Browsing by Subject "CO2-EOR (Enhanced oil recovery)"

Now showing 1 - 13 of 13

Analysis of time lapse seismic signal analysis for an EOR and CCS site, Cranfield, MS
(82nd Annual Meeting of the Society for Exploration Geophysics,, 2012-11-04) Ditkof, Julie; Meckel, Tip; Hovorka, Susan; Caspari, Eva; Pevzner, Roman; Urosevic, Milovan
The Cranfield, MS EOR field site has been under CO2 flood by Denbury Onshore, LLC since 2008. More than 3 million tons of CO2 has been injected. Time-lapse 3D surface seismic data displayed a readily observable signal related to CO2 injection into the lower Tuscaloosa Formation. The intensity and the spatial distribution of time-lapse (TL) signal required further analysis. For that purpose, we carried out fluid substitution analysis, followed by volumes cross-equalization, well ties, and acoustic impedance inversions. A Gassmann workflow was used to predict the response to injected CO2 at two well locations. The 31F-2 observation well, located in a detailed area of study (DAS), was used to compare the results of time-lapse sonic data with fluid substitution results. The objective was to predict a postinjection saturation curve. A second well, well 28-1, was used to help predict an acoustic impedance change in the reservoir to use for subsequent inversion. Finally, a model based inversion was performed to quantify the impedance change between two cross-equalized timelapse data sets. The acoustic impedance (AI) difference obtained through the inversion process is higher than that predicted for in the 28-1 injection well. The time-lapse AI signal is however in agreement with the large velocity change computed from the time delay along the marker horizon below the reservoir.
Assessment of Geological Storage Capacity of the Southeastern U.S. for CO2 in Brines and Economic Use for EOR
(SECARB Industry Briefing, 2006-01-18) Hovorka, Susan D.; Holtz, Mark H.; Smyth, Rebecca C.; Nunez Lopez, Vanessa; Kim, Eugene; Breton, Catherine L.; Scanlon, Bridget R.; Reedy, Reedy C.; Paine, Jeffrey; Tinker, Scott; Duncan, Ian
Case Study: Monitoring an EOR project to document sequestration value
(2008) Hovorka, Susan D.
CO2-EOR as geologic storage: Monitoring for permanence
(NA 2050 Sequestration Working Group, 2013-10-08) Hovorka, Susan D.
Diagenesis and reservoir heterogeneity in the Lower Tuscaloosa Formation at Cranfield Field, Mississippi
(60th Annual Convention of the Gulf Coast Association of Geologicial Societies and the Gulf Coast Section of SEPM, 2010-10-10) Kordi, M.; Hovorka, S.; Milliken, K.; Trevino, R.; Lu, J.
The Cretaceous Lower Tuscaloosa Formation in the Cranfield Field, Mississippi, is a siliciclastic reservoir and target for geologic CO2 sequestration and enhanced oil recovery (EOR). The reservoir is approximately 3 km deep with an average thickness of 30 m. Samples and data are from six wells at the Cranfield Field including whole cores from four wells and multiple sidewall cores from two wells. The lower Tuscaloosa Formation consists of fining-upward fluvial cycles. The lowermost parts of the fluvial channels are typically composed of conglomerate, and contain a significant component of chert pebbles. The conglomerate is overlain by light gray course to medium to fine-grained sandstones with minor interbedded mudstone. Petrographic analysis indicates that both original composition and diagenesis extensively affect reservoir heterogeneity. In highly porous and permeable zones, the dominant controls on reservoir quality include the original coarse-grained texture, low compaction, formation of thick chlorite cement rims around grains preventing formation of quartz overgrowth, and formation of secondary porosity by dissolution of rock fragments and cements. Conversely, in the zones of low porosity and permeability, diagenetic events which are the most destructive of reservoir quality include high compaction, formation of carbonate, authigenic kaolinite, Feoxide and quartz cement. The presence of thin chlorite cement rims in the upper portion of the reservoir did not prevent formation of quartz overgrowths which is, overall, the most important factor reducing the porosity and permeability.
Economic analysis of an integrated anthropogenic carbon dioxide network for capture and enhanced oil recovery along the Texas Gulf Coast
(Proceedings of the ASME 3rd International Conference on Energy Sustainability, 2009-07-19) King, Carey W.; Gülen, Gürcan; Essandoh-Yeddu, Joseph; Hovorka, Susan
This paper explains the system economics of an example integrated network that uses anthropogenic CO2 from Texas Gulf Coast fossil power plants for enhanced oil recovery (EOR). These CO2 sources and sinks are connected via a pipeline network. A discounted cash flow model indicates that for all candidate oil fields that require less than an estimated $10/BBL in EOR capital expenditure, all three entities (CO2 capture, pipelines, and EOR operators) can have 20% internal rate of return at $55 per tonne of CO2 and $56 per barrel of oil. These results include no existing or future tax incentives, and there are some costs not yet included. However, a Monte Carlo analysis shows insight by indicating that the total system rate of return is most sensitive to oil production parameters. Oil price and estimated amount of recoverable oil are the most positively influential factors while the EOR capital cost is the most negatively sensitive factor. The capital costs of capture and CO2 price are less sensitive, both negatively affecting rate of return.
