Log in

Relevant bibliographies by topics / Oil fields Geology / Dissertations / Theses

To see the other types of publications on this topic, follow the link: Oil fields Geology.

Dissertations / Theses on the topic 'Oil fields Geology'

Author: Grafiati

Published: 4 June 2021

Last updated: 16 February 2022

Create a spot-on reference in APA, MLA, Chicago, Harvard, and other styles

Select a source type:

Consult the top 29 dissertations / theses for your research on the topic 'Oil fields Geology.'

Next to every source in the list of references, there is an 'Add to bibliography' button. Press on it, and we will generate automatically the bibliographic reference to the chosen work in the citation style you need: APA, MLA, Harvard, Chicago, Vancouver, etc.

You can also download the full text of the academic publication as pdf and read online its abstract whenever available in the metadata.

Browse dissertations / theses on a wide variety of disciplines and organise your bibliography correctly.

1

Wolpert, Jeremy M. "Stratigraphic and structural analysis of the J1 Sandstone, Scotts Bluff Trend, Scotts Bluff and Morrill counties, Nebraska." Morgantown, W. Va. : [West Virginia University Libraries], 2006. https://eidr.wvu.edu/etd/documentdata.eTD?documentid=4925.

Full text

Abstract:

Thesis (M.S.)--West Virginia University, 2006.
Title from document title page. Document formatted into pages; contains xi, 103 p. : ill. (some col.), maps (some col.). Includes abstract. Includes bibliographical references (p. 90).

APA, Harvard, Vancouver, ISO, and other styles

2

Torn, Daniel. "Sedimentology and stratigraphy of diatomaceous sediments in the Casmalia Hills and Orcutt oil fields in the Santa Maria basin, California." Thesis, California State University, Long Beach, 2014. http://pqdtopen.proquest.com/#viewpdf?dispub=1528056.

Full text

Abstract:

Two industry acquired diatomite cores (Sisquoc Formation) from the Orcutt (Newlove 76-RD1) and Casmalia Hills (Stokes A-30804) oil fields were analyzed by core descriptions, laboratory analysis (XRD and SEM), and gamma ray logs. Based on these data, five distinct lithofacies, nine sedimentary features and compositional trends of both cores were established. Newlove 76-RD1 and Stokes A-30804 record an upward-shallowing succession at different depositional positions on the Pliocene paleo-slope of the Santa Maria basin. Stokes A-30804 reflects slope deposition on a lower flank of a paleo-bathymetric high receiving higher detrital influx from inter-ridge troughs. Slope deposition of Newlove 76-RD1 was closer to a paleo-bathymetric high where purer diatomaceous sediments accumulated. Within Stokes A-30804, purer opal-A dominant lithofacies contain the highest oil saturations. The diagenesis and precipitation of opal-CT and abundance of phyllosilicate significantly hinders oil saturation within lithofacies.

APA, Harvard, Vancouver, ISO, and other styles

3

Nakanishi, Takeshi. "Practical application of sequence stratigraphy and risk analysis for stratigraphic trap exploration." Title page, contents and abstract only, 2002. http://web4.library.adelaide.edu.au/theses/09PH/09phn1635.pdf.

Full text

Abstract:

"September 2002" Includes bibliographical references (leaves 200-209) Outlines an evaluation procedure for stratigraphic trap exploration by employing sequence stratigraphy, 3D seismic data visualisation and quantitative risk analysis with case studies in an actual exploration basin.

APA, Harvard, Vancouver, ISO, and other styles

4

Badescu, Adrian Constantin. "Reservoir characterization of the Miocene Starfak and Tiger Shoal fields, offshore Louisiana through integration of sequence stratigraphy, 3-D seismic, and well-log data." Access restricted to users with UT Austin EID, 2002. http://wwwlib.umi.com/cr/utexas/fullcit?p3108452.

Full text

APA, Harvard, Vancouver, ISO, and other styles

5

Boggs, Cheryle Ann. "Glacial Drift Thickness and Vs Characterized Using Three-Component Passive Seismic Data at the Dominion Stark-Summit Gas Storage Field, North Canton, Ohio." Wright State University / OhioLINK, 2014. http://rave.ohiolink.edu/etdc/view?acc_num=wright1420815127.

