservoirs. To accomplish this, a two-dimensional compositional numerical simulator was developed. The simulator was functional and verified in this study. The simulator was then used to generate simulation data for studying the effects of seven dimensionless parameters on the oil recovery efficiency: (1) reservoir length to height ratio, (2) sine of the reservoir dip angle, (3) vertical to horizontal permeability ratio, (4) gravity to viscosity ratio (GVR), (5) injection rate, (6) water to gas (WAG) injection ration, and (7) pore volumes injected. Results of the investigation showed that oil recovery efficiency as a percentage of the oil place (OIP) is affected to different degrees by the seven parameters. Two correlations of the oil recovery efficiency versus the seven dimensionless parameters were established. The first was established for pore volumes injection ranging from 0 to 1.0 and the second from 0 to 0.7. The second correlation showed better agreement with the simulation results. The correlations will provide useful information in the design of the carbon dioxide WAG processes in cross-sectional reservoirs.

Almalik, M.S.

1988-01-01T23:59:59.000Z

126

DESIGN AND IMPLEMENTATION OF A CO2 FLOOD UTILIZING ADVANCED RESERVOIR CHARACTERIZATION AND HORIZONTAL INJECTION WELLS IN A SHALLOW SHELF CARBONATE APPROACHING WATERFLOOD DEPLETION  

SciTech Connect (OSTI)

The purpose of this project was to economically design an optimum carbon dioxide (CO{sub 2}) flood for a mature waterflood nearing its economic abandonment. The original project utilized advanced reservoir characterization and CO{sub 2} horizontal injection wells as the primary methods to redevelop the South Cowden Unit (SCU). The development plans; project implementation and reservoir management techniques were to be transferred to the public domain to assist in preventing premature abandonment of similar fields. The Unit was a mature waterflood with water cut exceeding 95%. Oil must be mobilized through the use of a miscible or near-miscible fluid to recover significant additional reserves. Also, because the unit was relatively small, it did not have the benefit of economies of scale inherent in normal larger scale projects. Thus, new and innovative methods were required to reduce investment and operating costs. Two primary methods used to accomplish improved economics were use of reservoir characterization to restrict the flood to the higher quality rock in the unit and use of horizontal injection wells to cut investment and operating costs. The project consisted of two budget phases. Budget Phase I started in June 1994 and ended late June 1996. In this phase Reservoir Analysis, Characterization Tasks and Advanced Technology Definition Tasks were completed. Completion enabled the project to be designed, evaluated, and an Authority for Expenditure (AFE) for project implementation submitted to working interest owners for approval. Budget Phase II consisted of the implementation and execution of the project in the field. Phase II was completed in July 2001. Performance monitoring, during Phase II, by mid 1998 identified the majority of producing wells which under performed their anticipated withdrawal rates. Newly drilled and re-activated wells had lower offtake rates than originally forecasted. As a result of poor offtake, higher reservoir pressure was a concern for the project as it limited CO{sub 2} injectivity. To reduce voidage balance, and reservoir pressure, a disposal well was therefore drilled. Several injection surveys indicated the CO{sub 2} injection wells had severe conformance issues. After close monitoring of the project to the end of 1999, it was evident the project would not recover the anticipated tertiary reserves. The main reasons for under-performance were poor in zone CO{sub 2} injection into the upper San Andres layers, poorer offtake rates from newly drilled replacement wells and a higher than required reservoir pressure. After discussion internally within Phillips, externally with the Department of Energy (DOE) and SCU partners, a redevelopment of South Cowden was agreed upon to commence in year 2000. The redevelopment essentially abandoned the original development for Budget Phase II in favor of a revised approach. This involved conformance techniques to resolve out of zone CO{sub 2} injection and use of horizontal wells to improve in zone injectivity and productivity. A phased approach was used to ensure short radius lateral drilling could be implemented effectively at South Cowden. This involved monitoring drilling operations and then production response to determine if larger investments during the second phase were justified. Redevelopment Phase 1 was completed in May 2000. It was deemed a success in regard to finding suitable/cost-effective technology for drilling horizontal laterals and finding a technique that could sustain long-term productivity from the upper layers of the San Andres reservoir. Four existing vertical producing wells were isolated from their existing completions and sidetracked with horizontal laterals into the upper layers of the San Andres. Overall average offtake rates for the four wells increased by a factor of 12 during the first four months after completion of Phase 1. Phase 2 of the redevelopment focused on current CO{sub 2} vertical injection wells. Techniques were applied to resolve near well conformance concerns and then either single or dual laterals were dril

K.J. Harpole; Ed G. Durrett; Susan Snow; J.S. Bles; Carlon Robertson; C.D. Caldwell; D.J. Harms; R.L. King; B.A. Baldwin; D. Wegener; M. Navarrette

2002-09-01T23:59:59.000Z

127

Field Demonstration of Horizontal Infill Drilling Using Cost-effective Integrated Reservoir Modeling--Mississippian Carbonates, Central Kansas  

SciTech Connect (OSTI)

Mississippian carbonate reservoirs have produced in excess of 1 billion barrels of oil in Kansas accounting for over 16% of the state's production. With declining production from other age reservoirs, the contribution of Mississippian reservoirs to Kansas's oil production has risen to 43% as of 2004. However, solution-enhanced features such as vertical shale intervals extending from the karst erosional surface at the top introduce complexities/compartmentalizations in Mississippian carbonate reservoirs. Coupled with this, strong water drives charge many of these reservoirs resulting in limited drainage from vertical wells due to high water cuts after an initial period of low water production. Moreover, most of these fields are operated by small independent operators without access to the knowledge bank of modern research in field characterization and exploitation/development practices. Thus, despite increasing importance of Mississippian fields to Kansas production, these fields are beset with low recovery factors and high abandonment rates leaving significant resources in the ground. Worldwide, horizontal infill wells have been successful in draining compartmentalized reservoirs with limited pressure depletion. The intent of this project was to demonstrate the application of horizontal wells to successfully exploit the remaining potential in mature Mississippian fields of the mid-continent. However, it is of critical importance that for horizontal wells to be economically successful, they must be selectively targeted. This project demonstrated the application of initial and secondary screening methods, based on publicly available data, to quickly shortlist fields in a target area for detailed studies to evaluate their potential to infill horizontal well applications. Advanced decline curve analyses were used to estimate missing well-level production data and to verify if the well produced under unchanging bottom-hole conditions--two commonly occurring data constraints afflicting mature Mississippian fields. A publicly accessible databank of representative petrophysical properties and relationships was developed to overcome the paucity of such data that is critical to modeling the storage and flow in these reservoirs. Studies in 3 Mississippian fields demonstrated that traditional reservoir models built by integrating log, core, DST, and production data from existing wells on 40-acre spacings are unable to delineate karst-induced compartments, thus making 3D-seismic data critical to characterize these fields. Special attribute analyses on 3D data were shown to delineate reservoir compartments and predict those with pay porosities. Further testing of these techniques is required to validate their applicability in other Mississippian reservoirs. This study shows that detailed reservoir characterization and simulation on geomodels developed by integrating wireline log, core, petrophysical, production and pressure, and 3D-seismic data enables better evaluation of a candidate field for horizontal infill applications. In addition to reservoir compartmentalization, two factors were found to control the economic viability of a horizontal infill well in a mature Mississippian field: (a) adequate reservoir pressure support, and (b) an average well spacing greater than 40-acres.

Saibal Bhattacharya

2005-08-31T23:59:59.000Z

128

The thin section rock physics: Modeling and measurement of seismic wave velocity on the slice of carbonates  

SciTech Connect (OSTI)

This paper discusses a new approach for investigating the seismic wave velocity of rock, specifically carbonates, as affected by their pore structures. While the conventional routine of seismic velocity measurement highly depends on the extensive laboratory experiment, the proposed approach utilizes the digital rock physics view which lies on the numerical experiment. Thus, instead of using core sample, we use the thin section image of carbonate rock to measure the effective seismic wave velocity when travelling on it. In the numerical experiment, thin section images act as the medium on which wave propagation will be simulated. For the modeling, an advanced technique based on artificial neural network was employed for building the velocity and density profile, replacing image's RGB pixel value with the seismic velocity and density of each rock constituent. Then, ultrasonic wave was simulated to propagate in the thin section image by using finite difference time domain method, based on assumption of an acoustic-isotropic medium. Effective velocities were drawn from the recorded signal and being compared to the velocity modeling from Wyllie time average model and Kuster-Toksoz rock physics model. To perform the modeling, image analysis routines were undertaken for quantifying the pore aspect ratio that is assumed to represent the rocks pore structure. In addition, porosity and mineral fraction required for velocity modeling were also quantified by using integrated neural network and image analysis technique. It was found that the Kuster-Toksoz gives the closer prediction to the measured velocity as compared to the Wyllie time average model. We also conclude that Wyllie time average that does not incorporate the pore structure parameter deviates significantly for samples having more than 40% porosity. Utilizing this approach we found a good agreement between numerical experiment and theoretically derived rock physics model for estimating the effective seismic wave velocity of rock.

Wardaya, P. D., E-mail: pongga.wardaya@utp.edu.my; Noh, K. A. B. M., E-mail: pongga.wardaya@utp.edu.my; Yusoff, W. I. B. W., E-mail: pongga.wardaya@utp.edu.my [Petroleum Geosciences Department, Universiti Teknologi PETRONAS, Tronoh, Perak, 31750 (Malaysia); Ridha, S. [Petroleum Engineering Department, Universiti Teknologi PETRONAS, Tronoh, Perak, 31750 (Malaysia); Nurhandoko, B. E. B. [Wave Inversion and Subsurface Fluid Imaging Research Laboratory (WISFIR), Dept. of Physics, Institute of Technology Bandung, Bandung, Indonesia and Rock Fluid Imaging Lab, Bandung (Indonesia)

2014-09-25T23:59:59.000Z

129

Improved oil recovery in Mississippian carbonate reservoirs of Kansas near term Class 2. Annual report, September 18, 1994--March 15, 1997  

SciTech Connect (OSTI)

This annual report describes progress during the second year of the project entitled {open_quotes}Improved Oil Recovery in Mississippian Carbonate Reservoirs in Kansas{close_quotes}. This project funded under the Department of Energy`s Class 2 program targets improving the reservoir performance of mature oil fields located in shallow shelf carbonate reservoirs. The focus of this project is development and demonstration of cost-effective reservoir description and management technologies to extend the economic life of mature reservoirs in Kansas and the mid-continent. As part of the project, several tools and techniques for reservoir description and management were developed, modified and demonstrated. These include: (1) a new approach to subsurface visualization using electric logs ({open_quotes}Pseudoseismic{open_quotes}); (2) a low-cost easy-to-use spreadsheet log analysis software (PfEFFER); and (3) an extension of the BOAST-3 computer program for full field reservoir simulation. The world-wide-web was used to provide rapid and flexible dissemination of the project results through the Internet. Included in this report is a summary of significant project results at the demonstration site (Schaben Field, Ness County, Kansas). These results include an outline of the reservoir description based on available and newly acquired data and reservoir simulation results. Detailed information is available on-line through the Internet. Based on the reservoir simulation, three infill wells will be drilled to validate the reservoir description and demonstrate the effectiveness of the proposed reservoir management strategies. The demonstration phase of the project has just begun and will be presented in the next annual report.

Carr, T.R.; Green, D.W.; Willhite, G.P.

1998-04-01T23:59:59.000Z

130

A direct method for determining complete positive and negative capillary pressure curves for reservoir rock using the centrifuge  

SciTech Connect (OSTI)

A method is being developed for direct experimental determination of capillary pressure curves from saturation distributions produced during centrifuging fluids in a rock plug. A free water level is positioned along the length of the plugs to enable simultaneous determination of both positive and negative capillary pressures. Octadecane as the oil phase is solidified by temperature reduction while centrifuging to prevent fluid redistribution upon removal from the centrifuge. The water saturation is then measured via magnetic resonance imaging. The saturation profile within the plug and the calculation of pressures for each point of the saturation profile allows for a complete capillary pressure curve to be determined from one experiment. Centrifuging under oil with a free water level into a 100 percent water saturated plug results in the development of a primary drainage capillary pressure curve. Centrifuging similarly at an initial water saturation in the plug results in the development of an imbibition capillary pressure curve. Examples of these measurements are presented for Berea sandstone and chalk rocks.

Spinler, E.A.; Baldwin, B.A. [Phillips Petroleum Co., Bartlesville, OK (United States)

1997-08-01T23:59:59.000Z

131

Design and Implementation of a C02 Flood Utilizing Advanced Reservoir Characterization and Horizontal Injection Wells in a Shallow Shelf Carbonate Approaching Waterflood Depletion  

SciTech Connect (OSTI)

The objective is to utilize reservoir characteristics and advanced technologies to optimize the design of a carbon dioxide (CO2) project for the South Cowden Unit (SCU) located in Ector County, Texas. The SCU is a mature, relatively small, shallow shelf carbonate unit nearing waterflood depletion. Also the project seeks to demonstrate the performance and economic viability of the project in the field.

None

1997-08-01T23:59:59.000Z

132

Ranking of Texas reservoirs for application of carbon dioxide miscible displacement  

SciTech Connect (OSTI)

Of the 431 reservoirs screened, 211 projected revenue that exceeded cost, ie, were profitable. Only the top 154 reservoirs, however, showed a profit greater than 30%. The top 10 reservoirs predicted a profit of at least 80%. Six of the top ten were Gulf Coast sandstones. The reservoirs are representative of the most productive discoveries in Texas; they account for about 72% of the recorded 52 billion barrels oil production in the State. Preliminary evaluation in this study implied that potential production from CO{sub 2}-EOR could be as much as 4 billion barrels. In order to enhance the chances of achieving this, DOE should consider a targeted outreach program to the specific independent operators controlling the leases. Development of ownership/technical potential maps and an outreach program should be initiated to aid this identification.

Ham, J

1996-04-01T23:59:59.000Z

133

An alternative to the Winland R35 method for determining carbonate reservoir quality  

E-Print Network [OSTI]

fabrics. The Winland and Pittman petrophysical evaluation techniques, as well as the Lucia geological evaluation technique - when based on depositional facies alone - do not provide reliable measures of reservoir quality. An alternative method based...

Lafage, Stephanie Isabelle

2008-10-10T23:59:59.000Z

134

Data requirements and acquisition for reservoir characterization  

SciTech Connect (OSTI)

This report outlines the types of data, data sources and measurement tools required for effective reservoir characterization, the data required for specific enhanced oil recovery (EOR) processes, and a discussion on the determination of the optimum data density for reservoir characterization and reservoir modeling. The two basic sources of data for reservoir characterization are data from the specific reservoir and data from analog reservoirs, outcrops, and modern environments. Reservoir data can be divided into three broad categories: (1) rock properties (the container) and (2) fluid properties (the contents) and (3)interaction between reservoir rock and fluid. Both static and dynamic measurements are required.

Jackson, S.; Chang, Ming Ming; Tham, Min.

1993-03-01T23:59:59.000Z

135

Design and Implementation of a CO2 Flood Utilizing Advanced Reservoir Characterization and Horizontal Injection Wells In a Shallow Shelf Carbonate Approaching Waterflood Depletion, Class II  

SciTech Connect (OSTI)

The purpose of this project was to economically design an optimum carbon dioxide (CO2) flood for a mature waterflood nearing its economic abandonment. The original project utilized advanced reservoir characterization and CO2 horizontal injection wells as the primary methods to redevelop the South Cowden Unit (SCU). The development plans; project implementation and reservoir management techniques were to be transferred to the public domain to assist in preventing premature abandonment of similar fields.

Wier, Don R. Chimanhusky, John S.; Czirr, Kirk L.; Hallenbeck, Larry; Gerard, Matthew G.; Dollens, Kim B.; Owen, Rex; Gaddis, Maurice; Moshell, M.K.

2002-11-18T23:59:59.000Z

136

Waterflood and Enhanced Oil Recovery Studies using Saline Water and Dilute Surfactants in Carbonate Reservoirs  

E-Print Network [OSTI]

to decrease the residual oil saturation. In calcareous rocks, water from various resources (deep formation, seawater, shallow beds, lakes and rivers) is generally injected in different oil fields. The ions interactions between water molecules, salts ions, oil...

Alotaibi, Mohammed

2012-02-14T23:59:59.000Z

137

Sediment accumulation and carbon, nitrogen, and phosphorus deposition in the large tropical reservoir Lake Kariba  

E-Print Network [OSTI]

Kariba, the largest hydropower reservoir in the Zambezi River Basin (ZRB). Sediment characteristics large dams are constructed to provide socio- economic benefits in the form of hydropower, water storage regions of the world have considerable untapped hydropower potential [Bartle, 2002; Hydropower and Dams

Gilli, Adrian

138

Potential Impacts of Leakage from Black Rock Reservoir on the Hanford Site Unconfined Aquifer: Initial Hypothetical Simulations of Flow and Contaminant Transport  

SciTech Connect (OSTI)

Initial scoping calculations of the unconfined aquifer at the Hanford Site were carried out for the U.S. Bureau of Reclamation (USBR) to investigate the potential impacts on the Hanford unconfined aquifer that would result from leakage from the proposed Black Rock Reservoir to the west. Although impacts on groundwater flow and contaminant transport were quantified based on numerical simulation results, the investigation represented a qualitative assessment of the potential lateral recharge that could result in adverse effects on the aquifer. Because the magnitude of the potential leakage is unknown, hypothetical bounding calculations were performed. When a quantitative analysis of the magnitude of the potential recharge from Black Rock Reservoir is obtained, the hydrologic impacts analysis will be revisited. The analysis presented in this report represents initial bounding calculations. A maximum lateral recharge (i.e., upland flux) was determined in the first part of this study by executing steady-state flow simulations that raised the water table no higher than the elevation attained in the Central Plateau during the Hanford operational period. This metric was selected because it assumed a maximum remobilization of contaminants that existed under previous fully saturated conditions. Three steady-state flow fields were then used to analyze impacts to transient contaminant transport: a maximum recharge (27,000 acre-ft/yr), a no additional flux (365 acre-ft/yr), and an intermediate recharge case (16,000 acre-ft/yr). The transport behavior of four radionuclides was assessed for a 300 year simulation period with the three flow fields. The four radionuclides are tritium, iodine-129, technetium-99, and uranium-238. Transient flow and transport simulations were used to establish hypothetical concentration distributions in the subsurface. Using the simulated concentration distributions in 2005 as initial conditions for steady-state flow runs, simulations were executed to investigate the relative effects on contaminant transport from the increased upland fluxes. Contaminant plumes were analyzed for 1) peak concentrations and arrival times at downstream points of compliance, 2) the area of the aquifer contaminated at or above the drinking water standard (DWS), and 3) the total activity remaining in the domain at the end of the simulation. In addition to this analysis, unit source release simulations from a hypothetical tracer were executed to determine relative travel times from the Central Plateau. The results of this study showed that increases in the lateral recharge had limited impact on regional flow directions but accelerated contaminant transport. Although contaminant concentrations may have initially increased for the more mobile contaminants (tritium, technetium-99, and iodine-129), the accelerated transport caused dilution and a more rapid decline in concentrations relative to the Base Case (no additional flux). For the low-mobility uranium-238, higher lateral recharge caused increases in concentration, but these concentrations never approached the DWS. In this preliminary investigation, contaminant concentrations did not exceed the DWS study metric. With the increases in upland fluxes, more mass was transported out of the aquifer, and concentrations were diluted with respect to the base case where no additional flux was considered.

Freedman, Vicky L.

2008-01-30T23:59:59.000Z

139

Fluid Flow Simulation in Fractured Reservoirs  

E-Print Network [OSTI]

The purpose of this study is to analyze fluid flow in fractured reservoirs. In most petroleum reservoirs, particularly carbonate reservoirs and some tight sands, natural fractures play a critical role in controlling fluid ...

Sarkar, Sudipta

2002-01-01T23:59:59.000Z

140

Fractures of the Dammam Dome Carbonate Outcrops: Their Characterization, Development, and Implications for Subsurface Reservoirs.  

E-Print Network [OSTI]

??The exposed Tertiary carbonates of the Dammam Dome present an opportunity to study fractures in outcrops within the oil-producing region of Eastern Saudi Arabia. The… (more)

Al-Fahmi, Mohammed M

2012-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "reservoir rock carbon" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


141

CO{sub 2} HUFF-n-PUFF process in a light oil shallow shelf carbonate reservoir. Quarterly technical progress report, [January 1, 1995--March 31, 1995  

SciTech Connect (OSTI)

The principal objective of the Central Vacuum Unit (CVU) CO{sub 2} Huff-n-Puff (H-n-P) project is to determine the feasibility and practicality of the technology in a waterflooded shallow shelf carbonate environment. The results of parametric simulation of the CO{sub 2} H-n-P process, coupled with the CVU reservoir characterization components will determine if this process is technically and economically feasible for field implementation. The technology transfer objective of the project is to disseminate the knowledge gained through an innovative plan in support of the Department of Energy`s (DOE) objective of increasing domestic oil production and deferring the abandonment of shallow shelf carbonate (SSC) reservoirs. Technical progress is reported for geostatitical realizations; paramatric simulation; waterflood review; and reservoir characterization.

Cole, R.; Prieditis, J.; Vogt, J.; Wehner, S.

1995-04-21T23:59:59.000Z

142

CO{sub 2} Huff-n-Puff process in a light oil shallow shelf carbonate reservoir. Second quarterly technical progress report, [April 1995--June 1995  

SciTech Connect (OSTI)

The principal objective of the Central Vacuum Unit (CVU) CO{sub 2} Huff-n-Puff (H-n-P) project is to determine the feasibility and practicality of the technology in a waterflooded shallow shelf carbonate environment. The results of parametric simulation of the CO{sub 2} H-n-P process, coupled with the CVU reservoir characterization components will determine if this process is technically and economically feasible for field implementation. The technology transfer objective of the project is to disseminate the knowledge gained through an innovative plan in support of the Department of Energy`s (DOE) objective of increasing domestic oil production and deferring the abandonment of shallow shelf carbonate (SSC) reservoirs. Tasks associated with this objective are carried out in what is considered a timely effort for near-term goals. Technical progress is summarized for; geostatistical realizations; site-specific simulation;waterflood review; and reservoir characterization.

Cole, R.; Prieditis, J.; Vogt, J.; Wehner, S.

1995-07-11T23:59:59.000Z

143

DETERT RESERVOIR ROCK COTATI GLEN  

E-Print Network [OSTI]

OAKLAND EAST LAS TRAMPAS RIDGE DIABLO TASSAJARA BYRON HOT SPRINGS SAN FRANCISCO SOUTH HUNTERS POINT SAN

144

Importance of Low Permeability Natural Gas Reservoirs (released in AEO2010)  

Reports and Publications (EIA)

Production from low-permeability reservoirs, including shale gas and tight gas, has become a major source of domestic natural gas supply. In 2008, low-permeability reservoirs accounted for about 40% of natural gas production and about 35% of natural gas consumption in the United States. Permeability is a measure of the rate at which liquids and gases can move through rock. Low-permeability natural gas reservoirs encompass the shale, sandstone, and carbonate formations whose natural permeability is roughly 0.1 millidarcies or below. (Permeability is measured in darcies.)

2010-01-01T23:59:59.000Z

145

Stratigraphic and structural distribution of reservoirs in Romania  

SciTech Connect (OSTI)

In Romania, there are reservoirs at different levels of the whole Cambrian-Pliocene interval, but only some of these levels have the favorable structural conditions to accumulate hydrocarbons in commercial quantities. These levels are the Devonian, Triassic, Middle Jurassic, Lower Cretaceous (locally including the uppermost Jurassic), Eocene, Oligocene-lower Miocene, middle and upper Miocene, and Pliocene. The productive reservoirs are represented either by carbonate rocks (in Devonian, Middle Triassic and uppermost Jurassic-Lower Cretaceous) or by detrital rocks (in Lower and Upper Triassic, Middle Jurassic, Eocene, Oligocene, Miocene, and Pliocene). From the structural point of view, the Romanian territory is characterized by the coexistence both of platforms (East European, Scythian, and Moesian platforms) and of the strongly tectonized orogenes (North Dobrogea and Carpathian orogenes). Each importance crust shortening was followed by the accumulation of post-tectonic covers, some of them being folded during subsequently tectonic movements. The youngest post-tectonic cover is common both for the platforms (foreland) and Carpathian orogene, representing the Carpathian foredeep. Producing reservoirs are present in the East European and Moesian platforms, in the outer Carpathian units (Tarcau and Marginal folds nappes) and in certain post-tectonic covers which fill the Carpathian foredeep and the Transylvanian and Pannonian basins. In the platforms, hydrocarbons accumulated both in calcareous and detrital reservoirs, whereas in the Carpathian units and in their reservoirs, whereas in the Carpathian units and in their post-tectonic covers, hydrocarbons accumulated only in detrital reservoirs.

Stefanescu, M.O. (Inst. of Geology and Geophysics, Bucharest (Romania))

1991-08-01T23:59:59.000Z

146

Modeling and Optimization of Matrix Acidizing in Horizontal Wells in Carbonate Reservoirs  

E-Print Network [OSTI]

concentration, temperature and acid flux in the formation. The work concentrated on the investigation of the acid flux. Analytical equations for injection rate schedule for different wormhole models. In carbonate acidizing, the existence of the optimum...

Tran, Hau

2013-05-07T23:59:59.000Z

147

A New Organic Acid to Stimulate Deep Wells in Carbonate Reservoirs  

E-Print Network [OSTI]

Carbonate acidizing has been carried out using HCl-based stimulation fluids for decades. However, at high temperatures, HCl does not produce acceptable results because of its fast reaction, acid penetration, and hence surface dissolution, and its...

Al-Douri, Ahmad F

2014-05-28T23:59:59.000Z

148

Optimal Process Design for Coupled CO2 Sequestration and Enhanced Gas Recovery in Carbonate Reservoirs  

E-Print Network [OSTI]

Increasing energy demand combined with public concern for the environment obligates the oil industry to supply oil and natural gas to the public while minimizing the carbon footprint due to its activities. Today, fossil fuels are essential...

Odi, Uchenna

2013-12-09T23:59:59.000Z

149

Phase I (Year 1) Summary of Research--Establishing the Relationship between Fracture-Related Dolomite and Primary Rock Fabric on the Distribution of Reservoirs in the Michigan Basin  

SciTech Connect (OSTI)

This topical report covers the first 12 months of the subject 3-year grant, evaluating the relationship between fracture-related dolomite and dolomite constrained by primary rock fabric in the 3 most prolific reservoir intervals in the Michigan Basin (Ordovician Trenton-Black River Formations; Silurian Niagara Group; and the Devonian Dundee Formation). Phase I tasks, including Developing a Reservoir Catalog for selected dolomite reservoirs in the Michigan Basin, Characterization of Dolomite Reservoirs in Representative Fields and Technology Transfer have all been initiated and progress is consistent with our original scheduling. The development of a reservoir catalog for the 3 subject formations in the Michigan Basin has been a primary focus of our efforts during Phase I. As part of this effort, we currently have scanned some 13,000 wireline logs, and compiled in excess of 940 key references and 275 reprints that cover reservoir aspects of the 3 intervals in the Michigan Basin. A summary evaluation of the data in these publications is currently ongoing, with the Silurian Niagara Group being handled as a first priority. In addition, full production and reservoir parameter data bases obtained from available data sources have been developed for the 3 intervals in Excel and Microsoft Access data bases. We currently have an excess of 25 million cells of data for wells in the Basin. All Task 2 objectives are on time and on target for Phase I per our original proposal. Our mapping efforts to date, which have focused in large part on the Devonian Dundee Formation, have important implications for both new exploration plays and improved enhanced recovery methods in the Dundee ''play'' in Michigan--i.e. the interpreted fracture-related dolomitization control on the distribution of hydrocarbon reservoirs. In an exploration context, high-resolution structure mapping using quality-controlled well data should provide leads to convergence zones of fault/fracture trends that are not necessarily related to structural elevation. Further work in Phase II will be focused on delineating the relative contribution to fracture-only dolomitization to that which occurs in conjunction with primary facies and/or sequence stratigraphic framework.

G. Michael Grammer

2005-11-09T23:59:59.000Z

150

CO2 Huff-n-Puff process in a light oil shallow shelf carbonate reservoir. Annual report, January 1, 1995--December 31, 1995  

SciTech Connect (OSTI)

The application of cyclic CO{sub 2}, often referred to as the CO{sub 2} Huff-n-Puff process, may find its niche in the maturing waterfloods of the Permian Basin. Coupling the CO{sub 2} H-n-P process to miscible flooding applications could provide the needed revenue to sufficiently mitigate near-term negative cash flow concerns in the capital intensive miscible projects. Texaco Exploration & Production Inc. and the U.S. Department of Energy have teamed up in an attempt to develop the CO{sub 2} Huff-n-Puff process in the Grayburg/San Andres formation; a light oil, shallow shelf carbonate reservoir within the Permian Basin. This cost-shared effort is intended to demonstrate the viability of this underutilized technology in a specific class of domestic reservoir. A significant amount of oil reserves are located in carbonate reservoirs. Specifically, the carbonates deposited in shallow shelf (SSC) environments make up the largest percentage of known reservoirs within the Permian Basin of North America. Many of these known resources have been under waterflooding operations for decades and are at risk of abandonment if crude oil recoveries cannot be economically enhanced. The selected site for this demonstration project is the Central Vacuum Unit waterflood in Lea County, New Mexico.

Wehner, S.C.; Boomer, R.J.; Cole, R.; Preiditus, J.; Vogt, J.

1996-09-01T23:59:59.000Z

151

4-D High-Resolution Seismic Reflection Monitoring of Miscible CO2 Injected into a Carbonate Reservoir  

SciTech Connect (OSTI)

The objective of this research project was to acquire, process, and interpret multiple high-resolution 3-D compressional wave and 2-D, 2-C shear wave seismic data in the hopes of observing changes in fluid characteristics in an oil field before, during, and after the miscible carbon dioxide (CO{sub 2}) flood that began around December 1, 2003, as part of the DOE-sponsored Class Revisit Project (DOE No.DE-AC26-00BC15124). Unique and key to this imaging activity is the high-resolution nature of the seismic data, minimal deployment design, and the temporal sampling throughout the flood. The 900-m-deep test reservoir is located in central Kansas oomoldic limestones of the Lansing-Kansas City Group, deposited on a shallow marine shelf in Pennsylvanian time. After 30 months of seismic monitoring, one baseline and eight monitor surveys clearly detected changes that appear consistent with movement of CO{sub 2} as modeled with fluid simulators and observed in production data. Attribute analysis was a very useful tool in enhancing changes in seismic character present, but difficult to interpret on time amplitude slices. Lessons learned from and tools/techniques developed during this project will allow high-resolution seismic imaging to be routinely applied to many CO{sub 2} injection programs in a large percentage of shallow carbonate oil fields in the midcontinent.

Richard D. Miller; Abdelmoneam E. Raef; Alan P. Byrnes; William E. Harrison

2007-06-30T23:59:59.000Z

152

Impact of a large tropical reservoir on riverine transport of sediment, carbon, and nutrients to downstream wetlands  

E-Print Network [OSTI]

(P) cycling in Itezhi-Tezhi Reservoir (ITT; area ¼ 364 km2 , hydraulic residence time ¼ 0.7 yr in the reservoir, involving the installation of turbines driven by hypolimnetic water, will likely result [Harrison et al., 2009]). Finally, reservoir sediments have been shown to efficiently trap phosphorus (P

Wehrli, Bernhard

153

Summary of Research through Phase II/Year 2 of Initially Approved 3 Phase/3 Year Project - Establishing the Relationship between Fracture-Related Dolomite and Primary Rock Fabric on the Distribution of Reservoirs in the Michigan Basin  

SciTech Connect (OSTI)

This final scientific/technical report covers the first 2 years (Phases I and II of an originally planned 3 Year/3 Phase program). The project was focused on evaluating the relationship between fracture-related dolomite and dolomite constrained by primary rock fabric in the 3 most prolific reservoir intervals in the Michigan Basin. The characterization of select dolomite reservoirs was the major focus of our efforts in Phases I and II of the project. Structural mapping and log analysis in the Dundee (Devonian) and Trenton/Black River (Ordovician) suggest a close spatial relationship among gross dolomite distribution and regional-scale, wrench fault-related NW-SE and NE-SW structural trends. A high temperature origin for much of the dolomite in these 2 studied intervals (based upon fluid inclusion homogenization temperatures and stable isotopic analyses,) coupled with persistent association of this dolomite in reservoirs coincident with wrench fault-related features, is strong evidence for these reservoirs being influenced by hydrothermal dolomitization. In the Niagaran (Silurian), there is a general trend of increasing dolomitization shelfward, with limestone predominant in more basinward positions. A major finding is that facies types, when analyzed at a detailed level, are directly related to reservoir porosity and permeability in these dolomites which increases the predictability of reservoir quality in these units. This pattern is consistent with our original hypothesis of primary facies control on dolomitization and resulting reservoir quality at some level. The identification of distinct and predictable vertical stacking patterns within a hierarchical sequence and cycle framework provides a high degree of confidence at this point that the results should be exportable throughout the basin. Much of the data synthesis and modeling for the project was scheduled to be part of Year 3/Phase III, but the discontinuation of funding after Year 2 precluded those efforts. Therefore, the results presented in this document are not final, and in many cases represent a report of 'progress to date' as numerous tasks were scheduled to extend into Year 3.

G. Grammer

2007-09-30T23:59:59.000Z

154

Modeling of Water-rock interaction in the Mackenzie Basin: competition between sulfuric and carbonic acids  

E-Print Network [OSTI]

sulfuric and carbonic acids E. Beaulieu, Y. Godd´eris, D. Labat, C. Roelandt, D. Calmels, J. Gail- lardet of the resulting proof before it is published in its final form. Please note that during the production process in the Mackenzie Basin: competition between sulfuric and carbonic acids. E. Beaulieu1 , Y. Goddéris1 , D. Labat1

155

CO{sub 2} Huff-n-Puff process in a light oil shallow shelf carbonate reservoir. Topical report No. 1  

SciTech Connect (OSTI)

The principle objective of the Central Vacuum Unit (CVU) CO{sub 2} Huff-n-Puff (H-n-P) project is to determine the feasibility and practicality of the technology in a waterflooded shallow shelf carbonate environment. The results of parametric simulation of the CO{sub 2} H-n-P process coupled with the CVU reservoir characterization components will determine if this process is technically and economic for field implementation. The ultimate goal will be to develop guidelines based on commonly available data that other operators in the industry can use to investigate the applicability of the process within other field. The technology transfer objective of the project is to disseminate the knowledge gained through an innovative plan in support of the Department of Energy`s objective to increasing domestic oil production and deferring the abandonment of shallow shelf carbonate reservoirs. Accomplishments to date are described in this report.

Cole, R.; Prieditis, J.; Vogt, J.; Wehner, S.

1995-10-01T23:59:59.000Z

156

CO{sub 2} Huff-n-Puff process in a light oil shallow shelf carbonate reservoir. Quarterly technical progress report, July--September, 1995  

SciTech Connect (OSTI)

The principal objective of the Central Vacuum Unit (CVU) CO{sub 2} Huff-n-Puff (H-n-P) project is to determine the feasibility and practicality of the technology in a waterflooded shallow shelf carbonate environment. The results of parametric simulation of the CO{sub 2} H-n-P process, coupled with the CVU reservoir characterization components will determine if this process is technically and economically feasible for field implementation. The technology transfer objective of the project is to disseminate the knowledge gained through an innovative plan in support of the Department of Energy`s (DOE) objective of increasing domestic oil production and deferring the abandonment of shallow shelf carbonate (SSC) reservoirs. Tasks associated with this objective are carried out in what is considered a timely effort for near-term goals.

Cole, R.; Prieditis, J.; Vogt, J. Wehner, S.

1995-10-15T23:59:59.000Z

157

SPE 159255-PP Rock Classification from Conventional Well Logs in Hydrocarbon-Bearing  

E-Print Network [OSTI]

typing method for application in hydrocarbon-bearing shale (specifically source rock) reservoirs using conventional well logs and core data. Source rock reservoirs are known to be highly heterogeneous and often, petrophysical description of source rock reservoirs with well logs has been focused to quantifying rock

Torres-Verdín, Carlos

158

Source Term Modeling for Evaluating the Potential Impacts to Groundwater of Fluids Escaping from a Depleted Oil Reservoir Used for Carbon Sequestration  

SciTech Connect (OSTI)

In recent years depleted oil reservoirs have received special interest as carbon storage reservoirs because of their potential to offset costs through collaboration with enhanced oil recovery projects. Modeling is currently being conducted to evaluate potential risks to groundwater associated with leakage of fluids from depleted oil reservoirs used for storage of CO2. Modeling results reported here focused on understanding how toxic organic compounds found in oil will distribute between the various phases within a storage reservoir after introduction of CO2, understanding the migration potential of these compounds, and assessing potential groundwater impacts should leakage occur. Two model scenarios were conducted to evaluate how organic components in oil will distribute among the phases of interest (oil, CO2, and brine). The first case consisted of 50 wt.% oil and 50 wt.% water; the second case was 90 wt.% CO2 and 10 wt.% oil. Several key organic compounds were selected for special attention in this study based upon their occurrence in oil at significant concentrations, relative toxicity, or because they can serve as surrogate compounds for other more highly toxic compounds for which required input data are not available. The organic contaminants of interest (COI) selected for this study were benzene, toluene, naphthalene, phenanthrene, and anthracene. Partitioning of organic compounds between crude oil and supercritical CO2 was modeled using the Peng-Robinson equation of state over temperature and pressure conditions that represent the entire subsurface system (from those relevant to deep geologic carbon storage environments to near surface conditions). Results indicate that for a typical set of oil reservoir conditions (75°C, and 21,520 kPa) negligible amounts of the COI dissolve into the aqueous phase. When CO2 is introduced into the reservoir such that the final composition of the reservoir is 90 wt.% CO2 and 10 wt.% oil, a significant fraction of the oil dissolves into the vapor phase. As the vapor phase moves up through the stratigraphic column, pressures and temperatures decrease, resulting in significant condensation of oil components. The heaviest organic components condense early in this process (at higher pressures and temperatures), while the lighter components tend to remain in the vapor phase until much lower pressures and temperatures are reached. Based on the model assumptions, the final concentrations of COI to reach an aquifer at 1,520 kPa and 25°C were quite significant for benzene and toluene, whereas the concentrations of polynuclear aromatic hydrocarbons that reach the aquifer were very small. This work demonstrates a methodology that can provide COI source term concentrations in CO2 leaking from a reservoir and entering an overlying aquifer for use in risk assessments.

Cantrell, Kirk J.; Brown, Christopher F.

2014-06-13T23:59:59.000Z

159

Design and implementation of a CO{sub 2} flood utilizing advanced reservoir characterization and horizontal injection wells in a shallow shelf carbonate approaching waterflood depletion. Quarterly report, July 1 - September 30, 1996  

SciTech Connect (OSTI)

The first objective is to utilize reservoir characterization and advanced technologies to optimize the design of a carbon dioxide project for the South Cowden Unit (SCU) located in Ector County, Texas. The SCU is a mature, relatively small, shallow shelf carbonate unit nearing waterflood depletion. The second object is to demonstrate the performance and economic viability of the project in the field. The report include work on the reservoir characterization and project design objective and demonstration project objective.

Chimahusky, J.S.

1996-10-01T23:59:59.000Z

160

Application of reservoir characterization and advanced technology to improve recovery and economics in a lower quality shallow shelf carbonate reservoir. Quarterly progress report, August 1995--December 1995  

SciTech Connect (OSTI)

West Welch Unit is one of four large waterflood units in the Welch Field located in the Northwestern portion of Dawson County, Texas. The Welch Field was discovered in the early 1940`s and produces oil under a solution gas drive mechanism from the San Andres formation at approximately 4800 ft. The field has been under waterflood for 30 years and a significant portion has been infill drilled on 20-ac density. A 1982-86 Pilot CO{sub 2} injection project in the offsetting South Welch Unit yielded positive results. The recent installation of a CO{sub 2} pipeline near the field allowed the phased development of a miscible CO{sub 2} injection project at the South Welch Unit. The reservoir quality is poorer at the West Welch Unit due to its relative position to sea level during deposition. Because of the proximity of a CO{sub 2} source and the CO{sub 2} operating experience that would be available from the South Welch Unit, West Welch Unit is an ideal location for demonstrating methods for enhancing economics of IOR projects in lower quality SSC reservoirs. This Class 2 project concentrates on the efficient design of a miscible CO{sub 2} project based on detailed reservoir characterization from advanced petrophysics, 3-D seismic interpretations and cross wellbore tomography interpretations. During the quarter, progress was made in both the petrophysical analysis and the tomography processing. The final geologic model is dependent upon the petrophysical analysis and the seismic and tomography interpretations. The actual reservoir simulation has started using the base geologic model, with which, all the preliminary simulation work is being done. Progress was also made in understanding the abnormal fracture wing orientation obtained in well 4807 and the cyclic CO{sub 2} demonstration results.