Economic modeling of carbon dioxide integrated pipeline network for enhanced oil recovery and geologic sequestration in the Texas Gulf Coast region
(9th International Conference on Greenhouse Gas Control Technologies (GHGT-9), 2008-11-16) Essandoh-Yeddu, Joseph; Gülen, Gürcan
Naturally occurring CO2 is transported via pipelines to oil fields in West Texas to enhance production. A similar pipeline system is proposed for the Gulf Coast region of Texas. The CO2 would come from anthropogenic sources. Using GIS data, oil fields and CO2 sources are selected and a pipeline route is designed, taking into consideration rights of way and environmental sensitivities. We modified several pipeline cost models from the literature to capture recent construction cost escalations. Our resulting cost estimates agree with mid-to-high range cost quotes for pipelines reported to the Federal Energy Regulatory Commission by the companies.
EOR as sequestration: Geoscience perspective
(Symposium on Role of EOR in Accelerating Deployment of CCS, 2010-07-23) Hovorka, Susan D.; Tinker, Scott W.
CO2 Enhanced Oil Recovery (EOR) has a development and operational history several decades longer than geologic sequestration of CO2 designed to benefit the atmosphere and provides much of the experience on which confidence in the newer technology is based. With modest increases in surveillance and accounting, future CO2 EOR using anthropogenic CO2 (CO2-A) captured to decrease atmospheric emissions can be used as part of a sequestration program.
Executive summary: Recent results of the SACROC groundwater geochemistry summary
(Federal Requirements Under the Underground Injection Control (UIC) Program for Carbon Dioxide (CO2) Geologic Sequestration (GS) Wells – Notice of Data Availability and Request for Comment (EPA-HQ-OW-2008- 0390-0297), 2008) Romanak, Katherine D.; Smyth, Rebecca C.; Yang, Changbing; Hovorka, Susan D.; Nicot, Jean-Philipe; Lu, Jiemin
Gulf Coast Carbon Center 2011-2014 Retrospective
(2015) Meckel, T. A.; Treviño, R. H.; Carr, D. L.; Hosseini, S. A.; Lu, J.; Núñez-López, V.; Hovorka, S. D.; Sun, A.; Yang, C.; Anderson, J.; Patson, M.; Romanak, K. D.; Smyth, R. C.; Olson, H. C.
Source-Sink Matching and Potential for Carbon Capture and Storage in the Gulf Coast
(Proceedings of the 2006 UIC Conference of the Groundwater Protection Council, 2006) Ambrose, William A.; Breton, Caroline L.; Duncan, Ian; Holtz, Mark H.; Hovorka, Susan D.; Núñez-López, Vanessa; Lakshminarasimhan, Srivatsan
Current global levels of anthropogenic CO2 emissions are 25.6 Gigatons yr. Approximately 1 Gigaton comes from the Texas, Louisiana, and Mississippi Gulf Coast, representing 16 percent of the U.S. annual CO2 emissions from fossil fuels. The Gulf Coast region provides an opportunity for addressing the problem. Geologic sequestration results from the capturing of CO2 from combustion products and injecting the compressed gas as a supercritical fluid into subsurface brine aquifers for long-term storage. The Gulf Coast overlies an unusually thick succession of highly porous and permeable sand aquifers separated by thick shale aquitards. The Gulf Coast also has a large potential for enhanced oil recovery (EOR), in which CO2 injected into suitable oil reservoirs could be used first for EOR and then for large-volume, long-term storage of CO2 in nonproductive formations below the reservoir interval. For example, there are numerous opportunities for locating CO2 injection wells either in fields for EOR or in stacked brine aquifers near potential FutureGen sites, where a near-zero emission facility would generate primarily hydrogen and CO2 as by-products. We estimate that in the Gulf Coast, outside of the traditional area of CO2 EOR in the Permian Basin, an additional 4.5 billion barrels of oil could be produced by using miscible CO2. At $60 per barrel, this incremental production is estimated to have a wellhead value of $270 billion that could generate more than $40 billion in taxes.
Texas as a National Sink
(UK-Texas Technical Workshop, Houston, Texas, 2008-12-08) Hovorka, Susan D.; Meckel, Tip; Tinker, Scott
What to do with CO2: The Knowns and Unknowns of Geologic Sequestration and CO2 EOR in Greenhouse Gas Context
(Austin Professional Landmen’s Association, Austin, Texas, 2008-05-30) Hovorka, Susan D.