Full text

APA, Harvard, Vancouver, ISO, and other styles

6

Stevenson, Patrick M. "Petroleum geology and geochemistry of the Manyberries oil field, southeastern Alberta." Thesis, National Library of Canada = Bibliothèque nationale du Canada, 1999. http://www.collectionscanada.ca/obj/s4/f2/dsk2/ftp01/MQ38614.pdf.

Full text

APA, Harvard, Vancouver, ISO, and other styles

7

Stevenson, Patrick M. "Petroleum geology and geochemistry of the Manyberries oil field, southeastern Alberta." Calgary, Alta. : University of Calgary, 1998. https://dspace.ucalgary.ca/handle/1880/26270.

Full text

Abstract:

Thesis (M.Sc.) -- University of Calgary, 1998.
Three folded leaves and 3 1/2 in. computer disk in back pocket. 3 folded leaves and 3 1/2 in. computer disk in back pocket. Includes bibliographical references. Also available on microfiche. Available in PDF format via the World Wide Web.

APA, Harvard, Vancouver, ISO, and other styles

8

Duggan, James P. "Sedimentology and diagenesis of Swan Hills Simonette oil field, west-central Alberta basin." Thesis, National Library of Canada = Bibliothèque nationale du Canada, 1997. http://www.collectionscanada.ca/obj/s4/f2/dsk3/ftp04/mq37116.pdf.

Full text

APA, Harvard, Vancouver, ISO, and other styles

9

Benzagouta, Mohammed Said. "Petrophysical controls on sandstone reservoir characteristics in the Buchan Oil Field, northern North Sea." Thesis, University of Newcastle Upon Tyne, 1991. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.239703.

Full text

APA, Harvard, Vancouver, ISO, and other styles

10

Gyore, Domokos. "Noble gases as tracers of injected CO2 in the Cranfield enhanced oil recovery field." Thesis, University of Glasgow, 2015. http://theses.gla.ac.uk/7127/.

Full text

Abstract:

Identifying how injected CO2 is retained underground is a fundamental challenge for carbon capture and storage. Developing tracers that are cheap and widely applicable will increase confidence that stored CO2 remains in place. This PhD examines the applicability of the isotopic composition of noble gases (He, Ne, Ar, Kr and Xe) that are present as minor natural constituents in CO2, as tracers of the fate of injected CO2. The Cranfield oil field (MS, USA), into which natural CO2 is injected for enhanced oil recovery (EOR), was developed as a site for a parallel study of carbon capture and storage, and is the focus of this research. Samples of gas from the transported CO2, and the injection and production wells were taken 18 and 45 months after the commencement of injection in July 2008. Neon isotope data are consistent with simple binary mixing between the injected and in situ natural gas. This relationship allows the Ne isotope composition of the pre-injection gas in Cranfield to be determined. Coherent correlations between Ne, He and Ar isotopes allow the natural gas end-member composition to be calculated as well. The noble gas isotopic ratios (3He/4He = 0.05 RA, where RA is the atmospheric value of 1.39 x 10-6, 20Ne/22Ne = 9.62, 21Ne/22Ne = 0.0384, 40Ar/36Ar = 836 and 40Ar*/4He = 0.09, where 40Ar* is the sum of the radiogenic and mantle derived 40Ar) of the natural gas in Cranfield are typical of natural gases derived from the continental crust. Helium isotope ratios and the 40Ar*/4He ratio notably correlate with CO2 concentrations, indicating that the noble gas fingerprints of the injected gas are preserved, and may offer utility as a tracer of the CO2. The He and Ar isotope systematics of the four sampled wells that have the lowest CO2 concentrations identify the loss of a significant amount of CO2 from the free gas phase. The amount of loss in each of the four wells can be quantified from the measured 3He/4He and 40Ar*/4He ratios and changes in the CO2/3He values. Losses vary between 22% and 96%, with good agreement between the different methods. It is notable however, that these four wells do not have significant gas production, and do not contribute significantly to the total amount of produced and re-injected gas. So, even though there is a significant loss from these wells, the total amount of CO2 lost is estimated to be only ~0.1% of the total injected gas, equivalent to 10kt gas. Notwithstanding this, the new data indicate that, across the entire field, CO2 is retained as a free phase and stratigraphic trapping is the most important storage mechanism. The fractionation of 40Ar*/4He, CO2/3He and δ13CCO2 in the CO2-poor samples is consistent with dissolution in water. The non-radiogenic noble gases (20Ne, 36Ar, 84Kr, 132Xe) originate from the atmosphere and are present in the gas, water and oil phases in the reservoir to differing degrees. It has been revealed that groundwater degassing, induced by CO2 injection plays an important role in fractionating 20Ne/36Ar, 84Kr/36Ar and 132Xe/36Ar at the early stage of injection, but a large heterogeneity in the degree of degassing has been observed throughout the reservoir. Some wells have shown 100% water degassing, while others are close to 0%. Oil degassing, and therefore the active CO2 – oil contact, became important during the later phase of injection, which is consistent with the fact that more CO2 injection was required to degas the oil than water. Temporal variations in the non-radiogenic noble gas ratios and 3He/4He are indicative of the evolution of the oil displacement efficiency. This fully agrees with the injection – production well data recorded in the field during sampling. This suggests that noble gases can also be used as a reservoir engineering tool to better understand the interaction of CO2, water and oil in the subsurface not only during CO2 storage but also to track EOR operations.