Taylor, A.R.

1996-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "reservoir rock carbon" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


161

Rock Physics of Geologic Carbon Sequestration/Storage Type of Report: Final Scientific/Technical  

Office of Scientific and Technical Information (OSTI)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE:1 First Use of Energy for All Purposes (Fuel and Nonfuel),Feet) Year Jan Feb Mar Apr May Jun Jul(Summary)morphinan antagonist Journal Article: CrystalFG36-08GO18149Speeding accessProposal Title:TechnicalSmall)Rock

162

SciTech Connect: Rock Physics of Geologic Carbon Sequestration/Storage  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE:1 First Use of Energy for All Purposes (Fuel and Nonfuel),Feet) Year Jan Feb Mar Apr MayAtmosphericNuclear Security Administrationcontroller systemsBi (2) Sr (2) Ca (2)FrameworkextendedComposite Forfor aRock

163

The role of reservoir characterization in the reservoir management process (as reflected in the Department of Energy`s reservoir management demonstration program)  

SciTech Connect (OSTI)

Optimum reservoir recovery and profitability result from guidance of reservoir practices provided by an effective reservoir management plan. Success in developing the best, most appropriate reservoir management plan requires knowledge and consideration of (1) the reservoir system including rocks, and rock-fluid interactions (i.e., a characterization of the reservoir) as well as wellbores and associated equipment and surface facilities; (2) the technologies available to describe, analyze, and exploit the reservoir; and (3) the business environment under which the plan will be developed and implemented. Reservoir characterization is the essential to gain needed knowledge of the reservoir for reservoir management plan building. Reservoir characterization efforts can be appropriately scaled by considering the reservoir management context under which the plan is being built. Reservoir management plans de-optimize with time as technology and the business environment change or as new reservoir information indicates the reservoir characterization models on which the current plan is based are inadequate. BDM-Oklahoma and the Department of Energy have implemented a program of reservoir management demonstrations to encourage operators with limited resources and experience to learn, implement, and disperse sound reservoir management techniques through cooperative research and development projects whose objectives are to develop reservoir management plans. In each of the three projects currently underway, careful attention to reservoir management context assures a reservoir characterization approach that is sufficient, but not in excess of what is necessary, to devise and implement an effective reservoir management plan.

Fowler, M.L. [BDM-Petroleum Technologies, Bartlesville, OK (United States); Young, M.A.; Madden, M.P. [BDM-Oklahoma, Bartlesville, OK (United States)] [and others

1997-08-01T23:59:59.000Z

164

Application of reservoir characterization and advanced technology to improve recovery and economics in a lower quality shallow shelf carbonate reservoir. End of budget period report, August 3, 1994--December 31, 1996  

SciTech Connect (OSTI)

The Oxy West Welch project is designed to demonstrate how the use of advanced technology can improve the economics of miscible CO{sub 2} injection projects in a lower quality shallow shelf carbonate reservoir. The research and design phase primarily involves advanced reservoir characterization and accelerating the production response. The demonstration phase will implement the reservoir management plan based on an optimum miscible CO{sub 2} flood as designed in the initial phase. During Budget Period 1, work was completed on the CO{sub 2} stimulation treatments and the hydraulic fracture design. Analysis of the CO{sub 2} stimulation treatment provided a methodology for predicting results. The hydraulic fracture treatment proved up both the fracture design approach a and the use of passive seismic for mapping the fracture wing orientation. Although the 3-D seismic interpretation is still being integrated into the geologic model and interpretation of borehole seismic is still underway, the simulator has been enhanced to the point of giving good waterflood history matches. The simulator-forecasted results for an optimal designed miscible CO{sub 2} flood in the demonstration area gave sufficient economics to justify continuation of the project into Budget Period 2.

Taylor, A.R.; Hinterlong, G.; Watts, G.; Justice, J.; Brown, K.; Hickman, T.S.

1997-12-01T23:59:59.000Z

165

Using Carbon Dioxide to Enhance Recovery of Methane from Gas Hydrate Reservoirs: Final Summary Report  

SciTech Connect (OSTI)

Carbon dioxide sequestration coupled with hydrocarbon resource recovery is often economically attractive. Use of CO2 for enhanced recovery of oil, conventional natural gas, and coal-bed methane are in various stages of common practice. In this report, we discuss a new technique utilizing CO2 for enhanced recovery of an unconventional but potentially very important source of natural gas, gas hydrate. We have focused our attention on the Alaska North Slope where approximately 640 Tcf of natural gas reserves in the form of gas hydrate have been identified. Alaska is also unique in that potential future CO2 sources are nearby, and petroleum infrastructure exists or is being planned that could bring the produced gas to market or for use locally. The EGHR (Enhanced Gas Hydrate Recovery) concept takes advantage of the physical and thermodynamic properties of mixtures in the H2O-CO2 system combined with controlled multiphase flow, heat, and mass transport processes in hydrate-bearing porous media. A chemical-free method is used to deliver a LCO2-Lw microemulsion into the gas hydrate bearing porous medium. The microemulsion is injected at a temperature higher than the stability point of methane hydrate, which upon contacting the methane hydrate decomposes its crystalline lattice and releases the enclathrated gas. Small scale column experiments show injection of the emulsion into a CH4 hydrate rich sand results in the release of CH4 gas and the formation of CO2 hydrate

McGrail, B. Peter; Schaef, Herbert T.; White, Mark D.; Zhu, Tao; Kulkarni, Abhijeet S.; Hunter, Robert B.; Patil, Shirish L.; Owen, Antionette T.; Martin, P F.

2007-09-01T23:59:59.000Z

166

Simulation of fluid flow mechanisms in high permeability zones (Super-K) in a giant naturally fractured carbonate reservoir  

E-Print Network [OSTI]

and fractures were treated as two systems. Reservoir management practices and decisions should be very carefully reviewed and executed in this dual continuum reservoir based on the results of this work. Studying this dual media flow behavior is vital for better...

Abu-Hassoun, Amer H.

2009-05-15T23:59:59.000Z

167

Application of reservoir characterization and advanced technology to improve recovery and economics in a lower quality Shallow Shelf Carbonate reservoir. Quarterly report, October 1, 1996--December 31, 1996  

SciTech Connect (OSTI)

West Welch Unit is one of four large waterflood units in the Welch field in the northwestern portion of Dawson County, Texas. The Welch Field was discovered in the early 1940`s and produces oil under a solution gas drive mechanism from the San Andres formation at approximately 4800 ft. The field has been under waterflood for 30 years and a significant portion has been infill-drilled on 20-ac density. A 1982-86 pilot CO{sub 2} injection project in the offsetting South Welch Unit yielded positive results. Recent installation of CO{sub 2} pipeline near the field allowed the phased development of a miscible CO{sub 2} injection project at the South Welch Unit. This Class 2 project concentrates on the efficient design of a miscible CO{sub 2} project based on detailed reservoir characterization from advanced petrophysics, 3-D seismic interpretations and cross wellbore tomography interpretations. During the quarter, simulation performance forecasts were made using the base geologic model. The surface seismic and wellbore data were combined to develop an improved geologic model for the simulator. Efforts to integrate the wellbore seismic results into the reservoir characterization continue. Problems with the wellbore seismic processing were traced to the processing software which is being corrected.

Taylor, A.R.

1996-07-01T23:59:59.000Z

168

STUDY OF WATERFLOODING PROCESS IN NATURALLY FRACTURED RESERVOIRS FROM STATIC AND DYNAMIC IMBIBITION EXPERIMENTS  

E-Print Network [OSTI]

STUDY OF WATERFLOODING PROCESS IN NATURALLY FRACTURED RESERVOIRS FROM STATIC AND DYNAMIC IMBIBITION experiments, followed by waterflooding, were performed at reservoir conditions to investigate rock wettability Berea and Spraberry cores at reservoir conditions to illustrate the actual process of waterflooding

Schechter, David S.

169

Occurrence of pore-filling halite in carbonate rocks, Nesson Anticline, Williston basin, North Dakota  

SciTech Connect (OSTI)

Clear, colorless pore-filling halite of late diagenetic origin occurs locally in the Devonian Dawson Bay, Winnipegosis, and Ashern Formations, the Silurian Interlake Formation, and the Ordovician Red River Formation. The halite occludes a variety of pore types and individual pores are filled with single crystals or aggregates of only a few crystals. This halite is present in quantities ranging from a trace to approximately 12%. Cores from McGregor field, Williams County, show the Winnipegosis Formation consists of mixed-skeletal lime wackestones and mudstones. These contain vugs up to 4 in. (10 cm) in size, intraparticle pores, and shelter porosity within pelecypod shells, up to 4 in. (10 cm) in size, which are occluded with halite. Halite also fills common small discontinuous vertical fractures. The upper 200 ft (61 m) of the Interlake Formation locally exhibits the most striking occurrences of pore-filling halite. These dolostones consist predominantly of intraclast-peloid mudstones, wackestones, packstones, occasional grainstones, algal boundstones, and solution-collapse breccias containing vug, fenestral, interparticle, shelter, intercrystalline, moldic, channel, breccia, and fracture porosity types. All porosity types, except intercrystalline, can be halite filled. A rare occurrence of pore-filling halite exists in Red River cores from Blue Buttes field, McKenzie County, where a dolomitic, mixed-skeletal, lime mudstone and wackestone lithofacies contains vugs, discontinuous vertical fractures, and intraparticle porosity types occluded with halite. In most occurrences, the pore systems were noneffective prior to halite infilling and had no potential as hydrocarbon reservoirs. However, it has been demonstrated that halite plugging in the Interlake Formation has locally formed updip seals to hydrocarbon migration.

Bucher, E.J.

1988-07-01T23:59:59.000Z

170

Strontium Isotopic Composition of Paleozoic Carbonate Rocks in the Nevada Test Site Vicinity, Clark, Lincoln, and Nye Counties, Nevada and Inyo County, California.  

SciTech Connect (OSTI)

Ground water moving through permeable Paleozoic carbonate rocks represents the most likely pathway for migration of radioactive contaminants from nuclear weapons testing at the Nevada Test Site, Nye County, Nevada. The strontium isotopic composition (87Sr/86Sr) of ground water offers a useful means of testing hydrochemical models of regional flow involving advection and reaction. However, reaction models require knowledge of 87Sr/86Sr data for carbonate rock in the Nevada Test Site vicinity, which is scarce. To fill this data gap, samples of core or cuttings were selected from 22 boreholes at depth intervals from which water samples had been obtained previously around the Nevada Test Site at Yucca Flat, Frenchman Flat, Rainier Mesa, and Mercury Valley. Dilute acid leachates of these samples were analyzed for a suite of major- and trace-element concentrations (MgO, CaO, SiO2, Al2O3, MnO, Rb, Sr, Th, and U) as well as for 87Sr/86Sr. Also presented are unpublished analyses of 114 Paleozoic carbonate samples from outcrops, road cuts, or underground sites in the Funeral Mountains, Bare Mountain, Striped Hills, Specter Range, Spring Mountains, and ranges east of the Nevada Test Site measured in the early 1990's. These data originally were collected to evaluate the potential for economic mineral deposition at the potential high-level radioactive waste repository site at Yucca Mountain and adjacent areas (Peterman and others, 1994). Samples were analyzed for a suite of trace elements (Rb, Sr, Zr, Ba, La, and Ce) in bulk-rock powders, and 87Sr/86Sr in partial digestions of carbonate rock using dilute acid or total digestions of silicate-rich rocks. Pre-Tertiary core samples from two boreholes in the central or western part of the Nevada Test Site also were analyzed. Data are presented in tables and summarized in graphs; however, no attempt is made to interpret results with respect to ground-water flow paths in this report. Present-day 87Sr/86Sr values are compared to values for Paleozoic seawater present at the time of deposition. Many of the samples have 87Sr/86Sr compositions that remain relatively unmodified from expected seawater values. However, rocks underlying the northern Nevada Test Site as well as rocks exposed at Bare Mountain commonly have elevated 87Sr/86Sr values derived from post-depositional addition of radiogenic Sr most likely from fluids circulating through rubidium-rich Paleozoic strata or Precambrian basement rocks.

James B. Paces; Zell E. Peterman; Kiyoto Futa; Thomas A. Oliver; and Brian D. Marshall.

2007-08-07T23:59:59.000Z

171

Area of Interest 1, CO2 at the Interface: Nature and Dynamics of the Reservoir/Caprock Contact and Implications for Carbon Storage Performance  

SciTech Connect (OSTI)

We examined the influence of geologic features present at the reservoir/caprock interface on the transmission of supercritical CO2 into and through caprock. We focused on the case of deformation-band faults in reservoir lithologies that intersect the interface and transition to opening-mode fractures in caprock lithologies. Deformation-band faults are exceeding common in potential CO2 injection units and our fieldwork in Utah indicates that this sort of transition is common. To quantify the impact of these interface features on flow and transport we first described the sedimentology and permeability characteristics of selected sites along the Navajo Sandstone (reservoir lithology) and Carmel Formation (caprock lithology) interface, and along the Slickrock Member (reservoir lithology) and Earthy Member (caprock lithology) of the Entrada Sandstone interface, and used this information to construct conceptual permeability models for numerical analysis. We then examined the impact of these structures on flow using single-phase and multiphase numerical flow models for these study sites. Key findings include: (1) Deformation-band faults strongly compartmentalize the reservoir and largely block cross-fault flow of supercritical CO2. (2) Significant flow of CO2 through the fractures is possible, however, the magnitude is dependent on the small-scale geometry of the contact between the opening-mode fracture and the deformation band fault. (3) Due to the presence of permeable units in the caprock, caprock units are capable of storing significant volumes of CO2, particularly when the fracture network does not extend all the way through the caprock. The large-scale distribution of these deformation-bandfault- to-opening-mode-fractures is related to the curvature of the beds, with greater densities of fractures in high curvature regions. We also examined core and outcrops from the Mount Simon Sandstone and Eau Claire Formation reservoir/caprock interface in order to extend our work to a reservoir/caprock pair this is currently being assessed for long-term carbon storage. These analyses indicate that interface features similar to those observed at the Utah sites 3 were not observed. Although not directly related to our main study topic, one byproduct of our investigation is documentation of exceptionally high degrees of heterogeneity in the pore-size distribution of the Mount Simon Sandstone. This suggests that the unit has a greater-than-normal potential for residual trapping of supercritical CO2.

Mozley, Peter; Evans, James; Dewers, Thomas

2014-10-31T23:59:59.000Z

172

IMPROVING CO2 EFFICIENCY FOR RECOVERING OIL IN HETEROGENEOUS RESERVOIRS  

SciTech Connect (OSTI)

A three-year contract for the project, DOE Contract No. DE-FG26-01BC15364, ''Improving CO{sub 2} Efficiency for Recovering Oil in Heterogeneous Reservoirs,'' was awarded and started on September 28, 2001. This project examines three major areas in which CO2 flooding can be improved: fluid and matrix interactions, conformance control/sweep efficiency, and reservoir simulation for improved oil recovery. This report discusses the activity during the six-month period covering October 1, 2002 through March 31, 2003 that covers the first and second fiscal quarters of the project's second year. During these two quarters of the project we have been working in several areas: reservoir fluid/rock interactions and their relationships to changing injectivity, and surfactant adsorption on quarried core and pure component granules, foam stability, and high flow rate effects. We also had a very productive project review in Midland, Texas. A paper on CO{sub 2}-brine-reservoir rock interaction was presented and included in the proceedings of the SPE International Symposium on Oilfield Chemistry, Houston, 5-8 February, 2003. Papers have been accepted for the Second Annual Conference on Carbon Sequestration in Alexandria, VA in May, the Society of Core Analysis meeting in Pau, France in September, and two papers for the SPE Annual Meeting in Denver, CO in October.

Reid B. Grigg; Robert K. Svec; Zheng-Wen Zeng; Liu Yi; Baojun Bai

2003-05-01T23:59:59.000Z

173

Petrophysical characterization of Middle Pliocene Reservoirs, Guneschli Field, Caspian Sea, Azerbaijan  

SciTech Connect (OSTI)

Guneshli Field is one of several large fields on the Apsheron Ridge, a bathymmic, and structural high, separating the North and South Caspian deeps. In total this trend contains more than 4 billion barrels of oil equivalent. The main reservoir is the Middle Pliocene Productive Series which is interpreted as a series of stacked wave dominated deltas. Reservoirs are fine to very-fine-grained sublitharenites, to feldspathic litharenites with excellent well-connected macro and meso pore systems. Porosity and permeability are texturally controlled due to depositional energy and provenance (as opposed to diagenetically controlled) primarily by grain size, sorting and percent of ductile shale rock fragments. Rarely, carbonate cement partially occludes primary pores. Six main lithofacies were recognized in core and described according to pore throat geometry and flow unit characteristics. Porosity, permeability, and mercury injection capillary pressure data were collected on reservoir and seal rocks. These data were used to define pore throat size distribution, hydrocarbon column height, sealing capacity, and irreducible water saturation for each facies. Porosity and permeability tests on reservoir samples at increasing confining stress conditions show only minor reductions in porosity and permeability. Permeability of poorly consolidated sands, in the absence of conventional plugs, can be estimated from mercury injection data on core chips or cuttings and from grain size data. Reservoir simulation models suggest Guneshli reservoirs have good displacement characteristics and are good waterflood candidates, with recovery being as high as 40% of the original oil-in-place.

Adams, C. [Amoco Production Company, Houston, TX (United States); Gousseinov, B. [Socar, Baku (Azerbaijan)

1995-08-01T23:59:59.000Z

174

Multidisciplinary reservoir description of the Batu Raja Limestone, Bima field, offshore northwest Java, Indonesia  

SciTech Connect (OSTI)

Bima field is the largest hydrocarbon reservoir producing from carbonate rocks in the offshore northwest Java area. The giant field has multiple drive mechanisms and high viscosity oil, resulting in rapid gas/oil ratio and water-cut increase after 2 yr of production. Because of high stakes and reservoir complexities, a three dimensional reservoir simulation model was used to evaluate field development options. An integrated geological, geophysical, and engineering reservoir description was done to provide input for the model. Geologically, the Oligocene-Miocene Batu Raja Limestone was deposited on the Seribu Platform, a basement-controlled, fault-bounded carbonate build-up. The reservoir consists of a series of cleaning-upwards cycles that were exposed to meteoric leaching during a lower Miocene drop in sea level. This diagenetic event enhanced porosity and permeability across the buildup. Based on reservoir quality, the reservoir was zoned into five model layers. Geophysical input included micromodeling sections (a form of seismic inversion) that were generated from a dense grid of seismic data. These were calibrated to well logs and used to define the buildup edge and map the thickness of the entire Batu Raja and the main pay zone. Engineering reservoir description integrated capillary pressure, relative permeability, production, and drill-stem test data. The three-dimensional simulation model required treatments unique to the Bima Field including varying GOC depths to honor separate gas cap closures; making permeability pressure dependent in poorly consolidated zones, and setting up horizontal well completion treatments. The synergistic approach of geological, engineering, and geophysical input into the Bima reservoir study resulted in a reservoir management tool as well as a model to aid regional Batu Raja exploration strategies.

Kaldi, J.G.; Woodling, G.S. (ARCO Oil and Gas Co., Plano, TX (USA)); Roe, R.C. (Atlantic Richfield Indonesia, Inc., Jakarta (Indonesia))

1990-05-01T23:59:59.000Z

175

Design and implementation of a CO{sub 2} flood utilizing advanced reservoir characterization and horizontal injection wells in a shallow shelf carbonate approaching waterflood depletion. Technical progress report  

SciTech Connect (OSTI)

The first objective is to utilize reservoir characterization and advanced technologies to optimize the design of a CO{sub 2} project for the South Cowden Unit (SCU) located in Ector County, Texas. The SCU is a mature, relatively small, shallow shelf carbonate unit nearing waterflood depletion. The second objective is to demonstrate the performance and economic viability of the project in the field. This report includes work on the reservoir characterization and project design objective and the demonstration project objective.

Chimahusky, J.S.

1996-04-19T23:59:59.000Z

176

Application of Integrated Reservoir Management and Reservoir Characterization to Optimize Infill Drilling  

SciTech Connect (OSTI)

Initial drilling of wells on a uniform spacing, without regard to reservoir performance and characterization, must become a process of the past. Such efforts do not optimize reservoir development as they fail to account for the complex nature of reservoir heterogeneities present in many low permeability reservoirs, and carbonate reservoirs in particular. These reservoirs are typically characterized by: o Large, discontinuous pay intervals o Vertical and lateral changes in reservoir properties o Low reservoir energy o High residual oil saturation o Low recovery efficiency

P. K. Pande

1998-10-29T23:59:59.000Z

177

Experimental Study on Rock Deformation and Permeability Variation  

E-Print Network [OSTI]

The development of a petroleum reservoir would inevitably induce a rearrangement of the in-situ stress field. The rearrangement of the stress field would then bring about a deformation of the reservoir rock and a change of the permeability...

Ding, Jihui

2013-08-01T23:59:59.000Z

178

Scientists Pass Solid Particles Through Rock in DOE-Sponsored...  

Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

rock fractures in the laboratory. This technology has the potential for mapping fracture systems in detail and aid in determining reservoir characteristics. This research was...

179

Inversion of seismic attributes for petrophysical parameters and rock facies   

E-Print Network [OSTI]

Prediction of rock and fluid properties such as porosity, clay content, and water saturation is essential for exploration and development of hydrocarbon reservoirs. Rock and fluid property maps obtained from such predictions ...

Shahraeeni, Mohammad Sadegh

2011-01-01T23:59:59.000Z

180

Technology for Increasing Geothermal Energy Productivity. Computer Models to Characterize the Chemical Interactions of Goethermal Fluids and Injectates with Reservoir Rocks, Wells, Surface Equiptment  

SciTech Connect (OSTI)

This final report describes the results of a research program we carried out over a five-year (3/1999-9/2004) period with funding from a Department of Energy geothermal FDP grant (DE-FG07-99ID13745) and from other agencies. The goal of research projects in this program were to develop modeling technologies that can increase the understanding of geothermal reservoir chemistry and chemistry-related energy production processes. The ability of computer models to handle many chemical variables and complex interactions makes them an essential tool for building a fundamental understanding of a wide variety of complex geothermal resource and production chemistry. With careful choice of methodology and parameterization, research objectives were to show that chemical models can correctly simulate behavior for the ranges of fluid compositions, formation minerals, temperature and pressure associated with present and near future geothermal systems as well as for the very high PT chemistry of deep resources that is intractable with traditional experimental methods. Our research results successfully met these objectives. We demonstrated that advances in physical chemistry theory can be used to accurately describe the thermodynamics of solid-liquid-gas systems via their free energies for wide ranges of composition (X), temperature and pressure. Eight articles on this work were published in peer-reviewed journals and in conference proceedings. Four are in preparation. Our work has been presented at many workshops and conferences. We also considerably improved our interactive web site (geotherm.ucsd.edu), which was in preliminary form prior to the grant. This site, which includes several model codes treating different XPT conditions, is an effective means to transfer our technologies and is used by the geothermal community and other researchers worldwide. Our models have wide application to many energy related and other important problems (e.g., scaling prediction in petroleum production systems, stripping towers for mineral production processes, nuclear waste storage, CO2 sequestration strategies, global warming). Although funding decreases cut short completion of several research activities, we made significant progress on these abbreviated projects.

Nancy Moller Weare

2006-07-25T23:59:59.000Z

Note: This page contains sample records for the topic "reservoir rock carbon" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


181

Modeling of coupled thermodynamic and geomechanical performance of underground compressed air energy storage (CAES) in lined rock caverns  

E-Print Network [OSTI]

reservoir storage project in Sesta, Italy [1]; as well as two pilot tests in rock caverns associated with abandoned

Rutqvist, J.

2013-01-01T23:59:59.000Z

182

Design and implementation of a CO2 flood utilizing advanced reservoirs characterization and horizontal injection wells in a shallow shelf carbonate approaching water floods depletion: Technical progress report, January 1, 1997--March 31, 1997  

SciTech Connect (OSTI)

The first objective is to utilize reservoir characterization and advanced technologies to optimize the design of a carbon dioxide (CO{sub 2}) project for the South Cowden Unit (SCU) located in Ector County, Texas. The SCU is a mature, relatively small, shallow shelf carbonate unit nearing waterflood depletion. The second objective is to demonstrate the performance and economic viability of the project in the field. All work this quarter falls within the demonstration project.

Chimahusky, J.S., Casteel, J.F.

1997-05-01T23:59:59.000Z

183

Genetic pore typing as a means of characterizing reservoir flow units: san andres, sunflower field, terry country, texas  

E-Print Network [OSTI]

by heterogeneities in reservoir quality and performance owing to the wide variety of processes that influence pore formation. Unlike siliciclastic rocks, carbonates are primarily biogenic in origin and largely composed of skeletal and chemical grains... illustrates the difference between the two forms of diagenetic modification. Lower portions of the sample illustrate a dissolution enhanced skeletal wackestone with H1-Ae porosity. Conversely, the upper portion exhibits obvious porosity reduction through...

Humbolt, Aubrey Nicole

2009-05-15T23:59:59.000Z

184

DOE-Sponsored Field Test Demonstrates Viability of Simultaneous CO2 Storage and Enhanced Oil Recovery in Carbonate Reservoirs  

Broader source: Energy.gov [DOE]

A field test conducted by a U.S. Department of Energy team of regional partners has demonstrated that using carbon dioxide in an enhanced oil recovery method dubbed "huff-and-puff" can help assess the carbon sequestration potential of geologic formations while tapping America's valuable oil resources.

185

Crosswell Seismic Amplitude-Versus-Offset for Detailed Imaging of Facies and Fluid Distribution within Carbonate Oil Reservoirs  

SciTech Connect (OSTI)

Crosswell seismic surveys were conducted at two fields in northern Michigan. One of these, Springdale, included two monitor wells that are located external to the reef, and the other, Coldspring, employed two production wells within the reef. The Springdale wells extended to much greater depths than the reef, and imaging was conducted from above and from beneath the reef. The resulting seismic images provide the best views of pinnacle Niagaran reefs obtained to date. The tops of the reservoirs can be clearly distinguished, and their lateral extent or dipping edges can be observed along the profile. Reflecting events internal to the reef are evident; some of them are fairly continuous across the reef and others are discontinuous. Inversion of the seismic data indicates which events represent zones of higher porosity and which are lower porosity or even anhydrite plugged. The full stacked image includes angles that are beyond critical for many of the interfaces, and some reflections are visible only for a small range of angles, presumably near their critical angle. Stacking these angles in provides an opportunity for these events to be seen on the stacked image, where otherwise they would have been unrecognized. For inversion, however, the complexity associated with phase changes beyond critical can lead to poor results, and elastic inversion of partial angle stacks may be best conducted with restrictions to angles less than critical. Strong apparent attenuation of signals occurs when seismic ray paths pass through the upper part of the Springdale reservoir; this may be due to intrinsic attenuation and/or scattering of events due to the locally strongly varying gas saturation and extremely low fluid pressures. Signal-to-noise limitations become evident far from the source well in the Coldspring study, probably because the raw data were strongly affected by tube-wave noise generated by flow through the perforation of the receiver well. The seismic images obtained, and interpretations of them, as assisted by Amplitude-versus-Angle studies and accompanying inversion, provide additional insight into the internal geometry of these two reefs and provide data that should be useful for reservoir management.

Wayne Pennington; Mohamed Ibrahim; Roger Turpening; Sean Trisch; Josh Richardson; Carol Asiala; Walid Mabrouk

2008-09-30T23:59:59.000Z

186

Design and implementation of a CO{sub 2} flood utilizing advanced reservoir characterization and horizontal injection wells in a shallow shelf carbonate approaching waterflood depletion. [Quarterly report], October 1, 1995--December 31, 1995  

SciTech Connect (OSTI)

The first objective is to utilize reservoir characterization and advanced technologies to optimize the design of a CO{sub 2} project for the South Cowden Unit (SCU) located in Ector County, Texas. The SCU is a mature, relatively small, shallow shelf carbonate unit nearing waterflood depletion. The second objective is to demonstrate the performance and economic viability of the project in the field. This report includes work on the reservoir characterization and project design objective. In addition the initiation of the demonstration project objective includes work done in November and December, 1995.

NONE

1996-03-21T23:59:59.000Z

187

Rock Physics Based Determination of Reservoir Microstructure for Reservoir Characterization  

E-Print Network [OSTI]

than the critical value, Hertz-Mindlin (HM) contact theory over-predicts compressional velocity (V_p) by about 69%. This was reduced to 4% when PAR distribution was accounted for in the original HM formulation. The pore structure parameter was also...

Adesokan, Hamid 1976-

2013-01-09T23:59:59.000Z

188

Improved oil recovery in Mississippian carbonate reservoirs of Kansas - near term -- Class 2. Quarterly progress report, July 1, 1995--September 30, 1995  

SciTech Connect (OSTI)

The objective of this project is to demonstrate incremental reserves from Osagian and Meramecian dolomite reservoirs in western Kansas through application of reservoir characterization to identify areas of unrecovered mobile petroleum. Specific reservoirs targeted are the Schaben Field in Ness County and the Bindley Field in Hodgeman County.

Carr, T.; Green, D.W.; Willhite, G.P.

1995-11-01T23:59:59.000Z

189

Artificial Geothermal Energy Potential of Steam-flooded Heavy Oil Reservoirs  

E-Print Network [OSTI]

This study presents an investigation of the concept of harvesting geothermal energy that remains in heavy oil reservoirs after abandonment when steamflooding is no longer economics. Substantial heat that has accumulated within reservoir rock and its...

Limpasurat, Akkharachai

2011-10-21T23:59:59.000Z

190

Analysis of Geothermal Reservoir Stimulation using Geomechanics-Based Stochastic Analysis of Injection-Induced Seismicity  

Broader source: Energy.gov [DOE]

This project will develop a model for seismicity-based reservoir characterization (SBRC) by combining rock mechanics; finite element modeling; geo-statistical concepts to establish relationships between micro-seismicity; reservoir flow and geomechanical characteristics.

191

Design and implementation of a CO{sub 2} flood utilizing advanced reservoir characterization and horizontal injection wells in a shallow shelf carbonate approaching waterflood depletion. Annual report, June 3, 1994--October 31, 1995  

SciTech Connect (OSTI)

The work reported here covers Budget Phase I of the project. The principal tasks in Budget Phase I are the Reservoir Analysis and Characterization Task and the Advanced Technology Definition Task. Completion of these tasks have enabled an optimum carbon dioxide (CO{sub 2}) flood project to be designed and evaluated from an economic and risk analysis standpoint. Field implementation of the project has been recommended to the working interest owner of the South Cowden Unit (SCU) and approval has been obtained. The current project has focused on reducing initial investment cost by utilizing horizontal injection wells and concentrating the project in the best productivity area of the field. An innovative CO{sub 2} purchase agreement (no take or pay requirements, CO{sub 2} purchase price tied to West Texas Intermediate crude oil price) and gas recycle agreements (expensing cost as opposed to large capital investments for compression) were negotiated to further improve project economics. A detailed reservoir characterization study was completed by an integrated team of geoscientists and engineers. The study consisted of detailed core description, integration of log response to core descriptions, mapping of the major flow units, evaluation of porosity and permeability relationships, geostatistical analysis of permeability trends, and direct integration of reservoir performance with the geological interpretation. The study methodology fostered iterative bidirectional feedback between the reservoir characterization team and the reservoir engineering/simulation team to allow simultaneous refinement and convergence of the geological interpretation with the reservoir model. The fundamental conclusion from the study is that South Cowden exhibits favorable enhanced oil recovery characteristics, particularly reservoir quality and continuity.

Hallenbeck, L.D.; Harpole, K.J.; Gerard, M.G.

1996-05-01T23:59:59.000Z

192

Pressure analysis of the hydromechanical fracture behaviour in stimulated tight sedimentary geothermal reservoirs  

E-Print Network [OSTI]

in jointed and layered rocks in geothermal fields.of Volcanology and Geothermal Research 116, 257- 278.fracturing in a sedimentary geothermal reservoir: Results

Wessling, S.

2009-01-01T23:59:59.000Z

193

Petrofacies analysis - the petrophysical tool for geologic/engineering reservoir characterization  

SciTech Connect (OSTI)

Petrofacies analysis is defined as the characterization and classification of pore types and fluid saturations as revealed by petrophysical measures of a reservoir. The word {open_quotes}petrofacies{close_quotes} makes an explicit link between petroleum engineers concerns with pore characteristics as arbiters of production performance, and the facies paradigm of geologists as a methodology for genetic understanding and prediction. In petrofacies analysis, the porosity and resistivity axes of the classical Pickett plot are used to map water saturation, bulk volume water, and estimated permeability, as well as capillary pressure information, where it is available. When data points are connected in order of depth within a reservoir, the characteristic patterns reflect reservoir rock character and its interplay with the hydrocarbon column. A third variable can be presented at each point on the crossplot by assigning a color scale that is based on other well logs, often gamma ray or photoelectric effect, or other derived variables. Contrasts between reservoir pore types and fluid saturations will be reflected in changing patterns on the crossplot and can help discriminate and characterize reservoir heterogeneity. Many hundreds of analyses of well logs facilitated by spreadsheet and object-oriented programming have provided the means to distinguish patterns typical of certain complex pore types for sandstones and carbonate reservoirs, occurrences of irreducible water saturation, and presence of transition zones. The result has been an improved means to evaluate potential production such as bypassed pay behind pipe and in old exploration holes, or to assess zonation and continuity of the reservoir. Petrofacies analysis is applied in this example to distinguishing flow units including discrimination of pore type as assessment of reservoir conformance and continuity. The analysis is facilitated through the use of color cross sections and cluster analysis.

Watney, W.L.; Guy, W.J.; Gerlach, P.M. [Kansas Geological Survey, Lawrence, KS (United States)] [and others

1997-08-01T23:59:59.000Z

194

Rock Art  

E-Print Network [OSTI]

The archaeology of early Egypt: Social transformations inAlexander 1938 Rock-drawings of southern Upper Egypt. Vol.1. London: The Egypt Exploration Society. 1939 Rock-drawings

Huyge, Dirk

2009-01-01T23:59:59.000Z

195

Design and implementation of a CO{sub 2} flood utilizing advanced reservoir characterization and horizontal injection wells in a shallow shelf carbonate approaching waterflood depletion. Quarterly report, October 1, 1996--December 31, 1996  

SciTech Connect (OSTI)

The first objective is to utilize reservoir characterization and advanced technologies to optimize the design of a carbon dioxide (CO{sub 2}) project for the south Cowden Unit (SCU) located in Ector County, Texas. The SCU is a mature, relatively small, shallow shelf carbonate unit nearing waterflood depletion. The second objective is to demonstrate the performance and economic viability of the project in the field. All work this quarter falls within Task V field demonstration. Short progress reports are presented for field demonstration involving: drill horizontal injection wells 6C-25H and 7C-11H; and drill two vertical WAG injectors along South Cowden Unit boundary.

NONE

1997-02-27T23:59:59.000Z

196

Stratigraphy and Reservoir-analog Modeling of Upper Miocene Shallow-water and Deep-water Carbonate Deposits: Agua Amarga Basin, Southeast Spain  

E-Print Network [OSTI]

(97.7 x 10 6 m 3 of reservoir pore volume); dispersed-flow deep-water deposits (5.71 x 10 6 m 3 of reservoir pore volume) that are heterogeneous and widespread; focused-flow deep-water deposits (14.6 x 10 6 m 3 of reservoir pore volume... odel).......................136 Apendix IX Dip Angle Maps.........................................................136 Apendix X Porosity Evolution........................................................138 vii List of Figures & Tables Chapter...

Dvoretsky, Rachel Ana

2009-03-10T23:59:59.000Z

197

Feasibility of Geophysical Monitoring of Carbon-Sequestrated Deep Saline Aquifers  

SciTech Connect (OSTI)

As carbon dioxide (CO{sub 2}) is sequestered from the bottom of a brine reservoir and allowed to migrate upward, the effects of the relative permeability hysteresis due to capillary trapping and buoyancy driven migration tend to make the reservoir patchy saturated with different fluid phases over time. Seismically, such a patchy saturated reservoir induces an effective anisotropic behavior whose properties are primarily dictated by the nature of the saturation of different fluid phases in the pores and the elastic properties of the rock matrix. By combining reservoir flow simulation and modeling with seismic modeling, it is possible to derive these effective anisotropic properties, which, in turn, could be related to the saturation of CO{sub 2} within the reservoir volume any time during the post-injection scenario. Therefore, if time-lapse seismic data are available and could be inverted for the effective anisotropic properties of the reservoir, they, in combination with reservoir simulation could potentially predict the CO{sub 2} saturation directly from the time-lapse seismic data. It is therefore concluded that the time-lapse seismic data could be used to monitor the carbon sequestrated saline reservoirs. But for its successful implementation, seismic modeling and inversion methods must be integrated with the reservoir simulations. In addition, because CO{sub 2} sequestration induces an effective anisotropy in the sequestered reservoir and anisotropy is best detected using multicomponent seismic data compared to single component (P-wave) data, acquisition, processing, and analysis is multicomponent seismic data is recommended for these time-lapse studies. Finally, a successful implementation of using time-lapse seismic data for monitoring the carbon sequestrated saline reservoirs will require development of a robust methodology for inverting multicomponent seismic data for subsurface anisotropic properties.

Mallick, Subhashis; Alvarado, Vladimir

2013-09-30T23:59:59.000Z

198

Seismic signatures of the Lodgepole fractured reservoir in Utah-Wyoming overthrust belt  

SciTech Connect (OSTI)

In low porosity, low permeability zones, natural fractures are the primary source of permeability which affect both production and injection of fluids. The open fractures do not contribute much to porosity, but they provide an increased drainage network to any porosity. An important approach to characterizing the fracture orientation and fracture permeability of reservoir formations is one based upon the effects of such conditions on the propagation of acoustic and seismic waves in the rock. We present the feasibility of using seismic measurement techniques to map the fracture zones between wells spaced 2400 ft at depths of about 1000 ft. For this purpose we constructed computer models (which include azimuthal anisotropy) using Lodgepole reservoir parameters to predict seismic signatures recorded at the borehole scale, crosswell scale, and 3 D seismic scale. We have integrated well logs with existing 2D surfaces seismic to produce petrophysical and geological cross sections to determine the reservoir parameters and geometry for the computer models. In particular, the model responses are used to evaluate if surface seismic and crosswell seismic measurements can capture the anisotropy due to vertical fractures. Preliminary results suggested that seismic waves transmitted between two wells will propagate in carbonate fracture reservoirs, and the signal can be received above the noise level at the distance of 2400 ft. In addition, the large velocities contrast between the main fracture zone and the underlying unfractured Boundary Ridge Member, suggested that borehole reflection imaging may be appropriate to map and fracture zone thickness variation and fracture distributions in the reservoir.

Parra, J.; Collier, H.; Angstman, B.

1997-08-01T23:59:59.000Z

199

Hydroelectric power provides a cheap source of electricity with few carbon emissions. Yet, reservoirs are not operated sustainably, which we define as meeting societal needs for water and power while protecting long-term health of the river ecosystem. Reservoirs that generate hydropower are typically operated with the goal of maximizing energy reve  

SciTech Connect (OSTI)

Hydroelectric power provides a cheap source of electricity with few carbon emissions. Yet, reservoirs are not operated sustainably, which we define as meeting societal needs for water and power while protecting long-term health of the river ecosystem. Reservoirs that generate hydropower are typically operated with the goal of maximizing energy revenue, while meeting other legal water requirements. Reservoir optimization schemes used in practice do not seek flow regimes that maximize aquatic ecosystem health. Here, we review optimization studies that considered environmental goals in one of three approaches. The first approach seeks flow regimes that maximize hydropower generation, while satisfying legal requirements, including environmental (or minimum) flows. Solutions from this approach are often used in practice to operate hydropower projects. In the second approach, flow releases from a dam are timed to meet water quality constraints on dissolved oxygen (DO), temperature and nutrients. In the third approach, flow releases are timed to improve the health of fish populations. We conclude by suggesting three steps for bringing multi-objective reservoir operation closer to the goal of ecological sustainability: (1) conduct research to identify which features of flow variation are essential for river health and to quantify these relationships, (2) develop valuation methods to assess the total value of river health and (3) develop optimal control softwares that combine water balance modelling with models that predict ecosystem responses to flow.

