Spectroscopic Determination of Chromium(VI) during the Reduction of Chromium(VI) to Chromium(III)

This is the published version. Copyright 1991 Society for Applied SpectroscopyReduction of chromium(VI) to chromium(III) by thiourea between pH 3.0 and 5.5 is a key aspect of the chromium(VI)/thiourea/polyacrylamide gel polymer system used in enhanced oil recovery processes. A method has been developed to determine chromium(VI) concentration during the reduction of chromium(VI) to chromium(III) in this pH range. The reduction reaction is run in the presence of an acetic acid/sodium acetate buffer which reacts with the chromium(III) produced and prevents the formation of a brown precipitate which forms in the absence of the buffer. With interference from the precipitate eliminated, chromium(VI) concentration is determined from the visible absorbance of the reaction mixture and the unique molar absorptivity spectra of the five chromium species present in the reaction mixture. An average error of approximately 1% between known and measured chromium(VI) concentrations was demonstrated over a chromium(VI) concentration range from 0.0005 to 0.0025 M

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

The objective of this project is to demonstrate incremental reserves from Osagian and Meramecian (Mississippian) dolomite reservoirs in western Kansas through application of reservoir characterization to identify areas of unrecovered mobile oil. The project addresses producibility problems in two fields: Specific reservoirs target the Schaben Field in Ness County, Kansas, and the Bindley Field in Hodgeman County, Kansas. The producibility problems to be addressed include inadequate reservoir characterization, drilling and completion design problems, non-optimum recovery efficiency. The results of this project will be disseminated through various technology transfer activities. At the Schaben demonstration site, the Kansas team will conduct a field project to demonstrate better approaches to identify bypassed oil within and between reservoir units

Polyelectrolyte Complex Nanoparticles for Protection and Delayed Release of Enzymes in Alkaline pH and at Elevated Temperature during Hydraulic Fracturing of Oil Wells

Please note that this is an author-produced PDF of an article accepted for publication following peer review. The definitive version is available at www3.interscience.wiley.comPolyethylenimine-dextran sulfate polyelectrolyte complexes (PEC) were used to entrap two enzymes used to degrade polymer gels following hydraulic fracturing of oil wells in order to obtain delayed release and to protect the enzyme from harsh conditions. Degradation, as revealed by reduction in viscoelastic moduli, of borate-crosslinked hydroxypropyl guar gel by commercial enzyme loaded in polyelectrolyte nanoparticles was delayed up to 11 hours, compared to about three hours for equivalent systems where the enzyme mixture was not entrapped. PEC nanoparticles also protected both enzymes from denaturation at elevated temperature and pH

Field Demonstration of Carbon Dioxide Miscible Flooding in the Lansing-Kansas City Formation, Central Kansas

A pilot carbon dioxide miscible flood was initiated in the Lansing Kansas City C formation in the Hall Gurney Field, Russell County, Kansas. The reservoir zone is an oomoldic carbonate located at a depth of about 2900 feet. The pilot consists of one carbon dioxide injection well and three production wells. Continuous carbon dioxide injection began on December 2, 2003. By the end of June 2005, 16.19 MM lb of carbon dioxide was injected into the pilot area. Injection was converted to water on June 21, 2005 to reduce operating costs to a breakeven level with the expectation that sufficient carbon dioxide was injected to displace the oil bank to the production wells by water injection. By March 7,2010, 8,736 bbl of oil were produced from the pilot. Production from wells to the northwest of the pilot region indicates that oil displaced from carbon dioxide injection was produced from Colliver A7, Colliver A3, Colliver A14 and Graham A4 located on adjacent leases. About 19,166 bbl of incremental oil were estimated to have been produced from these wells as of March 7, 2010. There is evidence of a directional permeability trend toward the NW through the pilot region. The majority of the injected carbon dioxide remains in the pilot region, which has been maintained at a pressure at or above the minimum miscibility pressure. Estimated oil recovery attributed to the CO2 flood is 27,902 bbl which is equivalent to a gross CO2 utilization of 4.8 MCF/bbl. The pilot project is not economic

FIELD DEMONSTRATION OF CARBON DIOXIDE MISCIBLE FLOODING IN THE LANSING-KANSAS CITY FORMATION, CENTRAL KANSAS

A pilot carbon dioxide miscible flood was initiated in the Lansing Kansas City C formation in the Hall Gurney Field, Russell County, Kansas. Continuous carbon dioxide injection began on December 2, 2003. By the end of December 2004, 11.39 MM lb of carbon dioxide were injected into the pilot area. Carbon dioxide injection rates averaged about 242 MCFD. Vent losses were excessive during June as ambient temperatures increased. Installation of smaller plungers in the carbon dioxide injection pump reduced the recycle and vent loss substantially. Carbon dioxide was detected in one production well near the end of May and in the second production well in August. No channeling of carbon dioxide was observed. The GOR has remained within the range of 3000-4000 for most the last six months. Wells in the pilot area produced 100% water at the beginning of the flood. Oil production began in February, increasing to an average of about 2.35 B/D for the six month period between July 1 and December 31. Cumulative oil production was 814 bbls. Neither well has experienced increased oil production rates expected from the arrival of the oil bank generated by carbon dioxide injection