APA, Harvard, Vancouver, ISO, and other styles

11

Chavez, Jacqueline A. "Principal stress analysis of rock fracture data from the Long Beach oil field, Los Angeles basin, California." Thesis, California State University, Long Beach, 2015. http://pqdtopen.proquest.com/#viewpdf?dispub=1587889.

Full text

Abstract:

Twelve electric borehole-image logs from oil wells located in the Long Beach oil field were used to conduct a fracture analysis of principal stress orientations associated with the Newport-Inglewood Fault Zone. The fractures analyzed are located in the Puente, Repetto, Pico, and San Pedro formations. Fractures were grouped based on fracture type, orientation, and formation. In-situ SHmax orientation was interpreted to range between 320? to 40?. Variations form the in-situ stress were observed across every formation and interpreted as paleo-stress. The SHmax orientation begins to change from NW to N-NW in the Pico Formation, which may signal the onset of the dextral movement of the Newport-Inglewood Fault 2.5 million years ago or later. The NE SHmax orientation in the San Pedro Formation may reflect stress trajectory changes as the Newport-Inglewood Fault continues to propagate in the Pleistocene. Additional SHmax orientations indicate a more complex structural evolution of stress trajectories.

APA, Harvard, Vancouver, ISO, and other styles

12

Kwasny, Brianna. "An investigation of the crude oil in the Spivey-Grabs field of south-central Kansas: an insight into oil type and origin." Thesis, Kansas State University, 2015. http://hdl.handle.net/2097/19031.

Full text

Abstract:

Master of Science
Geology
Matthew W. Totten
The most common practice of typing crude oils utilizes biomarkers to gain insight on the history of the oil. This practice only considers the organic chemistry of the oil, and does not consider the trace element concentrations within the oil. Rare earth element and other trace element concentrations in crude oil might provide further insight into the oil’s source and origin. This study analyzed REE and other trace metal concentrations of crude oil in the Spivey-Grabs field of south-central Kansas through analysis by ICP-MS and ICP-AES that, coupled with visual physical characteristics of oil and FT-IR analysis, could explain the reported “compartmentalization” of the field and provide insight on the origin of the oils. Analysis of physical characteristics of the crude oils suggested the presence of two types of oil, of differing viscosities, in the field. FT-IR confirmed the presence of these two oil types based on functional groups present in the oils. The existence of a high viscosity oil could potentially explain the compartmentalization behavior in the field. PAAS-normalized REE distribution patterns showed a general LREE enrichment, a positive cerium and negative europium anomaly, and a MREE and HREE depletion, but higher viscosity oils showed additional MREE and HREE enrichment. K/Rb values ranged from 2,864 to 44,118, with oils from mixed-viscosity wells having lower ratios overall. K/Rb values of Spivey-Grabs crude oils more closely resembled those of the Lansing-Kansas City formation than the K/Rb values of the Woodford shale and Mississippian formation of the Anadarko basin. Comparing the rare earth element distribution patterns and K/Rb values from this study to those of the Woodford shale suggests the Spivey-Grabs oil originated from a local source and not from the Woodford shale.