Jager, Yetta [ORNL; Smith, Brennan T [ORNL

2008-02-01T23:59:59.000Z

200

Trace Metal Source Terms in Carbon Sequestration Environments  

SciTech Connect (OSTI)

Carbon dioxide sequestration in deep saline and depleted oil geologic formations is feasible and promising, however, possible CO{sub 2} or CO{sub 2}-saturated brine leakage to overlying aquifers may pose environmental and health impacts. The purpose of this study was to experimentally define trace metal source terms from the reaction of supercritical CO{sub 2}, storage reservoir brines, reservoir and cap rocks. Storage reservoir source terms for trace metals are needed to evaluate the impact of brines leaking into overlying drinking water aquifers. The trace metal release was measured from sandstones, shales, carbonates, evaporites, basalts and cements from the Frio, In Salah, Illinois Basin – Decatur, Lower Tuscaloosa, Weyburn-Midale, Bass Islands and Grand Ronde carbon sequestration geologic formations. Trace metal dissolution is tracked by measuring solution concentrations over time under conditions (e.g. pressures, temperatures, and initial brine compositions) specific to the sequestration projects. Existing metrics for Maximum Contaminant Levels (MCLs) for drinking water as defined by the U.S. Environmental Protection Agency (U.S. EPA) were used to categorize the relative significance of metal concentration changes in storage environments due to the presence of CO{sub 2}. Results indicate that Cr and Pb released from sandstone reservoir and shale cap rock exceed the MCLs by an order of magnitude while Cd and Cu were at or below drinking water thresholds. In carbonate reservoirs As exceeds the MCLs by an order of magnitude, while Cd, Cu, and Pb were at or below drinking water standards. Results from this study can be used as a reasonable estimate of the reservoir and caprock source term to further evaluate the impact of leakage on groundwater quality.

Karamalidis, Athanasios K.; Torres, Sharon G.; Hakala, J. Alexandra; Shao, Hongbo; Cantrell, Kirk J.; Carroll, Susan

2013-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "reservoir rock carbon" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


201

Problems of fluid flow in a deformable reservoir  

E-Print Network [OSTI]

itself and the surrounding rock mass. The change in the stress-strain state of the system is induced by pressure change in the layers of the reservoir. Numerical results qualitatively agree with observed field behavior. Such behavior includes (1...

Diyashev, Ildar

2006-04-12T23:59:59.000Z

202

Wettability and Oil Recovery by Imbibition and Viscous Displacement from Fractured and Heterogeneous Carbonates  

SciTech Connect (OSTI)

About one-half of U.S. oil reserves are held in carbonate formations. The remaining oil in carbonate reservoirs is regarded as the major domestic target for improved oil recovery. Carbonate reservoirs are often fractured and have great complexity even at the core scale. Formation evaluation and prediction is often subject to great uncertainty. This study addresses quantification of crude oil/brine/rock interactions and the impact of reservoir heterogeneity on oil recovery by spontaneous imbibition and viscous displacement from pore to field scale. Wettability-alteration characteristics of crude oils were measured at calcite and dolomite surfaces and related to the properties of the crude oils through asphaltene content, acid and base numbers, and refractive index. Oil recovery was investigated for a selection of limestones and dolomites that cover over three orders of magnitude in permeability and a factor of four variation in porosity. Wettability control was achieved by adsorption from crude oils obtained from producing carbonate reservoirs. The induced wettability states were compared with those measured for reservoir cores. The prepared cores were used to investigate oil recovery by spontaneous imbibition and viscous displacement. The results of imbibition tests were used in wettability characterization and to develop mass transfer functions for application in reservoir simulation of fractured carbonates. Studies of viscous displacement in carbonates focused on the unexpected but repeatedly observed sensitivity of oil recovery to injection rate. The main variables were pore structure, mobility ratio, and wettability. The potential for improved oil recovery from rate-sensitive carbonate reservoirs by increased injection pressure, increased injectivity, decreased well spacing or reduction of interfacial tension was evaluated.

Norman R. Morrow; Jill Buckley

2006-04-01T23:59:59.000Z

203

GHG Emissions from Hydropower Reservoirs The role of hydropower reservoirs in contributing to greenhouse gas (GHG) emissions is poorly  

E-Print Network [OSTI]

to characterize carbon dioxide (CO2) and methane (CH4) emissions from hydropower reservoirs in the US SoutheastGHG Emissions from Hydropower Reservoirs The role of hydropower reservoirs in contributing to greenhouse gas (GHG) emissions is poorly understood, but recent studies have indicated that GHG emissions

204

Geoscience/engineering characterization of the interwell environment in carbonate reservoirs based on outcrop analogs, Permian Basin, West Texas and New Mexico--waterflood performance analysis for the South Cowden Grayburg Reservoir, Ector County, Texas. Final report  

SciTech Connect (OSTI)

A reservoir engineering study was conducted of waterflood performance in the South Cowden field, an Upper Permian Grayburg reservoir on the Central Basin Platform in West Texas. The study was undertaken to understand the historically poor waterflood performance, evaluate three techniques for incorporating petrophysical measurements and geological interpretation into heterogeneous reservoir models, and identify issues in heterogeneity modeling and fluid-flow scaleup that require further research. The approach included analysis of relative permeability data, analysis of injection and production data, heterogeneity modeling, and waterflood simulation. The poor South Cowden waterflood recovery is due, in part, to completion of wells in only the top half of the formation. Recompletion of wells through the entire formation is estimated to improve recovery in ten years by 6 percent of the original oil in place in some areas of the field. A direct three-dimensional stochastic approach to heterogeneity modeling produced the best fit to waterflood performance and injectivity, but a more conventional model based on smooth mapping of layer-averaged properties was almost as good. The results reaffirm the importance of large-scale heterogeneities in waterflood modeling but demonstrate only a slight advantage for stochastic modeling at this scale. All the flow simulations required a reduction to the measured whole-core k{sub v}/k{sub h} to explain waterflood behavior, suggesting the presence of barriers to vertical flow not explicitly accounted for in any of the heterogeneity models. They also required modifications to the measured steady-state relative permeabilities, suggesting the importance of small-scale heterogeneities and scaleup. Vertical flow barriers, small-scale heterogeneity modeling, and relative permeability scaleup require additional research for waterflood performance prediction in reservoirs like South Cowden.

Jennings, J.W. Jr.

1997-05-01T23:59:59.000Z

205

Altering Reservoir Wettability to Improve Production from Single Wells  

SciTech Connect (OSTI)

Many carbonate reservoirs are naturally fractured and typically produce less than 10% original oil in place during primary recovery. Spontaneous imbibition has proven an important mechanism for oil recovery from fractured reservoirs, which are usually weak waterflood candidates. In some situations, chemical stimulation can promote imbibition of water to alter the reservoir wettability toward water-wetness such that oil is produced at an economic rate from the rock matrix into fractures. In this project, cores and fluids from five reservoirs were used in laboratory tests: the San Andres formation (Fuhrman Masho and Eagle Creek fields) in the Permian Basin of Texas and New Mexico; and the Interlake, Stony Mountain, and Red River formations from the Cedar Creek Anticline in Montana and South Dakota. Solutions of nonionic, anionic, and amphoteric surfactants with formation water were used to promote waterwetness. Some Fuhrman Masho cores soaked in surfactant solution had improved oil recovery up to 38%. Most Eagle Creek cores did not respond to any of the tested surfactants. Some Cedar Creek anticline cores had good response to two anionic surfactants (CD 128 and A246L). The results indicate that cores with higher permeability responded better to the surfactants. The increased recovery is mainly ascribed to increased water-wetness. It is suspected that rock mineralogy is also an important factor. The laboratory work generated three field tests of the surfactant soak process in the West Fuhrman Masho San Andres Unit. The flawlessly designed tests included mechanical well clean out, installation of new pumps, and daily well tests before and after the treatments. Treatments were designed using artificial intelligence (AI) correlations developed from 23 previous surfactant soak treatments. The treatments were conducted during the last quarter of 2006. One of the wells produced a marginal volume of incremental oil through October. It is interesting to note that the field tests were conducted in an area of the field that has not met production expectations. The dataset on the 23 Phosphoria well surfactant soaks was updated. An analysis of the oil decline curves indicted that 4.5 lb of chemical produced a barrel of incremental oil. The AI analysis supports the adage 'good wells are the best candidates.' The generally better performance of surfactant in the high permeability core laboratory tests supports this observation. AI correlations were developed to predict the response to water-frac stimulations in a tight San Andres reservoir. The correlations maybe useful in the design of Cedar Creek Anticline surfactant soak treatments planned for next year. Nuclear Magnetic Resonance scans of dolomite cores to measure porosity and saturation during the high temperature laboratory work were acquired. The scans could not be correlated with physical measurement using either conventional or AI methods.

W. W. Weiss

2006-09-30T23:59:59.000Z

206

Hydraulic fracturing in a naturally fractured reservoir  

SciTech Connect (OSTI)

Hydraulic fracturing of wells in naturally fractured reservoirs can differ dramatically from fracturing wells in conventional isotropic reservoirs. Fluid leakoff is the primary difference. In conventional reservoirs, fluid leakoff is controlled by reservoir matrix and fracture fluid parameters. The fluid leakoff rate in naturally fractured reservoirs is typically excessive and completely dominated by the natural fractures. This paper presents several field examples of a fracture stimulation program performed on the naturally fractured Devonia carbonate of West Texas. Qualitative pressure decline analysis and net treating pressure interpretation techniques were utilized to evaluate the existence of natural fractures in the Devonian Formation. Quantitative techniques were utilized to assess the importance of the natural fractures to the fracturing process. This paper demonstrates that bottomhole pressure monitoring of fracture stimulations has benefits over conducting minifrac treatments in naturally fractured reservoirs. Finally, the results of this evaluation were used to redesign fracture treatments to ensure maximum productivity and minimize costs.

Britt, L.K.; Hager, C.J.; Thompson, J.W.

1994-12-31T23:59:59.000Z

207

Micromodel Investigations of CO2 Exsolution from Carbonated Water...  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

Micromodel Investigations of CO2 Exsolution from Carbonated Water in Sedimentary Rocks. Micromodel Investigations of CO2 Exsolution from Carbonated Water in Sedimentary Rocks....

208

Figure 2. Stratigraphic Summary of Ages, Names and Rock Types...  

Gasoline and Diesel Fuel Update (EIA)

2. Stratigraphic Summary of Ages, Names and Rock Types in the ANWR 1002 and Coastal Plain Area of the Alaska North Slope. Potentially Productive Reservoirs and Plays Assessed by...

209

Characterization and reservoir evaluation of a hydraulically fractured, shaly gas reservoir  

E-Print Network [OSTI]

, Shaly Gas Reservoir. ( December 1991 ) Cesar Alfonso Santiago Molina, Ingeniero de Petroleos, Universidad Nacional de Colombia; Chair of Advisory Committee: Dr. Steven W. Poston Shale content in reservoir rocks affect their petrophysical properties... for their support. The author also wishes to express his deepest appreciation to Dr. H. Chen for all the help and suggestions he made in this study. The author expresses his gratitude to every one in Empresa Colombiana de Petroleos, Ecopetrol, who made possible...

Santiago Molina, Cesar Alfonso

1991-01-01T23:59:59.000Z

210

Non-Darcy flow in geothermal reservoirs  

SciTech Connect (OSTI)

The effects of non-Darcy flow laws are investigated for two geothermal reservoir types: multiphase and Hot Dry Rock (HDR). Long-term thermal behavior is emphasized as short-term pressure transient behavior is addressed in the oil field literature. Comparisons of Darcy and non-Darcy flow laws are made.

Zyvoloski, G.

1982-01-01T23:59:59.000Z

211

Fourteenth workshop geothermal reservoir engineering: Proceedings  

SciTech Connect (OSTI)

The Fourteenth Workshop on Geothermal Reservoir Engineering was held at Stanford University on January 24--26, 1989. Major areas of discussion include: (1) well testing; (2) various field results; (3) geoscience; (4) geochemistry; (5) reinjection; (6) hot dry rock; and (7) numerical modelling. For these workshop proceedings, individual papers are processed separately for the Energy Data Base.

Ramey, H.J. Jr.; Kruger, P.; Horne, R.N.; Miller, F.G.; Brigham, W.E.; Cook, J.W.

1989-01-01T23:59:59.000Z

212

Fourteenth workshop geothermal reservoir engineering: Proceedings  

SciTech Connect (OSTI)

The Fourteenth Workshop on Geothermal Reservoir Engineering was held at Stanford University on January 24--26, 1989. Major areas of discussion include: (1) well testing; (2) various field results; (3) geoscience; (4) geochemistry; (5) reinjection; (6) hot dry rock; and (7) numerical modelling. For these workshop proceedings, individual papers are processed separately for the Energy Data Base.

Ramey, H.J. Jr.; Kruger, P.; Horne, R.N.; Miller, F.G.; Brigham, W.E.; Cook, J.W.

1989-12-31T23:59:59.000Z

213

Evaluating the Influence of Pore Architecture and Initial Saturation on Wettability and Relative Permeability in Heterogeneous, Shallow-Shelf Carbonates  

SciTech Connect (OSTI)

Thin (3-40 ft thick), heterogeneous, limestone and dolomite reservoirs, deposited in shallow-shelf environments, represent a significant fraction of the reservoirs in the U.S. midcontinent and worldwide. In Kansas, reservoirs of the Arbuckle, Mississippian, and Lansing-Kansas City formations account for over 73% of the 6.3 BBO cumulative oil produced over the last century. For these reservoirs basic petrophysical properties (e.g., porosity, absolute permeability, capillary pressure, residual oil saturation to waterflood, resistivity, and relative permeability) vary significantly horizontally, vertically, and with scale of measurement. Many of these reservoirs produce from structures of less than 30-60 ft, and being located in the capillary pressure transition zone, exhibit vertically variable initial saturations and relative permeability properties. Rather than being simpler to model because of their small size, these reservoirs challenge characterization and simulation methodology and illustrate issues that are less apparent in larger reservoirs where transition zone effects are minor and most of the reservoir is at saturations near S{sub wirr}. These issues are further augmented by the presence of variable moldic porosity and possible intermediate to mixed wettability and the influence of these on capillary pressure and relative permeability. Understanding how capillary-pressure properties change with rock lithology and, in turn, within transition zones, and how relative permeability and residual oil saturation to waterflood change through the transition zone is critical to successful reservoir management and as advanced waterflood and improved and enhanced recovery methods are planned and implemented. Major aspects of the proposed study involve a series of tasks to measure data to reveal the nature of how wettability and drainage and imbibition oil-water relative permeability change with pore architecture and initial water saturation. Focus is placed on carbonate reservoirs of widely varying moldic pore systems that represent the major of reservoirs in Kansas and are important nationally and worldwide. A goal of the project is to measure wettability, using representative oils from Kansas fields, on a wide range of moldic-porosity lithofacies that are representative of Kansas and midcontinent shallow-shelf carbonate reservoirs. This investigation will discern the relative influence of wetting and pore architecture. In the midcontinent, reservoir water saturations are frequently greater than 'irreducible' because many reservoirs are largely in the capillary transition zone. This can change the imbibition oil-water relative permeability relations. Ignoring wettability and transition-zone relative permeabilities in reservoir modeling can lead to over- and under-prediction of oil recovery and recovery rates, and less effective improved recovery management. A goal of this project is to measure drainage and imbibition oil-water relative permeabilities for a large representative range of lithofacies at differ ent initial water saturations to obtain relations that can be applied everywhere in the reservoir. The practical importance of these relative permeability and wettability models will be demonstrated by using reservoir simulation studies on theoretical/generic and actual reservoir architectures. The project further seeks to evaluate how input of these new models affects reservoir simulation results at varying scales. A principal goal is to obtain data that will allow us to create models that will show how to accurately simulate flow in the shallow-structure, complex carbonate reservoirs that lie in the transition zone. Tasks involved to meet the project objectives include collection and consolidation of available data into a publicly accessible relational digital database and collection of oil and rock samples from carbonate fields around the state (Task 1). Basic properties of these rocks and oils will be measured and used in wettability tests. Comparison will be performed between crude and synthetic oil wettability and

Alan P. Byrnes; Saibal Bhattacharya; John Victorine; Ken Stalder

2007-09-30T23:59:59.000Z

214

Core Analysis for the Development and Constraint of Physical Models of Geothermal Reservoirs  

SciTech Connect (OSTI)

Effective reservoir exploration, characterization, and engineering require a fundamental understanding of the geophysical properties of reservoir rocks and fracture systems. Even in the best of circumstances, spatial variability in porosity, fracture density, salinity, saturation, tectonic stress, fluid pressures, and lithology can all potentially produce and/or contribute to geophysical anomalies. As a result, serious uniqueness problems frequently occur when interpreting assumptions based on a knowledge base founded in validated rock physics models of reservoir material.

Greg N. Boitnott

2003-12-14T23:59:59.000Z

215

FRACTURED PETROLEUM RESERVOIRS  

SciTech Connect (OSTI)

The four chapters that are described in this report cover a variety of subjects that not only give insight into the understanding of multiphase flow in fractured porous media, but they provide also major contribution towards the understanding of flow processes with in-situ phase formation. In the following, a summary of all the chapters will be provided. Chapter I addresses issues related to water injection in water-wet fractured porous media. There are two parts in this chapter. Part I covers extensive set of measurements for water injection in water-wet fractured porous media. Both single matrix block and multiple matrix blocks tests are covered. There are two major findings from these experiments: (1) co-current imbibition can be more efficient than counter-current imbibition due to lower residual oil saturation and higher oil mobility, and (2) tight fractured porous media can be more efficient than a permeable porous media when subjected to water injection. These findings are directly related to the type of tests one can perform in the laboratory and to decide on the fate of water injection in fractured reservoirs. Part II of Chapter I presents modeling of water injection in water-wet fractured media by modifying the Buckley-Leverett Theory. A major element of the new model is the multiplication of the transfer flux by the fractured saturation with a power of 1/2. This simple model can account for both co-current and counter-current imbibition and computationally it is very efficient. It can be orders of magnitude faster than a conventional dual-porosity model. Part II also presents the results of water injection tests in very tight rocks of some 0.01 md permeability. Oil recovery from water imbibition tests from such at tight rock can be as high as 25 percent. Chapter II discusses solution gas-drive for cold production from heavy-oil reservoirs. The impetus for this work is the study of new gas phase formation from in-situ process which can be significantly different from that of gas displacement processes. The work is of experimental nature and clarifies several misconceptions in the literature. Based on experimental results, it is established that the main reason for high efficiency of solution gas drive from heavy oil reservoirs is due to low gas mobility. Chapter III presents the concept of the alteration of porous media wettability from liquid-wetting to intermediate gas-wetting. The idea is novel and has not been introduced in the petroleum literature before. There are significant implications from such as proposal. The most direct application of intermediate gas wetting is wettability alteration around the wellbore. Such an alteration can significantly improve well deliverability in gas condensate reservoirs where gas well deliverability decreases below dewpoint pressure. Part I of Chapter III studies the effect of gravity, viscous forces, interfacial tension, and wettability on the critical condensate saturation and relative permeability of gas condensate systems. A simple phenomenological network model is used for this study, The theoretical results reveal that wettability significantly affects both the critical gas saturation and gas relative permeability. Gas relative permeability may increase ten times as contact angle is altered from 0{sup o} (strongly liquid wet) to 85{sup o} (intermediate gas-wetting). The results from the theoretical study motivated the experimental investigation described in Part II. In Part II we demonstrate that the wettability of porous media can be altered from liquid-wetting to gas-wetting. This part describes our attempt to find appropriate chemicals for wettability alteration of various substrates including rock matrix. Chapter IV provides a comprehensive treatment of molecular, pressure, and thermal diffusion and convection in porous media Basic theoretical analysis is presented using irreversible thermodynamics.

Abbas Firoozabadi

1999-06-11T23:59:59.000Z

216

White Rock  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

Furnished house for rent in rural White Rock Bright and sunny Ideal for a young family Safe neighborhood 10 min drive to LANL 1300 per month, basic utilities included 1180 sq ft....

217

Application of reservoir models to Cherokee Reservoir  

SciTech Connect (OSTI)

As a part of the Cherokee Reservoir Project hydrodynamic-temperature models and water quality models hav

Kim, B.R.; Bruggink, D.J.

1982-01-01T23:59:59.000Z

218

4D Seismic to Image a Thin Carbonate Reservoir During a Miscible CO2 Flood: Hall-Gurney Field, Kansas, USA  

E-Print Network [OSTI]

and processing, and use of amplitude envelope 4D horizon attributes. Comparison of production data and reservoir simulations to seismic images provided a measure of the effectiveness of time-lapse (TL) to detect weak anomalies associated with changes in fluid...

Raef, A.E.; Miller, Richard D.; Franseen, Evan K.; Byrnes, A.P.; Watney, W.L.; Harrison, W.E.

2005-05-01T23:59:59.000Z

219

Application of integrated reservoir management and reservoir characterization to optimize infill drilling  

SciTech Connect (OSTI)

This project has used a multi-disciplinary approach employing geology, geophysics, and engineering to conduct advanced reservoir characterization and management activities to design and implement an optimized infill drilling program at the North Robertson (Clearfork) Unit in Gaines County, Texas. The activities during the first Budget Period consisted of developing an integrated reservoir description from geological, engineering, and geostatistical studies, and using this description for reservoir flow simulation. Specific reservoir management activities were identified and tested. The geologically targeted infill drilling program currently being implemented is a result of this work. A significant contribution of this project is to demonstrate the use of cost-effective reservoir characterization and management tools that will be helpful to both independent and major operators for the optimal development of heterogeneous, low permeability shallow-shelf carbonate (SSC) reservoirs. The techniques that are outlined for the formulation of an integrated reservoir description apply to all oil and gas reservoirs, but are specifically tailored for use in the heterogeneous, low permeability carbonate reservoirs of West Texas.

NONE

1997-04-01T23:59:59.000Z

220

USING RECENT ADVANCES IN 2D SEISMIC TECHNOLOGY AND SURFACE GEOCHEMISTRY TO ECONOMICALLY REDEVELOP A SHALLOW SHELF CARBONATE RESERVOIR: VERNON FIELD, ISABELLA COUNTY, MI  

SciTech Connect (OSTI)

One of the main objectives of this demonstration project is to test surface geochemical techniques for detecting trace amounts of light hydrocarbons in pore gases as a means of reducing risk in hydrocarbon exploration and production. As part of the project, several field demonstrations were undertaken to assess the validity and usefulness of the microbial surface geochemical technique. The important observations from each of these field demonstrations are briefly reviewed in this annual report. These demonstrations have been successful in identifying the presence or lack of hydrocarbons in the subsurface and can be summarized as follows: (1) The surface geochemistry data showed a fair-to-good microbial anomaly that may indicate the presence of a fault or stratigraphic facies change across the drilling path of the State Springdale & O'Driscoll No.16-16 horizontal demonstration well in Manistee County, Michigan. The well was put on production in December 2003. To date, the well is flowing nearly 100 barrels of liquid hydrocarbons per day plus gas, which is a good well in Michigan. Reserves have not been established yet. Two successful follow-up horizontal wells have also been drilled in the Springdale area. Additional geochemistry data will be collected in the Springdale area in 2004. (2) The surface geochemistry sampling in the Bear Lake demonstration site in Manistee County, Michigan was updated after the prospect was confirmed and production begun; the original subsurface and seismic interpretation used to guide the location of the geochemical survey for the Charlich Fauble re-entry was different than the interpretation used by the operator who ultimately drilled the well. As expected, the anomaly appears to be diminishing as the positive (apical) microbial anomaly is replaced by a negative (edge) anomaly, probably due to the pressure draw-down in the reservoir. (3) The geochemical sampling program over the Vernon Field, Isabella County, Michigan is now interpreted as a large negative anomaly associated with the entire field. The results of the State Smock horizontal well and the Bowers 4-25 well confirmed the lack of additional recoverable hydrocarbons in the Vernon Field. (4) The surface geochemistry data showed a strong anomaly in the Myrtle Beach, Burke County, North Dakota area that would justify drilling by itself and even more so in conjunction with the structural interpretation from the geological and geophysical data; the microbial values here were the highest we have observed. The Myrtle Beach geochemical survey indicated a good to excellent prospect which was confirmed by drilling, however, a pipeline has not yet been completed that would allow the wells to be placed into production. We also present in this annual report the results of recent efforts to map carbonate facies tracts in the middle Devonian Dundee and Rogers City Limestones using gamma ray, bulk density, and photoelectric effect geophysical well log amplitudes. This work was undertaken to identify fairways for exploration in the Dundee and Rogers City where surface geochemical techniques could then be used to screen potential leads.

James R. Wood; A. Wylie; W. Quinlan

2004-04-01T23:59:59.000Z

Note: This page contains sample records for the topic "reservoir rock carbon" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


221

Petroleum potential of lower and middle Paleozoic rocks in Nebraska portion of Mid-Continent  

SciTech Connect (OSTI)

Central North America during the Paleozoic was characterized by northern (Williston) and southern (Anadarko) depositional regimes separated by a stable Transcontinental arch. Nebraska lies on the southern flank of this arch and contains the northern zero edges of the lower and middle Paleozoic rocks of the southern regime. Most of these rocks are secondary dolomites with zones of excellent intercrystalline porosity. The Reagan-LaMotte Sandstones and the overlying Arbuckle dolomites are overlapped by Middle Ordovician rocks toward the Transcontinental arch. Rocks equivalent to the Simpson consist of a basal sand (St. Peter) and overlying interbedded gray-green shales and dolomitic limestones. An uppermost shale facies is present in the Upper Ordovician (Viola-Maquoketa) eastward and southward across Nebraska. The dolomite facies extends northward into the Williston basin. The Silurian dolomites, originally more widely deposited, are overlapped by Devonian dolomites in southeastern Nebraska. Upper Devonian rocks exhibit a regional facies change from carbonate to green-gray shale to black shale southeastward across the Mid-Continent. Mississippian carbonates overlap the Devonian westward and northward across the Transcontinental arch. Pennsylvanian uplift and erosion were widespread, producing numerous stratigraphic traps. Sands related to the basal Pennsylvanian unconformity produce along the Cambridge arch. Arbuckle, Simpson, Viola, and Hunton production is present in the Forest City basin and along the Central Kansas uplift. Although source rocks are scarce and the maturation is marginal, current theories of long-distance oil migration encourage exploration in the extensive lower and middle Paleozoic reservoirs in this portion of the Mid-Continent.

Carlson, M.P. (Univ. of Nebraska, Lincoln (USA))

1989-08-01T23:59:59.000Z

222

An Integrated Study of the Grayburg/San Andres Reservoir, Foster and South Cowden Fields, Ector County, Texas  

SciTech Connect (OSTI)

A project to recover economic amounts of oil from a very mature oil field is being conducted by Laguna Petroleum Corporation of Midland, Texas, with partial funding from a U. S. Department of Energy grant to study shallow carbonate rock reservoirs. The objectives of the project are to use modern engineering methods to optimize oil field management and to use geological and geophysical data to recover untapped potential within the petroleum reservoirs. The integration of data and techniques from these disciplines has yielded results greater than those achievable without their cooperation. The cost of successfully accomplishing these goals is to be low enough for even small independent operators to afford. This article is a report describing accomplishments for the fiscal year 1997-1998.

Robinson, William C.; Trentham, Robert C.; Widner, Kevin; Wienbrandt, Richard

1999-06-22T23:59:59.000Z

223

Enhancing the Spontaneous Imbibition Process in Naturally Fractured Reservoirs through Wettability Alteration Using Surfactants: Mechanistic Study and Feasibility of Using Biosurfactants Produced from Agriculture Waste Streams  

E-Print Network [OSTI]

to adsorption onto the reservoir rock, because for the process to be effective, the injected surfactant solution should be able to penetrate deep into the reservoir. So, in this work, static and dynamic adsorption isotherms for both biosurfactant and benchmark...

Salehi, Mehdi

2009-01-01T23:59:59.000Z

224

Design and Implementation of a CO2 Flood Utilizing Advanced Reservoir Characterization and Horizontal Injection Wells In a Shallow Shelf Carbonate Approaching Waterflood Depletion  

SciTech Connect (OSTI)

This project consist of two budget phases. Budget Phase I started in June 1994 and ended late June 1996. During this phase the Reservoir Analysis and Characterization Task and the Advanced Technology Definition Task were completed. Completion of these tasks enabled the project to be designed, and an Authority for Expenditure (AFE) for project implementation to be generated and submitted to the working interest owners for approval. Budget Phase II consists of the implementation and execution of the project in the field.

Czirr, K.L.; Owen, R.; Robertson, C.R.; Harpole, K.J.; Durrett, E.G.

1999-11-09T23:59:59.000Z

225

Carbon Sequestration  

SciTech Connect (OSTI)

Carbon Sequestration- the process of capturing the CO2 released by the burning of fossil fuels and storing it deep withing the Earth, trapped by a non-porous layer of rock.

None

2013-05-06T23:59:59.000Z

226

An Evaluation of the Carbon Sequestration Potential of the Cambro-Ordovician Strata of the Illinois and Michigan Basins: Part 1: Evaluation of Phase 2 CO{sub 2} Injection Testing in the Deep Saline Gunter Sandstone Reservoir (Cambro-Ordovician Knox Group), Marvin Blan No. 1 Hancock County, Kentucky Part 2: Time-lapse Three-Dimensional Vertical Seismic Profile (3D-VSP) of Sequestration Target Interval with Injected Fluids  

SciTech Connect (OSTI)

Part 1 of this report focuses on results of the western Kentucky carbon storage test, and provides a basis for evaluating injection and storage of supercritical CO{sub 2} in Cambro-Ordovician carbonate reservoirs throughout the U.S. Midcontinent. This test demonstrated that the Cambro- Ordovician Knox Group, including the Beekmantown Dolomite, Gunter Sandstone, and Copper Ridge Dolomite in stratigraphic succession from shallowest to deepest, had reservoir properties suitable for supercritical CO{sub 2} storage in a deep saline reservoir hosted in carbonate rocks, and that strata with properties sufficient for long-term confinement of supercritical CO{sub 2} were present in the deep subsurface. Injection testing with brine and CO{sub 2} was completed in two phases. The first phase, a joint project by the Kentucky Geological Survey and the Western Kentucky Carbon Storage Foundation, drilled the Marvin Blan No. 1 carbon storage research well and tested the entire Knox Group section in the open borehole � including the Beekmantown Dolomite, Gunter Sandstone, and Copper Ridge Dolomite � at 1152�2255 m, below casing cemented at 1116 m. During Phase 1 injection testing, most of the 297 tonnes of supercritical CO{sub 2} was displaced into porous and permeable sections of the lowermost Beekmantown below 1463 m and Gunter. The wellbore was then temporarily abandoned with a retrievable bridge plug in casing at 1105 m and two downhole pressure-temperature monitoring gauges below the bridge plug pending subsequent testing. Pressure and temperature data were recorded every minute for slightly more than a year, providing a unique record of subsurface reservoir conditions in the Knox. In contrast, Phase 2 testing, this study, tested a mechanically-isolated dolomitic-sandstone interval in the Gunter. Operations in the Phase 2 testing program commenced with retrieval of the bridge plug and long-term pressure gauges, followed by mechanical isolation of the Gunter by plugging the wellbore with cement below the injection zone at 1605.7 m, then cementing a section of a 14-cm casing at 1470.4�1535.6. The resultant 70.1-m test interval at 1535.6�1605.7 m included nearly all of the Gunter sandstone facies. During the Phase 2 injection, 333 tonnes of CO{sub 2} were injected into the thick, lower sand section in the sandy member of the Gunter. Following the completion of testing, the injection zone below casing at 1116 m in the Marvin Blan No. 1 well, and wellbore below 305 m was permanently abandoned with cement plugs and the wellsite reclaimed. The range of most-likely storage capacities found in the Knox in the Marvin Blan No. 1 is 1000 tonnes per surface hectare in the Phase 2 Gunter interval to 8685 tonnes per surface hectare if the entire Knox section were available including the fractured interval near the base of the Copper Ridge. By itself the Gunter lacks sufficient reservoir volume to be considered for CO{sub 2} storage, although it may provide up to 18% of the reservoir volume available in the Knox. Regional extrapolation of CO{sub 2} storage potential based on the results of a single well test can be problematic, although indirect evidence of porosity and permeability can be demonstrated in the form of active saltwater-disposal wells injecting into the Knox. The western Kentucky region suitable for CO{sub 2} storage in the Knox is limited updip, to the east and south, by the depth at which the base of the Maquoketa shale lies above the depth required to ensure storage of CO{sub 2} in its supercritical state and the deepest a commercial well might be drilled for CO{sub 2} storage. The resulting prospective region has an area of approximately 15,600 km{sup 2}, beyond which it is unlikely that suitable Knox reservoirs may be developed. Faults in the subsurface, which serve as conduits for CO{sub 2} migration and compromise sealing strata, may mitigate the area with Knox reservoirs suitable for CO{sub 2} storage. The results of the injection tes

Richard Bowersox; John Hickman; Hannes Leetaru

2012-12-01T23:59:59.000Z

227

Establishment of an oil and gas database for increased recovery and characterization of oil and gas carbonate reservoir heterogeneity. [Jurassic Smackover Formation  

SciTech Connect (OSTI)

This volume contains maps, well logging correlated to porosity and permeability, structural cross section, graph of production history, porosity vs. natural log permeability plot, detailed core log, paragenetic sequence and reservoir characterization sheet of the following fields in southwest Alabama: Appleton oil field; Barnett oil field; Barrytown oil field; Big Escambia Creek gas and condensate field; Blacksher oil field; Broken Leg Creed oil field; Bucatunna Creed oil field; Chappell Hill oil field; Chatom gas and condensate field; Choctaw Ridge oil field; Chunchula gas and condensate field; Cold Creek oil field; Copeland gas and condensate field; Crosbys Creed gas and condensate field; and East Barnett oil field. (AT)

Kopaska-Merkel, D.C.; Moore, H.E. Jr.; Mann, S.D.; Hall, D.R.

1992-06-01T23:59:59.000Z

228

Establishment of an oil and gas database for increased recovery and characterization of oil and gas carbonate reservoir heterogeneity. Appendix 1, Volume 1  

SciTech Connect (OSTI)

This volume contains maps, well logging correlated to porosity and permeability, structural cross section, graph of production history, porosity vs. natural log permeability plot, detailed core log, paragenetic sequence and reservoir characterization sheet of the following fields in southwest Alabama: Appleton oil field; Barnett oil field; Barrytown oil field; Big Escambia Creek gas and condensate field; Blacksher oil field; Broken Leg Creed oil field; Bucatunna Creed oil field; Chappell Hill oil field; Chatom gas and condensate field; Choctaw Ridge oil field; Chunchula gas and condensate field; Cold Creek oil field; Copeland gas and condensate field; Crosbys Creed gas and condensate field; and East Barnett oil field. (AT)

Kopaska-Merkel, D.C.; Moore, H.E. Jr.; Mann, S.D.; Hall, D.R.

1992-06-01T23:59:59.000Z

229

Identification of Pore Structure and Clay Content from Seismic Data within an Argillaceous Sandstone Reservoir  

E-Print Network [OSTI]

IDENTIFICATION OF PORE STRUCTURE AND CLAY CONTENT FROM SEISMIC DATA WITHIN AN ARGILLACEOUS SANDSTONE RESERVOIR A Thesis by ROBERT LELAND SCHELSTRATE Submitted to the Office of Graduate and Professional Studies of Texas A&M University... Ds Compressibility of the rock matrix Dd Compressibility of the dry rock frame Df Compressibility of the pore-filling fluid F, FK Frame flexibility factors kd Bulk modulus of dry rock Ks Bulk modulus of the rock...

Schelstrate, Robert

2014-08-11T23:59:59.000Z

230

2. INVESTIGATION OF CRUDE OIL/BRINE/ROCK INTERACTION 2.1 STUDY OF WATERFLOODING PROCESS IN NATURALLY FRACTURED  

E-Print Network [OSTI]

, followed by waterflooding, were performed at reservoir conditions to investigate rock wettability. A two Berea and Spraberry cores at reservoir conditions to illustrate the actual process of waterflooding- 31 - 2. INVESTIGATION OF CRUDE OIL/BRINE/ROCK INTERACTION 2.1 STUDY OF WATERFLOODING PROCESS

Schechter, David S.

231

APPLICATION OF RESERVOIR CHARACTERIZATION AND ADVANCED TECHNOLOGY TO IMPROVE RECOVERY AND ECONOMICS IN A LOWER QUALITY SHALLOW SHELF SANANDRES RESERVOIR  

SciTech Connect (OSTI)

The Class 2 Project at West Welch was designed to demonstrate the use of advanced technologies to enhance the economics of improved oil recovery (IOR) projects in lower quality Shallow Shelf Carbonate (SSC) reservoirs, resulting in recovery of additional oil that would otherwise be left in the reservoir at project abandonment. Accurate reservoir description is critical to the effective evaluation and efficient design of IOR projects in the heterogeneous SSC reservoirs. Therefore, the majority of Budget Period 1 was devoted to reservoir characterization. Technologies being demonstrated include: (1) Advanced petrophysics; (2) Three-dimensional (3-D) seismic; (3) Crosswell bore tomography; (4) Advanced reservoir simulation; (5) Carbon dioxide (CO{sub 2}) stimulation treatments; (6) Hydraulic fracturing design and monitoring; (7) Mobility control agents.

Unknown

2003-01-15T23:59:59.000Z

232

Experimental and Simulation Studies to Evaluate the Improvement of Oil Recovery by Different Modes of CO2 Injection in Carbonate Reservoirs  

E-Print Network [OSTI]

Experimental and numerical simulation studies were conducted to investigate the improvement of light oil recovery in carbonate cores during CO2 injection. The main steps in the study are as follows. First, the minimum miscibility pressure of 31º...

Aleidan, Ahmed Abdulaziz S.

2011-02-22T23:59:59.000Z

233

Thermo-Poroelastic Modeling of Reservoir Stimulation and Microseismicity Using Finite Element Method with Damage Mechanics  

E-Print Network [OSTI]

, changing rock permeability. In this work, two- and three-dimensional finite element methods were developed to simulate coupled reservoirs with damage mechanics and stress-dependent permeability. The model considers the influence of fluid flow, temperature...

Lee, Sang Hoon

2012-02-14T23:59:59.000Z

234

Imaging the Soultz Enhanced Geothermal Reservoir using double-difference tomography and microseismic data  

E-Print Network [OSTI]

We applied the double-difference tomography method to image the P and S-wave velocity structure of the European Hot Dry Rock geothermal reservoir (also known as the Soultz Enhanced Geothermal System) at Soultz-sous-Forets, ...

Piñeros Concha, Diego Alvaro

2010-01-01T23:59:59.000Z

235

Enhanced oil recovery through water imbibition in fractured reservoirs using Nuclear Magnetic Resonance  

E-Print Network [OSTI]

Conventional waterflooding methods of oil recovery are difficult to apply when reservoirs show evidence of natural fractures, because injected water advances through paths of high permeability, and oil trapped in the rock matrix system...

Hervas Ordonez, Rafael Alejandro

1994-01-01T23:59:59.000Z

236

Structural Reliability: Assessing the Condition and Reliability of Casing in Compacting Reservoirs  

E-Print Network [OSTI]

. Effective stress may exceed rock compressive strength, inducing compaction. Wells in compacting reservoirs risk high failure and deformation rates. This project introduces the concept of structural reliability to quantify casing failure risks in compacting...

Chantose, Prasongsit

2012-02-14T23:59:59.000Z

237

ANALYSIS O F HEAT TRANSFER AND ENERGY RECOVERY I N FRACTURED GEOTHERMAL RESERVOIRS  

E-Print Network [OSTI]

Produced . . . . . . . . . . . 4.5 Experimental Reservoir Rock Energy Extracted Fraction . 4.6 Cold-Water Fraction Produced . . . . . . . . 3.6.4 Energy Balance . . . . . . . . . . . . . . . . . . 3.7 One-Dimensional Model of a Cold-Water Sweep Process . . 4 . RESULTS

Stanford University

238

The Effect of Proppant Size and Concentration on Hydraulic Fracture Conductivity in Shale Reservoirs  

E-Print Network [OSTI]

Hydraulic fracture conductivity in ultra-low permeability shale reservoirs is directly related to well productivity. The main goal of hydraulic fracturing in shale formations is to create a network of conductive pathways in the rock which increase...