APA, Harvard, Vancouver, ISO, and other styles

13

Weller, Ryan M. "Compositional and Diagenetic Controls of Hardness in Siliceous Mudstones of the Monterey Formation, Belridge Oil Field, CA| Implications for Fracture Development." Thesis, California State University, Long Beach, 2018. http://pqdtopen.proquest.com/#viewpdf?dispub=10748533.

Full text

Abstract:

Rock hardness, as a proxy for geomechanical properties of brittleness and unconfined compressive strength, is useful as a high-resolution tool for fracture prediction. This study examines the compositional and diagenetic influences on rebound hardness of upper Monterey Formation mudstones in the San Joaquin Basin of California. The hardness of highly siliceous mudstones evolves through multiple stages of silica diagenesis (opal-A to opal-CT to quartz). Silica diagenesis occurs in two steps that dramatically change porosity from about 60% to 40% to 20% at about 2,000 feet and 5,500 feet of burial depth, respectively. Each step creates a more crystalline and connected silica framework that is increasingly prone to brittle failure. Micro-rebound hardness (HLD) and X-ray fluorescence scanning data show that proportion of diagenetic silica relative to clay-rich detritus is the primary influence on rock hardness within any single diagenetic phase. In general, rocks with higher silica contents are harder. Silica diagenesis increases mean hardness by 69% from opal-A to opal-CT but only 10% from opal-CT to quartz. In rocks buried to 12,500 feet, hardness increases by 24% occurs with no additional silica-phase change but through compaction and cementation during illitization and catagenesis. Opal-A mudstones failed to show a clear trend of hardness to most physical properties. In opal-CT and 6000-foot quartz phase mudstones hardness trends converge at greater than 70% diagenetic silica. Failure by brittle jointing is likely to prevail at >775 HLD in 12,000-foot quartz phase mudstones. The Monterey Formation is consistently harder and potentially more heterogeneous than the Marcellus, Niobrara, Eagle Ford, Horn River, and Woodford shale formations. This study clearly demonstrates an evolution of mechanical stratigraphy due to silica diagenesis; a process that may be under-regarded in the timing of natural fractures of other shales with siliceous components.

APA, Harvard, Vancouver, ISO, and other styles

14

El-Zaroug, Rajab Faraj. "Palynostratigraphy and palynofacies of subsurface Devonian (Middle-Upper) strata of the NE Al-Rar Gas & Oil Field, N.W. Libya." Thesis, University of Southampton, 1996. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.388217.

Full text

APA, Harvard, Vancouver, ISO, and other styles

15

Wall, Meagan. "An oil-source rock correlation examining the potential of the Chattanooga shale as a source rock for oil within the Spivey-Grabs-Basil Field, Kingman and Harper Counties, Kansas." Thesis, Kansas State University, 2015. http://hdl.handle.net/2097/19013.

Full text

Abstract:

Master of Science
Department of Geology
Matthew Totten
Oil production in Kansas has a long history with plays being found on all sides of the state. The source of Kansas’s hydrocarbons has been traditionally thought to be outside the state due to low thermal maturity and the shallow burial of potential source rocks within Kansas. This research addresses the question regarding the source of the oil in Kansas, at least within a small geographic area of roughly 146mi[superscript]2. The Spivey-Grabs-Basil Field has been one of the more successful fields within the state of Kansas since the 1960’s. This field is compartmentalized and offers a natural laboratory in which to conduct the field’s first formal oil-source rock correlation since oils are locked into place. While the main focus of this research relies heavily on pyrolysis and GCMS for biomarker analysis, it also investigates the possibility of using rare earth element (REE) concentrations as a possible fingerprint of organic matter within a source bed. TOC values of the Chattanooga shale samples from the Spivey-Grabs-Basil filed range from 0.75 and 3.95 wt. %, well within productive capacity. Pyrograms show both the potential for additional production, and the likely previous expulsion of hydrocarbons. Biomarker concentration percentages between C[subscript]27, C[subscript]28, and C[subscript]29 steranes, as well as pentacyclic terpane ratios compared between crude oil from the Spivey-Grabs-Basil and the Chattanooga shale show a definite genetic relationship. REE values of the organic fraction of the Chattanooga inversely correlate with those of the crude oils, suggesting fractionation during oil generation. After comparison of results with the Woodford shale in Oklahoma, the conclusion of this study is that the Chattanooga shale which underlies the Spivey-Grabs-Basil oil field of southern Kansas is the probable source rock which generated the oil now being produced.

APA, Harvard, Vancouver, ISO, and other styles

16

Slaker, Brent Allan. "Double-Difference Tomography Applied to Monitoring of Geologic Carbon Sequestration in the Aneth Oil Field, Utah." Thesis, Virginia Tech, 2011. http://hdl.handle.net/10919/36316.

Full text

Abstract:

Double-difference seismic tomography is performed on a carbon sequestration operation in the Aneth Oil Field in southeast Utah as part of a Department of Energy initiative on monitoring, verification, and accounting of sequestered CO2. A total of 1,211 seismic events were recorded from a borehole array of 22 geophones. Aneth Unit data were divided into four time periods for time-lapse analysis. A low velocity zone spanning the lateral extents of the observable region, likely representing a CO2 plume, is detected when considering voxels containing the highest ray path coverage. A series of synthetic tomography tests simulating different CO2 plume sizes and locations was performed to assist in characterizing velocity changes associated with Aneth Unit data. Inferences about the existence of a CO2 plume should be made by comparing actual data to synthetic data resulting from simulations performed under similar conditions. Considering synthetic simulation similarities and a derivative weight sum analysis, a CO2 plume can be imaged within the Desert Creek reservoir, but the resolution of the CO2 plume is too low for proper monitoring, verification, and accounting of injected CO2. Recommendations, for improving CO2 plume resolution through double difference seismic tomography, are made to increase the ray path distribution throughout the Aneth Unit by varying geophone locations.
Master of Science

APA, Harvard, Vancouver, ISO, and other styles

17

Slaker, Brent. "Double-Difference Tomography Applied to Monitoring of Geologic Carbon Sequestration in the Aneth Oil Field, Utah." Thesis, Virginia Tech, 2011. http://hdl.handle.net/10919/36316.

Full text

Abstract:

Double-difference seismic tomography is performed on a carbon sequestration operation in the Aneth Oil Field in southeast Utah as part of a Department of Energy initiative on monitoring, verification, and accounting of sequestered CO2. A total of 1,211 seismic events were recorded from a borehole array of 22 geophones. Aneth Unit data were divided into four time periods for time-lapse analysis. A low velocity zone spanning the lateral extents of the observable region, likely representing a CO2 plume, is detected when considering voxels containing the highest ray path coverage. A series of synthetic tomography tests simulating different CO2 plume sizes and locations was performed to assist in characterizing velocity changes associated with Aneth Unit data. Inferences about the existence of a CO2 plume should be made by comparing actual data to synthetic data resulting from simulations performed under similar conditions. Considering synthetic simulation similarities and a derivative weight sum analysis, a CO2 plume can be imaged within the Desert Creek reservoir, but the resolution of the CO2 plume is too low for proper monitoring, verification, and accounting of injected CO2. Recommendations, for improving CO2 plume resolution through double difference seismic tomography, are made to increase the ray path distribution throughout the Aneth Unit by varying geophone locations.
Master of Science

APA, Harvard, Vancouver, ISO, and other styles

18

Avcioglu, Emre. "Hydrocarbon Microseepage Mapping Via Remote Sensing For Gemrik Anticline, Bozova Oil Field, Adiyaman, Turkey." Master's thesis, METU, 2010. http://etd.lib.metu.edu.tr/upload/12612639/index.pdf.