Kamenov, Anton

2013-04-11T23:59:59.000Z

239

Status of Cherokee Reservoir  

SciTech Connect (OSTI)

This is the first in a series of reports prepared by Tennessee Valley Authority (TVA) for those interested in the conditions of TVA reservoirs. This overviews of Cherokee Reservoir summarizes reservoir and watershed characteristics, reservoir uses and use impairments, water quality and aquatic biological conditions, and activities of reservoir management agencies. This information was extracted from the most current reports, publications, and data available, and interviews with water resource professionals in various Federal, state, and local agencies and in public and private water supply and wastewater treatment facilities. 11 refs., 4 figs., 1 tab.

Not Available

1990-08-01T23:59:59.000Z

240

Development and distribution of Rival reservoirs in central Williston basin, western North Dakota  

SciTech Connect (OSTI)

The Mississippian Rival (Nesson) beds in the central Williston basin, North Dakota, are a limestone to evaporite regressive sequence. Progradation of the depositional system produced several distinct shallowing-upward genetic units. Cyclicity in Rival beds was produced by periodic fluctuations in sea level. Rival oil reservoirs are porous and permeable packstones and grainstones. The dominant allochems in these reservoir rocks are peloids and skeletal and algal fragments. These sediments were deposited along carbonate shorelines and within algal banks that developed basinward of shorelines. The trapping mechanism along shorelines is a lithofacies change from limestone to anhydride. Algal banks are locally productive along paleostructural trends where bathymetric shallowing produced shoals dominated by the Codiacean alga Ortonella. Algal banks are flanked by impermeable carbonate mudstones and wackestones deposited in interbank and protected shelf environments. Two distinct Rival bank trends occur in the central basin: a northwest-southeast trend in McKenzie and Williams Counties, North Dakota, parallel with the Cedar Creek anticline, and a northeast-southwest trend along the Nesson anticline and the northeast flank of the basin, parallel with the Weldon-Brockton fault trend.

Hendricks, M.L.

1988-07-01T23:59:59.000Z

Note: This page contains sample records for the topic "reservoir rock carbon" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


241

Reservoir Character of the Avalon Shale (Bone Spring Formation) of the Delaware Basin, West Texas and Southeast New Mexico: Effect of Carbonate-rich Sediment Gravity Flows  

E-Print Network [OSTI]

play is not considered to extend to the top of the first Bone Spring carbonate because hydraulic fracturing in the upper parts may penetrate overlying water-bearing units within the Delaware Mountains Group. The Avalon has been reported to range from...

Stolz, Dustin

2014-05-31T23:59:59.000Z

242

Fractured shale reservoirs: Towards a realistic model  

SciTech Connect (OSTI)

Fractured shale reservoirs are fundamentally unconventional, which is to say that their behavior is qualitatively different from reservoirs characterized by intergranular pore space. Attempts to analyze fractured shale reservoirs are essentially misleading. Reliance on such models can have only negative results for fractured shale oil and gas exploration and development. A realistic model of fractured shale reservoirs begins with the history of the shale as a hydrocarbon source rock. Minimum levels of both kerogen concentration and thermal maturity are required for effective hydrocarbon generation. Hydrocarbon generation results in overpressuring of the shale. At some critical level of repressuring, the shale fractures in the ambient stress field. This primary natural fracture system is fundamental to the future behavior of the fractured shale gas reservoir. The fractures facilitate primary migration of oil and gas out of the shale and into the basin. In this process, all connate water is expelled, leaving the fractured shale oil-wet and saturated with oil and gas. What fluids are eventually produced from the fractured shale depends on the consequent structural and geochemical history. As long as the shale remains hot, oil production may be obtained. (e.g. Bakken Shale, Green River Shale). If the shale is significantly cooled, mainly gas will be produced (e.g. Antrim Shale, Ohio Shale, New Albany Shale). Where secondary natural fracture systems are developed and connect the shale to aquifers or to surface recharge, the fractured shale will also produce water (e.g. Antrim Shale, Indiana New Albany Shale).

Hamilton-Smith, T. [Applied Earth Science, Lexington, KY (United States)

1996-09-01T23:59:59.000Z

243

Brine and Gas Flow Patterns Between Excavated Areas and Disturbed Rock Zone in the 1996 Performance Assessment for the Waste Isolation Pilot Plant for a Single Drilling Intrusion that Penetrates Repository and Castile Brine Reservoir  

SciTech Connect (OSTI)

The Waste Isolation Pilot Plant (WIPP), which is located in southeastern New Mexico, is being developed for the geologic disposal of transuranic (TRU) waste by the U.S. Department of Energy (DOE). Waste disposal will take place in panels excavated in a bedded salt formation approximately 2000 ft (610 m) below the land surface. The BRAGFLO computer program which solves a system of nonlinear partial differential equations for two-phase flow, was used to investigate brine and gas flow patterns in the vicinity of the repository for the 1996 WIPP performance assessment (PA). The present study examines the implications of modeling assumptions used in conjunction with BRAGFLO in the 1996 WIPP PA that affect brine and gas flow patterns involving two waste regions in the repository (i.e., a single waste panel and the remaining nine waste panels), a disturbed rock zone (DRZ) that lies just above and below these two regions, and a borehole that penetrates the single waste panel and a brine pocket below this panel. The two waste regions are separated by a panel closure. The following insights were obtained from this study. First, the impediment to flow between the two waste regions provided by the panel closure model is reduced due to the permeable and areally extensive nature of the DRZ adopted in the 1996 WIPP PA, which results in the DRZ becoming an effective pathway for gas and brine movement around the panel closures and thus between the two waste regions. Brine and gas flow between the two waste regions via the DRZ causes pressures between the two to equilibrate rapidly, with the result that processes in the intruded waste panel are not isolated from the rest of the repository. Second, the connection between intruded and unintruded waste panels provided by the DRZ increases the time required for repository pressures to equilibrate with the overlying and/or underlying units subsequent to a drilling intrusion. Third, the large and areally extensive DRZ void volumes is a significant source of brine to the repository, which is consumed in the corrosion of iron and thus contributes to increased repository pressures. Fourth, the DRZ itself lowers repository pressures by providing storage for gas and access to additional gas storage in areas of the repository. Fifth, given the pathway that the DRZ provides for gas and brine to flow around the panel closures, isolation of the waste panels by the panel closures was not essential to compliance with the U.S. Environment Protection Agency's regulations in the 1996 WIPP PA.

ECONOMY,KATHLEEN M.; HELTON,JON CRAIG; VAUGHN,PALMER

1999-10-01T23:59:59.000Z

244

Evolution of seismic velocities in heavy oil sand reservoirs during thermal recovery process  

E-Print Network [OSTI]

1 Evolution of seismic velocities in heavy oil sand reservoirs during thermal recovery process. Larribau 64018 Pau Cedex, France Oil and Gas Science and Technology 2012, 67 (6), 1029-1039, doi:10 pressure and temperature in the rock reservoir, that are most often unconsolidated or weakly consolidated

Paris-Sud XI, Université de

245

Multiscale heterogeneity characterization of tidal channel, tidal delta and foreshore facies, Almond Formation outcrops, Rock Springs uplift, Wyoming  

SciTech Connect (OSTI)

In order to accurately predict fluid flow within a reservoir, variability in the rock properties at all scales relevant to the specific depositional environment needs to be taken into account. The present work describes rock variability at scales from hundreds of meters (facies level) to millimeters (laminae) based on outcrop studies of the Almond Formation. Tidal channel, tidal delta and foreshore facies were sampled on the eastern flank of the Rock Springs uplift, southeast of Rock Springs, Wyoming. The Almond Fm. was deposited as part of a mesotidal Upper Cretaceous transgressive systems tract within the greater Green River Basin. Bedding style, lithology, lateral extent of beds of bedsets, bed thickness, amount and distribution of depositional clay matrix, bioturbation and grain sorting provide controls on sandstone properties that may vary more than an order of magnitude within and between depositional facies in outcrops of the Almond Formation. These features can be mapped on the scale of an outcrop. The products of diagenesis such as the relative timing of carbonate cement, scale of cemented zones, continuity of cemented zones, selectively leached framework grains, lateral variability of compaction of sedimentary rock fragments, and the resultant pore structure play an equally important, although less predictable role in determining rock property heterogeneity. A knowledge of the spatial distribution of the products of diagenesis such as calcite cement or compaction is critical to modeling variation even within a single facies in the Almond Fin. because diagenesis can enhance or reduce primary (depositional) rock property heterogeneity. Application of outcrop heterogeneity models to the subsurface is greatly hindered by differences in diagenesis between the two settings. The measurements upon which this study is based were performed both on drilled outcrop plugs and on blocks.

Schatzinger, R.A.; Tomutsa, L. [BDM Petroleum Technologies, Bartlesville, OK (United States)

1997-08-01T23:59:59.000Z

246

The effects of gas-fluid-rock interactions on CO2 injection and storage: Insights from reactive transport modeling  

SciTech Connect (OSTI)

Possible means of reducing atmospheric CO{sub 2} emissions include injecting CO{sub 2} in petroleum reservoirs for Enhanced Oil Recovery or storing CO{sub 2} in deep saline aquifers. Large-scale injection of CO{sub 2} into subsurface reservoirs would induce a complex interplay of multiphase flow, capillary trapping, dissolution, diffusion, convection, and chemical reactions that may have significant impacts on both short-term injection performance and long-term fate of CO{sub 2} storage. Reactive Transport Modeling is a promising approach that can be used to predict the spatial and temporal evolution of injected CO{sub 2} and associated gas-fluid-rock interactions. This presentation will summarize recent advances in reactive transport modeling of CO{sub 2} storage and review key technical issues on (1) the short- and long-term behavior of injected CO{sub 2} in geological formations; (2) the role of reservoir mineral heterogeneity on injection performance and storage security; (3) the effect of gas mixtures (e.g., H{sub 2}S and SO{sub 2}) on CO{sub 2} storage; and (4) the physical and chemical processes during potential leakage of CO{sub 2} from the primary storage reservoir. Simulation results suggest that CO{sub 2} trapping capacity, rate, and impact on reservoir rocks depend on primary mineral composition and injecting gas mixtures. For example, models predict that the injection of CO{sub 2} alone or co-injection with H{sub 2}S in both sandstone and carbonate reservoirs lead to acidified zones and mineral dissolution adjacent to the injection well, and carbonate precipitation and mineral trapping away from the well. Co-injection of CO{sub 2} with H{sub 2}S and in particular with SO{sub 2} causes greater formation alteration and complex sulfur mineral (alunite, anhydrite, and pyrite) trapping, sometimes at a much faster rate than previously thought. The results from Reactive Transport Modeling provide valuable insights for analyzing and assessing the dynamic behaviors of injected CO{sub 2}, identifying and characterizing potential storage sites, and managing injection performance and reducing costs.

Xiao, Y.; Xu, T.; Pruess, K.

2008-10-15T23:59:59.000Z

247

USING RECENT ADVANCES IN 2D SEISMIC TECHNOLOGY AND SURFACE GEOCHEMISTRY TO ECONOMICALLY REDEVELOP A SHALLOW SHELF CARBONATE RESERVOIR: VERNON FIELD, ISABELLA COUNTY, MI  

SciTech Connect (OSTI)

One of the principal objectives of this demonstration project is to test surface geochemical techniques for detecting trace amounts of light hydrocarbons in pore gases as a means of reducing risk in hydrocarbon exploration and production. During this reporting period, microbial samples were collected from the Trusty Steed prospect area in Grand Traverse County, Michigan. The samples were analyzed using the Microbial Oil Surveying Technique (MOST) technique and revealed only a local (1-point) anomaly. A decision to resample over that point is pending, but drilling has been postponed for the time being. The main news this reporting period is that in the Bear Lake area, northwest Michigan, Federated Oil & Gas Properties' Charlich-Fauble 2-9HD horizontal lateral, has cumulative production of more than 72,000 barrels of oil and is still producing 50 to 75 bopd from a Silurian Niagaran reef reservoir eighteen months after the well was completed. Surface geochemical surveys conducted in the demonstration area were consistent with production results although the ultimate decision to drill was based on interpretation of conventional subsurface and 2D seismic data. The surface geochemical techniques employed were Solid Phase MicroExtraction (SPME) and MOST. The geochemical results have been submitted to World Oil for publication. New geochemical surveys are planned for November in the Springdale quadrangle in Manistee County, Michigan. These surveys will concentrate on sampling over the trace of the proposed horizontal wells rather than a broad grid survey.

James R. Wood; A. Wylie; W. Quinlan

2004-10-01T23:59:59.000Z

248

Properties of CO2-Rich Pore Fluids and Their Effect on Porosity Evolution in EGS Rocks  

Broader source: Energy.gov [DOE]

Project objective: Quantify key parameters critically needed for developing and validating numerical modeling of chemical interactions between EGS reservoir rocks and supercritical CO2and CO2-rich aqueous fluids.

249

Improving reservoir conformance using gelled polymer systems. Final report, September 25, 1992--July 31, 1996  

SciTech Connect (OSTI)

The objectives of the research program were to (1) identify and develop polymer systems which have potential to improve reservoir conformance of fluid displacement processes, (2) determine the performance of these systems in bulk and in porous media, and (3) develop methods to predict their performance in field applications. The research focused on four types of gel systems--KUSP1 systems that contain an aqueous polysaccharide designated KUSP1, phenolic-aldehyde systems composed of resorcinol and formaldehyde, colloidal-dispersion systems composed of polyacrylamide and aluminum citrate, and a chromium-based system where polyacrylamide is crosslinked by chromium(III). Gelation behavior of the resorcinol-formaldehyde systems and the KUSP1-borate system was examined. Size distributions of aggregates that form in the polyacrylamide-aluminum colloidal-dispersion gel system were determined. Permeabilities to brine of several rock materials were significantly reduced by gel treatments using the KUSP1 polymer-ester (monoethyl phthalate) system, the KUSP1 polymer-boric acid system, and the sulfomethylated resorcinol-formaldehyde system were also shown to significantly reduce the permeability to supercritical carbon dioxide. A mathematical model was developed to simulate the behavior of a chromium redox-polyacrylamide gel system that is injected through a wellbore into a multi-layer reservoir in which crossflow between layers is allowed. The model describes gelation kinetics and filtration of pre-gel aggregates in the reservoir. Studies using the model demonstrated the effect filtration of gel aggregates has on the placement of gel systems in layered reservoirs.

Green, D.W.; Willhite, G.P.; Buller, C.; McCool, S.; Vossoughi, S.; Michnick, M.

1997-06-01T23:59:59.000Z

250

Improving reservoir conformance using gelled polymer systems. Annual report, September 25, 1994--September 24, 1995  

SciTech Connect (OSTI)

The objectives of the research program are to (1) identify and develop polymer systems which have potential to improve reservoir conformance of fluid displacement processes, (2) determine the performance of these systems in bulk and in porous media, and (3) develop methods to predict their performance in field applications. The research focused on four types of gel systems -- KUSP1 systems which contain an aqueous polysaccharide designated KUSP1, phenolic-aldehyde systems composed of resorcinol and formaldehyde, colloidal-dispersion systems composed of polyacrylamide and aluminum citrate, and a chromium-based system where polyacrylamide is crosslinked by chromium(III). Gelation behavior of the resorcinol-formaldehyde systems and the KUSP1-borate system was examined. Size distributions of aggregates that form in the polyacrylamide-aluminum colloidal-dispersion gel system were determined. Permeabilities to brine of several rock materials were significantly reduced by gel treatments using the KUSP1 polymer-ester (monoethylphthalate) system, the KUSP1 polymer-boric acid system, and the sulfomethylated resorcinol-formaldehyde system. The KUSP1 polymer-ester system and the sulfomethylated resorcinol-formaldehyde system were also shown to significantly reduce the permeability to super-critical carbon dioxide. A mathematical model was developed to simulate the behavior of a chromium redox-polyacrylamide gel system that is injected through a wellbore into a multi-layer reservoir in which crossflow between layers is allowed. The model describes gelation kinetics and filtration of pre-gel aggregates in the reservoir. Studies using the model demonstrated the effect filtration of gel aggregates has on the placement of gel systems in layered reservoirs.

Green, D.W.; Willhite, G.P.

1996-05-01T23:59:59.000Z

251

RESERVOIR CHARACTERIZATION OF THE LOWER GREEN RIVER FORMATION, SOUTHWEST UINTA BASIN, UTAH  

SciTech Connect (OSTI)

Anastamosing, low gradient distributary channels produce {approx}30 gravity, paraffinic oils from the Middle Member of the lacustrine Eocene Green River Formation in the south-central portion of the Uinta Basin. This localized depocenter was situated along the fluctuating southern shoreline of Lake Uinta, where complex deposits of marginal-lacustrine to lower delta plain accumulations are especially characteristic. The Middle Member contains several fining-upward parasequences that can be recognized in outcrop, core, and downhole logs. Each parasequence is about 60 to 120 feet thick and consists of strata deposited during multiple lake level fluctuations that approach 30 to 35 feet in individual thickness. Such parasequences represent 300,000-year cycles based on limited absolute age dating. The subaerial to subaqueous channels commonly possess an erosional base and exhibit a fining upward character. Accordingly, bedding features commonly range from large-scale trough and planar cross bedding or lamination at the base, to a nonreservoir, climbing ripple assemblage near the uppermost reservoir boundary. The best reservoir quality occurs within the laminated to cross-stratified portions, and the climbing ripple phase usually possesses more deleterious micas and/or detrital clays. Diagenesis also exerts a major control on reservoir quality. Certain sandstones were cemented by an early, iron-poor calcite cement, which can be subsequently leached. Secondary intergranular porosity (up to 20%) is largely responsible for the 10 -100 millidarcy rock, which represents petrophysical objectives for both primary and secondary production. Otherwise, intense compaction, silicic and iron-rich carbonate cements, and authigenic clays serve to reduce reservoir quality to marginal economic levels.

S. Robert Bereskin

2003-02-11T23:59:59.000Z

252

Application of integrated reservoir management and reservoir characterization to optimize infill drilling. Annual report, June 13, 1994--June 12, 1995  

SciTech Connect (OSTI)

This project has used a multi-disciplinary approach employing geology, geophysics, and engineering to conduct advanced reservoir characterization and management activities to design and implement an optimized infill drilling program at the North Robertson (Clearfork) Unit in Gaines County, Texas. The activities during the first Budget Period have consisted of developing an integrated reservoir description from geological, engineering, and geostatistical studies, and using this description for reservoir flow simulation. Specific reservoir management activities are being identified and tested. The geologically targeted infill drilling program will be implemented using the results of this work. A significant contribution of this project is to demonstrate the use of cost-effective reservoir characterization and management tools that will be helpful to both independent and major operators for the optimal development of heterogeneous, low permeability shallow-shelf carbonate (SSC) reservoirs. The techniques that are outlined for the formulation of an integrated reservoir description apply to all oil and gas reservoirs, but are specifically tailored for use in the heterogeneous, low permeability carbonate reservoirs of West Texas.

Pande, P.K.

1996-11-01T23:59:59.000Z

253

2 INVESTIGATION OF CRUDE OIL/BRINE/ROCK INTERACTION 2.1 EXPERIMENTAL STUDY OF CRUDE/BRINE/ROCK INTERACTION AT  

E-Print Network [OSTI]

as the temperature increased. The aging of low permeability cores saturated with oil had little effect in the rate44 2 INVESTIGATION OF CRUDE OIL/BRINE/ROCK INTERACTION 2.1 EXPERIMENTAL STUDY OF CRUDE in this section and expand the understanding of the interactions of the Spraberry reservoir rock, oil and brine

Schechter, David S.

254

USING RECENT ADVANCES IN 2D SEISMIC TECHNOLOGY AND SURFACE GEOCHEMISTRY TO ECONOMICALLY REDEVELOP A SHALLOW SHELF CARBONATE RESERVOIR: VERNON FIELD, ISABELLA COUNTRY, MI  

SciTech Connect (OSTI)

The principal objective of this demonstration project is to test surface geochemical techniques for detecting trace amounts of light hydrocarbons in pore gases as a means of reducing risk in hydrocarbon exploration and production. A major part of the remaining project will focus on using surface geochemistry to delineate prospects. A Niagaran reef field geochemical survey, the Bagley Prospect area in Otsego County, Michigan is scheduled to take place this summer. Previous wells drilled in Bagley Prospect area in the early 1970's and in place in late 2002 and early 2003 resulted in discoveries and numerous hydrocarbon shows in the Brown Niagaran reservoir interval. The Bagley region is still considered an area of interest by the industry and appears ripe for a geochemical survey. Our industry partner is interested in a possible test in the Bagley prospect because subsurface geophysical and geological interpretation indicates the presence of structures. Anomalous production and pressure data further suggest the region is not yet well understood and should not be considered mature. The most recent well, the Bagley 1-22A sidetrack, was unsuccessful at locating a new reef culmination to the south of the original vertical well and did not encounter hydrocarbon shows. The sidetrack and well were plugged and abandoned. The proposed geochemical survey will concentrate on areas away from the Bagley 1-22A to the north and west but will include the entire prospect so that the existing data can be used in interpretations. Bagley appears to offer a unique combination of potential and data for a geochemical study that focuses on looking for new oil in an area that has exhausted traditional geologic and geophysical methods. The Bear Lake pinnacle reef trend in Manistee County, Michigan, is also scheduled for further geochemical work this summer. Industry interest, mostly by small companies, is picking up in this area and it is also ripe for targeted geochemical surveys for the same reasons cited above.

James R. Wood; A. Wylie; W. Quinlan

2004-04-01T23:59:59.000Z

255

USING RECENT ADVANCES IN 2D SEISMIC TECHNOLOGY AND SURFACE GEOCHEMISTRY TO ECONOMICALLY REDEVELOP A SHALLOW SHELF CARBONATE RESERVOIR: VERNON FIELD, ISABELLA COUNTY, MI.  

SciTech Connect (OSTI)

The geochemical sampling team collected additional 148 samples at Vernon Field along 5 new traverses. Most of the locations were sampled for three types of analyses: microbial, iodine and enzyme leach; no results from the second batch of samples were available in time for this report. In addition to the sampling, a study was begun on the feasibility of collecting and analyzing hydrocarbon gases (C1-C8) directly. Although several companies offer these services, the cost ($200-300/sample w/o sampling fee) is high, on par with the cost of a 3D seismic survey, and may not include the raw data. However direct sampling of reservoir gases collecting in the soil appear to offer the best approach and should be included in this study. It would probably work well at Vernon Field. It may be possible to lower costs considerably; initial estimates of $20/sample for GCMS (Gas Chromatography--mass spectrometry) analysis are attractive and might induce to Michigan producers to include soil surveys in their routine field work-ups. A complete set of digital data was assembled for Vernon Field and nearby locations. The set consists of well locations, formation top picks, lithologies and scanned images of driller's reports and scout tickets. Well logs are still being located. The annual meeting for the Class Revisit work group is tentatively scheduled for the week of March 1-7 in Tampa, Fl. By that time all of the geochemical data will be available and final decisions regarding drilling can be made.

James R. Wood; T.J. Bornhorst; S.D. Chittichk; William B. Harrison; W. Quinlan

2001-01-01T23:59:59.000Z

256

USING RECENT ADVANCES IN 2ND SEISMIC TECHNOLOGY AND SURFACE GEOCHEMISTRY TO ECONOMICALLY REDEVELOP A SHALLOW SHELF CARBONATE RESERVOIR: VERNON FIELD, ISABELLA COUNTY, MI.  

SciTech Connect (OSTI)

Three horizontal wells have been completed (St. Springdale & Trezil 9-15 HD, St. Springdale 13-14 HD, St. Springdale & Stedronsky 10-15 HD) and three more wells were spudded (St. Springdale & CSX 2-22 HD, St. Springdale & Mann 9-21 HD and St. Springdale 7-22 HD) in the Springdale play this past reporting period. All are horizontal wells in the Brown Niagaran. This brings the total wells in the play to 12 with seven wells contributing to a total daily production exceeding 350 bbls/day. Data from these wells has been converted from drillers logs (footage calls) and converted to Michigan GeoRef coordinates and plotted. The Gamma Ray data along the well bore was available since it was used to steer the tool during drilling and this data was superimposed on the well trajectories in an effort to help distinguish pay zones from unproductive rock. One new geochemical survey was conducted over the projected surface path of the State Springdale & Stedronsky 14-15 HD and a final project survey was planned over one of the unsurveyed wells. This will bring the total surveyed wells to five and should provide enough data to determine if the idea of only sampling along the well bore is a sound strategy.

James R. Wood; A. Wylie; W. Quinlan

2005-06-30T23:59:59.000Z

257

Assessing the role of ancient and active geothermal systems in oil-reservoir evolution in the eastern Basin and Range province, western USA. Annual progress report, June 1, 1992--May 31, 1993  

SciTech Connect (OSTI)

Results of our research on the oil fields of the Basin and Range province of the western USA continue to support the following concept: Convecting, moderate-temperature geothermal systems in this region have fostered and in some cases critically influenced the generation, migration, and entrapment of oil. At one Basin-Range field (Grant Canyon), oil-bearing and aqueous fluid inclusions in late-stage hydrothermal quartz were entrapped at temperatures comparable to those now prevailing at reservoir depths (120--130{degrees}C); apparent salinities of the aqueous varieties match closely the actual salinity of the modern, dilute oil-field waters. The inclusion-bearing quartz has the oxygen-isotopic signature for precipitation of the mineral at contemporary temperatures from modern reservoir waters. Measured and fluid-inclusion temperatures define near-coincident isothermal profiles through the oil-reservoir interval, a phenomenon suggesting ongoing heat and mass transfer. These findings are consistent with a model whereby a still-active, convectively circulating, meteoric-hydrothermal system: (1) enhanced porosity in the reservoir rock through dissolution of carbonate; (2) hydrothermally sealed reservoir margins; (3) transported oil to the reservoirs from a deep source of unknown size and configuration; and (4) possibly accelerated source-rock maturation through an increase in the local thermal budget. Grant Canyon and other Basin-Range oil fields are similar to the oil-bearing, Carlin-type, sediment-hosted, disseminated gold deposits of the nearby Alligator Ridge district. The oil fields could represent either weakly mineralized analogues of these deposits, or perhaps an incipient phase in their evolution.

Hulen, J.B.

1993-07-01T23:59:59.000Z

258

Seismic and Rockphysics Diagnostics of Multiscale Reservoir Textures  

SciTech Connect (OSTI)

This final technical report summarizes the results of the work done in this project. The main objective was to quantify rock microstructures and their effects in terms of elastic impedances in order to quantify the seismic signatures of microstructures. Acoustic microscopy and ultrasonic measurements were used to quantify microstructures and their effects on elastic impedances in sands and shales. The project led to the development of technologies for quantitatively interpreting rock microstructure images, understanding the effects of sorting, compaction and stratification in sediments, and linking elastic data with geologic models to estimate reservoir properties. For the public, ultimately, better technologies for reservoir characterization translates to better reservoir development, reduced risks, and hence reduced energy costs.

Gary Mavko

2005-07-01T23:59:59.000Z

259

Trace Metal Source Terms in Carbon Sequestration Environments  

SciTech Connect (OSTI)

ABSTRACT: Carbon dioxide sequestration in deep saline and depleted oil geologic formations is feasible and promising; however, possible CO2 or CO2-saturated brine leakage to overlying aquifers may pose environmental and health impacts. The purpose of this study was to experimentally define to provide a range of concentrations that can be used as the trace element source term for reservoirs and leakage pathways in risk simulations. Storage source terms for trace metals are needed to evaluate the impact of brines leaking into overlying drinking water aquifers. The trace metal release was measured from cements and sandstones, shales, carbonates, evaporites, and basalts from the Frio, In Salah, Illinois Basin, Decatur, Lower Tuscaloosa, Weyburn-Midale, Bass Islands, and Grand Ronde carbon sequestration geologic formations. Trace metal dissolution was tracked by measuring solution concentrations over time under conditions (e.g., pressures, temperatures, and initial brine compositions) specific to the sequestration projects. Existing metrics for maximum contaminant levels (MCLs) for drinking water as defined by the U.S. Environmental Protection Agency (U.S. EPA) were used to categorize the relative significance of metal concentration changes in storage environments because of the presence of CO2. Results indicate that Cr and Pb released from sandstone reservoir and shale cap rocks exceed the MCLs byan order of magnitude, while Cd and Cu were at or below drinking water thresholds. In carbonate reservoirs As exceeds the MCLs by an order of magnitude, while Cd, Cu, and Pb were at or below drinking water standards. Results from this study can be used as a reasonable estimate of the trace element source term for reservoirs and leakage pathways in risk simulations to further evaluate the impact of leakage on groundwater quality.

Karamalidis, Athanasios; Torres, Sharon G.; Hakala, Jacqueline A.; Shao, Hongbo; Cantrell, Kirk J.; Carroll, Susan A.

2013-01-01T23:59:59.000Z

260

Geochemistry of selected oils and rocks from the central portion of the West Siberian basin, Russia  

SciTech Connect (OSTI)

Six analyzed oils, produced from Middle jurassic to Upper Cretaceous strata in the Middle Ob region of the West Siberian basin, show biomarker and stable carbon isotope compositions indicating an origin from the Upper Jurassic Bazhenov Formation. The chemical compositions of these oils are representative of more than 85% of the reserves in West Siberia (Kontorovich et al., 1975). Bazhenov-sourced oil in Cenomanian strata in the Van-Egan field underwent biodegradation in the reservoir, resulting in a low API gravity, an altered homohopane distribution, and the appearance of 25-norhopanes without alteration of the steranes. High API gravity oil from the Salym field has surpassed the peak of the oil window, consistent with abnormally high temperatures and pressures in the Bazhenov source rock from which it is produced. The remaining oils are very similar, including samples from Valanginian and Bathonian-Callovian intervals in a sequence of stacked reservoirs in the Fedorov field. Bazhenov rock samples from the study area contain abundant oil-prone, marine organic matter preserved under anoxic conditions. While the Upper Jurassic Vasyugan Formation shows lower oil-regenerative potential than the Bazhenov Formation, it cannot be excluded as a source rock because insufficient sample was available for biomarker analysis. Core from the Lower to Middle Jurassic Tyumen Formation in the YemYegov 15 well was compared with the oils because it is thermally mature and shows TOC and HI values, indicating slightly more favorable oil-generative characteristics than the average for the formation (2.75 wt. % for 270 samples; 95 mg HC/g TOC for 25 samples). The core contains terrigenous, gas-prone organic matter that shows no relationship with the analyzed oils. 59 refs., 15 figs., 8 tabs.

Peters, K.E.; Huizinga, B.J. (Chevron Overseas Petroleum Inc., San Ramon, CA (United States)); Kontorovich, A.Eh.; Andrusevich, V.E. (Inst. of Geology, Novosibirsk (Russian Federation)); Moldowan, J.M. (Chevron Petroleum Technology Co., Richmond, CA (United States)); Demaison, G.J. (Petroscience Inc., Walnut Creek, CA (United States)); Stasova, O.F. (NPO SIBGEO, Novosibirsk (Russian Federation))

1993-05-01T23:59:59.000Z

Note: This page contains sample records for the topic "reservoir rock carbon" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


261

Fundamentals of log analysis. Part 10: Determining rock mechanical property values from log analysis  

SciTech Connect (OSTI)

Correct design and execution of well completions, including hydraulic fracturing, can enhance a reservoir`s productivity. Success in this optimization depends in part on being able to predict how hydraulic fracturing affects performance. Controls on the performance of a hydraulically fractured well are the fracture, reservoir characteristics and the well. This article will cover methods for obtaining values of in-situ stress in a specific rock layer and the in-situ stress profile, and determining Young`s modulus.

Hunt, E.R.; McCain, W.D. Jr. [S.A. Holditch and Associates, Inc., College Station, TX (United States)

1997-10-01T23:59:59.000Z

262

Reservoir management using streamline simulation  

E-Print Network [OSTI]

of information and sparsity of data. Quantifying this uncertainty in terms of reservoir performance forecast poses a major reservoir management challenge. One solution to this problem is flow simulation of a large number of these plausible reservoir descriptions...

Choudhary, Manoj Kumar

2000-01-01T23:59:59.000Z

263

EXPLOITATION AND OPTIMIZATION OF RESERVOIR PERFORMANCE IN HUNTON FORMATION, OKLAHOMA  

SciTech Connect (OSTI)

The main objectives of the proposed study are as follows: (1) To understand and evaluate an unusual primary oil production mechanism which results in decreasing (retrograde) oil cut (ROC) behavior as reservoir pressure declines. (2) To improve calculations of initial oil in place so as to determine the economic feasibility of completing and producing a well. (3) To optimize the location of new wells based on understanding of geological and petrophysical properties heterogeneities. (4) To evaluate various secondary recovery techniques for oil reservoirs producing from fractured formations. (5) To enhance the productivity of producing wells by using new completion techniques. These objectives are important for optimizing field performance from West Carney Field located in Lincoln County, Oklahoma. The field, which was discovered in 1980, produces from Hunton Formation in a shallow-shelf carbonate reservoir. The early development in the field was sporadic. Many of the initial wells were abandoned due to high water production and constraints in surface facilities for disposing excess produced water. The field development began in earnest in 1995 by Altex Resources. They had recognized that production from this field was only possible if large volumes of water can be disposed. Being able to dispose large amounts of water, Altex aggressively drilled several producers. With few exceptions, all these wells exhibited similar characteristics. The initial production indicated trace amount of oil and gas with mostly water as dominant phase. As the reservoir was depleted, the oil cut eventually improved, making the overall production feasible. The decreasing oil cut (ROC) behavior has not been well understood. However, the field has been subjected to intense drilling activity because of prior success of Altex Resources. In this work, we will investigate the primary production mechanism by conducting several core flood experiments. After collecting cores from representative wells, we will study the wettability of the rock and simulate the depletion behavior by mimicking such behavior under controlled lab conditions. The overall project goal would be to validate our hypothesis and to determine the best method to exploit reservoirs exhibiting ROC behavior. To that end, we have completed the Budget Period I and have fulfilled many of the objectives. We have developed a viable model to explain the reservoir mechanism and have been able to develop a correlation between core and log data so that we can extend our analysis to other, yet unexploited, regions. In Budget Period II, we will continue to drill several additional, geologically targeted wells. Depending on the depositional system, these wells can be either vertical or horizontal wells. We will closely examine the secondary recovery techniques to improve the ultimate recovery from this field. In the mean time, we will continue to refine our geological and petrophysical model so that we can extend our approach to other adjacent fields. In the Budget Period III, we will monitor the field performance and revise and refine our models to further optimize the performance.

Mohan Kelkar

2003-01-01T23:59:59.000Z

264

Reservoir characterization and enhanced oil recovery research  

SciTech Connect (OSTI)

The research in this annual report falls into three tasks each dealing with a different aspect of enhanced oil recovery. The first task strives to develop procedures for accurately modeling reservoirs for use as input to numerical simulation flow models. This action describes how we have used a detail characterization of an outcrop to provide insights into what features are important to fluid flow modeling. The second task deals with scaling-up and modeling chemical and solvent EOR processes. In a sense this task is the natural extension of task 1 and, in fact, one of the subtasks uses many of the same statistical procedures for insight into the effects of viscous fingering and heterogeneity. The final task involves surfactants and their interactions with carbon dioxide and reservoir minerals. This research deals primarily with phenomena observed when aqueous surfactant solutions are injected into oil reservoirs.

Lake, L.W.; Pope, G.A.; Schechter, R.S.

1992-03-01T23:59:59.000Z

265

Characterization of oil and gas reservoir heterogeneity  

SciTech Connect (OSTI)

Research described In this report addresses the internal architecture of two specific reservoir types: restricted-platform carbonates and fluvial-deltaic sandstones. Together, these two reservoir types contain more than two-thirds of the unrecovered mobile oil remaining ill Texas. The approach followed in this study was to develop a strong understanding of the styles of heterogeneity of these reservoir types based on a detailed outcrop description and a translation of these findings into optimized recovery strategies in select subsurface analogs. Research targeted Grayburg Formation restricted-platform carbonate outcrops along the Algerita Escarpment and In Stone Canyon In southeastern New Mexico and Ferron deltaic sandstones in central Utah as analogs for the North Foster (Grayburg) and Lake Creek (Wilcox) units, respectively. In both settings, sequence-stratigraphic style profoundly influenced between-well architectural fabric and permeability structure. It is concluded that reservoirs of different depositional origins can therefore be categorized Into a heterogeneity matrix'' based on varying intensity of vertical and lateral heterogeneity. The utility of the matrix is that it allows prediction of the nature and location of remaining mobile oil. Highly stratified reservoirs such as the Grayburg, for example, will contain a large proportion of vertically bypassed oil; thus, an appropriate recovery strategy will be waterflood optimization and profile modification. Laterally heterogeneous reservoirs such as deltaic distributary systems would benefit from targeted infill drilling (possibly with horizontal wells) and improved areal sweep efficiency. Potential for advanced recovery of remaining mobile oil through heterogeneity-based advanced secondary recovery strategies In Texas is projected to be an Incremental 16 Bbbl. In the Lower 48 States this target may be as much as 45 Bbbl at low to moderate oil prices over the near- to mid-term.

Tyler, N.; Barton, M.D.; Bebout, D.G.; Fisher, R.S.; Grigsby, J.D.; Guevara, E.; Holtz, M.; Kerans, C.; Nance, H.S.; Levey, R.A.

1992-10-01T23:59:59.000Z

266

Evaluation of Five Sedimentary Rocks Other Than Salt for Geologic Repository Siting Purposes  

SciTech Connect (OSTI)

The US Department of Energy (DOE), in order to increase the diversity of rock types under consideration by the geologic disposal program, initiated the Sedimary ROck Program (SERP), whose immediate objectiv eis to evaluate five types of secimdnary rock - sandstone, chalk, carbonate rocks (limestone and dolostone), anhydrock, and shale - to determine the potential for siting a geologic repository. The evaluation of these five rock types, together with the ongoing salt studies, effectively results in the consideration of all types of relatively impermeable sedimentary rock for repository purposes. The results of this evaluation are expressed in terms of a ranking of the five rock types with respect to their potential to serve as a geologic repository host rock. This comparative evaluation was conducted on a non-site-specific basis, by use of generic information together with rock evaluation criteria (RECs) derived from the DOE siting guidelines for geologic repositories (CFR 1984). An information base relevant to rock evaluation using these RECs was developed in hydrology, geochemistry, rock characteristics (rock occurrences, thermal response, rock mechanics), natural resources, and rock dissolution. Evaluation against postclosure and preclosure RECs yielded a ranking of the five subject rocks with respect to their potential as repository host rocks. Shale was determined to be the most preferred of the five rock types, with sandstone a distant second, the carbonate rocks and anhydrock a more distant third, and chalk a relatively close fourth.

Croff, A.G.; Lomenick, T.F.; Lowrie, R.S.; Stow, S.H.

2003-11-15T23:59:59.000Z

267

PROCEEDINGS, Thirty-Sixth Workshop on Geothermal Reservoir Engineering Stanford University, Stanford, California, January 31 -February 2, 2011  

E-Print Network [OSTI]

PROCEEDINGS, Thirty-Sixth Workshop on Geothermal Reservoir Engineering Stanford University, 94720, USA ABSTRACT Interactions between hydrothermal fluids and rock alter mineralogy, leading permeability reduction in fractured and intact Westerly granite due to high-temperature fluid flow through core

Stanford University

268

Prediction of oil gravity prior to drill-stem testing in Monterey Formation Reservoirs, offshore California  

SciTech Connect (OSTI)

This paper discusses empirical geochemical correlations used to predict API oil gravities prior to drill-stem testing in Monterey Formation reservoirs, offshore southern California. The primary objective was to eliminate expensive well testing by identifying intervals that contain low-gravity, nonproducible oil (usually <14[degrees] API). However, the correlations proved very successful in accurately predicting (within 4[degrees]API) oil gravities that range from 5 to 35[degrees] API throughout the offshore Santa Barbara and Santa Maria areas. The primary data are weight-percent sulfur and Rock-Eval pyrolysis of bitumen chemically extracted from reservoir rock samples. In general, reservoirs that contain higher gravity, producible oil have bitumen organic sulfur contents of less than 5 wt. %, Rock-Eval bitumen, and Rock-Eval bitumen S[sub 1]/S[sub 2] ratios greater than 1.0. These data are usually supplemented with Rock-Eval pyrolysis of the reservoir rock, where whole-rock S[sub 1]/S[sub 2] ratios greater than 0.30 usually indicate associated oil gravities greater than 14[degrees] API. This analytical mix gives a multiple approach for estimating reservoir oil gravities within proposed drill-stem test (DST) intervals. Using this approach, oil gravities of more than 50 DSTs have been accurately predicted in the offshore southern California area. The technique is also useful for reevaluating API gravities in older wells where Monterey reservoirs were not the primary target. Moreover, the technique should have application elsewhere, provided the range of oil gravities are not the result of obvious biodegradation and sufficient rock and oil samples are available to establish pertinent correlations. 34 refs., 14 figs., 4 tabs.