Full text

Abstract:

Hydrocarbon (HC) microseepages can be indicator of possible reservoirs. For that reason, mapping the microseepages has potential to be used in petroleum exploration. This study presents a methodology for mapping HC microseepages and related clay mineral alteration in Gemrik Anticline, Adiyaman. For this purpose samples were collected from the potential seepage zones and tested by geochemical analysis. All samples were found to contain some HC. Then, an ASTER image of the region was obtained and a band combination was generated to map this particular region. To map related clay mineral alteration, firstly reflectance spectra of samples were measured using field spectrometer. Secondly, spectrally-known samples were analyzed in USGS Library to determine the reflectance spectra of the constitutional clay minerals in the samples. Lastly, the reflectance characteristics of selected end v members were represented as ASTER band combinations based on their spectral absorption characteristics and literature information. Crosta Technique was used to determine required principal components to map HC microseepage and related clay mineral alteration. Then, this methodology is applied to the whole ASTER image. Ground truth study showed that more than 65% of the revisited anomalies show similar prospects to that of the referenced anticline regardless of their geochemical content. In order to certify the ASTER band combination for mapping HC microseepages, anomalous and non-anomalous pixels were selected from the resultant HC map and given as training data samples to AdaBoost loop which is an image processing algorithm. It has been found that ASTER band combination offered for mapping HC microseepages is similar to that of AdaBoost Algorithm output.

APA, Harvard, Vancouver, ISO, and other styles

19

Ball, Nathaniel H. Atchley Stacy C. "Depositional and diagenetic controls on reservoir quality and their petrophysical predictors within the Upper Cretaceous (Cenomanian) Doe Creek Member of the Kaskapau Formation at Valhalla Field, Northwest Alberta." Waco, Tex. : Baylor University, 2009. http://hdl.handle.net/2104/5296.

Full text

APA, Harvard, Vancouver, ISO, and other styles

20

Townley, Paul Joseph. "Preliminary investigation for underground storage of pipeline gas in the Bruer and Flora pools, Mist gas field, Columbia County, Oregon." PDXScholar, 1985. https://pdxscholar.library.pdx.edu/open_access_etds/3542.

Full text

Abstract:

Northwest Natural Gas Canpany has proposed to convert the Bruer and Flora pools of the Mist Gas Field in west-central Columbia County, Northwestern Oregon, to pipeline gas storage reservoirs. Conversion to underground storage of pipeline gas in these depleted gas reservoirs would be the first in the Pacific Northwest. The Bruer and Flora Pools are fault trapped within the Cowlitz Formation. The shales overlying the Cowlitz Formation create a local seal for these gas reservoirs. X-ray diffraction and density log measurements suggest that the clay in these shales is primarily composed of smectite, which provides an excellent caprock seal. The reservoir rock of the Bruer and Flora Pools is the arkosic Cl ark and Wilson Sand. An average weighted grain density for the sand is 2.65 g/cm3. The abundance of potassium feldspar in the sand, hence K40, creates a background gamma radiation for the sand roughly equal to that of the shale, making the sand and shale virtually indistinguishable on the gamma ray log. Bottan Hole Temperatures (BHT), which were recorded on open hole logs, indicate the Bruer Pool is 7°C (20°F) wanner than the Flora Pool, even though the Flora Pool is deeper. This temperature anomaly may be the result of equipment variation. A calibrated temperature survey would remove any discrepancies. A comparison of the thermal gradient determined in a previous study of the Oregon Coast Range and a gradient determined using BHT, suggest that BHT provide a good approximation of formation temperature. Utilizing the formation water analysis determined from four different wells in the Mist Gas Field, average total dissolved solids was found to be 24, 444 mg/l. Of the four analyses, the sample from Well CC#6 R/D2 is considered to be the most representative of the Bruer and Flora fools formation waters. Analysis of the four samples using the Palmer System suggests that the formation water of the Cowlitz Formation is in the early stages of sea water diagenasis. Formation water resistivity (Rw) was determined using a chemical and spontaneous potential analysis. Rw derived using chemical analysis averaged 0.175 ohm-meters and is considered the ITDst precise. Water saturation determined using the Archie saturation equation averaged 47.5% and ranged from 26.4 to 80.0% for the zone 814-836 meters (2670-2742 feet) in CC#10. These results are similar to those determined by the Thermal Time Decay (TDT) log.

APA, Harvard, Vancouver, ISO, and other styles

21

Dalrymple, Ashley. "Reservoir Characterization and Outcrop Analogs to the Navajo Sandstone in the Central Utah Thrust Belt Exploration Play." BYU ScholarsArchive, 2007. https://scholarsarchive.byu.edu/etd/954.

Full text

Abstract:

Reservoir heterogeneity plays an important role in oil field economics and completion strategies. We herein characterize the reservoir heterogeneity of the Early Jurassic Navajo Sandstone in the Justensen Flat/Devils Canyon area of the San Rafael Swell, Utah. These outcrops are located approximately 60 kilometers (45 mi) east of the recently discovered Covenant oil field which is located in the central Utah thrust belt exploration play. The reservoir for the Covenant field is the Navajo Sandstone. This study can serve as an outcrop analogue for this developing play and other eolian reservoirs worldwide. There are eight facies within the Navajo Sandstone in the Justensen Flat/Devils Canyon area based on differences in primary and secondary sedimentary structures, sedimentary texture, petrology, porosity/permeability, and other macro-scale features of the outcrop. Three facies were deposited by eolian dunes. These serve as the primary reservoir facies of the Navajo in the Justensen Flat/Devils Canyon area, displaying relatively high porosity and permeability (approximately 28 percent porosity and 100 mD of permeability). Five interdune facies display finer grain size, more abundant cement, and relatively lower porosity and permeability (approximately 18 percent porosity and 29 mD of permeability). Four of the five inderdune facies have variable porosity and permeability or are not laterally extensive (tens of meters). These four facies act as baffles to fluid flow within the reservoir. One interdune facies, the Wavy Algal Matted facies (WAM), displays very low porosity (10 percent) and permeability (0.265 mD) based on 4 samples, and is laterally extensive in the field area (greater than 1 km2). There are nine facies in the Wolverine Federal 17-3 core from the Covenant Field, four of which are tidally influenced. This is unique compare to the Justensen Flat/Devils Canyon outcrop. Tidal influence was apparently present in western Utah but did not have a direct influence on sedimentation 60 kilometers (45 mi) to the east. The Large Trough Cross-stratified (LTC) facies, which serves as the primary reservoir of the Navajo Sandstone, was observed in both outcrop and core. The laterally extensive, low permeability WAM facies was also present in both core and outcrop, suggesting the possibility of reservoir partitioning within oil fields having eolian reservoirs similar to the Navajo Sandstone.

APA, Harvard, Vancouver, ISO, and other styles

22

Ferry, Mark Peter. "An evaluation of the sedimentology and the influence of grain size and facies on permeability for the White Rose A-17 cored interval, White Rose Oilfield, offshore eastern Newfoundland /." Internet access available to MUN users only, 2005. http://collections.mun.ca/u?/theses,16593.

Full text

APA, Harvard, Vancouver, ISO, and other styles

23

Bidgood, Michael John. "Hibernia Formation sequences and Breathitt Group (Kentucky) analogue /." Internet access available to MUN users only, 2003. http://collections.mun.ca/u?/theses,64374.

Full text

APA, Harvard, Vancouver, ISO, and other styles

24

Pethe, Swardhuni. "Subsurface analysis of Sundaland basins : source rocks, structural trends and the distribution of oil fields." 2013. http://liblink.bsu.edu/uhtbin/catkey/1741652.