Baskin, D.K. (Chevron Petroleum Technology Company, La Habra, CA (United States)); Jones, R.W. (Chevron Oil Field Research Company, Encinitas, CA (United States))

1993-09-01T23:59:59.000Z

269

APPLICATION OF RESERVOIR CHARACTERIZATION AND ADVANCED TECHNOLOGY TO IMPROVE RECOVERY AND ECONOMICS IN A LOWER QUALITY SHALLOW SHELF SAN ANDRES RESERVOIR  

SciTech Connect (OSTI)

The Class 2 Project at West Welch was designed to demonstrate the use of advanced technologies to enhance the economics of improved oil recovery (IOR) projects in lower quality Shallow Shelf Carbonate (SSC) reservoirs, resulting in recovery of additional oil that would otherwise be left in the reservoir at project abandonment. Accurate reservoir description is critical to the effective evaluation and efficient design of IOR projects in the heterogeneous SSC reservoirs. Therefore, the majority of Budget Period 1 was devoted to reservoir characterization. Technologies being demonstrated include: (1) Advanced petrophysics; (2) Three-dimensional (3-D) seismic; (3) Crosswell bore tomography; (4) Advanced reservoir simulation; (5) Carbon dioxide (CO{sub 2}) stimulation treatments; (6) Hydraulic fracturing design and monitoring; and (7) Mobility control agents.

T. Scott Hickman; James J. Justice

2001-06-16T23:59:59.000Z

270

APPLICATION OF RESERVOIR CHARACTERIZATION AND ADVANCED TECHNOLOGY TO IMPROVE RECOVERY AND ECONOMICS IN A LOWER QUALITY SHALLOW SHELF SAN ANDRES RESERVOIR  

SciTech Connect (OSTI)

The Class 2 Project at West Welch was designed to demonstrate the use of advanced technologies to enhance the economics of improved oil recovery (IOR) projects in lower quality Shallow Shelf Carbonate (SSC) reservoirs, resulting in recovery of additional oil that would otherwise be left in the reservoir at project abandonment. Accurate reservoir description is critical to the effective evaluation and efficient design of IOR projects in the heterogeneous SSC reservoirs. Therefore, the majority of Budget Period 1 was devoted to reservoir characterization. Technologies being demonstrated include: (1) Advanced petrophysics; (2) Three-dimensional (3-D) seismic; (3) Crosswell bore tomography; (4) Advanced reservoir simulation; (5) Carbon dioxide (CO{sub 2}) stimulation treatments; (6) Hydraulic fracturing design and monitoring; and (7) Mobility control agents.

T. Scott Hickman; James J. Justice

2001-08-10T23:59:59.000Z

271

APPLICATION OF RESERVOIR CHARACTERIZATION AND ADVANCED TECHNOLOGY TO IMPROVE RECOVERY AND ECONOMICS IN A LOWER QUALITY SHALLOW SHELF SAN ANDRES RESERVOIR  

SciTech Connect (OSTI)

The Class 2 Project at West Welch was designed to demonstrate the use of advanced technologies to enhance the economics of improved oil recovery (IOR) projects in lower quality Shallow Shelf Carbonate (SSC) reservoirs, resulting in recovery of additional oil that would otherwise be left in the reservoir at project abandonment. Accurate reservoir description is critical to the effective evaluation and efficient design of IOR projects in the heterogeneous SSC reservoirs. Therefore, the majority of Budget Period 1 was devoted to reservoir characterization. Technologies being demonstrated include: (1) Advanced petrophysics; (2) Three-dimensional (3-D) seismic; (3) Crosswell bore tomography; (4) Advanced reservoir simulation; (5) Carbon dioxide (CO{sub 2}) stimulation treatments; (6) Hydraulic fracturing design and monitoring; and (7) Mobility control agents.

Raj Kumar; Keith Brown; T. Scott Hickman; James J. Justice

2000-04-27T23:59:59.000Z

272

APPLICATION OF RESERVOIR CHARACTERIZATION AND ADVANCED TECHNOLOGY TO IMPROVE RECOVERY AND ECONOMICS IN A LOWER QUALITY SHALLOW SHELF SAN ANDRES RESERVOIR  

SciTech Connect (OSTI)

The Class 2 Project at West Welch was designed to demonstrate the use of advanced technologies to enhance the economics of improved oil recovery (IOR) projects in lower quality Shallow Shelf Carbonate (SSC) reservoirs, resulting in recovery of additional oil that would otherwise be left in the reservoir at project abandonment. Accurate reservoir description is critical to the effective evaluation and efficient design of IOR projects in the heterogeneous SSC reservoirs. Therefore, the majority of Budget Period 1 was devoted to reservoir characterization. Technologies being demonstrated include: (1) Advanced petrophysics; (2) Three-dimensional (3-D) seismic; (3) Crosswell bore tomography; (4) Advanced reservoir simulation; (5) Carbon dioxide (CO{sub 2}) stimulation treatments; (6) Hydraulic fracturing design and monitoring; and (7) Mobility control agents.

T. Scott Hickman; James J. Justice

2001-12-11T23:59:59.000Z

273

APPLICATION OF RESERVOIR CHARACTERIZATION AND ADVANCED TECHNOLOGY TO IMPROVE RECOVERY AND ECONOMICS IN A LOWER QUALITY SHALLOW SHELF SAN ANDRES RESERVOIR  

SciTech Connect (OSTI)

The Class 2 Project at West Welch was designed to demonstrate the use of advanced technologies to enhance the economics of improved oil recovery (IOR) projects in lower quality Shallow Shelf Carbonate (SSC) reservoirs, resulting in recovery of additional oil that would otherwise be left in the reservoir at project abandonment. Accurate reservoir description is critical to the effective evaluation and efficient design of IOR projects in the heterogeneous SSC reservoirs. Therefore, the majority of Budget Period 1 was devoted to reservoir characterization. Technologies being demonstrated include: (1) Advanced petrophysics; (2) Three-dimensional (3-D) seismic; (3) Crosswell bore tomography; (4) Advanced reservoir simulation; (5) Carbon dioxide (CO{sub 2}) stimulation treatments; (6) Hydraulic fracturing design and monitoring; and (7) Mobility control agents.

T. Scott Hickman

2003-01-17T23:59:59.000Z

274

Lithology and Alteration Mineralogy of Reservoir Rocks at Coso...  

Open Energy Info (EERE)

upwelling zone. The upwelling zone lies within a epidote-quartz veined, coarse-grained granite at depth in the southern portion of the field. The mineralogy of the clays varies...

275

Lithology and alteration mineralogy of reservoir rocks at Coso...  

Open Energy Info (EERE)

upwelling zone. The upwelling zone lies within a epidote-quartz veined, coarse-grained granite at depth in the southern portion of the field. The mineralogy of the clays varies...

276

Lithology and Alteration Mineralogy of Reservoir Rocks at Coso Geothermal  

Open Energy Info (EERE)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data Center Home5b9fcbce19 No revision hasInformation Earth's Heat JumpInc Place:KeystoneSolarList ofPassiveMachineBalance

277

Lithology and alteration mineralogy of reservoir rocks at Coso Geothermal  

Open Energy Info (EERE)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data Center Home5b9fcbce19 No revision hasInformation Earth's Heat JumpInc Place:KeystoneSolarList ofPassiveMachineBalanceArea, California |

278

Reservoir Investigations on the Hot Dry Rock Geothermal System, Fenton  

Open Energy Info (EERE)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data Center Home5b9fcbce19 No revisionEnvReviewNonInvasiveExplorationUT-g Grant of Access(CaliforniaProduction (RECP) in DevelopingHill, New

279

Hot Dry Rock Reservoir Engineering | Open Energy Information  

Open Energy Info (EERE)

AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data Center Home5b9fcbce19 No revision hasInformation Earth's Heat Jump to:PhotonHolyName HousingIII Wind Farm Facility HorseEngineering

280

IMPROVING CO2 EFFICIENCY FOR RECOVERING OIL IN HETEROGENEOUS RESERVOIRS  

SciTech Connect (OSTI)

This document is the First Annual Report for the U.S. Department of Energy under contract No., a three-year contract entitled: ''Improving CO{sub 2} Efficiency for Recovering Oil in Heterogeneous Reservoirs.'' The research improved our knowledge and understanding of CO{sub 2} flooding and includes work in the areas of injectivity and mobility control. The bulk of this work has been performed by the New Mexico Petroleum Recovery Research Center, a research division of New Mexico Institute of Mining and Technology. This report covers the reporting period of September 28, 2001 and September 27, 2002. Injectivity continues to be a concern to the industry. During this period we have contacted most of the CO{sub 2} operators in the Permian Basin and talked again about their problems in this area. This report has a summary of what we found. It is a given that carbonate mineral dissolution and deposition occur in a formation in geologic time and are expected to some degree in carbon dioxide (CO{sub 2}) floods. Water-alternating-gas (WAG) core flood experiments conducted on limestone and dolomite core plugs confirm that these processes can occur over relatively short time periods (hours to days) and in close proximity to each other. Results from laboratory CO{sub 2}-brine flow experiments performed in rock core were used to calibrate a reactive transport simulator. The calibrated model is being used to estimate in situ effects of a range of possible sequestration options in depleted oil/gas reservoirs. The code applied in this study is a combination of the well known TOUGH2 simulator, for coupled groundwater/brine and heat flow, with the chemistry code TRANS for chemically reactive transport. Variability in response among rock types suggests that CO{sub 2} injection will induce ranges of transient and spatially dependent changes in intrinsic rock permeability and porosity. Determining the effect of matrix changes on CO{sub 2} mobility is crucial in evaluating the efficacy and potential environmental implications of storing CO{sub 2} in the subsurface. Chemical cost reductions are identified that are derived from the synergistic effects of cosurfactant systems using a good foaming agent and a less expensive poor foaming agent. The required good foaming agent is reduced by at least 75%. Also the effect on injectivity is reduced by as much as 50% using the cosurfactant system, compared to a previously used surfactant system. Mobility control of injected CO{sub 2} for improved oil recovery can be achieved with significant reduction in the chemical cost of SAG, improved injectivity of SAG, and improved economics of CO{sub 2} injection project when compared to reported systems. Our past work has identified a number of mobility control agents to use for CO{sub 2}-foam flooding. In particular the combination of the good foaming agent CD 1045 and a sacrificial agent and cosurfactant lignosulfonate. This work scrutinizes the methods that we are using to determine the efficiency of the sacrificial agents and cosurfactant systems. These have required concentration determinations and reusing core samples. Here, we report some of the problems that have been found and some interesting effects that must be considered.

Reid B. Grigg; Robert K. Svec

2002-12-20T23:59:59.000Z

Note: This page contains sample records for the topic "reservoir rock carbon" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


281

Numerical modeling of carbon dioxide sequestration on the rate of pressure solution creep in limestone: Preliminary results  

E-Print Network [OSTI]

When carbon dioxide (CO2) is injected into an aquifer or a depleted geological reservoir, its dissolution into solution results in acidification of the pore waters. As a consequence, the pore waters become more reactive, which leads to enhanced dissolution-precipitation processes and a modification of the mechanical and hydrological properties of the rock. This effect is especially important for limestones given that the solubility and reactivity of carbonates is strongly dependent on pH and the partial pressure of CO2. The main mechanism that couples dissolution, precipitation and rock matrix deformation is commonly referred to as intergranular pressure solution creep (IPS) or pervasive pressure solution creep (PSC). This process involves dissolution at intergranular grain contacts subject to elevated stress, diffusion of dissolved material in an intergranular fluid, and precipitation in pore spaces subject to lower stress. This leads to an overall and pervasive reduction in porosity due to both grain indent...

Renard, Francois; Hellmann, Roland; Collombet, Marielle; Guen, Yvi Le

2008-01-01T23:59:59.000Z

282

Reservoir Operation in Texas  

E-Print Network [OSTI]

management of the surface water resources of the various river basins of the state. The operation of these essential water control facilities is examined in this report. Reservoir operation is viewed here from the perspective of deciding how much water...

Wurbs, Ralph A.

283

Reservoir Protection (Oklahoma)  

Broader source: Energy.gov [DOE]

The Oklahoma Water Resource Board has the authority to make rules for the control of sanitation on all property located within any reservoir or drainage basin. The Board works with the Department...

284

1. RESERVOIR PERFORMANCE ANALYSIS 1.1 Analysis of Step Rate Injection Tests in the O'Daniel Pilot Area  

E-Print Network [OSTI]

- 1- 1. RESERVOIR PERFORMANCE ANALYSIS 1.1 Analysis of Step Rate Injection Tests in the O the reservoir rock. This pressure is referred as to formation parting pressure. Determination of formation demonstrates stress-sensitive behavior, one of the phenomena that influences the performance of waterflooding

Schechter, David S.

285

Session: Reservoir Technology  

SciTech Connect (OSTI)

This session at the Geothermal Energy Program Review X: Geothermal Energy and the Utility Market consisted of five papers: ''Reservoir Technology'' by Joel L. Renner; ''LBL Research on the Geysers: Conceptual Models, Simulation and Monitoring Studies'' by Gudmundur S. Bodvarsson; ''Geothermal Geophysical Research in Electrical Methods at UURI'' by Philip E. Wannamaker; ''Optimizing Reinjection Strategy at Palinpinon, Philippines Based on Chloride Data'' by Roland N. Horne; ''TETRAD Reservoir Simulation'' by G. Michael Shook

Renner, Joel L.; Bodvarsson, Gudmundur S.; Wannamaker, Philip E.; Horne, Roland N.; Shook, G. Michael

1992-01-01T23:59:59.000Z

286

Sequence stratigraphic controls of hydrocarbon reservoir architecture - case study of Late Permian (Guadalupian) Queen Formation, Means Field, Andrews County, Texas.  

E-Print Network [OSTI]

properties in wells; 13 and (3) interpolation of this variability regionally between wells (Griffiths, 1990; Moss, 1990; Pereira et al., 1990; Jian et al., 1994; Tinker, 1996). Reservoir description is a crucial building process for the basic skeleton... and Wagoner, 1991; Kerans and Tinker, 1997). Many previous stochastic reservoir descriptions and characterization studies start with a poorly defined classification of reservoir rocks from a geologic viewpoint (Hurst and Archer, 1986; Moss, 1990; Pereira et...

Ryu, Changsu

2004-09-30T23:59:59.000Z

287

Carbon Cycle Discussion After the warm-up quiz, discuss the carbon cycle.  

E-Print Network [OSTI]

Carbon Cycle Discussion After the warm-up quiz, discuss the carbon cycle. Carbon is one is without carbon. Where else is carbon on our Earth? In rocks, living organisms, the atmosphere, oceans Does carbon stay in one place? What processes include moving carbon? Introduce residence time: How long does

Carrington, Emily

288

Hot Dry Rock Geothermal Energy Development Program  

SciTech Connect (OSTI)

During Fiscal Year 1987, emphasis in the Hot Dry Rock Geothermal Energy Development Program was on preparations for a Long-Term Flow Test'' of the Phase II'' or Engineering'' hot dry rock energy system at Fenton Hill, New Mexico. A successful 30-day flow test of the system during FY86 indicated that such a system would produce heat at a temperature and rate that could support operation of a commercial electrical power plant. However, it did not answer certain questions basic to the economics of long-term operation, including the rate of depletion of the thermal reservoir, the rate of water loss from the system, and the possibility of operating problems during extended continuous operation. Preparations for a one-year flow test of the system to answer these and more fundamental questions concerning hot dry rock systems were made in FY87: design of the required surface facilities; procurement and installation of some of their components; development and testing of slimline logging tools for use through small-diameter production tubing; research on temperature-sensitive reactive chemical tracers to monitor thermal depletion of the reservoir; and computer simulations of the 30-day test, extended to modeling the planned Long-Term Flow Test. 45 refs., 34 figs., 5 tabs.

Smith, M.C.; Hendron, R.H.; Murphy, H.D.; Wilson, M.G.

1989-12-01T23:59:59.000Z

289

Hot Dry Rock; Geothermal Energy  

SciTech Connect (OSTI)

The commercial utilization of geothermal energy forms the basis of the largest renewable energy industry in the world. More than 5000 Mw of electrical power are currently in production from approximately 210 plants and 10 000 Mw thermal are used in direct use processes. The majority of these systems are located in the well defined geothermal generally associated with crustal plate boundaries or hot spots. The essential requirements of high subsurface temperature with huge volumes of exploitable fluids, coupled to environmental and market factors, limit the choice of suitable sites significantly. The Hot Dry Rock (HDR) concept at any depth originally offered a dream of unlimited expansion for the geothermal industry by relaxing the location constraints by drilling deep enough to reach adequate temperatures. Now, after 20 years intensive work by international teams and expenditures of more than $250 million, it is vital to review the position of HDR in relation to the established geothermal industry. The HDR resource is merely a body of rock at elevated temperatures with insufficient fluids in place to enable the heat to be extracted without the need for injection wells. All of the major field experiments in HDR have shown that the natural fracture systems form the heat transfer surfaces and that it is these fractures that must be for geothermal systems producing from naturally fractured formations provide a basis for directing the forthcoming but, equally, they require accepting significant location constraints on HDR for the time being. This paper presents a model HDR system designed for commercial operations in the UK and uses production data from hydrothermal systems in Japan and the USA to demonstrate the reservoir performance requirements for viable operations. It is shown that these characteristics are not likely to be achieved in host rocks without stimulation processes. However, the long term goal of artificial geothermal systems developed by systematic engineering procedures at depth may still be attained if high temperature sites with extensive fracturing are developed or exploited. [DJE -2005

None

1990-01-01T23:59:59.000Z

290

Reservoir permeability from seismic attribute analysis  

SciTech Connect (OSTI)

In case of porous fluid-saturated medium the Biot's poroelasticity theory predicts a movement of the pore fluid relative to the skeleton on seismic wave propagation through the medium. This phenomenon opens an opportunity for investigation of the flow properties of the hydrocarbon-saturated reservoirs. It is well known that relative fluid movement becomes negligible at seismic frequencies if porous material is homogeneous and well cemented. In this case the theory predicts an underestimated seismic wave velocity dispersion and attenuation. Based on Biot's theory, Helle et al. (2003) have numerically demonstrated the substantial effects on both velocity and attenuation by heterogeneous permeability and saturation in the rocks. Besides fluid flow effect, the effects of scattering (Gurevich, et al., 1997) play very important role in case of finely layered porous rocks and heterogeneous fluid saturation. We have used both fluid flow and scattering effects to derive a frequency-dependent seismic attribute which is proportional to fluid mobility and applied it for analysis of reservoir permeability.

Silin, Dmitriy; Goloshubin, G.; Silin, D.; Vingalov, V.; Takkand, G.; Latfullin, M.

2008-02-15T23:59:59.000Z

291

Radiocarbon dating of ancient rock paintings  

SciTech Connect (OSTI)

This report presents progress made on a technique for {sup 14}C dating pictographs. A low-temperature oxygen plasma is used coupled with high-vacuum technologies to selectively remove C-containing material in the paints without contamination from inorganic carbon from rock substrates or accretions.

Ilger, W.A.; Hyman, M.; Rowe, M.W. [Texas A and M Univ., College Station, TX (United States). Dept. of Chemistry; Southon, J. [Lawrence Livermore National Lab., CA (United States)

1995-06-20T23:59:59.000Z

292

Carbon Dioxide Sealing Capacity: Textural or Compositional Controls?  

SciTech Connect (OSTI)

This research project is aiming to assess the carbon dioxide sealing capacity of most common seal-rocks, such as shales and non-fractured limestones, by analyzing the role of textural and compositional parameters of those rocks. We hypothesize that sealing capacity is controlled by textural and/or compositional pa-rameters of caprocks. In this research, we seek to evaluate the importance of textural and compositional parameters affecting the sealing capacity of caprocks. The conceptu-al framework involves two testable end-member hypotheses concerning the sealing ca-pacity of carbon dioxide reservoir caprocks. Better understanding of the elements controlling sealing quality will advance our knowledge regarding the sealing capacity of shales and carbonates. Due to relatively low permeability, shale and non-fractured carbonate units are considered relatively imper-meable formations which can retard reservoir fluid flow by forming high capillary pres-sure. Similarly, these unites can constitute reliable seals for carbon dioxide capture and sequestration purposes. This project is a part of the comprehensive project with the final aim of studying the caprock sealing properties and the relationship between microscopic and macroscopic characteristics of seal rocks in depleted gas fields of Oklahoma Pan-handle. Through this study we examined various seal rock characteristics to infer about their respective effects on sealing capacity in special case of replacing reservoir fluid with super critical carbon dioxide (scCO{sub 2}). To assess the effect of textural and compositional properties on scCO{sub 2} maximum reten-tion column height we collected 30 representative core samples in caprock formations in three counties (Cimarron, Texas, Beaver) in Oklahoma Panhandle. Core samples were collected from various seal formations (e.g., Cherokee, Keys, Morrowan) at different depths. We studied the compositional and textural properties of the core samples using several techniques. Mercury Injection Porosimetry (MIP), Scanning Electron Microsco-py SEM, and Sedigraph measurements are used to assess the pore-throat-size distribu-tion, sorting, texture, and grain size of the samples. Also, displacement pressure at 10% mercury saturation (Pd) and graphically derived threshold pressure (Pc) were deter-mined by MIP technique. SEM images were used for qualitative study of the minerals and pores texture of the core samples. Moreover, EDS (Energy Dispersive X-Ray Spec-trometer), BET specific surface area, and Total Organic Carbon (TOC) measurements were performed to study various parameters and their possible effects on sealing capaci-ty of the samples. We found that shales have the relatively higher average sealing threshold pressure (Pc) than carbonate and sandstone samples. Based on these observations, shale formations could be considered as a promising caprock in terms of retarding scCO{sub 2} flow and leak-age into above formations. We hypothesized that certain characteristics of shales (e.g., 3 fine pore size, pore size distribution, high specific surface area, and strong physical chemical interaction between wetting phase and mineral surface) make them an effi-cient caprock for sealing super critical CO{sub 2}. We found that the displacement pressure at 10% mercury saturation could not be the ultimate representative of the sealing capacity of the rock sample. On the other hand, we believe that graphical method, introduced by Cranganu (2004) is a better indicator of the true sealing capacity. Based on statistical analysis of our samples from Oklahoma Panhandle we assessed the effects of each group of properties (textural and compositional) on maximum supercriti-cal CO{sub 2} height that can be hold by the caprock. We conclude that there is a relatively strong positive relationship (+.40 to +.69) between supercritical CO{sub 2} column height based on Pc and hard/ soft mineral content index (ratio of minerals with Mohs hardness more than 5 over minerals with Mohs hardness less than 5) in both shales and limestone samples. Average median pore rad

Cranganu, Constantin; Soleymani, Hamidreza; Sadiqua, Soleymani; Watson, Kieva

2013-11-30T23:59:59.000Z

293

GEOTHERMAL RESERVOIR SIMULATIONS WITH SHAFT79  

E-Print Network [OSTI]

that well blocks must geothermal reservoir s·tudies, paperof Califomia. LBL-10066 GEOTHERMAL RESERVOIR SIMULATIONSbe presented at the Fifth Geothermal Reservoir Engineering

Pruess, Karsten

2012-01-01T23:59:59.000Z

294

Reviving Abandoned Reservoirs with High-Pressure Air Injection: Application in a Fractured and Karsted Dolomite Reservoir  

SciTech Connect (OSTI)

Despite declining production rates, existing reservoirs in the United States contain vast volumes of remaining oil that is not being effectively recovered. This oil resource constitutes a huge target for the development and application of modern, cost-effective technologies for producing oil. Chief among the barriers to the recovery of this oil are the high costs of designing and implementing conventional advanced recovery technologies in these mature, in many cases pressure-depleted, reservoirs. An additional, increasingly significant barrier is the lack of vital technical expertise necessary for the application of these technologies. This lack of expertise is especially notable among the small operators and independents that operate many of these mature, yet oil-rich, reservoirs. We addressed these barriers to more effective oil recovery by developing, testing, applying, and documenting an innovative technology that can be used by even the smallest operator to significantly increase the flow of oil from mature U.S. reservoirs. The Bureau of Economic Geology and Goldrus Producing Company assembled a multidisciplinary team of geoscientists and engineers to evaluate the applicability of high-pressure air injection (HPAI) in revitalizing a nearly abandoned carbonate reservoir in the Permian Basin of West Texas. The Permian Basin, the largest oil-bearing basin in North America, contains more than 70 billion barrels of remaining oil in place and is an ideal venue to validate this technology. We have demonstrated the potential of HPAI for oil-recovery improvement in preliminary laboratory tests and a reservoir pilot project. To more completely test the technology, this project emphasized detailed characterization of reservoir properties, which were integrated to access the effectiveness and economics of HPAI. The characterization phase of the project utilized geoscientists and petroleum engineers from the Bureau of Economic Geology and the Department of Petroleum Engineering (both at The University of Texas at Austin) to define the controls on fluid flow in the reservoir as a basis for developing a reservoir model. The successful development of HPAI technology has tremendous potential for increasing the flow of oil from deep carbonate reservoirs in the Permian Basin, a target resource that can be conservatively estimated at more than 1.5 billion barrels. Successful implementation in the field chosen for demonstration, for example, could result in the recovery of more than 34 million barrels of oil that will not otherwise be produced. Geological and petrophysical analysis of available data at Barnhart field reveals the following important observations: (1) the Barnhart Ellenburger reservoir is similar to most other Ellenburger reservoirs in terms of depositional facies, diagenesis, and petrophysical attributes; (2) the reservoir is characterized by low to moderate matrix porosity much like most other Ellenburger reservoirs in the Permian Basin; (3) karst processes (cave formation, infill, and collapse) have substantially altered stratigraphic architecture and reservoir properties; (4) porosity and permeability increase with depth and may be associated with the degree of karst-related diagenesis; (5) tectonic fractures overprint the reservoir, improving overall connectivity; (6) oil-saturation profiles show that the oil-water contact (OWC) is as much as 125 ft lower than previous estimations; (7) production history and trends suggest that this reservoir is very similar to other solution-gas-drive reservoirs in the Permian Basin; and (8) reservoir simulation study showed that the Barnhart reservoir is a good candidate for HPAI and that application of horizontal-well technology can improve ultimate resource recovery from the reservoir.

Robert Loucks; Stephen C. Ruppel; Dembla Dhiraj; Julia Gale; Jon Holder; Jeff Kane; Jon Olson; John A. Jackson; Katherine G. Jackson

2006-09-30T23:59:59.000Z

295

PROCEEDINGS, Thirty-Sixth Workshop on Geothermal Reservoir Engineering Stanford University, Stanford, California, January 31 -February 2, 2011  

E-Print Network [OSTI]

] Basics of Geological Carbon Sequestration and Well Integrity (Adapted from Carbon Sequestration Research may lead to compromising the integrity of the reservoir. Results, obtained using LDEC, which analyze the integrity of the reservoir, the containment of the working geofluid, the surface deformation and ultimately

Stanford University

296

Application of horizontal drilling to tight gas reservoirs  

SciTech Connect (OSTI)

Vertical fractures and lithologic heterogeneity are extremely important factors controlling gas flow rates and total gas recovery from tight (very low permeability) reservoirs. These reservoirs generally have in situ matrix permeabilities to gas of less than 0.1 md. Enhanced gas recovery methods have usually involved hydraulic fracturing; however, the induced vertical hydraulic fractures almost always parallel the natural fracture and may not be an efficient method to establish a good conduit to the wellbore. Horizontal drilling appears to be an optimum method to cut across many open vertical fractures. Horizontal holes will provide an efficient method to drain heterogeneous tight reservoirs even in unfractured rocks. Although many horizontal wells have now been completed in coalbed methane and oil reservoirs, very few have been drilled to exclusively evaluate tight gas reservoirs. The U.S. Department of Energy (DOE) has funded some horizontal and slanthole drilling in order to demonstrate the applicability of these techniques for gas development. Four DOE holes have been drilled in Devonian gas shales in the Appalachian basin, and one hole has been drilled in Upper Cretaceous tight sandstones in the Piceance basin of Colorado. The Colorado field experiment has provided valuable information on the abundance and openness of deeply buried vertical fractures in tight sandstones. These studies, plus higher gas prices, should help encourage industry to begin to further utilize horizontal drilling as a new exploitation method for tight gas reservoirs.

Spencer, C.W. (U.S. Geological Survey, Lakewood, CO (United States)); Lorenz, J.C. (Sandia National Labs., Albuquerque, NM (United States)); Brown, C.A. (Synder Oil Co., Denver, CO (United States))

1991-03-01T23:59:59.000Z

297

Hot dry rock venture risks investigation:  

SciTech Connect (OSTI)

This study assesses a promising resource in central Utah as the potential site of a future commerical hot dry rock (HDR) facility for generating electricity. The results indicate that, if the HDR reservoir productivity equals expectations based on preliminary results from research projects to date, a 50 MWe HDR power facility at Roosevelt Hot Springs could generate power at cost competitive with coal-fired plants. However, it is imperative that the assumed productivity be demonstrated before funds are committed for a commercial facility. 72 refs., 39 figs., 38 tabs.

Not Available

1988-01-01T23:59:59.000Z

298

A reservoir management strategy for multilayered reservoirs in eastern Venezuela  

E-Print Network [OSTI]

A reservoir management strategy has been developed for a field located in eastern Venezuela. The field contains deep, high pressure, multilayer reservoirs. A thorough formation evaluation was accomplished using the log data, core data, PVT data...

Espinel Diaz, Arnaldo Leopoldo

1998-01-01T23:59:59.000Z

299

Optoelectronic Reservoir Computing  

E-Print Network [OSTI]

Reservoir computing is a recently introduced, highly efficient bio-inspired approach for processing time dependent data. The basic scheme of reservoir computing consists of a non linear recurrent dynamical system coupled to a single input layer and a single output layer. Within these constraints many implementations are possible. Here we report an opto-electronic implementation of reservoir computing based on a recently proposed architecture consisting of a single non linear node and a delay line. Our implementation is sufficiently fast for real time information processing. We illustrate its performance on tasks of practical importance such as nonlinear channel equalization and speech recognition, and obtain results comparable to state of the art digital implementations.

Yvan Paquot; François Duport; Anteo Smerieri; Joni Dambre; Benjamin Schrauwen; Marc Haelterman; Serge Massar

2011-11-30T23:59:59.000Z

300

PROCEEDINGS, Thirty-Sixth Workshop on Geothermal Reservoir Engineering Stanford University, Stanford, California, January 31 -February 2, 2011  

E-Print Network [OSTI]

in water has implications for long term carbon sequestration and water-rock interactions (Liu et al. 2003 be superior to water in its ability to mine heat from hot fractured rock. Carbon dioxide also offers modeling. 1. Introduction With increasing concerns about carbon dioxide emissions into the atmosphere

Stanford University

Note: This page contains sample records for the topic "reservoir rock carbon" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


301

Fire flood method for recovering petroleum from oil reservoirs of low permeability and temperature  

DOE Patents [OSTI]

The present invention is directed to a method of enhanced oil recovery by fire flooding petroleum reservoirs characterized by a temperature of less than the critical temperature of carbon dioxide, a pore pressure greater than the saturated vapor pressure of carbon dioxide at said temperature (87.7.degree. F. at 1070 psia), and a permeability in the range of about 20 to 100 millidarcies. The in situ combustion of petroleum in the reservoir is provided by injecting into the reservoir a combustion supporting medium consisting essentially of oxygen, ozone, or a combination thereof. The heat of combustion and the products of this combustion which consist essentially of gaseous carbon dioxide and water vapor sufficiently decrease the viscosity of oil adjacent to fire front to form an oil bank which moves through the reservoir towards a recovery well ahead of the fire front. The gaseous carbon dioxide and the water vapor are driven into the reservoir ahead of the fire front by pressure at the injection well. As the gaseous carbon dioxide cools to less than about 88.degree. F. it is converted to liquid which is dissolved in the oil bank for further increasing the mobility thereof. By using essentially pure oxygen, ozone, or a combination thereof as the combustion supporting medium in these reservoirs the permeability requirements of the reservoirs are significantly decreased since the liquid carbon dioxide requires substantially less voidage volume than that required for gaseous combustion products.

1984-08-14T23:59:59.000Z

302

Fire flood method for recovering petroleum from oil reservoirs of low permeability and temperature  

SciTech Connect (OSTI)

The present invention is directed to a method of enhanced oil recovery by fire flooding petroleum reservoirs characterized by a temperature of less than the critical temperature of carbon dioxide, a pore pressure greater than the saturated vapor pressure of carbon dioxide at said temperature (87.7/sup 0/ F. at 1070 psia), and a permeability in the range of about 20 to 100 millidarcies. The in situ combustion of petroleum in the reservoir is provided by injecting into the reservoir a combustion supporting medium consisting essentially of oxygen, ozone, or a combination thereof. The heat of combustion and the products of this combustion which consist essentially of gaseous carbon dioxide and water vapor sufficiently decrease the viscosity of oil adjacent to fire front to form an oil bank which moves through the reservoir towards a recovery well ahead of the fire front. The gaseous carbon dioxide and the water vapor are driven into the reservoir ahead of the fire front by pressure at the injection well. As the gaseous carbon dioxide cools to less than about 88/sup 0/ F. it is converted to liquid which is dissolved in the oil bank for further increasing the mobility thereof. By using essentially pure oxygen, ozone, or a combination thereof as the combustion supporting medium in these reservoirs the permeability requirements of the reservoirs are significantly decreased since the liquid carbon dioxide requires substantially less voidage volume than that required for gaseous combustion products.

Kamath, K.

1984-08-14T23:59:59.000Z

303

Fire flood method for recovering petroleum from oil reservoirs of low permeability and temperature  

SciTech Connect (OSTI)

The present invention is directed to a method of enhanced oil recovery by fire flooding petroleum reservoirs characterized by a temperature of less than the critical temperature of carbon dioxide, a pore pressure greater than the saturated vapor pressure of carbon dioxide at said temperature (87.7/sup 0/F at 1070 psia), and a permeability in the range of about 20 to 100 millidarcies. The in situ combustion of petroleum in the reservoir is provided by injecting into the reservoir a combustion supporting medium consisting essentially of oxygen, ozone, or a combination thereof. The heat of combustion and the products of this combustion which consist essentially of gaseous carbon dioxide and water vapor sufficiently decrease the viscosity of oil adjacent to fire front to form an oil bank which moves through the reservoir towards a recovery well ahead of the fire front. The gaseous carbon dioxide and the water vapor are driven into the reservoir ahead of the fire front by pressure at the injection well. As the gaseous carbon dioxide cools to less than about 88/sup 0/F it is converted to liquid which is dissolved in the oil bank for further increasing the mobility thereof. By using essentially pure oxygen, ozone, or a combination thereof as the combustion supporting medium in these reservoirs the permeability requirements of the reservoirs are significantly decreased since the liquid carbon dioxide requires substantially less voidage volume than that required for gaseous combustion products. 1 table.

Kamath, K.

1983-05-03T23:59:59.000Z

304

Geothermal Reservoir Engineering Research. Fourth annual report, October 1, 1983-September 30, 1984  

SciTech Connect (OSTI)

Reservoir definition research consisted of well test analysis and bench-scale experiments. Well testing included both single-well pressure drawdown and buildup testing, and multiple-well interference testing. The development of new well testing methods continued to receive major emphasis during the year. Work included a project on multiphase compressibility, including the thermal content of the rock. Several projects on double-porosity systems were completed, and work was done on relative-permeability. Heat extraction from rock will determine the long-term response of geothermal reservoirs to development. The work in this task area involved a combination of physical and mathematical modeling of heat extraction from fractured geothermal reservoirs. International cooperative research dealt with adsorption of water on reservoir cores, the planning of tracer surveys, and an injection and tracer test in the Los Azufres fields. 32 refs.

Ramey, H.J. Jr.; Kruger, P.; Horne, R.N.; Brigham, W.E.; Miller, F.G.

1984-09-01T23:59:59.000Z

305

The Big Group of People Looking at How to Control Putting the Parts of the Air That Are the Same as What You Breathe Out Into Small Spaces in Rocks  

SciTech Connect (OSTI)

Representing the Nanoscale Control of Geologic CO2 (NCGC), this document is one of the entries in the Ten Hundred and One Word Challenge. As part of the challenge, the 46 Energy Frontier Research Centers were invited to represent their science in images, cartoons, photos, words and original paintings, but any descriptions or words could only use the 1000 most commonly used words in the English language, with the addition of one word important to each of the EFRCs and the mission of DOE energy. The mission of NCGC is to build a fundamental understanding of molecular-to-pore-scale processes in fluid-rock systems, and to demonstrate the ability to control critical aspects of flow, transport, and mineralization in porous rock media as applied to the injection and storage of carbon dioxide (CO2) in subsurface reservoirs.

Stack, Andrew

2013-07-18T23:59:59.000Z

306

Modeling of Acid Fracturing in Carbonate Reservoirs  

E-Print Network [OSTI]

The acid fracturing process is a thermal, hydraulic, mechanical, and geochemical (THMG)-coupled phenomena in which the behavior of these variables are interrelated. To model the flow behavior of an acid into a fracture, mass and momentum balance...

Al Jawad, Murtada s

2014-06-05T23:59:59.000Z

307

Heterogeneous reservoirs in the marine carbon cycle  

E-Print Network [OSTI]

Understanding the fate of primary production in the ocean is a challenging task because once produced, organic material is oxidized over timescales which range from minutes, to millions of years. This timescale diversity ...

Follett, Christopher L

2014-01-01T23:59:59.000Z

308

Distribution of petroleum reservoirs relative to allocycles and autocycles, upper portion of the Cherokee Group (Middle Pennsylvanian, Desmoinesian), Mid-Continent Region, U. S. A  

SciTech Connect (OSTI)

Sequences of mud rocks, lenticular sandstones, coals, and thin carbonates form autocycles and allocycles in the upper portion of the Cherokee Group. Autocycles delineated in eastern Kansas and northern Oklahoma are relatively local in extent, while allocycles are traceable over the entire region. All autocycles delineated in this study are embedded within the regressive portions of allocycles. Petroleum-bearing sandstones consist of shoestring-shaped and thin sheetlike units in thicker sedimentary lobes. These lobes were deposited as deltaic complexes, which included fluvial and distributary channel sands, interdistributary muds, crevasse splay sands and muds, flood-basin muds, delta-front sands, and predeltaic muds. Delta lobes prograded across the margins of the Middle Pennsylvanian epeiric sea during times of eustatic stillstand or regression. When lobes were abandoned, waves and currents winnowed their upper portions, leaving thin sheetlike lenses of sand. These reworked sands along with marine muds above regressive deltaic sequences form the transgressive parts of autocyclothems. The transgressive parts of allocyclothems, generally consisting of marine shale, resulted from sea level rises that rapidly shifted shorelines far northeastward, moving siliciclastic sources away from the study area. The positions of reservoir-containing deltaic complexes were determined by strandline positions at various sea levels. Extent of eustatic sea level changes appears to have been the major mechanism that controlled the distribution of petroleum reservoir and source units. In addition, sea level changes probably were a significant factor in the nature of diagenetic alterations that affected reservoir properties.

Brenner, R.L.

1987-05-01T23:59:59.000Z

309

A Thermoelastic Hydraulic Fracture Design Tool for Geothermal Reservoir Development  

SciTech Connect (OSTI)

Geothermal energy is recovered by circulating water through heat exchange areas within a hot rock mass. Geothermal reservoir rock masses generally consist of igneous and metamorphic rocks that have low matrix permeability. Therefore, cracks and fractures play a significant role in extraction of geothermal energy by providing the major pathways for fluid flow and heat exchange. Thus, knowledge of conditions leading to formation of fractures and fracture networks is of paramount importance. Furthermore, in the absence of natural fractures or adequate connectivity, artificial fracture are created in the reservoir using hydraulic fracturing. At times, the practice aims to create a number of parallel fractures connecting a pair of wells. Multiple fractures are preferred because of the large size necessary when using only a single fracture. Although the basic idea is rather simple, hydraulic fracturing is a complex process involving interactions of high pressure fluid injections with a stressed hot rock mass, mechanical interaction of induced fractures with existing natural fractures, and the spatial and temporal variations of in-situ stress. As a result it is necessary to develop tools that can be used to study these interactions as an integral part of a comprehensive approach to geothermal reservoir development, particularly enhanced geothermal systems. In response to this need we have set out to develop advanced thermo-mechanical models for design of artificial fractures and rock fracture research in geothermal reservoirs. These models consider the significant hydraulic and thermo-mechanical processes and their interaction with the in-situ stress state. Wellbore failure and fracture initiation is studied using a model that fully couples poro-mechanical and thermo-mechanical effects. The fracture propagation model is based on a complex variable and regular displacement discontinuity formulations. In the complex variable approach the displacement discontinuities are defined from the numerical solution of a complex hypersingular integral equation written for a given fracture configuration and loading. The fracture propagation studies include modeling interaction of induced fractures with existing discontinuities such as faults and joints. In addition to the fracture propagation studies, two- and three-dimensional heat extraction solution algorithms have been developed and used to estimate heat extraction and the variations of the reservoir stress with cooling. The numerical models have been developed in a user-friendly environment to create a tool for improving fracture design and investigating single or multiple fracture propagation in rock.

Ahmad Ghassemi

2003-06-30T23:59:59.000Z

310

Reservoir Stimulation Optimization with Operational Monitoring for Creation of EGS  

DOE Data Explorer [Office of Scientific and Technical Information (OSTI)]

EGS field projects have not sustained production at rates greater than ½ of what is needed for economic viability. The primary limitation that makes commercial EGS infeasible is our current inability to cost-effectively create high-permeability reservoirs from impermeable, igneous rock within the 3,000-10,000 ft depth range. Our goal is to develop a novel fracturing fluid technology that maximizes reservoir permeability while reducing stimulation cost and environmental impact. Laboratory equipment development to advance laboratory characterization/monitoring is also a priority of this project to study and optimize the physicochemical properties of these fracturing fluids in a range of reservoir conditions. Barrier G is the primarily intended GTO barrier to be addressed as well as support addressing barriers D, E and I.

Fernandez, Carlos A.

311

US production of natural gas from tight reservoirs  

SciTech Connect (OSTI)

For the purposes of this report, tight gas reservoirs are defined as those that meet the Federal Energy Regulatory Commission`s (FERC) definition of tight. They are generally characterized by an average reservoir rock permeability to gas of 0.1 millidarcy or less and, absent artificial stimulation of production, by production rates that do not exceed 5 barrels of oil per day and certain specified daily volumes of gas which increase with the depth of the reservoir. All of the statistics presented in this report pertain to wells that have been classified, from 1978 through 1991, as tight according to the FERC; i.e., they are ``legally tight`` reservoirs. Additional production from ``geologically tight`` reservoirs that have not been classified tight according to the FERC rules has been excluded. This category includes all producing wells drilled into legally designated tight gas reservoirs prior to 1978 and all producing wells drilled into physically tight gas reservoirs that have not been designated legally tight. Therefore, all gas production referenced herein is eligible for the Section 29 tax credit. Although the qualification period for the credit expired at the end of 1992, wells that were spudded (began to be drilled) between 1978 and May 1988, and from November 5, 1990, through year end 1992, are eligible for the tax credit for a subsequent period of 10 years. This report updates the EIA`s tight gas production information through 1991 and considers further the history and effect on tight gas production of the Federal Government`s regulatory and tax policy actions. It also provides some high points of the geologic background needed to understand the nature and location of low-permeability reservoirs.

Not Available

1993-10-18T23:59:59.000Z

312

Machel, H.G., Buschkuehle, B.E. and Michael, K., 2001, Squeegee flow in Devonian carbonate aquifers in Alberta, Canada. In: Cidu, R. (ed.), Water-Rock Interaction, Vol. 1. Proceedings of the Tenth International Symposium on Water-Rock-Interaction WRI-  

E-Print Network [OSTI]

in thickness. Across much of the basin the four Devonian aquifers, which contain oil, sweet and sour gas reservoirs, are interbedded with marly and evaporitic aquitards, and are confined by tight evaporites

Machel, Hans

313

Reinjection into geothermal reservoirs  

SciTech Connect (OSTI)

Reinjection of geothermal wastewater is practiced as a means of disposal and for reservoir pressure support. Various aspects of reinjection are discussed, both in terms of theoretical studies as well as specific field examples. The discussion focuses on the major effects of reinjection, including pressure maintenance and chemical and thermal effects. (ACR)

Bodvarsson, G.S.; Stefansson, V.

1987-08-01T23:59:59.000Z

314

Dispersion measurement as a method of quantifying geologic characterization and defining reservoir heterogeneity. Final report  

SciTech Connect (OSTI)

The main objective of this research project is to investigate dispersion as a method of quantifying geological characterization and defining reservoir heterogeneity in order to enhance crude oil recovery. The dispersion of flow of a reservoir rock (dispersion coefficient and dispersivity) was identified as one of the physical properties of a reservoir rock by measuring the mixing of two miscible fluids, one displacing the other in a porous medium. A rock was 100% saturated with a resident fluid and displaced by a miscible fluid of equal viscosity and equal density. Some specific experiments were performed with unequal densities. Produced fluid was analyzed by refractometer, nuclear reaction, electrical conductivity and X-ray scan. Several physical and flow characteristics were measured on the sand rock sample in order to establish correlations with the measured dispersion property. Absolute permeability, effective porosity, relative permeability, capillary pressure, the heterogeneity factor and electrical conductivity were used to better understand the flow system. Linear, transverse, 2-D and 3-D dispersions were measured and used to characterize the rock heterogeneity of the flow system. A new system of measuring dispersion was developed using a gas displacing gas system in a porous medium. An attempt was also made to determine the dispersion property of an actual reservoir from present day well log data on a producing well. 275 refs., 102 figs., 17 tabs.

Menzie, D.E.

1995-05-01T23:59:59.000Z

315

Reservoir Characterization and Modeling of the Glorieta and the Clearfork Formations, Monahans Field, Permian Basin, Texas  

E-Print Network [OSTI]

Monahans Field of the Permian Basin in West Texas is a complex carbonate reservoir due to the lateral heterogeneity caused by facies changes throughout the Lower Guadalupian Glorieta Formation and the Upper Leonardian Upper Clearfork Formation. A...

Yeatman, Ryan Yeatman

2012-10-19T23:59:59.000Z

316

Analysis of condensate banking dynamics in a gas condensate reservoir under different injection schemes  

E-Print Network [OSTI]

condensate reservoir under natural depletion, and injection of methane, injection of carbon dioxide, produced gas recycling and water injection. To monitor the condensate banking dynamics near the wellbore area, such as oil saturation and compositional...

Sandoval Rodriguez, Angelica Patricia

2002-01-01T23:59:59.000Z

317

Use of uranium^thorium dating to determine C reservoir eects in lakes: examples from Antarctica  

E-Print Network [OSTI]

Use of uranium^thorium dating to determine past 14 C reservoir e¡ects in lakes: examples from of dissolved `dead' carbon or to slow air^water exchange. Here we use the TIMS uranium^thorium disequilibrium

Henderson, Gideon

318

Heavy oil reservoirs recoverable by thermal technology. Annual report  

SciTech Connect (OSTI)

The purpose of this study was to compile data on reservoirs that contain heavy oil in the 8 to 25/sup 0/ API gravity range, contain at least ten million barrels of oil currently in place, and are non-carbonate in lithology. The reservoirs within these constraints were then analyzed in light of applicable recovery technology, either steam-drive or in situ combustion, and then ranked hierarchically as candidate reservoirs. The study is presented in three volumes. Volume I presents the project background and approach, the screening analysis, ranking criteria, and listing of candidate reservoirs. The economic and environmental aspects of heavy oil recovery are included in appendices to this volume. This study provides an extensive basis for heavy oil development, but should be extended to include carbonate reservoirs and tar sands. It is imperative to look at heavy oil reservoirs and projects on an individual basis; it was discovered that operators, and industrial and government analysts will lump heavy oil reservoirs as poor producers, however, it was found that upon detailed analysis, a large number, so categorized, were producing very well. A study also should be conducted on abandoned reservoirs. To utilize heavy oil, refiners will have to add various unit operations to their processes, such as hydrotreaters and hydrodesulfurizers and will require, in most cases, a lighter blending stock. A big problem in producing heavy oil is that of regulation; specifically, it was found that the regulatory constraints are so fluid and changing that one cannot settle on a favorable recovery and production plan with enough confidence in the regulatory requirements to commit capital to the project.

Kujawa, P.

1981-02-01T23:59:59.000Z

319

Effects of carbon dioxide injection on the displacement of methane and carbonate dissolution in sandstone cores  

E-Print Network [OSTI]

of carbon dioxide in depleted gas reservoirs appears to be a feasible way to dispose of industrial quantities of carbon dioxide generated by fossil fired power plants. Depleted gas reservoirs amongst others (oil reservoirs, saline aquifers) is a very... from the Sleipner Vest field is separated from the produced natural gas and is injected each year into the underlying Utsira aquifer. 1, 7, 8 A combined enhanced oil recovery (EOR) scheme and CO2 sequestration project has been undertaken in which CO2...

Maduakor, Ekene Obioma

2006-10-30T23:59:59.000Z

320

A METHODOLOGY TO INTEGRATE MAGNETIC RESONANCE AND ACOUSTIC MEASUREMENTS FOR RESERVOIR CHARACTERIZATION  

SciTech Connect (OSTI)

The work reported herein represents the third year of development efforts on a methodology to interpret magnetic resonance and acoustic measurements for reservoir characterization. In this last phase of the project we characterize a vuggy carbonate aquifer in the Hillsboro Basin, Palm Beach County, South Florida, using two data sets--the first generated by velocity tomography and the second generated by reflection tomography. First, we integrate optical macroscopic (OM), scanning electron microscope (SEM) and x-ray computed tomography (CT) images, as well as petrography, as a first step in characterizing the aquifer pore system. This pore scale integration provides information with which to evaluate nuclear magnetic resonance (NMR) well log signatures for NMR well log calibration, interpret ultrasonic data, and characterize flow units at the field scale between two wells in the aquifer. Saturated and desaturated NMR core measurements estimate the irreducible water in the rock and the variable T{sub 2} cut-offs for the NMR well log calibration. These measurements establish empirical equations to extract permeability from NMR well logs. Velocity and NMR-derived permeability and porosity relationships integrated with velocity tomography (based on crosswell seismic measurements recorded between two wells 100 m apart) capture two flow units that are supported with pore scale integration results. Next, we establish a more detailed picture of the complex aquifer pore structures and the critical role they play in water movement, which aids in our ability to characterize not only carbonate aquifers, but reservoirs in general. We analyze petrography and cores to reveal relationships between the rock physical properties that control the compressional and shear wave velocities of the formation. A digital thin section analysis provides the pore size distributions of the rock matrix, which allows us to relate pore structure to permeability and to characterize flow units at the core and borehole scales. Vp, density, porosity, and permeability logs are integrated with crosswell reflection data to produce impedance, permeability, and porosity images. These images capture three flow units that are characterized at the pore and borehole scales. The upper flow units are thin, continuous beds, and the deeper flow unit is thicker and heterogeneous. NMR well log calibration data and thin section analysis demonstrate that interwell region permeability is controlled mainly by micropores and macropores, which represent the flow unit matrices of the confined aquifer. Reflection image-derived impedance provides lateral detail and the depth of the deeper confining unit. The permeable regions identified in both parts of this phase of the study are consistent with the hydrological results of high water production being monitored between two wells in the South Florida aquifer. Finally, we describe the two major methodologies developed to support the aquifer characterization efforts--(1) a method to estimate frequency-dependent scattering attenuation based on the volume fraction and typical size of vugs or karsts, and (2) a method to more accurately interpret NMR well logs by taking into account the diffusion of magnetization between large and small pores. For the first method, we take the exact vug structure from x-ray CT scans of two carbonate cores and use 3-D finite difference modeling to determine the P-wave scattering attenuation in these cores at ultrasonic frequencies. In spite of the sharp contrast in medium properties between cavity and rock and the violation of the small perturbation assumption, the computed scattering attenuation is roughly comparable to that predicted by various random medium scattering theories. For the second method, we investigate how the diffusion of magnetization between macropores and micropores influences NMR log interpretation through 2D simulation of magnetization diffusion in realistic macropore geometries derived from digital images of thin sections. In most cases, our simulations show that the resulting simulate

Jorge O. Parra; Chris L. Hackert; Lorna L. Wilson

2002-09-20T23:59:59.000Z

Note: This page contains sample records for the topic "reservoir rock carbon" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


321

THERMO-HYDRO-MECHANICAL MODELING OF WORKING FLUID INJECTION AND THERMAL ENERGY EXTRACTION IN EGS FRACTURES AND ROCK MATRIX  

SciTech Connect (OSTI)

Development of enhanced geothermal systems (EGS) will require creation of a reservoir of sufficient volume to enable commercial-scale heat transfer from the reservoir rocks to the working fluid. A key assumption associated with reservoir creation/stimulation is that sufficient rock volumes can be hydraulically fractured via both tensile and shear failure, and more importantly by reactivation of naturally existing fractures (by shearing), to create the reservoir. The advancement of EGS greatly depends on our understanding of the dynamics of the intimately coupled rock-fracture-fluid-heat system and our ability to reliably predict how reservoirs behave under stimulation and production. Reliable performance predictions of EGS reservoirs require accurate and robust modeling for strongly coupled thermal-hydrological-mechanical (THM) processes. Conventionally, these types of problems have been solved using operator-splitting methods, usually by coupling a subsurface flow and heat transport simulators with a solid mechanics simulator via input files. An alternative approach is to solve the system of nonlinear partial differential equations that govern multiphase fluid flow, heat transport, and rock mechanics simultaneously, using a fully coupled, fully implicit solution procedure, in which all solution variables (pressure, enthalpy, and rock displacement fields) are solved simultaneously. This paper describes numerical simulations used to investigate the poro- and thermal- elastic effects of working fluid injection and thermal energy extraction on the properties of the fractures and rock matrix of a hypothetical EGS reservoir, using a novel simulation software FALCON (Podgorney et al., 2011), a finite element based simulator solving fully coupled multiphase fluid flow, heat transport, rock deformation, and fracturing using a global implicit approach. Investigations are also conducted on how these poro- and thermal-elastic effects are related to fracture permeability evolution.

Robert Podgorney; Chuan Lu; Hai Huang

2012-01-01T23:59:59.000Z

322

Data Integration for the Generation of High Resolution Reservoir Models  

SciTech Connect (OSTI)

The goal of this three-year project was to develop a theoretical basis and practical technology for the integration of geologic, production and time-lapse seismic data in a way that makes best use of the information for reservoir description and reservoir performance predictions. The methodology and practical tools for data integration that were developed in this research project have been incorporated into computational algorithms that are feasible for large scale reservoir simulation models. As the integration of production and seismic data require calibrating geological/geostatistical models to these data sets, the main computational tool is an automatic history matching algorithm. The following specific goals were accomplished during this research. (1) We developed algorithms for calibrating the location of the boundaries of geologic facies and the distribution of rock properties so that production and time-lapse seismic data are honored. (2) We developed and implemented specific procedures for conditioning reservoir models to time-lapse seismic data. (3) We developed and implemented algorithms for the characterization of measurement errors which are needed to determine the relative weights of data when conditioning reservoir models to production and time-lapse seismic data by automatic history matching. (4) We developed and implemented algorithms for the adjustment of relative permeability curves during the history matching process. (5) We developed algorithms for production optimization which accounts for geological uncertainty within the context of closed-loop reservoir management. (6) To ensure the research results will lead to practical public tools for independent oil companies, as part of the project we built a graphical user interface for the reservoir simulator and history matching software using Visual Basic.

Albert Reynolds; Dean Oliver; Gaoming Li; Yong Zhao; Chaohui Che; Kai Zhang; Yannong Dong; Chinedu Abgalaka; Mei Han

2009-01-07T23:59:59.000Z

323

Seismic-Scale Rock Physics of Methane Hydrate  

SciTech Connect (OSTI)

We quantify natural methane hydrate reservoirs by generating synthetic seismic traces and comparing them to real seismic data: if the synthetic matches the observed data, then the reservoir properties and conditions used in synthetic modeling might be the same as the actual, in-situ reservoir conditions. This approach is model-based: it uses rock physics equations that link the porosity and mineralogy of the host sediment, pressure, and hydrate saturation, and the resulting elastic-wave velocity and density. One result of such seismic forward modeling is a catalogue of seismic reflections of methane hydrate which can serve as a field guide to hydrate identification from real seismic data. We verify this approach using field data from known hydrate deposits.

Amos Nur

2009-01-08T23:59:59.000Z

324

A general-purpose, geochemical reservoir simulator  

SciTech Connect (OSTI)

A geochemical simulator for the analysis of coupled reaction and transport processes is presented. The simulator is based on the numerical solution of the equations of coupled multi-phase fluid flow, species transport, energy balance and rock/fluid reactions. It also accounts for the effects of grain growth/dissolution and the alteration of porosity and permeability due to mineral reactions. The simulator can be used to analyze core floods, single-well scenarios and multiple production/injection well systems on the reservoir scale. Additionally, the simulator provides two flow options: the Darcy law for fluid flow in porous media and the Brinkman law that subsumes both free and porous medium flows. The simulator was tested using core acidizing data and results were in good agreement with laboratory observations. The simulator was applied to analyze matrix acidizing treatments for a horizontal well. The evolution of the skin factor was predicted and the optimal volume of acid required to remove the near-wellbore damage was determined. Reactive fluid infiltration was shown to lead to reaction-front fingering under certain conditions. Viscosity contrast in multiphase flow could also result in viscous fingering. Examples in this study also address these nonlinear fingering phenomena. A waterflood on the reservoir scale was analyzed and simulation results show that scale formation during waterfloods can occur far beyond injection wells. Two cases of waste disposal by deep well injection were evaluated and our simulation results were consistent with field measured data.

Liu, X.; Ortoleva, P.

1996-12-31T23:59:59.000Z

325

Seventeenth workshop on geothermal reservoir engineering: Proceedings  

SciTech Connect (OSTI)

PREFACE The Seventeenth Workshop on Geothermal Reservoir Engineering was held at Stanford University on January 29-31, 1992. There were one hundred sixteen registered participants which equaled the attendance last year. Participants were from seven foreign countries: Italy, Japan, United Kingdom, France, Belgium, Mexico and New Zealand. Performance of many geothermal fields outside the United States was described in the papers. The Workshop Banquet Speaker was Dr. Raffaele Cataldi. Dr. Cataldi gave a talk on the highlights of his geothermal career. The Stanford Geothermal Program Reservoir Engineering Award for Excellence in Development of Geothermal Energy was awarded to Dr. Cataldi. Dr. Frank Miller presented the award at the banquet. Thirty-eight papers were presented at the Workshop with two papers submitted for publication only. Dr. Roland Horne opened the meeting and the key note speaker was J.E. ''Ted'' Mock who discussed the DOE Geothermal R. & D. Program. The talk focused on aiding long-term, cost effective private resource development. Technical papers were organized in twelve sessions concerning: geochemistry, hot dry rock, injection, geysers, modeling, and reservoir mechanics. Session chairmen were major contributors to the program and we thank: Sabodh Garg., Jim Lovekin, Jim Combs, Ben Barker, Marcel Lippmann, Glenn Horton, Steve Enedy, and John Counsil. The Workshop was organized by the Stanford Geothermal Program faculty, staff, and graduate students. We wish to thank Pat Ota, Ted Sumida, and Terri A. Ramey who also produces the Proceedings Volumes for publication. We owe a great deal of thanks to our students who operate audiovisual equipment and to Francois Groff who coordinated the meeting arrangements for the Workshop. Henry J. Ramey, Jr. Roland N. Horne Frank G. Miller Paul Kruger William E. Brigham Jean W. Cook -vii

Ramey, H.J. Jr.; Kruger, P.; Miller, F.G.; Horne, R.N.; Brigham, W.E.; Cook, J.W. (Stanford Geothermal Program)

1992-01-31T23:59:59.000Z

326

Characterization and interwell connectivity evaluation of Green Rver reservoirs, Wells Draw study area, Uinta Basin, Utah  

E-Print Network [OSTI]

and seal rocks of the Green River petroleum system. Datum is Mahoganey oil shale bed (1). 49 27 Fig. 11?Cross-section of thermal maturity of oil accumulations in the Green River petroleum system. 49 28 Fig. 12? Lake Uinta depositional... This petroleum system has produced more than 450 MMBO mainly from two formations, the Green River and Colton Formations. 7 The Green River Formation contains the source rock and most of the reservoir and seal rocks (Fig. 10). 49 Most of the kerogen-rich oil...

Abiazie, Joseph Uchechukwu

2009-05-15T23:59:59.000Z

327

Interface Induced Carbonate Mineralization: A Fundamental Geochemical Process Relevant to Carbon Sequestration  

SciTech Connect (OSTI)

Mica, biotite, muscovite, diopside, tremolite, ultramafic rock, hematite, Ca-Mg-carbonate, calcite, aragonite, dolomite, crystal nucleation, crystallization, interface, catalysis, EBSD, XRD, TEM

Xu, Huifang; Zhou, Mo; Zhang, Fangfu; Konishi, Hiromi; Shen, Zhizhang; Teng, H.

2013-10-16T23:59:59.000Z

328

Experimental study of potential wellbore cement carbonation by various phases of carbon dioxide during geologic carbon sequestration  

SciTech Connect (OSTI)

Hydrated Portland cement was reacted with carbon dioxide (CO2) in supercritical, gaseous, and aqueous phases to understand the potential cement alteration processes along the length of a wellbore, extending from deep CO2 storage reservoir to the shallow subsurface during geologic carbon sequestration. The 3-D X-ray microtomography (XMT) images displayed that the cement alteration was significantly more extensive by CO2-saturated synthetic groundwater than dry or wet supercritical CO2 at high P (10 MPa)-T (50°C) conditions. Scanning electron microscopy with energy dispersive spectroscopy (SEM-EDS) analysis also exhibited a systematic Ca depletion and C enrichment in cement matrix exposed to CO2-saturated groundwater. Integrated XMT, XRD, and SEM-EDS analyses identified the formation of extensive carbonated zone filled with CaCO3(s), as well as the porous degradation front and the outermost silica-rich zone in cement after exposure to CO2-saturated groundwater. The cement alteration by CO2-saturated groundwater for 2-8 months overall decreased the porosity from 31% to 22% and the permeability by an order of magnitude. Cement alteration by dry or wet supercritical CO2 was slow and minor compared to CO2-saturated groundwater. A thin single carbonation zone was formed in cement after exposure to wet supercritical CO2 for 8 months or dry supercritical CO2 for 15 months. Extensive calcite coating was formed on the outside surface of a cement sample after exposure to wet gaseous CO2 for 1-3 months. The chemical-physical characterization of hydrated Portland cement after exposure to various phases of carbon dioxide indicates that the extent of cement carbonation can be significantly heterogeneous depending on CO2 phase present in the wellbore environment. Both experimental and geochemical modeling results suggest that wellbore cement exposure to supercritical, gaseous, and aqueous phases of CO2 during geologic carbon sequestration is unlikely to damage the wellbore integrity because cement alteration by all phases of CO2 is dominated by carbonation reaction. This is consistent with previous field studies of wellbore cement with extensive carbonation after exposure to CO2 for 3 decades. However, XMT imaging indicates that preferential cement alteration by supercritical CO2 or CO2-saturated groundwater can occur along the cement-steel or cement-rock interfaces. This highlights the importance of further investigation of cement degradation along the interfaces of wellbore materials to ensure permanent geologic carbon storage.

Jung, Hun Bok; Um, Wooyong

2013-08-16T23:59:59.000Z

329

Geochemical Impacts of Leaking CO2 from Subsurface Storage Reservoirs to Unconfined and Confined Aquifers  

SciTech Connect (OSTI)

Experimental research work has been conducted and is undergoing at Pacific Northwest National Laboratory (PNNL) to address a variety of scientific issues related with the potential leaks of the carbon dioxide (CO2) gas from deep storage reservoirs. The main objectives of this work are as follows: • Develop a systematic understanding of how CO2 leakage is likely to influence pertinent geochemical processes (e.g., dissolution/precipitation, sorption/desorption and redox reactions) in the aquifer sediments. • Identify prevailing environmental conditions that would dictate one geochemical outcome over another. • Gather useful information to support site selection, risk assessment, policy-making, and public education efforts associated with geological carbon sequestration. In this report, we present results from experiments conducted at PNNL to address research issues related to the main objectives of this effort. A series of batch and column experiments and solid phase characterization studies (quantitative x-ray diffraction and wet chemical extractions with a concentrated acid) were conducted with representative rocks and sediments from an unconfined, oxidizing carbonate aquifer, i.e., Edwards aquifer in Texas, and a confined aquifer, i.e., the High Plains aquifer in Kansas. These materials were exposed to a CO2 gas stream simulating CO2 gas leaking scenarios, and changes in aqueous phase pH and chemical composition were measured in liquid and effluent samples collected at pre-determined experimental times. Additional research to be conducted during the current fiscal year will further validate these results and will address other important remaining issues. Results from these experimental efforts will provide valuable insights for the development of site-specific, generation III reduced order models. In addition, results will initially serve as input parameters during model calibration runs and, ultimately, will be used to test model predictive capability and competency. The results from these investigations will provide useful information to support site selection, risk assessment, and public education efforts associated with geological, deep subsurface CO2 storage and sequestration.

Qafoku, Nikolla; Brown, Christopher F.; Wang, Guohui; Sullivan, E. C.; Lawter, Amanda R.; Harvey, Omar R.; Bowden, Mark

2013-04-15T23:59:59.000Z

330

How secure is CO2 storage? Leakage mechanisms of natural CO2 reservoirs  

E-Print Network [OSTI]

technology available to reduce greenhouse gas emissions from large point sources such as power plants and the burial of organic rich rocks such as coal seams.2 We have compiled the first global dataset on natural CO ­ but not necessarily leaking. Figure 4: Diagram showing the state of CO2 in the studied reservoirs. Supercritical

331

Resolution of reservoir scale electrical anisotropy from marine CSEM data Vanessa Brown1  

E-Print Network [OSTI]

in distinguishing oil sand from anisotropic shale. Shale is the most common rock where Manuscript received- tropy located in a deep-water exploration reservoir target. Be- cause strongly anisotropic shale layers discriminate confounding shale layers through their characteristically lower horizontal resistivity. Forward

Chen, Jinsong

332

Fundamentals of Reservoir Surface Energy as Related to Surface Properties, Wettability, Capillary Action, and Oil Recovery from Fractured Reservoirs by Spontaneous Imbibition  

SciTech Connect (OSTI)

The objective of this project is to increase oil recovery from fractured reservoirs through improved fundamental understanding of the process of spontaneous imbibition by which oil is displaced from the rock matrix into the fractures. Spontaneous imbibition is fundamentally dependent on the reservoir surface free energy but this has never been investigated for rocks. In this project, the surface free energy of rocks will be determined by using liquids that can be solidified within the rock pore space at selected saturations. Thin sections of the rock then provide a two-dimensional view of the rock minerals and the occupant phases. Saturations and oil/rock, water/rock, and oil/water surface areas will be determined by advanced petrographic analysis and the surface free energy which drives spontaneous imbibition will be determined as a function of increase in wetting phase saturation. The inherent loss in surface free energy resulting from capillary instabilities at the microscopic (pore level) scale will be distinguished from the decrease in surface free energy that drives spontaneous imbibition. A mathematical network/numerical model will be developed and tested against experimental results of recovery versus time over broad variation of key factors such as rock properties, fluid phase viscosities, sample size, shape and boundary conditions. Two fundamentally important, but not previously considered, parameters of spontaneous imbibition, the capillary pressure acting to oppose production of oil at the outflow face and the pressure in the non-wetting phase at the no-flow boundary versus time, will also be measured and modeled. Simulation and network models will also be tested against special case solutions provided by analytic models. In the second stage of the project, application of the fundamental concepts developed in the first stage of the project will be demonstrated. The fundamental ideas, measurements, and analytic/numerical modeling will be applied to mixed-wet rocks. Imbibition measurements will include novel sensitive pressure measurements designed to elucidate the basic mechanisms that determine induction time and drive the very slow rate of spontaneous imbibition commonly observed for mixed-wet rocks. In further demonstration of concepts, three approaches to improved oil recovery from fractured reservoirs will be tested; use of surfactants to promote imbibition in oil wet rocks by wettability alteration: manipulation of injection brine composition: reduction of the capillary back pressure which opposes production of oil at the fracture face.

Norman Morrow; Herbert Fischer; Yu Li; Geoffrey Mason; Douglas Ruth; Siddhartha Seth; Zhengxin Tong; Evren Unsal; Siluni Wickramathilaka; Shaochang Wo; Peigui Yin

2008-06-30T23:59:59.000Z

333

Fundamentals of reservoir surface energy as related to surface properties, wettability, capillary action, and oil recovery from fractured reservoirs by spontaneous imbibition  

SciTech Connect (OSTI)

The objective of this project is to increase oil recovery from fractured reservoirs through improved fundamental understanding of the process of spontaneous imbibition by which oil is displaced from the rock matrix into the fractures. Spontaneous imbibition is fundamentally dependent on the reservoir surface free energy but this has never been investigated for rocks. In this project, the surface free energy of rocks will be determined by using liquids that can be solidified within the rock pore space at selected saturations. Thin sections of the rock then provide a two-dimensional view of the rock minerals and the occupant phases. Saturations and oil/rock, water/rock, and oil/water surface areas will be determined by advanced petrographic analysis and the surface free energy which drives spontaneous imbibition will be determined as a function of increase in wetting phase saturation. The inherent loss in surface free energy resulting from capillary instabilities at the microscopic (pore level) scale will be distinguished from the decrease in surface free energy that drives spontaneous imbibition. A mathematical network/numerical model will be developed and tested against experimental results of recovery versus time over broad variation of key factors such as rock properties, fluid phase viscosities, sample size, shape and boundary conditions. Two fundamentally important, but not previously considered, parameters of spontaneous imbibition, the capillary pressure acting to oppose production of oil at the outflow face and the pressure in the non-wetting phase at the no-flow boundary versus time, will also be measured and modeled. Simulation and network models will also be tested against special case solutions provided by analytic models. In the second stage of the project, application of the fundamental concepts developed in the first stage of the project will be demonstrated. The fundamental ideas, measurements, and analytic/numerical modeling will be applied to mixed-wet rocks. Imbibition measurements will include novel sensitive pressure measurements designed to elucidate the basic mechanisms that determine induction time and drive the very slow rate of spontaneous imbibition commonly observed for mixed-wet rocks. In further demonstration of concepts, three approaches to improved oil recovery from fractured reservoirs will be tested; use of surfactants to promote imbibition in oil wet rocks by wettability alteration: manipulation of injection brine composition: reduction of the capillary back pressure which opposes production of oil at the fracture face.

Norman R. Morrow; Herbert Fischer; Yu Li; Geoffrey Mason; Douglas Ruth; Siddhartha Seth; Jason Zhengxin Tong; Peigui Yin; Shaochang Wo

2006-06-08T23:59:59.000Z

334

Fundamentals of Reservoir Surface Energy as Related to Surface Properties, Wettability, Capillary Action and Oil Recovery from Fractured Reservoirs by Spontaneous Imbibition  

SciTech Connect (OSTI)

The objective of this project is to increase oil recovery from fractured reservoirs through improved fundamental understanding of the process of spontaneous imbibition by which oil is displaced from the rock matrix into the fractures. Spontaneous imbibition is fundamentally dependent on the reservoir surface free energy but this has never been investigated for rocks. In this project, the surface free energy of rocks will be determined by using liquids that can be solidified within the rock pore space at selected saturations. Thin sections of the rock then provide a two-dimensional view of the rock minerals and the occupant phases. Saturations and oil/rock, water/rock, and oil/water surface areas will be determined by advanced petrographic analysis and the surface free energy which drives spontaneous imbibition will be determined as a function of increase in wetting phase saturation. The inherent loss in surface free energy resulting from capillary instabilities at the microscopic (pore level) scale will be distinguished from the decrease in surface free energy that drives spontaneous imbibition. A mathematical network/numerical model will be developed and tested against experimental results of recovery versus time over broad variation of key factors such as rock properties, fluid phase viscosities, sample size, shape and boundary conditions. Two fundamentally important, but not previously considered, parameters of spontaneous imbibition, the capillary pressure acting to oppose production of oil at the outflow face and the pressure in the non-wetting phase at the no-flow boundary versus time, will also be measured and modeled. Simulation and network models will also be tested against special case solutions provided by analytic models. In the second stage of the project, application of the fundamental concepts developed in the first stage of the project will be demonstrated. The fundamental ideas, measurements, and analytic/numerical modeling will be applied to mixed-wet rocks. Imbibition measurements will include novel sensitive pressure measurements designed to elucidate the basic mechanisms that determine induction time and drive the very slow rate of spontaneous imbibition commonly observed for mixed-wet rocks. In further demonstration of concepts, three approaches to improved oil recovery from fractured reservoirs will be tested; use of surfactants to promote imbibition in oil wet rocks by wettability alteration: manipulation of injection brine composition: reduction of the capillary back pressure which opposes production of oil at the fracture face.

Norman R. Morrow; Herbert Fischer; Yu Li; Geoffrey Mason; Douglas Ruth; Peigui Yin; Shaochang Wo

2006-12-08T23:59:59.000Z

335

Fundamentals of reservoir surface energy as related to surface properties, wettability, capillary action, and oil recovery from fractured reservoirs by spontaneous imbibition  

SciTech Connect (OSTI)

The objective of this project is to increase oil recovery from fractured reservoirs through improved fundamental understanding of the process of spontaneous imbibition by which oil is displaced from the rock matrix into the fractures. Spontaneous imbibition is fundamentally dependent on the reservoir surface free energy but this has never been investigated for rocks. In this project, the surface free energy of rocks will be determined by using liquids that can be solidified within the rock pore space at selected saturations. Thin sections of the rock then provide a two-dimensional view of the rock minerals and the occupant phases. Saturations and oil/rock, water/rock, and oil/water surface areas will be determined by advanced petrographic analysis and the surface free energy which drives spontaneous imbibition will be determined as a function of increase in wetting phase saturation. The inherent loss in surface free energy resulting from capillary instabilities at the microscopic (pore level) scale will be distinguished from the decrease in surface free energy that drives spontaneous imbibition. A mathematical network/numerical model will be developed and tested against experimental results of recovery versus time over broad variation of key factors such as rock properties, fluid phase viscosities, sample size, shape and boundary conditions. Two fundamentally important, but not previously considered, parameters of spontaneous imbibition, the capillary pressure acting to oppose production of oil at the outflow face and the pressure in the nonwetting phase at the no-flow boundary versus time, will also be measured and modeled. Simulation and network models will also be tested against special case solutions provided by analytic models. In the second stage of the project, application of the fundamental concepts developed in the first stage of the project will be demonstrated. The fundamental ideas, measurements, and analytic/numerical modeling will be applied to mixed-wet rocks. Imbibition measurements will include novel sensitive pressure measurements designed to elucidate the basic mechanisms that determine induction time and drive the very slow rate of spontaneous imbibition commonly observed for mixed-wet rocks. In further demonstration of concepts, three approaches to improved oil recovery from fractured reservoirs will be tested; use of surfactants to promote imbibition in oil wet rocks by wettability alteration: manipulation of injection brine composition: reduction of the capillary back pressure which opposes production of oil at the fracture face.

Norman R. Morrow; Herbert Fischer; Yu Li; Geoffrey Mason; Douglas Ruth; Siddhartha Seth; Jason Zhengxin Tong; Peigui Yin; Shaochang Wo

2006-02-01T23:59:59.000Z

336

FUNDAMENTALS OF RESERVOIR SURFACE ENERGY AS RELATED TO SURFACE PROPERTIES, WETTABILITY, CAPILLARY ACTION, AND OIL RECOVERY FROM FRACTURED RESERVOIRS BY SPONTANEOUS IMBIBITION  

SciTech Connect (OSTI)

The objective of this project is to increase oil recovery from fractured reservoirs through improved fundamental understanding of the process of spontaneous imbibition by which oil is displaced from the rock matrix into the fractures. Spontaneous imbibition is fundamentally dependent on the reservoir surface free energy but this has never been investigated for rocks. In this project, the surface free energy of rocks will be determined by using liquids that can be solidified within the rock pore space at selected saturations. Thin sections of the rock then provide a two-dimensional view of the rock minerals and the occupant phases. Saturations and oil/rock, water/rock, and oil/water surface areas will be determined by advanced petrographic analysis and the surface free energy which drives spontaneous imbibition will be determined as a function of increase in wetting phase saturation. The inherent loss in surface free energy resulting from capillary instabilities at the microscopic (pore level) scale will be distinguished from the decrease in surface free energy that drives spontaneous imbibition. A mathematical network/numerical model will be developed and tested against experimental results of recovery versus time over broad variation of key factors such as rock properties, fluid phase viscosities, sample size, shape and boundary conditions. Two fundamentally important, but not previously considered, parameters of spontaneous imbibition, the capillary pressure acting to oppose production of oil at the outflow face and the pressure in the nonwetting phase at the no-flow boundary versus time, will also be measured and modeled. Simulation and network models will also be tested against special case solutions provided by analytic models. In the second stage of the project, application of the fundamental concepts developed in the first stage of the project will be demonstrated. The fundamental ideas, measurements, and analytic/numerical modeling will be applied to mixed-wet rocks. Imbibition measurements will include novel sensitive pressure measurements designed to elucidate the basic mechanisms that determine induction time and drive the very slow rate of spontaneous imbibition commonly observed for mixed-wet rocks. In further demonstration of concepts, three approaches to improved oil recovery from fractured reservoirs will be tested; use of surfactants to promote imbibition in oil wet rocks by wettability alteration: manipulation of injection brine composition: reduction of the capillary back pressure which opposes production of oil at the fracture face.

Norman R. Morrow; Herbert Fischer; Yu Li; Geoffrey Mason; Douglas Ruth; Siddhartha Seth; Peigui Yin; Shaochang Wo

2004-10-01T23:59:59.000Z

337

Hedberg Research Conference on Fundamental Controls on Flow in Carbonates: Request for Travel Support for Post-Doctoral Fellows  

SciTech Connect (OSTI)

Carbonate reservoirs pose a scientific and engineering challenge to geophysical prediction and monitoring of fluid flow in the subsurface. Difficulties in interpreting hydrological, reservoir and other exploration data arise because carbonates are composed of a hierarchy of geological structures, constituents and processes that span a wide spectrum of length and time scales. What makes this problem particularly challenging is that length scales associated with physical structure and processes are often not discrete, but overlap, preventing the definition of discrete elements at one scale to become the building blocks of the next scale. This is particularly true for carbonates where complicated depositional environments, subsequent post-deposition diagenesis and geochemical interactions result in pores that vary in scale from submicron to centimeters to fractures, variation in fabric composition with fossils, minerals and cement, as well as variations in structural features (e.g., oriented inter- and intra layered - interlaced bedding and/or discontinuous rock units). In addition, this complexity is altered by natural and anthropogenic processes such as changes in stress, fluid content, reactive fluid flow, etc. Thus an accurate geophysical assessment of the flow behavior of carbonate reservoirs requires a fundamental understanding of the interplay of textural and structural features subjected to physical processes that affect and occur on various length and time scales. To address this complexity related to carbonates, a Hedberg conference on “Fundamental Controls on Flow in Carbonates” was held July 8 to 13, 2012, to bring together industry and academic scientists to stimulate innovative ideas that can accelerate research advances related to flow prediction and recovery in carbonate reservoirs. Participants included scientist and engineers from multiple disciplines (such as hydrology, structural geology, geochemistry, reservoir engineering, geophysics, geomechanics, numerical modeling, physical experiments, sedimentology, well-testing, statistics, mathematics, visualization, etc.) who encompass experience as well as the latest advances in these multi-faceted fields. One of the goals was to include early career scientists and engineers (post-doctoral fellows, assistant professors, etc.). With this grant 10 early career scientists and engineers were supported to attend the conference. This reports contains a brief overview of the conference and the list of support participants supported by this grant. Full details of the outcomes of the conference are given in the publication found in the Attachment section of this report.

Pyrak-Nolte, Laura J.