Full text

Abstract:

According to the Ade observation (Ade, W., pers. Comm.) “95% of all commercial oil fields in the Sumatra region occur within 17 km of seismically mappable structural grabens in the producing basins”. The Ade observation proposes a link between the subsidence of the source rocks (the Talang Akar Formation) in the grabens and the maturity of the organic material. To test the validity of the Ade observation, subsurface mapping of the region was carried out using geophysical logs. Using the well log information, the basement and the formation tops have been mapped with a special emphasis on Talang Akar and Air Benakat Formations. The isopach maps of these formations show that most of the producing wells on the Sunda shelf are in fact located in and around the major structural basins. Trends in the occurrence of the oil fields have also been observed which are analogous to the orientation of the grabens. Structural mapping of the basins have identified several wrench faults. These are of particular interest as wrench faults provide good structural traps for oil in the Los Angeles and the North Sumatra Basins and may prove to be very important for future exploration in southern Sumatra and northwest Java. In South Sumatra Basin, 77.78% of the potential oil fields are located in the 17 km margin from the grabens. For Sunda/Asri Basins and the Ardjuna Basin, it is 100 and 92 respectively. Identifying the source rocks in this 17 km window will enhance the success rate of oil exploration in the Sundaland Basins.
Department of Geological Sciences

APA, Harvard, Vancouver, ISO, and other styles

25

Kılıç, Cem Okan. "Characterization and quantification of middle Miocene reservoirs of starfak and tiger shoal fields, offshore Louisiana, using genetic sequence stratigraphy and neural-networks." Thesis, 2004. http://hdl.handle.net/2152/1342.

Full text

APA, Harvard, Vancouver, ISO, and other styles

26

Philip, Zeno George. "Incorporating subcritical crack growth mechanics into natural fracture characterization for improved reservoir simulation." Thesis, 2003. http://hdl.handle.net/2152/860.

Full text

APA, Harvard, Vancouver, ISO, and other styles

27

Richards, Matthew E. "Subsurface geology of the Santa Clara Avenue oil field and the Las Posas area, Ventura basin, California." Thesis, 1985. http://hdl.handle.net/1957/26496.

Full text

Abstract:

In the Santa Clara Avenue oil field, the nonmarine Sespe Formation of Oligocene age has produced 4 million barrels of oil trapped by a Miocene mafic igneous intrusion that cuts across bedding. Throughout most of the oil field, the Miocene and older beds dip about 15° northwest. The intrusion may be related to the outpouring of Conejo Volcanics throughout much of the southern Ventura basin. The Pacific Farms #1 well penetrated 1000 feet of igneous rocks below 5100 feet, whereas wells less than 500 feet to the northwest penetrated Sespe Formation over this interval. The western wall of the intrusion is located by 10 wells which pass repeatedly through the Sespe-intrusive contact. Structure contours on the intrusive contact with the Sespe on the northwest show Redacted for Privacy that the contact varies from N20°E,80°SE in the southern portion of the field, to N90°E,85°S in the northern end of the field. The southeast wall of the intrusion is not cut by wells, but its location is controlled by a well about 1200 feet southeast of the northwest wall. If the intrusive contact is rotated to its position when it was intruded prior to tilting of the middle and late Miocene Modelo Formation, the Sespe overhangs the igneous body along a contact with a paleo-dip of 80°NW. Lateral closure in the field may be due to early Miocene normal faulting of the Sespe Formation. In the Las Posas area, two faults are documented. Both faults cut the entire Miocene section but do not cut the Pliocene-Pleistocene Pico Formation. The Miocene Vaqueros is found only on the south side of the Las Posas fault. Intra-Sespe correlations show that the upthrown block of the Las Posas fault lost to erosion 1000 feet of Sespe in addition to the Vaqueros Formation. The Epworth syncline and Beryiwood anticline were folded prior to the deposition of the Pico Formation.
Graduation date: 1986

APA, Harvard, Vancouver, ISO, and other styles

28

Jaffri, Ali. "Enhanced recovery from a fractured reservoir using high impact biostratigraphy a case study from the Fim Kassar Oil Field, Pakistan /." 2006. http://digital.library.okstate.edu/etd/umi-okstate-1851.pdf.

Full text

APA, Harvard, Vancouver, ISO, and other styles

29

Soliman, Osama Mahmoud. "Depositional facies and calcite cementation in the Avalon Formation, Hibernia Oil Field, Jeanne d'Arc Basin, Grand Banks of Newfoundland /." 1995. http://collections.mun.ca/u?/theses,83302.

Full text

APA, Harvard, Vancouver, ISO, and other styles

We offer discounts on all premium plans for authors whose works are included in thematic literature selections. Contact us to get a unique promo code!