2013-04-28T23:59:59.000Z

338

REAL-TIME TRACER MONITORING OF RESERVOIR STIMULATION PROCEDURES  

SciTech Connect (OSTI)

Ongoing Phase 2 work comprises the development and field-testing of a real-time reservoir stimulation diagnostic system. Phase 3 work commenced in June 2001, and involved conducting research, development and field-testing of real-time enhanced dual-fluid stimulation processes. Experimental field-testing to date includes three well tests. Application of these real-time stimulation processes and diagnostic technologies has been technically successful with commercial production from the ''marginal'' reservoirs in the first two well tests. The third well test proved downhole-mixing is an efficient process for acid stimulation of a carbonate reservoir that produced oil and gas with 2200 psi bottomhole reservoir pressure, however, subsequent shut-in pressure testing indicated the reservoir was characterized by low-permeability. Realtimezone continues to seek patent protection in foreign markets to the benefit of both RTZ and NETL. Realtimezone and the NETL have licensed the United States patented to Halliburton Energy Services (HES). Ongoing Phase 2 and Phase 3 field-testing continues to confirm applications of both real-time technologies, from well testing conducted over the last 12-month work period and including well test scheduled for year-end of 2002. Technical data transfer to industry is ongoing via Internet tech-transfer, public presentations and industry publications. Final Phase 3 test work will be focused on further field-testing the innovational process of blending stimulation fluids downhole. This system provides a number of advantages in comparison to older industry fracturing techniques and allows the operator to control reservoir fracture propagation and concentrations of proppant placed in the reservoir, in real-time. Another observed advantage is that lower friction pressures result, which results in lower pump treating pressures and safer reservoir hydraulic fracturing jobs.

George Scott III

2002-08-01T23:59:59.000Z

339

CO{sub 2} Injectivity, Storage Capacity, Plume Size, and Reservoir and Seal Integrity of the Ordovician St. Peter Sandstone and the Cambrian Potosi Formation in the Illnois Basin  

SciTech Connect (OSTI)

The Cambro-Ordovician strata of the Illinois and Michigan Basins underlie most of the states of Illinois, Indiana, Kentucky, and Michigan. This interval also extends through much of the Midwest of the United States and, for some areas, may be the only available target for geological sequestration of CO{sub 2}. We evaluated the Cambro-Ordovician strata above the basal Mt. Simon Sandstone reservoir for sequestration potential. The two targets were the Cambrian carbonate intervals in the Knox and the Ordovician St. Peter Sandstone. The evaluation of these two formations was accomplished using wireline data, core data, pressure data, and seismic data from the USDOE-funded Illinois Basin â?? Decatur Project being conducted by the Midwest Geological Sequestration Consortium in Macon County, Illinois. Interpretations were completed using log analysis software, a reservoir flow simulator, and a finite element solver that determines rock stress and strain changes resulting from the pressure increase associated with CO{sub 2} injection. Results of this research suggest that both the St. Peter Sandstone and the Potosi Dolomite (a formation of the Knox) reservoirs may be capable of storing up to 2 million tonnes of CO{sub 2} per year for a 20-year period. Reservoir simulation results for the St. Peter indicate good injectivity and a relatively small CO{sub 2} plume. While a single St. Peter well is not likely to achieve the targeted injection rate of 2 million tonnes/year, results of this study indicate that development with three or four appropriately spaced wells may be sufficient. Reservoir simulation of the Potosi suggest that much of the CO{sub 2} flows into and through relatively thin, high permeability intervals, resulting in a large plume diameter compared with the St. Peter.

Hannes Leetaru; Alan Brown; Donald Lee; Ozgur Senel; Marcia Coueslan

2012-05-01T23:59:59.000Z

340

Using microstructure observations to quantify fracture properties and improve reservoir simulations. Final report, September 1998  

SciTech Connect (OSTI)

The research for this project provides new technology to understand and successfully characterize, predict, and simulate reservoir-scale fractures. Such fractures have worldwide importance because of their influence on successful extraction of resources. The scope of this project includes creation and testing of new methods to measure, interpret, and simulate reservoir fractures that overcome the challenge of inadequate sampling. The key to these methods is the use of microstructures as guides to the attributes of the large fractures that control reservoir behavior. One accomplishment of the project research is a demonstration that these microstructures can be reliably and inexpensively sampled. Specific goals of this project were to: create and test new methods of measuring attributes of reservoir-scale fractures, particularly as fluid conduits, and test the methods on samples from reservoirs; extrapolate structural attributes to the reservoir scale through rigorous mathematical techniques and help build accurate and useful 3-D models of the interwell region; and design new ways to incorporate geological and geophysical information into reservoir simulation and verify the accuracy by comparison with production data. New analytical methods developed in the project are leading to a more realistic characterization of fractured reservoir rocks. Testing diagnostic and predictive approaches was an integral part of the research, and several tests were successfully completed.

Laubach, S.E.; Marrett, R.; Rossen, W.; Olson, J.; Lake, L.; Ortega, O.; Gu, Y.; Reed, R.

1999-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "reservoir rock carbon" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


341

Characterization of dynamic change of Fan-delta reservoir properties in water-drive development  

SciTech Connect (OSTI)

Fan-delta reservoir in Huzhuangji oil field of east China, is a typical highly heterogeneous reservoir. The oil field has been developed by water-drive for 10 years, but the oil recovery is less than 12%, and water cut is over 90%, resulting from high heterogeneity and serious dynamic change of reservoir properties. This paper aims at the study of dynamic change of reservoir properties in water-drive development. Through quantitative imaging analysis and mercury injection analysis of cores from inspection wells, the dynamic change of reservoir pore structure in water-drive development was studied. The results show that the {open_quotes}large pore channels{close_quotes} develop in distributary channel sandstone and become larger in water-drive development, resulting in more serious pore heterogeneity. Through reservoir sensitivity experiments, the rock-fluid reaction in water-drive development is studied. The results show the permeability of some distal bar sandstone and deserted channel sandstone becomes lower due to swelling of I/S clay minerals in pore throats. OD the other hand, the permeability of distributary channel and mouth bar sandstone become larger because the authigenic Koalinites in pore throats are flushed away with the increase of flow rate of injection water. Well-logging analysis of flooded reservoirs are used to study the dynamic change of reservoir properties in various flow units. The distribution of remaining oil is closely related to the types and distribution of flow units.

Wu Shenghe; Xiong Qihua; Liu Yuhong [Univ. of Petroleum Changping, Beijing (China)

1997-08-01T23:59:59.000Z

342

MAPPING OF RESERVOIR PROPERTIES AND FACIES THROUGH INTEGRATION OF STATIC AND DYNAMIC DATA  

SciTech Connect (OSTI)

Knowledge of the distribution of permeability and porosity in a reservoir is necessary for the prediction of future oil production, estimation of the location of bypassed oil, and optimization of reservoir management. The volume of data that can potentially provide information on reservoir architecture and fluid distributions has increased enormously in the past decade. The techniques developed in this research will make it easier to use all the available data in an integrated fashion. While it is relatively easy to generate plausible reservoir models that honor static data such as core, log, and seismic data, it is far more difficult to generate plausible reservoir models that honor dynamic data such as transient pressures, saturations, and flow rates. As a result, the uncertainty in reservoir properties is higher than it could be and reservoir management can not be optimized. In this project, we have developed computationally efficient automatic history matching techniques for generating geologically plausible reservoir models which honor both static and dynamic data. Specifically, we have developed methods for adjusting porosity and permeability fields to match both production and time-lapse seismic data and have also developed a procedure to adjust the locations of boundaries between facies to match production data. In all cases, the history matched rock property fields are consistent with a prior model based on static data and geologic information. Our work also indicates that it is possible to adjust relative permeability curves when history matching production data.

Albert C. Reynolds; Dean S. Oliver; Yannong Dong; Ning Liu; Guohua Gao; Fengjun Zhang; Ruijian Li

2004-12-01T23:59:59.000Z

343

The use of tracers to analyze the effects of reinjection into fractured geothermal reservoirs  

SciTech Connect (OSTI)

This paper discusses the use of tracers as a reservoir engineering tool in fractured geothermal reservoirs. The principle concern in injecting cooler spent fluids into a fractured reservoir is that the fluids may move through high permeability channels and return to the production wells after contacting a relatively small volume of rock. As a consequence of this rapid transport, the fluids will be only partially reheated and after a short period time will effectively mine the heat from the limited volume of rock. The production wells will then experience a rapid and premature reduction in thermal output. Tracers can be used to infer the existence of high mobility conduits between injection and production wells and to monitor chemical changes of an injected fluid. Since tracer arrival precedes thermal breakthrough, tracer tests are a very useful forecasting tool.

Horne, R.N.; Johns, R.A.; Adams, M.C.; Moore, J.N.; Stiger, S.G.

1987-01-01T23:59:59.000Z

344

Exploitation and Optimization of Reservoir Performance in Hunton Formation, Oklahoma  

SciTech Connect (OSTI)

West Carney field--one of the newest fields discovered in Oklahoma--exhibits many unique production characteristics. These characteristics include: (1) decreasing water-oil ratio; (2) decreasing gas-oil ratio followed by an increase; (3) poor prediction capability of the reserves based on the log data; and (4) low geological connectivity but high hydrodynamic connectivity. The purpose of this investigation is to understand the principal mechanisms affecting the production, and propose methods by which we can extend the phenomenon to other fields with similar characteristics. In our experimental investigation section, we continue to describe the use of surfactant to alter the wettability of the rock. By altering the wettability, we should be able to change the water-gas ratio in the reservoir and, hence, improve productivity from the well. In our Engineering and Geological Analysis section, we present our rock typing analysis work which combines the geological data with engineering data to develop a unique rock characteristics description. By using porosity as a variable, we can generate alternate rock type descriptions at logged wells. This procedure also allows us to quantify uncertainties in rock type description.

Mohan Kelkar

2005-10-01T23:59:59.000Z

345

Low Pore Connectivity in Natural Rock  

SciTech Connect (OSTI)

As repositories for CO? and radioactive waste, as oil and gas reservoirs, and as contaminated sites needing remediation, rock formations play a central role in energy and environmental management. The connectivity of the rock's porespace strongly affects fluid flow and solute transport. This work examines pore connectivity and its implications for fluid flow and chemical transport. Three experimental approaches (imbibition, tracer concentration profiles, and imaging) were used in combination with network modeling. In the imbibition results, three types of imbibition slope [log (cumulative imbibition) vs. log (imbibition time)] were found: the classical 0.5, plus 0.26, and 0.26 transitioning to 0.5. The imbibition slope of 0.26 seen in Indiana sandstone, metagraywacke, and Barnett shale indicates low pore connectivity, in contrast to the slope of 0.5 seen in the well-connected Berea sandstone. In the tracer profile work, rocks exhibited different distances to the plateau porosity, consistent with the pore connectivity from the imbibition tests. Injection of a molten metal into connected pore spaces, followed by 2-D imaging of the solidified alloy in polished thin sections, allowed direct assessment of pore structure and lateral connection in the rock samples. Pore-scale network modeling gave results consistent with measurements, confirming pore connectivity as the underlying cause of both anomalous behaviors: imbibition slope not having the classical value of 0.5, and accessible porosity being a function of distance from the edge. A poorly connected porespace will exhibit anomalous behavior in fluid flow and chemical transport, such as a lower imbibition slope (in air–water system) and diffusion rate than expected from classical behavior.

Hu, Qinhong; Ewing, Robert P.; Dultz, Stefan

2012-05-15T23:59:59.000Z

346

The thermal conductivity of rock under hydrothermal conditions: measurements and applications  

SciTech Connect (OSTI)

The thermal conductivities of most major rock-forming minerals vary with both temperature and confining pressure, leading to substantial changes in the thermal properties of some rocks at the high temperatures characteristic of geothermal systems. In areas with large geothermal gradients, the successful use of near-surface heat flow measurements to predict temperatures at depth depends upon accurate corrections for varying thermal conductivity. Previous measurements of the thermal conductivity of dry rock samples as a function of temperature were inadequate for porous rocks and susceptible to thermal cracking effects in nonporous rocks. We have developed an instrument for measuring the thermal conductivity of water-saturated rocks at temperatures from 20 to 350 °C and confining pressures up to 100 MPa. A transient line-source of heat is applied through a needle probe centered within the rock sample, which in turn is enclosed within a heated pressure vessel with independent controls on pore and confining pressure. Application of this technique to samples of Franciscan graywacke from The Geysers reveals a significant change in thermal conductivity with temperature. At reservoir-equivalent temperatures of 250 °C, the conductivity of the graywacke decreases by approximately 25% relative to the room temperature value. Where heat flow is constant with depth within the caprock overlying the reservoir, this reduction in conductivity with temperature leads to a corresponding increase in the geothermal gradient. Consequently, reservoir temperature are encountered at depths significantly shallower than those predicted by assuming a constant temperature gradient with depth. We have derived general equations for estimating the thermal conductivity of most metamorphic and igneous rocks and some sedimentary rocks at elevated temperature from knowledge of the room temperature thermal conductivity. Application of these equations to geothermal exploration should improve estimates of subsurface temperatures derived from heat flow measurements.

Williams, Colin F.; Sass, John H.

1996-01-24T23:59:59.000Z

347

Environment of deposition and reservoir properties of Teapot sandstones (Upper Cretaceous), Well Draw field, Converse County, Wyoming  

E-Print Network [OSTI]

= monocrystalline quartz, F = feldspar, Rx = rock fragments including chert, micas, and polycrystalline quartz, Mx = maxtrix, and 0th = other minerals. c Sil = silica as grain overgrowths including minor chert, Cal = calcite including minor dolomite and siderite... fossils, and reservoir morphology. Three distinct sandstone facies produce oil and gas at Well Draw field. The main producing zone consists of thicker, channel turbidites. The lower two zones are thinly interbedded with shale and have limited reservoir...

Sullivan, John Joseph

1982-01-01T23:59:59.000Z

348

Advanced Reservoir Imaging Using Frequency-Dependent Seismic Attributes  

SciTech Connect (OSTI)

Our report concerning advanced imaging and interpretation technology includes the development of theory, the implementation of laboratory experiments and the verification of results using field data. We investigated a reflectivity model for porous fluid-saturated reservoirs and demonstrated that the frequency-dependent component of the reflection coefficient is asymptotically proportional to the reservoir fluid mobility. We also analyzed seismic data using different azimuths and offsets over physical models of fractures filled with air and water. By comparing our physical model synthetics to numerical data we have identified several diagnostic indicators for quantifying the fractures. Finally, we developed reflectivity transforms for predicting pore fluid and lithology using rock-property statistics from 500 reservoirs in both the shelf and deep-water Gulf of Mexico. With these transforms and seismic AVO gathers across the prospect and its down-dip water-equivalent reservoir, fluid saturation can be estimated without a calibration well that ties the seismic. Our research provides the important additional mechanisms to recognize, delineate, and validate new hydrocarbon reserves and assist in the development of producing fields.

Fred Hilterman; Tad Patzek; Gennady Goloshubin; Dmitriy Silin; Charlotte Sullivan; Valeri Korneev

2007-12-31T23:59:59.000Z

349

STATISTICAL APPLICATIONS TO QUANTITATIVE SEISMIC RESERVOIR CHARACTERIZATION AND MONITORING AT WEST PEARL QUEEN  

E-Print Network [OSTI]

in the reservoir characterization and monitoring of CO2 sequestration at West Pearl Queen Field, ear Hobbs, New is composed of: 42% siliciclastics (quartz sandstone and siltstone), 38% carbonates (dolomite and limestone bivariate statistical classifications, is detected from changes in carbon dioxide saturation on both the Vp

350

ANALYSIS OF PRODUCTION DECLINE IN GEOTHERMAL RESERVOIRS  

E-Print Network [OSTI]

Petroleum Reservoirs. Geothermal Reservoirs IV. DATA1970, Superheating of Geothermal Steam, Proc. of the U.N.the Development & Utilization of Geothermal Resources, Pisa.

Zais, E.J.; Bodvarsson, G.

2008-01-01T23:59:59.000Z

351

Analysis of Geothermal Reservoir Stimulation using Geomechanics...  

Broader source: Energy.gov (indexed) [DOE]

Analysis of Geothermal Reservoir Stimulation using Geomechanics-Based Stochastic Analysis of Injection-Induced Seismicity Analysis of Geothermal Reservoir Stimulation using...

352

Use of adaptive matching filters to improve reservoir definition  

SciTech Connect (OSTI)

Improvements in seismic resolution through better seismic acquisition and processing coupled with geometric improvements provided by 3-D surveys should allow better depiction of reservoir settings. To more fully benefit from these data improvements, is is desirable to translate the seismic acoustic attributes into a form that has more lithologic meaning. Tuning and thin bed effects etc. are automatically taken into account, and the acoustic data rendered into rock terms by matched filtering. The advantage of the present method is that the matching filter is allowed to adapt over time, but only slowly. The result is adaptive filters that give better prediction of lithologic characteristics in areas adjacent to the control data. Slowly adaptive matching filters can provide better prediction of reservoir characteristics between control points (wells). Such techniques are particularly suitable in multiwell settings where it is possible to frequently calibrate the filters.

DuBose, J.B. Jr; Blackwelder, B.

1995-12-31T23:59:59.000Z

353

Depositional sequence analysis and sedimentologic modeling for improved prediction of Pennsylvanian reservoirs (Annex 1)  

SciTech Connect (OSTI)

Interdisciplinary studies of the Upper Pennsylvanian Lansing and Kansas City groups have been undertaken in order to improve the geologic characterization of petroleum reservoirs and to develop a quantitative understanding of the processes responsible for formation of associated depositional sequences. To this end, concepts and methods of sequence stratigraphy are being used to define and interpret the three-dimensional depositional framework of the Kansas City Group. The investigation includes characterization of reservoir rocks in oil fields in western Kansas, description of analog equivalents in near-surface and surface sites in southeastern Kansas, and construction of regional structural and stratigraphic framework to link the site specific studies. Geologic inverse and simulation models are being developed to integrate quantitative estimates of controls on sedimentation to produce reconstructions of reservoir-bearing strata in an attempt to enhance our ability to predict reservoir characteristics.

Watney, W.L.

1992-01-01T23:59:59.000Z

354

Application of fractal theory in refined reservoir description for EOR pilot area  

SciTech Connect (OSTI)

A reliable reservoir description is essential to investigate scenarios for successful EOR pilot test. Reservoir characterization includes formation composition, permeability, porosity, reservoir fluids and other petrophysical parameters. In this study, various new tools have been applied to characterize Kilamayi conglomerate formation. This paper examines the merits of various statistical methods for recognizing rock property correlation in vertical columns and gives out methods to determine fractal dimension including R/S analysis and power spectral analysis. The paper also demonstrates that there is obvious fractal characteristics in conglomerate reservoirs of Kilamayi oil fields. Well log data in EOR pilot area are used to get distribution profile of parameters including permeability, porosity, water saturation and shale content.

Yue Li; Yonggang Duan; Yun Li; Yuan Lu

1997-08-01T23:59:59.000Z

355

Geological control on the reservoir characteristics of Olkaria West Geothermal Field, Kenya  

SciTech Connect (OSTI)

The reservoir of the West Olkaria Geothermal Field is hosted within tuffs and the reservoir fluid is characterized by higher concentrations of reservoir CO{sub 2} (10,000-100,000 mg/kg) but lower chloride concentrations of about 200 mg/kg than the East and North East Fields. The West Field is in the outflow and main recharge area of the Olkaria geothermal system. Permeability is generally low in the West Field and its distribution is strongly controlled by the structures. Fault zones show higher permeability with wells drilled within the structures havin larger total mass outputs. However, N-S and NW-SE faults are mainly channels for cold water downflow into the reservoir. Well feeder zones occur mostly at lava-tuff contacts; within fractured lava flows and at the contacts of intrusives and host rocks.

Omenda, Peter A.

1994-01-20T23:59:59.000Z

356

Characterization of oil and gas reservoir heterogeneity. Final report  

SciTech Connect (OSTI)

Research described In this report addresses the internal architecture of two specific reservoir types: restricted-platform carbonates and fluvial-deltaic sandstones. Together, these two reservoir types contain more than two-thirds of the unrecovered mobile oil remaining ill Texas. The approach followed in this study was to develop a strong understanding of the styles of heterogeneity of these reservoir types based on a detailed outcrop description and a translation of these findings into optimized recovery strategies in select subsurface analogs. Research targeted Grayburg Formation restricted-platform carbonate outcrops along the Algerita Escarpment and In Stone Canyon In southeastern New Mexico and Ferron deltaic sandstones in central Utah as analogs for the North Foster (Grayburg) and Lake Creek (Wilcox) units, respectively. In both settings, sequence-stratigraphic style profoundly influenced between-well architectural fabric and permeability structure. It is concluded that reservoirs of different depositional origins can therefore be categorized Into a ``heterogeneity matrix`` based on varying intensity of vertical and lateral heterogeneity. The utility of the matrix is that it allows prediction of the nature and location of remaining mobile oil. Highly stratified reservoirs such as the Grayburg, for example, will contain a large proportion of vertically bypassed oil; thus, an appropriate recovery strategy will be waterflood optimization and profile modification. Laterally heterogeneous reservoirs such as deltaic distributary systems would benefit from targeted infill drilling (possibly with horizontal wells) and improved areal sweep efficiency. Potential for advanced recovery of remaining mobile oil through heterogeneity-based advanced secondary recovery strategies In Texas is projected to be an Incremental 16 Bbbl. In the Lower 48 States this target may be as much as 45 Bbbl at low to moderate oil prices over the near- to mid-term.

Tyler, N.; Barton, M.D.; Bebout, D.G.; Fisher, R.S.; Grigsby, J.D.; Guevara, E.; Holtz, M.; Kerans, C.; Nance, H.S.; Levey, R.A.

1992-10-01T23:59:59.000Z

357

Development of hot dry rock geothermal resources; technical and economic issues  

SciTech Connect (OSTI)

Technical and economic issues related to the commercial feasibility of hot dry rock geothermal energy for producing electricity and heat are discussed. Topics covered include resource characteristics, reservoir thermal capacity and lifetime, drilling and surface plant costs, financial risk and anticipated rate of return. The current status of research and deveopment efforts in the US are also summarized.

Tester, J.W.

1980-01-01T23:59:59.000Z

358

Reservoir characterization using oil-production-induced microseismicity, Clinton County, Kentucky  

E-Print Network [OSTI]

, Kentucky James T. Rutledge, Nambe Geophysical, Inc., jrutledge@lanl.gov W. Scott Phillips, Nambe, Clinton County, Kentucky. Oil is produced from low-porosity, fractured carbonate rocks at

359

TEXAS A&M UNIVERSITY Reservoir Geophysics Program  

E-Print Network [OSTI]

includes applications to clastic reservoirs, heavy oil reservoirs, gas/oil shale, gas hydrates. Basic

360

Analysis of real-time reservoir monitoring : reservoirs, strategies, & modeling.  

SciTech Connect (OSTI)

The project objective was to detail better ways to assess and exploit intelligent oil and gas field information through improved modeling, sensor technology, and process control to increase ultimate recovery of domestic hydrocarbons. To meet this objective we investigated the use of permanent downhole sensors systems (Smart Wells) whose data is fed real-time into computational reservoir models that are integrated with optimized production control systems. The project utilized a three-pronged approach (1) a value of information analysis to address the economic advantages, (2) reservoir simulation modeling and control optimization to prove the capability, and (3) evaluation of new generation sensor packaging to survive the borehole environment for long periods of time. The Value of Information (VOI) decision tree method was developed and used to assess the economic advantage of using the proposed technology; the VOI demonstrated the increased subsurface resolution through additional sensor data. Our findings show that the VOI studies are a practical means of ascertaining the value associated with a technology, in this case application of sensors to production. The procedure acknowledges the uncertainty in predictions but nevertheless assigns monetary value to the predictions. The best aspect of the procedure is that it builds consensus within interdisciplinary teams The reservoir simulation and modeling aspect of the project was developed to show the capability of exploiting sensor information both for reservoir characterization and to optimize control of the production system. Our findings indicate history matching is improved as more information is added to the objective function, clearly indicating that sensor information can help in reducing the uncertainty associated with reservoir characterization. Additional findings and approaches used are described in detail within the report. The next generation sensors aspect of the project evaluated sensors and packaging survivability issues. Our findings indicate that packaging represents the most significant technical challenge associated with application of sensors in the downhole environment for long periods (5+ years) of time. These issues are described in detail within the report. The impact of successful reservoir monitoring programs and coincident improved reservoir management is measured by the production of additional oil and gas volumes from existing reservoirs, revitalization of nearly depleted reservoirs, possible re-establishment of already abandoned reservoirs, and improved economics for all cases. Smart Well monitoring provides the means to understand how a reservoir process is developing and to provide active reservoir management. At the same time it also provides data for developing high-fidelity simulation models. This work has been a joint effort with Sandia National Laboratories and UT-Austin's Bureau of Economic Geology, Department of Petroleum and Geosystems Engineering, and the Institute of Computational and Engineering Mathematics.

Mani, Seethambal S.; van Bloemen Waanders, Bart Gustaaf; Cooper, Scott Patrick; Jakaboski, Blake Elaine; Normann, Randy Allen; Jennings, Jim (University of Texas at Austin, Austin, TX); Gilbert, Bob (University of Texas at Austin, Austin, TX); Lake, Larry W. (University of Texas at Austin, Austin, TX); Weiss, Chester Joseph; Lorenz, John Clay; Elbring, Gregory Jay; Wheeler, Mary Fanett (University of Texas at Austin, Austin, TX); Thomas, Sunil G. (University of Texas at Austin, Austin, TX); Rightley, Michael J.; Rodriguez, Adolfo (University of Texas at Austin, Austin, TX); Klie, Hector (University of Texas at Austin, Austin, TX); Banchs, Rafael (University of Texas at Austin, Austin, TX); Nunez, Emilio J. (University of Texas at Austin, Austin, TX); Jablonowski, Chris (University of Texas at Austin, Austin, TX)

2006-11-01T23:59:59.000Z

Note: This page contains sample records for the topic "reservoir rock carbon" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


361

Sequence stratigraphy of the upper San Andres and Grayburg formations, Waddell Field, Crane County, Texas: implications for hydrocarbon reservoir distribution  

E-Print Network [OSTI]

The upper San Andres and Grayburg formations (Guadalupian) were deposited on carbonate platforms around the Permian Basin region and are extensive hydrocarbon reservoirs in the region. The Waddell Field (East Waddell Ranch) on the eastern margin...

Pinsonnault, Scott Michael

1996-01-01T23:59:59.000Z

362

PROCEEDINGS, Thirty-Fourth Workshop on Geothermal Reservoir Engineering Stanford University, Stanford, California, February 9-11, 2009  

E-Print Network [OSTI]

, there has been some interest in the use of carbon dioxide as a heat extraction fluid. CO2 offers a number and geological sequestration of CO2 within the reservoir · Possibility of direct use of produced CO2

Stanford University

363

CHARACTERIZATION OF CENTRAL APPALACHIAN BASIN CBM DEVELOPMENT: POTENTIAL FOR CARBON SEQUESTRATION  

E-Print Network [OSTI]

of the carbon sequestration potential of the Pennsylvanian-age coalbeds in the Central Appalachian Basin favorable reservoirs for carbon sequestration due to their thickness, depth, rank, and permeability high gas content should provide the optimum reservoirs for carbon sequestration since these coals

364

Research on oil recovery mechanisms in heavy oil reservoirs  

SciTech Connect (OSTI)

The research described here was directed toward improved understanding of thermal and heavy-oil production mechanisms and is categorized into: (1) flow and rock properties, (2) in-situ combustion, (3) additives to improve mobility control, (4) reservoir definition, and (5) support services. The scope of activities extended over a three-year period. Significant work was accomplished in the area of flow properties of steam, water, and oil in consolidated and unconsolidated porous media, transport in fractured porous media, foam generation and flow in homogeneous and heterogeneous porous media, the effects of displacement pattern geometry and mobility ratio on oil recovery, and analytical representation of water influx.

Kovscek, Anthony R.; Brigham, William E., Castanier, Louis M.

2000-03-16T23:59:59.000Z

365

Advanced Reservoir Characterization and Evaluation of CO2 Gravity Drainage in the Naturally Fractured Spraberry Trend Area, Class III  

SciTech Connect (OSTI)

The goal of this project was to assess the economic feasibility of CO2 flooding the naturally fractured Spraberry Trend Area in west Texas. This objective was accomplished through research in four areas: (1) extensive characterization of the reservoirs, (2) experimental studies of crude oil/brine/rock (COBR) interactions in the reservoirs, (3) reservoir performance analysis, and (4) experimental investigations on CO2 gravity drainage in Spraberry whole cores. This provides results of the final year of the six-year project for each of the four areas.

Knight, Bill; Schechter, David S.

2002-07-26T23:59:59.000Z

366

Advanced Reservoir Characterization and Evaluation of CO{sub 2} Gravity Drainage in the Naturally Fractured Spraberry Trend Area  

SciTech Connect (OSTI)

The overall goal of this project is to assess the economic feasibility of CO{sub 2} flooding the naturally fractured Spraberry Trend Area in West Texas. This objective is being accomplished by conducting research in four areas: (1) extensive characterization of the reservoirs, (2) experimental studies of crude oil/brine/rock (COBR) interactions in the reservoirs, (3) reservoir performance analysis, and, (4) experimental investigations on CO2 gravity drainage in Spraberry whole cores. This report provides results of the third year of the five-year project for each of the four areas including a status report of field activities leading up to injection of CO2.

Schechter, D.S.

1999-02-03T23:59:59.000Z

367

Construction of a diagenetic history and identification with quality ranking of reservoir flow units: Grayson field, Columbia County, Arkansas  

E-Print Network [OSTI]

). The middle and lower mudstones are organic-rich and dark colored. They probably serve as the source rock for many of the Smackover fields in and around the study area though they could also be reservoirs in some cases. These mudstones formed in quiet..., basinal marine, reducing waters during a marine transgression. The upper Smackover grainstones represent a regressive portion of the sequence. This upper section is identifiable in the rock record as a series of shoaling upward mudstone to grainstone...

Poole, Kathleen Renee

2007-04-25T23:59:59.000Z

368

Statistical Correlation and Modelling of Carbonate Heterogeneity   

E-Print Network [OSTI]

In many carbonate reservoirs, much of the porosity is in the form of micropores (with diameter 1-10 microns). This porosity lies far below the resolution of any conventional wireline logging tools and can only be observed ...

Price, David P

2009-01-01T23:59:59.000Z

369

Fractured reservoir discrete feature network technologies. Annual report, March 7, 1996--February 28, 1997  

SciTech Connect (OSTI)

This report describes progress on the project, {open_quotes}Fractured Reservoir Discrete Feature Network Technologies{close_quotes} during the period March 7, 1996 to February 28, 1997. The report presents summaries of technology development for the following research areas: (1) development of hierarchical fracture models, (2) fractured reservoir compartmentalization and tributary volume, (3) fractured reservoir data analysis, and (4) integration of fractured reservoir data and production technologies. In addition, the report provides information on project status, publications submitted, data collection activities, and technology transfer through the world wide web (WWW). Research on hierarchical fracture models included geological, mathematical, and computer code development. The project built a foundation of quantitative, geological and geometrical information about the regional geology of the Permian Basin, including detailed information on the lithology, stratigraphy, and fracturing of Permian rocks in the project study area (Tracts 17 and 49 in the Yates field). Based on the accumulated knowledge of regional and local geology, project team members started the interpretation of fracture genesis mechanisms and the conceptual modeling of the fracture system in the study area. Research on fractured reservoir compartmentalization included basic research, technology development, and application of compartmentalized reservoir analyses for the project study site. Procedures were developed to analyze compartmentalization, tributary drainage volume, and reservoir matrix block size. These algorithms were implemented as a Windows 95 compartmentalization code, FraCluster.

Dershowitz, W.S.; La Pointe, P.R.; Einstein, H.H.; Ivanova, V.

1998-01-01T23:59:59.000Z

370

Software Engineer RockAuto www.RockAuto.com  

E-Print Network [OSTI]

Software Engineer ­ RockAuto www.RockAuto.com Position Description Software is the foundation · Familiarity with open-source development technologies like PHP, Perl, JavaScript and C (Linux system Lane, Madison, WI 53719) Why RockAuto? Strategic and tactical impact. We're an e-commerce company

Liblit, Ben

371

The Landscape of Klamath Basin Rock Art  

E-Print Network [OSTI]

the Lines: Ethnographic Sources and Rock Art Interpretationwhen applying these sources toward rock art interpretation.information source for developing rock art interpretations.

David, Robert James

2012-01-01T23:59:59.000Z

372

Eighteenth workshop on geothermal reservoir engineering: Proceedings  

SciTech Connect (OSTI)

PREFACE The Eighteenth Workshop on Geothermal Reservoir Engineering was held at Stanford University on January 26-28, 1993. There were one hundred and seventeen registered participants which was greater than the attendance last year. Participants were from eight foreign countries: Italy, Japan, United Kingdom, Mexico, New Zealand, the Philippines, Guatemala, and Iceland. Performance of many geothermal fields outside the United States was described in several of the papers. Dean Gary Ernst opened the meeting and welcomed the visitors to the campus. The key note speaker was J.E. ''Ted'' Mock who gave a brief overview of the Department of Energy's current plan. The Stanford Geothermal Program Reservoir Engineering Award for Excellence in Development of Geothermal Energy was awarded to Dr. Mock who also spoke at the banquet. Thirty-nine papers were presented at the Workshop with two papers submitted for publication only. Technical papers were organized in twelve sessions concerning: field operations, The Geysers, geoscience, hot-dry-rock, injection, modeling, slim hole wells, geochemistry, well test and wellbore. Session chairmen were major contributors to the program and we thank: John Counsil, Kathleen Enedy, Harry Olson, Eduardo Iglesias, Marcelo Lippmann, Paul Atkinson, Jim Lovekin, Marshall Reed, Antonio Correa, and David Faulder. The Workshop was organized by the Stanford Geothermal Program faculty, staff, and graduate students. We wish to thank Pat Ota, Ted Sumida, and Terri A. Ramey who also produces the Proceedings Volumes for publication. We owe a great deal of thanks to our students who operate audiovisual equipment and to John Hornbrook who coordinated the meeting arrangements for the Workshop. Henry J. Ramey, Jr. Roland N. Horne Frank G. Miller Paul Kruger William E. Brigham Jean W. Cook

Ramey, H.J. Jr.; Horne, R.J.; Kruger, P.; Miller, F.G.; Brigham, W.E.; Cook, J.W. (Stanford Geothermal Program)

1993-01-28T23:59:59.000Z

373

Microwave assisted hard rock cutting  

DOE Patents [OSTI]

An apparatus for the sequential fracturing and cutting of subsurface volume of hard rock (102) in the strata (101) of a mining environment (100) by subjecting the volume of rock to a beam (25) of microwave energy to fracture the subsurface volume of rock by differential expansion; and , then bringing the cutting edge (52) of a piece of conventional mining machinery (50) into contact with the fractured rock (102).

Lindroth, David P. (Apple Valley, MN); Morrell, Roger J. (Bloomington, MN); Blair, James R. (Inver Grove Heights, MN)

1991-01-01T23:59:59.000Z

374

Flow dynamics and solute transport in unsaturated rock fractures  

SciTech Connect (OSTI)

Rock fractures play an important role in flow and contaminant transport in fractured aquifers, production of oil from petroleum reservoirs, and steam generation from geothermal reservoirs. In this dissertation, phenomenological aspects of flow in unsaturated fractures were studied in visualization experiments conducted on a transparent replica of a natural, rough-walled rock fracture for inlet conditions of constant pressure and flow rate over a range of angles of inclination. The experiments demonstrated that infiltrating liquid proceeds through unsaturated rock fractures along non-uniform, localized preferential flow paths. Even in the presence of constant boundary conditions, intermittent flow was a persistent flow feature observed, where portions of the flow channel underwent cycles of snapping and reforming. Two modes of intermittent flow were observed, the pulsating blob mode and the rivulet snapping mode. A conceptual model for the rivulet snapping mode was proposed and examined using idealized, variable-aperture fractures. The frequency of intermittent flow events was measured in several experiments and related to the capillary and Bond numbers to characterize this flow behavior.

Su, G. W.

1999-10-01T23:59:59.000Z

375

E-Print Network 3.0 - atmospheric carbon monoxide Sample Search...  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

reservoirs (storages, especially the atmosphere, terrestrial biosphere, oceans... emissions trading and the control of greenhouse gas emissions. Carbon monoxide a chemical...

376

Chickamauga reservoir embayment study - 1990  

SciTech Connect (OSTI)

The objectives of this report are three-fold: (1) assess physical, chemical, and biological conditions in the major embayments of Chickamauga Reservoir; (2) compare water quality and biological conditions of embayments with main river locations; and (3) identify any water quality concerns in the study embayments that may warrant further investigation and/or management actions. Embayments are important areas of reservoirs to be considered when assessments are made to support water quality management plans. In general, embayments, because of their smaller size (water surface areas usually less than 1000 acres), shallower morphometry (average depth usually less than 10 feet), and longer detention times (frequently a month or more), exhibit more extreme responses to pollutant loadings and changes in land use than the main river region of the reservoir. Consequently, embayments are often at greater risk of water quality impairments (e.g. nutrient enrichment, filling and siltation, excessive growths of aquatic plants, algal blooms, low dissolved oxygen concentrations, bacteriological contamination, etc.). Much of the secondary beneficial use of reservoirs occurs in embayments (viz. marinas, recreation areas, parks and beaches, residential development, etc.). Typically embayments comprise less than 20 percent of the surface area of a reservoir, but they often receive 50 percent or more of the water-oriented recreational use of the reservoir. This intensive recreational use creates a potential for adverse use impacts if poor water quality and aquatic conditions exist in an embayment.

Meinert, D.L.; Butkus, S.R.; McDonough, T.A.

1992-12-01T23:59:59.000Z

377

Can Rock-Eval pyrolysis assess the biogeochemical composition of organic matter during peatification?  

E-Print Network [OSTI]

as a screening tool to investigate soil organic matter (SOM) chemistry and vulnerability. In order to test the validity of Rock-Eval as an indicator of SOM chemistry and of OM transformations, we compared classical Rock-Eval-derived parameters (Total Organic Carbon - TOC, Hydrogen Index - HI and Oxygen Index - OI

Boyer, Edmond

378

Rock Physics Characterization of Organic-Rich Shale Formations to Predict Organic Properties  

E-Print Network [OSTI]

rely on to assess the economic potential of these formations are: total organic carbon (TOC), thermal maturity, hydrocarbon saturation, porosity, mineralogy and brittleness. In this thesis, I investigate rock physics models and methods for the possible...

Bush, Brandon

2013-07-29T23:59:59.000Z

379

Effect of permeability on cooling of magmatic intrusion in a goethermal reservoir  

SciTech Connect (OSTI)

Transient cooling of magmatic intrusion in a geothermal reservoir due to conduction and convection is studied. The effects of overlying cap rock and different horizontal and vertical permeability of the reservoir are considered. Results are compared to the data from Salton Sea Geothermal Field. It is also observed that multiple layers of convection cells exist when horizontal permeability is much larger than the vertical permeability. The sharp dropoff of surface heat flow observed at Salton Sea Geothermal Field is confirmed by numerical results. Based on these numerical results, it is possible to speculate that the age of the intrusive body is about 8000 to 12,000 years.

Lau, K.H.

1980-09-01T23:59:59.000Z

380

Integration of advanced geoscience and engineering techniques to quantify interwell heterogeneity in reservoir models. Final report, September 29, 1993--September 30, 1996  

SciTech Connect (OSTI)

The goal of this three-year project was to provide a quantitative definition of reservoir heterogeneity. This objective was accomplished through the integration of geologic, geophysical, and engineering databases into a multi-disciplinary understanding of reservoir architecture and associated fluid-rock and fluid-fluid interactions. This interdisciplinary effort integrated geological and geophysical data with engineering and petrophysical results through reservoir simulation to quantify reservoir architecture and the dynamics of fluid-rock and fluid-fluid interactions. An improved reservoir description allows greater accuracy and confidence during simulation and modeling as steps toward gaining greater recovery efficiency from existing reservoirs. A field laboratory, the Sulimar Queen Unit, was available for the field research. Several members of the PRRC staff participated in the development of improved reservoir description by integration of the field and laboratory data as well as in the development of quantitative reservoir models to aid performance predictions. Subcontractors from Stanford University and the University of Texas at Austin (UT) collaborated in the research and participated in the design and interpretation of field tests. The three-year project was initiated in September 1993 and led to the development and application of various reservoir description methodologies. A new approach for visualizing production data graphically was developed and implemented on the Internet. Using production data and old gamma rays logs, a black oil reservoir model that honors both primary and secondary performance was developed. The old gamma ray logs were used after applying a resealing technique, which was crucial for the success of the project. In addition to the gamma ray logs, the development of the reservoir model benefitted from an inverse Drill Stem Test (DST) technique which provided initial estimates of the reservoir permeability at different wells.

Weiss, W.W.; Buckley, J.S.; Ouenes, A.

1997-05-01T23:59:59.000Z

Note: This page contains sample records for the topic "reservoir rock carbon" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


381

PROCEEDINGS, Thirty-Sixth Workshop on Geothermal Reservoir Engineering Stanford University, Stanford, California, January 31 -February 2, 2011  

E-Print Network [OSTI]

extraction from deep, hot rocks for energy production is based on water circulation through a man made TESTS IN GEOTHERMAL RESERVOIRS M.R. Safari and A. Ghassemi Department of Petroleum Engineering at Texas A&M University College Station, Texas, U.S.A e-mail: ahmad.ghassemi@pe.tamu.edu ABSTRACT Heat

Stanford University

382

PROCEEDINGS, Thirty-Sixth Workshop on Geothermal Reservoir Engineering Stanford University, Stanford, California, January 31 -February 2, 2011  

E-Print Network [OSTI]

is not an active volcanic region or plate boundary .Geothermal source might be from different source. The source of hot dry rock and geothermal reservoir and flow regimes have not be extensively explored. The Vijayan to geology of the study area with special emphasize on the dolerite dike which may have been the source

Stanford University

383

PROCEEDINGS, Thirty-Fifth Workshop on Geothermal Reservoir Engineering Stanford University, Stanford, California, February 1-3, 2010  

E-Print Network [OSTI]

, Stanford, California, February 1-3, 2010 SGP-TR-188 HYDRAULIC FRACTURING OF NATURALLY FRACTURED RESERVOIRS hydraulic fractures formed in naturally fractured crystalline rock masses. The propped fractures were formed on injection of thin or low viscosity fluids (e.g. water) at pressures that are below the fracture opening

Stanford University

384

PROCEEDINGS, Thirty-Sixth Workshop on Geothermal Reservoir Engineering Stanford University, Stanford, California, January 31 -February 2, 2011  

E-Print Network [OSTI]

treatments have been limited, however, to only fractures that are or will open by pumping water from by pumping water from the surface to create a limited number of fractures in the open hole reservoir rock be to temporarily hydraulically isolate the stimulated fractures in the well and then create and/or stimulate

Stanford University

385

PROCEEDINGS, Thirty-Sixth Workshop on Geothermal Reservoir Engineering Stanford University, Stanford, California, January 31 -February 2, 2011  

E-Print Network [OSTI]

; HEAd: heat exchange area density (area per volume of fluid and/or rock, to be specified); BTC: tracer. In fact, everything that matters about HEA(d) in geothermal reservoirs has already been identified is equivalent to HEAd in the first of 4 meanings discussed in the

Stanford University

386

PROCEEDINGS, Thirty-Eighth Workshop on Geothermal Reservoir Engineering Stanford University, Stanford, California, February 11-13, 2013  

E-Print Network [OSTI]

-elastic deformation with damage evolution, and groundwater flow are solved using the Explicit Finite Difference Lagrangian Method for solid deformation and the Finite Element Method for fluid mass conservation. Rock, Stanford, California, February 11-13, 2013 SGP-TR-198 MODELING RESERVOIR STIMULATION INDUCED BY WELLBORE

Lyakhovsky, Vladimir

387

EXPLOITATION AND OPTIMIZATION OF RESERVOIR PERFORMANCE IN HUNTON FORMATION, OKLAHOMA  

SciTech Connect (OSTI)

This report presents the work done so far on Hunton Formation in West Carney Field in Lincoln County, Oklahoma. West Carney Field produces oil and gas from the Hunton Formation. The field was developed starting in 1995. Some of the unique characteristics of the field include decreasing water oil ratio over time, decreasing gas-oil ratio at the beginning of production, inability to calculate oil reserves in the field based on log data, and sustained oil rates over long periods of time. To understand the unique characteristics of the field, an integrated evaluation was undertaken. Production data from the field were meticulously collected, and over forty wells were cored and logged to better understand the petrophysical and engineering characteristics. Based on the work done in this budget period so far, some of the preliminary conclusions can be listed as follows: (1) Based on PVT analysis, the field most likely contains volatile oil with bubble point close to initial reservoir pressure of 1,900 psia. (2) The initial oil in place, which is contact with existing wells, can be determined by newly developed material balance technique. The oil in place, which is in communication, is significantly less than determined by volumetric analysis, indicating heterogeneous nature of the reservoir. The oil in place, determined by material balance, is greater than determined by decline curve analysis. This difference may lead to additional locations for in fill wells. (3) The core and log evaluation indicates that the intermediate pores (porosity between 2 and 6 %) are very important in determining production potential of the reservoir. These intermediate size pores contain high oil saturation. (4) The limestone part of the reservoir, although low in porosity (mostly less than 6 %) is much more prolific in terms of oil production than the dolomite portion of the reservoir. The reason for this difference is the higher oil saturation in low porosity region. As the average porosity increases, the remaining oil saturation decreases. This is evident from log and core analysis. (5) Using a compositional simulator, we are able to reproduce the important reservoir characteristics by assuming a two layer model. One layer is high permeability region containing water and the other layer is low permeability region containing mostly oil. The results are further verified by using a dual porosity model. Assuming that most of the volatile oil is contained in the matrix and the water is contained in the fractures, we are able to reproduce important reservoir performance characteristics. (6) Evaluation of secondary mechanisms indicates that CO{sub 2} flooding is potentially a viable option if CO{sub 2} is available at reasonable price. We have conducted detailed simulation studies to verify the effectiveness of CO{sub 2} huff-n-puff process. We are in the process of conducting additional lab tests to verify the efficacy of the same displacement. (7) Another possibility of improving the oil recovery is to inject surfactants to change the near well bore wettability of the rock from oil wet to water wet. By changing the wettability, we may be able to retard the water flow and hence improve the oil recovery as a percentage of total fluid produced. If surfactant is reasonably priced, other possibility is also to use huff-n-puff process using surfactants. Laboratory experiments are promising, and additional investigation continues. (8) Preliminary economic evaluation indicates that vertical wells outperform horizontal wells. Future work in the project would include: (1) Build multi-well numerical model to reproduce overall reservoir performance rather than individual well performance. Special emphasis will be placed on hydrodynamic connectivity between wells. (2) Collect data from adjacent Hunton reservoirs to validate our understanding of what makes it a productive reservoir. (3) Develop statistical methods to rank various reservoirs in Hunton formation. This will allow us to evaluate other Hunton formations based on old well logs, and determine, apriori, if

Mohan Kelkar

2003-10-01T23:59:59.000Z

388

A correlation of rock compressibility with temperature and pressure  

E-Print Network [OSTI]

reservoir rocks to higher temperatures. Tests were conducted on 17 specimens cut from 5 sandstone cores and 0 4 specimens cut from one limestone core at temperatures of 76 F, 0 0 0 200 F, 300 F, and 400 F and at pressures ranging from 100-14, 000 0 psi.... The net change in 0 0 pore volume from 100-14, 000 psi ranges between 4. 0 /o and 9. 6 /o 0 0 at room temperature and 5. 1 ? 14. 1 /o at 400 F. A definite trend was established between pore volume compressibility and porosity of the specimens tested...

Choudhary, Bijoy Kumar

1967-01-01T23:59:59.000Z

389

Geologic characterization of tight gas reservoirs  

SciTech Connect (OSTI)

The objectives of US Geological Survey (USGS) work during FY 89 were to conduct geologic research characterizing tight gas-bearing sandstone reservoirs and their resources in the western United States. Our research has been regional in scope but, in some basins, our investigations have focused on single wells or small areas containing several wells where a large amount of data is available. The investigations, include structure, stratigraphy, petrography, x-ray mineralogy, source-rock evaluation, formation pressure and temperature, borehole geophysics, thermal maturity mapping, fission-track age dating, fluid-inclusion thermometry, and isotopic geochemistry. The objectives of these investigations are to provide geologic models that can be compared and utilized in tight gas-bearing sequences elsewhere. Nearly all of our work during FY 89 was devoted to developing a computer-based system for the Uinta basin and collecting, analyzing, and storage of data. The data base, when completed will contain various types of stratigraphic, organic chemistry, petrographic, production, engineering, and other information that relate to the petroleum geology of the Uinta basin, and in particular, to the tight gas-bearing strata. 16 refs., 3 figs.

Law, B.E.

1990-12-01T23:59:59.000Z

390

A STOCHASTIC METHOD FOR MODELING FLUID DISPLACEMENT IN PETROLEUM RESERVOIRS  

E-Print Network [OSTI]

FLUID DISPLACEMENT IN PETROLEUM RESERVOIRS C. Anderson andFLUID DISPLACEMENT IN PETROLEUM RESERVOIRS C. Anderson andachieve optimal recovery of petroleum from a reservoir, it

Anderson, C.

2011-01-01T23:59:59.000Z

391

STATUS OF GEOTHERMAL RESERVOIR ENGINEERING MANAGEMENT PROGRAM ("GREMP") -DECEMBER, 1979  

E-Print Network [OSTI]

the characteristics of a geothermal reservoir: Items 2, 6,new data important to geothermal reservoir engineering prac-forecast performance of the geothermal reservoir and bore

Howard, J. H.

2012-01-01T23:59:59.000Z

392

Berea Sandstone reservoirs in Ashland and Medina Counties, Ohio  

SciTech Connect (OSTI)

The Berea Sandstone is one of the better known rock formations in Ohio. It occurs at shallow depths throughout a broad belt in central Ohio and crops out to the north and west of these counties. In Ashland and Medina Counties, the Berea may be divided into two separately identifiable units. The upper unit, called the blanket Berea in outcrop, is approximately equivalent to the cap Berea in the subsurface. The second unit, which lies below the cap Berea varies considerably in its thickness. The traditional, long-standing, and generally accepted view is that the Berea Sandstone was deposited in Ashland and Medina Counties in southward-flowing river channels. More recent drilling in these counties has demonstrated that these sand channels are not continuous, but are isolated sandstone bodies in which petroleum has accumulated. The reservoir capacity of the Berea is between 8 and 22% with an average porosity of 15%. The sandstone consists of loosely cemented, medium to fine-grained quartz with only rare shale breaks below the cap Berea. In Ashland and Medina Counties, Berea wells generally produce oil. Initial production in this area ranges between 1 or 2 bbl and to 40 BOPD after treatment. Reservoirs in the Berea Sandstone generally are productive where the sandstones are thick. They are also productive where the sandstone is thinner, but high on structure. Although a high structural position is preferred, the critical consideration is the thickness of the sandstone body and the reservoir geometry.

Hillebrand, L.B.; Coogan, A.H.

1984-12-01T23:59:59.000Z

393

2018 MAX-C/EXOMARS MISSION: THE ORLEANS MARS-ANALOGUE ROCK COLLECTION FOR INSTRUMENT TESTING. N. Bost1,2  

E-Print Network [OSTI]

Svalbard (Norway) with carbonate concretions in vesi- cules, and hydrothermal calcareous exhalite crusts) Hydrothermal carbonate (exhalite on the Svalbard basalt). Methods : Textural and compositional information nontronite. Some of the rocks have been subjected to hydrothermal alteration (silicifica- tion) and some

Paris-Sud XI, Université de

394

Real-time and post-frac' 3-D analysis of hydraulic fracture treatments in geothermal reservoirs  

SciTech Connect (OSTI)

Economic power production from Hot Dry Rock (HDR) requires the establishment of an efficient circulation system between wellbores in reservoir rock with extremely low matrix permeability. Hydraulic fracturing is employed to establish the necessary circulation system. Hydraulic fracturing has also been performed to increase production from hydrothermal reservoirs by enhancing the communication with the reservoir's natural fracture system. Optimal implementation of these hydraulic fracturing applications, as with any engineering application, requires the use of credible physical models and the reconciliation of the physical models with treatment data gathered in the field. Analysis of the collected data has shown that 2-D models and 'conventional' 3-D models of the hydraulic fracturing process apply very poorly to hydraulic fracturing in geothermal reservoirs. Engineering decisions based on these more 'conventional' fracture modeling techniques lead to serious errors in predicting the performance of hydraulic fracture treatments. These errors can lead to inappropriate fracture treatment design as well as grave errors in well placement for hydrothermal reservoirs or HDR reservoirs. This paper outlines the reasons why conventional modeling approaches fall short, and what types of physical models are needed to credibly estimate created hydraulic fracture geometry. The methodology of analyzing actual measured fracture treatment data and matching the observed net fracturing pressure (in realtime as well as after the treatment) is demonstrated at two separate field sites. Results from an extensive Acoustic Emission (AE) fracture diagnostic survey are also presented for the first case study aS an independent measure of the actual created hydraulic fracture geometry.

Wright, C.A.; Tanigawa, J.J.; Hyodo, Masami; Takasugi, Shinji

1994-01-20T23:59:59.000Z

395

Play Analysis and Digital Portfolio of Major Oil Reservoirs in the Permian Basin: Application and Transfer of Advanced Geological and Engineering Technologies for Incremental Production Opportunities  

SciTech Connect (OSTI)

A play portfolio is being constructed for the Permian Basin in west Texas and southeast New Mexico, the largest onshore petroleum-producing basin in the United States. Approximately 1,300 reservoirs in the Permian Basin have been identified as having cumulative production greater than 1 MMbbl (1.59 x 10{sup 5} m{sup 3}) of oil through 2000. Of these significant-sized reservoirs, approximately 1,000 are in Texas and 300 in New Mexico. There are 32 geologic plays that have been defined for Permian Basin oil reservoirs, and each of the 1,300 major reservoirs was assigned to a play. The reservoirs were mapped and compiled in a Geographic Information System (GIS) by play. The final reservoir shapefile for each play contains the geographic location of each reservoir. Associated reservoir information within the linked data tables includes RRC reservoir number and district (Texas only), official field and reservoir name, year reservoir was discovered, depth to top of the reservoir, production in 2000, and cumulative production through 2000. Some tables also list subplays. Play boundaries were drawn for each play; the boundaries include areas where fields in that play occur but are smaller than 1 MMbbl (1.59 x 10{sup 5} m{sup 3}) of cumulative production. Oil production from the reservoirs in the Permian Basin having cumulative production of >1 MMbbl (1.59 x 10{sup 5} m{sup 3}) was 301.4 MMbbl (4.79 x 10{sup 7} m{sup 3}) in 2000. Cumulative Permian Basin production through 2000 was 28.9 Bbbl (4.59 x 10{sup 9} m{sup 3}). The top four plays in cumulative production are the Northwest Shelf San Andres Platform Carbonate play (3.97 Bbbl [6.31 x 10{sup 8} m{sup 3}]), the Leonard Restricted Platform Carbonate play (3.30 Bbbl [5.25 x 10{sup 8} m{sup 3}]), the Pennsylvanian and Lower Permian Horseshoe Atoll Carbonate play (2.70 Bbbl [4.29 x 10{sup 8} m{sup 3}]), and the San Andres Platform Carbonate play (2.15 Bbbl [3.42 x 10{sup 8} m{sup 3}]). Detailed studies of three reservoirs are in progress: Kelly-Snyder (SACROC unit) in the Pennsylvanian and Lower Permian Horseshoe Atoll Carbonate play, Fullerton in the Leonard Restricted Platform Carbonate play, and Barnhart (Ellenburger) in the Ellenburger Selectively Dolomitized Ramp Carbonate play. For each of these detailed reservoir studies, technologies for further, economically viable exploitation are being investigated.

Shirley P. Dutton; Eugene M. Kim; Ronald F. Broadhead; Caroline L. Breton; William D. Raatz; Stephen C. Ruppel; Charles Kerans

2004-01-13T23:59:59.000Z

396

The Carpenteria reservoir redevelopment project  

SciTech Connect (OSTI)

This is the final report of a one-year, Laboratory Directed Research and Development (LDRD) project at the Los Alamos National Laboratory (LANL). The objective of this project was to develop a simulation-based reservoir management system that could be used to guide the redevelopment of the Carpenteria Offshore Field, which is located just seven miles from Santa Barbara. The system supports geostatistical and geological modeling and reservoir forecasting. Moreover, it is also a shared resource between the field operator, Pacific Operators Offshore, and the mineral owners, the U.S. Department of the Interior and the State of California.

Kendall, R.P.; Whitney, E.M.; Krogh, K.E. [Los Alamos National Lab., NM (United States); Coombs, S. [Pacific Operators Offshore, Inc., Carpinteria, CA (United States); Paul, R.G. [Dept. of the Interior (United States); Voskanian, M.M. [California State Lands Commission, Sacramento, CA (United States); Ershaghi, I. [University of Southern California, Los Angeles, CA (United States)

1997-08-01T23:59:59.000Z

397

Burial diagenesis and timing of reservoir development, North Haynesville Field, Louisiana  

E-Print Network [OSTI]

of MASTER OF SCIENCE December 1982 Major Subject: Geology BURIAL DIAGENESIS AND TIMING OF RESERVOIR DEVELOPMENT, NORTH HAYNESVILLE FIELD, LOUISIANA A Thesis by HARRIS BENJAMIN HULL Approved as to style and content by: syne M. Ahr (Chairman...'s encouragement and support also was greatly appreciated. TABLE OF CONTFNTS Page INTRODUCTION Reg'onal Geology Present Status Methods SMACKOVER ROCK PROPERTIES 13 Composition Sedimentary Structures Microfacies 13 28 29 DEPOSITIONAL ENVIRONMENTS 38...

Hull, Harris Benjamin

1982-01-01T23:59:59.000Z

398

Rock Properties Model  

SciTech Connect (OSTI)

The purpose of this model report is to document the Rock Properties Model version 3.1 with regard to input data, model methods, assumptions, uncertainties and limitations of model results, and qualification status of the model. The report also documents the differences between the current and previous versions and validation of the model. The rock properties model provides mean matrix and lithophysae porosity, and the cross-correlated mean bulk density as direct input to the ''Saturated Zone Flow and Transport Model Abstraction'', MDL-NBS-HS-000021, REV 02 (BSC 2004 [DIRS 170042]). The constraints, caveats, and limitations associated with this model are discussed in Section 6.6 and 8.2. Model validation accomplished by corroboration with data not cited as direct input is discussed in Section 7. The revision of this model report was performed as part of activities being conducted under the ''Technical Work Plan for: The Integrated Site Model, Revision 05'' (BSC 2004 [DIRS 169635]). The purpose of this revision is to bring the report up to current procedural requirements and address the Regulatory Integration Team evaluation comments. The work plan describes the scope, objectives, tasks, methodology, and procedures for this process.

C. Lum

2004-09-16T23:59:59.000Z

399

Subsurface Geology of the Fenton Hill Hot Dry Rock Geothermal Energy Site  

SciTech Connect (OSTI)

The Precambrian rock penetrated by wells EE-2A and -3A belongs to one or more granitic to granodioritic plutons. The plutonic rock contains two major xenolith zones of amphibolite, locally surrounded by fine-grained mafic rock of hybrid igneous origin. The granodiorite is cut by numerous leucogranite dikes that diminish in abundance with depth. The most prominent structural feature is the main breccia zone, in which the rock is highly fractured and moderately altered. This zone is at least 75 m thick and is of uncertain but near-horizontal orientation. Fracture abundance decreases with increasing depth below the main breccia zone, and fractures tend to be associated with leucogranite dikes. This association suggests that at least some of the fractures making up the geothermal reservoir are of Precambrian age or have long-range orientations controlled by the presence of Precambrian-age granitic dikes.

Levey, Schon S.

2010-12-01T23:59:59.000Z

400

Rock Bands/Rock Brands: Mediation and Musical Performance in Post-liberalization Bangalore  

E-Print Network [OSTI]

these recorded sources important rock pedagogical tools inwere a primary source of western rock music for young fans,Nevertheless, a source of funding for rock music performance

Coventry, Chloe Louise

2013-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "reservoir rock carbon" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


401

3D Sedimentological and geophysical studies of clastic reservoir analogs: Facies architecture, reservoir properties, and flow behavior within delta front facies elements of the Cretaceous Wall Creek Member, Frontier Formation, Wyoming  

SciTech Connect (OSTI)

Significant volumes of oil and gas occur in reservoirs formed by ancient river deltas. This has implications for the spatial distribution of rock types and the variation of transport properties. A between mudstones and sandstones may form baffles that influence productivity and recovery efficiency. Diagenetic processes such as compaction, dissolution, and cementation can also alter flow properties. A better understanding of these properties and improved methods will allow improved reservoir development planning and increased recovery of oil and gas from deltaic reservoirs. Surface exposures of ancient deltaic rocks provide a high-resolution view of variability. Insights gleaned from these exposures can be used to model analogous reservoirs, for which data is sparser. The Frontier Formation in central Wyoming provides an opportunity for high-resolution models. The same rocks exposed in the Tisdale anticline are productive in nearby oil fields. Kilometers of exposure are accessible, and bedding-plane exposures allow use of high-resolution ground-penetrating radar. This study combined geologic interpretations, maps, vertical sections, core data, and ground-penetrating radar to construct geostatistical and flow models. Strata-conforming grids were use to reproduce the observed geometries. A new Bayesian method integrates outcrop, core, and radar amplitude and phase data. The proposed method propagates measurement uncertainty and yields an ensemble of plausible models for calcite concretions. These concretions affect flow significantly. Models which integrate more have different flow responses from simpler models, as demonstrated an exhaustive two-dimensional reference image and in three dimensions. This method is simple to implement within widely available geostatistics packages. Significant volumes of oil and gas occur in reservoirs that are inferred to have been formed by ancient river deltas. This geologic setting has implications for the spatial distribution of rock types (\\Eg sandstones and mudstones) and the variation of transport properties (\\Eg permeability and porosity) within bodies of a particular rock type. Both basin-wide processes such as sea-level change and the autocyclicity of deltaic processes commonly cause deltaic reservoirs to have large variability in rock properties; in particular, alternations between mudstones and sandstones may form baffles and trends in rock body permeability can influence productivity and recovery efficiency. In addition, diagenetic processes such as compaction, dissolution, and cementation can alter the spatial pattern of flow properties. A better understanding of these properties, and improved methods to model the properties and their effects, will allow improved reservoir development planning and increased recovery of oil and gas from deltaic reservoirs. Surface exposures of ancient deltaic rocks provide a high resolution, low uncertainty view of subsurface variability. Patterns and insights gleaned from these exposures can be used to model analogous reservoirs, for which data is much sparser. This approach is particularly attractive when reservoir formations are exposed at the surface. The Frontier Formation in central Wyoming provides an opportunity for high resolution characterization. The same rocks exposed in the vicinity of the Tisdale anticline are productive in nearby oil fields, including Salt Creek. Many kilometers of good-quality exposure are accessible, and the common bedding-plane exposures allow use of shallow-penetration, high-resolution electromagnetic methods known as ground-penetrating radar. This study combined geologic interpretations, maps, vertical sections, core data, and ground-penetrating radar to construct high-resolution geostatistical and flow models for the Wall Creek Member of the Frontier Formation. Stratal-conforming grids were use to reproduce the progradational and aggradational geometries observed in outcrop and radar data. A new, Bayesian method integrates outcrop--derived statistics, core observations of concretions, and radar amplitude and

Christopher D. White

2009-12-21T23:59:59.000Z

402

The Effect Of Viscoelastic Surfactants Used In Carbonate Matrix Acidizing On Wettability  

E-Print Network [OSTI]

Carbonate reservoirs are heterogeneous; therefore, proper acid placement/diversion is required to make matrix acid treatments effective. Viscoelastic surfactants (VES) are used as diverting agents in carbonate matrix acidizing. However...

Adejare, Oladapo

2012-07-16T23:59:59.000Z

403

CONFERENCE PROCEEDINGS EIGHTH ANNUAL CONFERENCE ON CARBON CAPTURE AND SEQUESTRATION -DOE/NETL  

E-Print Network [OSTI]

CONFERENCE PROCEEDINGS EIGHTH ANNUAL CONFERENCE ON CARBON CAPTURE AND SEQUESTRATION - DOE/NETL May ON CARBON CAPTURE AND SEQUESTRATION - DOE/NETL May 4 ­ 7, 2009 Abstract Reservoir simulation is the industry

Mohaghegh, Shahab

404

Geothermal reservoir engineering research at Stanford University. First annual report, October 1, 1980-September 30, 1981  

SciTech Connect (OSTI)

The work on energy extraction experiments concerns the efficiency with which the in-place heat and fluids can be produced. The work on noncondensable gas reservoir engineering covers both the completed and continuing work in these two interrelated research areas: radon emanation from the rock matrix of geothermal reservoirs, and radon and ammonia variations with time and space over geothermal reservoirs. Cooperative research programs with Italy and Mexico are described. The bench-scale experiments and well test analysis section covers both experimental and theoretical studies. The small core model continues to be used for the study of temperature effects on absolute permeability. The unconsolidated sand study was completed at the beginning of this contract period. The Appendices describe some of the Stanford Geothermal program activities that results in interactions with the geothermal community. These occur in the form of SGP Technical Reports, presentations at technical meetings and publications in the open literature.

Brigham, W.E.; Horne, R.N.; Kruger, P.; Miller, F.G.; Ramey, H.J. Jr.

1981-09-01T23:59:59.000Z

405

Core analysis in a low permeability sandstone reservoir: Results from the Multiwell Experiment  

SciTech Connect (OSTI)

Over 4100 ft (1100 ft oriented) of Mesaverde core was taken during the drilling of the three Multiwell Experiment (MWX) wells, for study in a comprehensive core analysis program. This core traversed five separate depositional environments (shoreline/marine, coastal, paludal, fluvial, and paralic), and almost every major sand in the Mesaverde at the site was sampled. This paper summarizes MWX core analysis and describes the petrophysical properties at the MWX site; reservoir parameters, including permeabilities of naturally fractured core; and mechanical rock properties including stress-related measurements. Some correlations are made between reservoir properties and mineralogy/petrology data. Comparisons are made between the properties of lenticular and blanket sandstone morphologies existing at the site. This paper provides an overview of a complete core analysis in a low-permeability sandstone reservoir. 66 refs., 17 figs. , 9 tabs.

Sattler, A.R.

1989-04-01T23:59:59.000Z

406

Naturally fractured tight gas reservoir detection optimization. Final report  

SciTech Connect (OSTI)

This DOE-funded research into seismic detection of natural fractures is one of six projects within the DOE`s Detection and Analysis of Naturally Fractured Gas Reservoirs Program, a multidisciplinary research initiative to develop technology for prediction, detection, and mapping of naturally fractured gas reservoirs. The demonstration of successful seismic techniques to locate subsurface zones of high fracture density and to guide drilling orientation for enhanced fracture permeability will enable better returns on investments in the development of the vast gas reserves held in tight formations beneath the Rocky Mountains. The seismic techniques used in this project were designed to capture the azimuthal anisotropy within the seismic response. This seismic anisotropy is the result of the symmetry in the rock fabric created by aligned fractures and/or unequal horizontal stresses. These results may be compared and related to other lines of evidence to provide cross-validation. The authors undertook investigations along the following lines: Characterization of the seismic anisotropy in three-dimensional, P-wave seismic data; Characterization of the seismic anisotropy in a nine-component (P- and S-sources, three-component receivers) vertical seismic profile; Characterization of the seismic anisotropy in three-dimensional, P-to-S converted wave seismic data (P-wave source, three-component receivers); and Description of geological and reservoir-engineering data that corroborate the anisotropy: natural fractures observed at the target level and at the surface, estimation of the maximum horizontal stress in situ, and examination of the flow characteristics of the reservoir.

NONE

1997-11-19T23:59:59.000Z

407

Modeling well performance in compartmentalized gas reservoirs  

E-Print Network [OSTI]

Predicting the performance of wells in compartmentalized reservoirs can be quite challenging to most conventional reservoir engineering tools. The purpose of this research is to develop a Compartmentalized Gas Depletion Model that applies not only...

Yusuf, Nurudeen

2008-10-10T23:59:59.000Z

408

Modeling well performance in compartmentalized gas reservoirs  

E-Print Network [OSTI]

Predicting the performance of wells in compartmentalized reservoirs can be quite challenging to most conventional reservoir engineering tools. The purpose of this research is to develop a Compartmentalized Gas Depletion Model that applies not only...

Yusuf, Nurudeen

2009-05-15T23:59:59.000Z

409

Optimizing injected solvent fraction in stratified reservoirs  

E-Print Network [OSTI]

Waterflooding has become standard practice for extending the productive life of many solution gas drive reservoirs, but has the disadvantage of leaving a substantial residual oil volume in the reservoir. Solvent flooding has been offered as a...

Moon, Gary Michael

1993-01-01T23:59:59.000Z

410

Comparative Evaluation of Generalized River/Reservoir System Models  

E-Print Network [OSTI]

This report reviews user-oriented generalized reservoir/river system models. The terms reservoir/river system, reservoir system, reservoir operation, or river basin management "model" or "modeling system" are used synonymously to refer to computer...

Wurbs, Ralph A.

411

Optimization Online - Managing Hydroelectric Reservoirs over an ...  

E-Print Network [OSTI]

Jul 7, 2013 ... Managing Hydroelectric Reservoirs over an Extended Planning Horizon using a Benders Decomposition Algorithm Exploiting a Memory Loss ...

Pierre-Luc Carpentier

2013-07-07T23:59:59.000Z

412

Producing Light Oil from a Frozen Reservoir: Reservoir and Fluid Characterization of Umiat Field, National Petroleum Reserve, Alaska  

SciTech Connect (OSTI)

Umiat oil field is a light oil in a shallow, frozen reservoir in the Brooks Range foothills of northern Alaska with estimated oil-in-place of over 1 billion barrels. Umiat field was discovered in the 1940’s but was never considered viable because it is shallow, in the permafrost, and far from any transportation infrastructure. The advent of modern drilling and production techniques has made Umiat and similar fields in northern Alaska attractive exploration and production targets. Since 2008 UAF has been working with Renaissance Alaska Inc. and, more recently, Linc Energy, to develop a more robust reservoir model that can be combined with rock and fluid property data to simulate potential production techniques. This work will be used to by Linc Energy as they prepare to drill up to 5 horizontal wells during the 2012-2013 drilling season. This new work identified three potential reservoir horizons within the Cretaceous Nanushuk Formation: the Upper and Lower Grandstand sands, and the overlying Ninuluk sand, with the Lower Grandstand considered the primary target. Seals are provided by thick interlayered shales. Reserve estimates for the Lower Grandstand alone range from 739 million barrels to 2437 million barrels, with an average of 1527 million bbls. Reservoir simulations predict that cold gas injection from a wagon-wheel pattern of multilateral injectors and producers located on 5 drill sites on the crest of the structure will yield 12-15% recovery, with actual recovery depending upon the injection pressure used, the actual Kv/Kh encountered, and other geologic factors. Key to understanding the flow behavior of the Umiat reservoir is determining the permeability structure of the sands. Sandstones of the Cretaceous Nanushuk Formation consist of mixed shoreface and deltaic sandstones and mudstones. A core-based study of the sedimentary facies of these sands combined with outcrop observations identified six distinct facies associations with distinctive permeability trends. The Lower Grandstand sand consists of two coarsening-upward shoreface sands sequences while the Upper Grandstand consists of a single coarsening-upward shoreface sand. Each of the shoreface sands shows a distinctive permeability profile with high horizontal permeability at the top getting progressively poorer towards the base of the sand. In contrast, deltaic sandstones in the overlying Ninuluk are more permeable at the base of the sands, with decreasing permeability towards the sand top. These trends impart a strong permeability anisotropy to the reservoir and are being incorporated into the reservoir model. These observations also suggest that horizontal wells should target the upper part of the major sands. Natural fractures may superimpose another permeability pattern on the Umiat reservoir that need to be accounted for in both the simulation and in drilling. Examination of legacy core from Umiat field indicate that fractures are present in the subsurface, but don't provide information on their orientation and density. Nearby surface exposures of folds in similar stratigraphy indicate there are at least three possible fracture sets: an early, N/S striking set that may predate folding and two sets possibly related to folding: an EW striking set of extension fractures that are parallel to the fold axes and a set of conjugate shear fractures oriented NE and NW. Analysis of fracture spacing suggests that these natural fractures are fairly widely spaced (25-59 cm depending upon the fracture set), but could provide improved reservoir permeability in horizontal legs drilled perpendicular to the open fracture set. The phase behavior of the Umiat fluid needed to be well understood in order for the reservoir simulation to be accurate. However, only a small amount of Umiat oil was available; this oil was collected in the 1940’s and was severely weathered. The composition of this ‘dead’ Umiat fluid was characterized by gas chromatography. This analysis was then compared to theoretical Umiat composition derived using the Pedersen method with original Umiat

Hanks, Catherine

2012-12-31T23:59:59.000Z

413

Advancing New 3D Seismic Interpretation Methods for Exploration and Development of Fractured Tight Gas Reservoirs  

SciTech Connect (OSTI)

In a study funded by the U.S. Department of Energy and GeoSpectrum, Inc., new P-wave 3D seismic interpretation methods to characterize fractured gas reservoirs are developed. A data driven exploratory approach is used to determine empirical relationships for reservoir properties. Fractures are predicted using seismic lineament mapping through a series of horizon and time slices in the reservoir zone. A seismic lineament is a linear feature seen in a slice through the seismic volume that has negligible vertical offset. We interpret that in regions of high seismic lineament density there is a greater likelihood of fractured reservoir. Seismic AVO attributes are developed to map brittle reservoir rock (low clay) and gas content. Brittle rocks are interpreted to be more fractured when seismic lineaments are present. The most important attribute developed in this study is the gas sensitive phase gradient (a new AVO attribute), as reservoir fractures may provide a plumbing system for both water and gas. Success is obtained when economic gas and oil discoveries are found. In a gas field previously plagued with poor drilling results, four new wells were spotted using the new methodology and recently drilled. The wells have estimated best of 12-months production indicators of 2106, 1652, 941, and 227 MCFGPD. The latter well was drilled in a region of swarming seismic lineaments but has poor gas sensitive phase gradient (AVO) and clay volume attributes. GeoSpectrum advised the unit operators that this location did not appear to have significant Lower Dakota gas before the well was drilled. The other three wells are considered good wells in this part of the basin and among the best wells in the area. These new drilling results have nearly doubled the gas production and the value of the field. The interpretation method is ready for commercialization and gas exploration and development. The new technology is adaptable to conventional lower cost 3D seismic surveys.

James Reeves

2005-01-31T23:59:59.000Z

414

HIGH TEMPERATURE GEOTHERMAL RESERVOIR ENGINEERING  

E-Print Network [OSTI]

on the Cerro P r i e t o Geothermal F i e l d , Mexicali,e C e r r o P r i e t o Geothermal F i e l d , Baja C a l i1979 HIGH TEMPERATURE GEOTHERMAL RESERVOIR ENGINEERING R.

Schroeder, R.C.

2009-01-01T23:59:59.000Z

415

Tenth workshop on geothermal reservoir engineering: proceedings  

SciTech Connect (OSTI)

The workshop contains presentations in the following areas: (1) reservoir engineering research; (2) field development; (3) vapor-dominated systems; (4) the Geysers thermal area; (5) well test analysis; (6) production engineering; (7) reservoir evaluation; (8) geochemistry and injection; (9) numerical simulation; and (10) reservoir physics. (ACR)

Not Available

1985-01-22T23:59:59.000Z

416

STIMULATION AND RESERVOIR ENGINEERING OF GEOTHERMAL RESOURCES  

E-Print Network [OSTI]

STIMULATION AND RESERVOIR ENGINEERING OF GEOTHERMAL RESOURCES Paul Kruger and Henry J . Ramey, Jr . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 THE GEOTHERMAL CHIMNEY MODEL . . . . . . . . . . . . . . . . . . . 3 Current Design of t h e . . . . . . . . . . . . . . . 67 Geothermal Reservoir Phy.Sica1 PIodels . . . . . . . . . . . . 73 RAD3N I N GEOTHERMAL RESERVOIRS

Stanford University

417

Atmospheric Lifetime of Fossil Fuel Carbon Dioxide  

E-Print Network [OSTI]

Atmospheric Lifetime of Fossil Fuel Carbon Dioxide David Archer,1 Michael Eby,2 Victor Brovkin,3 released from combustion of fossil fuels equilibrates among the various carbon reservoirs of the atmosphere literature on the atmospheric lifetime of fossil fuel CO2 and its impact on climate, and we present initial

Scherer, Norbert F.

418

Increasing Waterflooding Reservoirs in the Wilmington Oil Field through Improved Reservoir Characterization and Reservoir Management, Class III  

SciTech Connect (OSTI)

This project was intended to increase recoverable waterflood reserves in slope and basin reservoirs through improved reservoir characterization and reservoir management. The particular application of this project is in portions of Fault Blocks IV and V of the Wilmington Oil Field, in Long Beach, California, but the approach is widely applicable in slope and basin reservoirs, transferring technology so that it can be applied in other sections of the Wilmington field and by operators in other slope and basin reservoirs is a primary component of the project.

Koerner, Roy; Clarke, Don; Walker, Scott; Phillips, Chris; Nguyen, John; Moos, Dan; Tagbor, Kwasi

2001-08-07T23:59:59.000Z

419

Sixteenth workshop on geothermal reservoir engineering: Proceedings  

SciTech Connect (OSTI)

The Sixteenth Workshop on Geothermal Reservoir Engineering was held at Stanford University on January 23-25, 1991. The Workshop Banquet Speaker was Dr. Mohinder Gulati of UNOCAL Geothermal. Dr. Gulati gave an inspiring talk on the impact of numerical simulation on development of geothermal energy both in The Geysers and the Philippines. Dr. Gulati was the first recipient of The Stanford Geothermal Program Reservoir Engineering Award for Excellence in Development of Geothermal Energy. Dr. Frank Miller presented the award. The registered attendance figure of one hundred fifteen participants was up slightly from last year. There were seven foreign countries represented: Iceland, Italy, Philippines, Kenya, the United Kingdom, Mexico, and Japan. As last year, papers on about a dozen geothermal fields outside the United States were presented. There were thirty-six papers presented at the Workshop, and two papers were submitted for publication only. Attendees were welcomed by Dr. Khalid Aziz, Chairman of the Petroleum Engineering Department at Stanford. Opening remarks were presented by Dr. Roland Horne, followed by a discussion of the California Energy Commission's Geothermal Activities by Barbara Crowley, Vice Chairman; and J.E. ''Ted'' Mock's presentation of the DOE Geothermal Program: New Emphasis on Industrial Participation. Technical papers were organized in twelve sessions concerning: hot dry rock, geochemistry, tracer injection, field performance, modeling, and chemistry/gas. As in previous workshops, session chairpersons made major contributions to the program. Special thanks are due to Joel Renner, Jeff Tester, Jim Combs, Kathy Enedy, Elwood Baldwin, Sabodh Garg, Marcel0 Lippman, John Counsil, and Eduardo Iglesias. The Workshop was organized by the Stanford Geothermal Program faculty, staff, and graduate students. We wish to thank Pat Ota, Angharad Jones, Rosalee Benelli, Jeanne Mankinen, Ted Sumida, and Terri A. Ramey who also produces the Proceedings Volumes for publication. We owe a great deal of thanks to our students who operate the audiovisual equipment and to Michael Riley who coordinated the meeting arrangements for a second year. Henry J. Ramey, Jr. Roland N. Horne Frank G. Miller Paul Kruger William E. Brigham Jean W. Cook

Ramey, H.J. Jr.; Kruger, P.; Miller, F.G.; Horne, R.N.; Brigham, W.E.; Cook, J.W. (Stanford Geothermal Program) [Stanford Geothermal Program

1991-01-25T23:59:59.000Z

420

Stratigraphic cyclicity and reservoir heterogeneity within upper San Andres and Grayburg strata (upper Permian-Guadalupian), Maljamar field, Se New Mexico  

E-Print Network [OSTI]

of upper San Andres strata. Cavernous porosity was later plugged with massive anhydrite, resulting in the degradation of reservoir quality. In the overlying Grayburg Formation, cycles consist of mixed sandstone and shallowwater carbonate facies...

Modica, Christopher James

1997-01-01T23:59:59.000Z

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