Deep Underground Science and Engineering Laboratory - Preliminary Design Report

The DUSEL Project has produced the Preliminary Design of the Deep Underground Science and Engineering Laboratory (DUSEL) at the rehabilitated former Homestake mine in South Dakota. The Facility design calls for, on the surface, two new buildings - one a visitor and education center, the other an experiment assembly hall - and multiple repurposed existing buildings. To support underground research activities, the design includes two laboratory modules and additional spaces at a level 4,850 feet underground for physics, biology, engineering, and Earth science experiments. On the same level, the design includes a Department of Energy-shepherded Large Cavity supporting the Long Baseline Neutrino Experiment. At the 7,400-feet level, the design incorporates one laboratory module and additional spaces for physics and Earth science efforts. With input from some 25 science and engineering collaborations, the Project has designed critical experimental space and infrastructure needs, including space for a suite of multidisciplinary experiments in a laboratory whose projected life span is at least 30 years. From these experiments, a critical suite of experiments is outlined, whose construction will be funded along with the facility. The Facility design permits expansion and evolution, as may be driven by future science requirements, and enables participation by other agencies. The design leverages South Dakota's substantial investment in facility infrastructure, risk retirement, and operation of its Sanford Laboratory at Homestake. The Project is planning education and outreach programs, and has initiated efforts to establish regional partnerships with underserved populations - regional American Indian and rural populations

Field Demonstration of Carbon Dioxide Miscible Flooding in the Lansing-Kansas City Formation, Central Kansas

Progress is reported for the period from January 1, 2002 to March 31, 2002. Technical design and budget for a larger (60-acre, 24.3 ha) CO2 demonstration project are being reviewed by the US DOE for approval. While this review process is being conducted, work is proceeding on well testing to obtain reservoir properties and on the VIP reservoir simulation model to improve model prediction and better understand the controls that certain parameters exert on predicted performance. In addition, evaluation of the economics of commercial application in the surrounding area was performed. In a meeting on January 14, 2002 the possibility of staging the demonstration, starting with a 10-acre sub-pattern flood was raised and the decision made to investigate this plan in detail. The influence of carbon dioxide on oil properties and the influence of binary interaction parameters (BIP) used in the VIP simulator were investigated. VIP calculated swelling factors are in good agreement with published values up to 65% mole-fraction CO2. Swelling factor and saturated liquid density are relatively independent of the BIP over the range of BIPs used (0.08-0.15) up to 65% mole-fraction CO2. Assuming a CO2 EOR recovery rate projected as being most likely by current modeling, commercial scale CO2 flooding at $20/BO is possible in the leases in Hall-Gurney field. Relatively small floods (240-320 acres, 4-6 patterns) are economically viable at$20/BO in areas of very high primary and secondary productivity (>14 MBO/net acre recovery). Leases with moderately high primary and secondary productivity (> 10 MBO/net acre recovery) can be economic when combined with high productivity leases to form larger floods (>640 acres, 9 or more patterns)

The Long-Baseline Neutrino Experiment: Exploring Fundamental Symmetries of the Universe

The preponderance of matter over antimatter in the early Universe, the dynamics of the supernova bursts that produced the heavy elements necessary for life and whether protons eventually decay --- these mysteries at the forefront of particle physics and astrophysics are key to understanding the early evolution of our Universe, its current state and its eventual fate. The Long-Baseline Neutrino Experiment (LBNE) represents an extensively developed plan for a world-class experiment dedicated to addressing these questions. LBNE is conceived around three central components: (1) a new, high-intensity neutrino source generated from a megawatt-class proton accelerator at Fermi National Accelerator Laboratory, (2) a near neutrino detector just downstream of the source, and (3) a massive liquid argon time-projection chamber deployed as a far detector deep underground at the Sanford Underground Research Facility. This facility, located at the site of the former Homestake Mine in Lead, South Dakota, is approximately 1,300 km from the neutrino source at Fermilab -- a distance (baseline) that delivers optimal sensitivity to neutrino charge-parity symmetry violation and mass ordering effects. This ambitious yet cost-effective design incorporates scalability and flexibility and can accommodate a variety of upgrades and contributions. With its exceptional combination of experimental configuration, technical capabilities, and potential for transformative discoveries, LBNE promises to be a vital facility for the field of particle physics worldwide, providing physicists from around the globe with opportunities to collaborate in a twenty to thirty year program of exciting science. In this document we provide a comprehensive overview of LBNE's scientific objectives, its place in the landscape of neutrino physics worldwide, the technologies it will incorporate and the capabilities it will possess.Comment: Major update of previous version. This is the reference document for LBNE science program and current status. Chapters 1, 3, and 9 provide a comprehensive overview of LBNE's scientific objectives, its place in the landscape of neutrino physics worldwide, the technologies it will incorporate and the capabilities it will possess. 288 pages, 116 figure

Field Demonstration of Carbon Dioxide Miscible Flooding in the Lansing-Kansas City Formation Progress Report

Progress is reported for the period from July 1, 2003 to September 30, 2003. Conductivity testing between the CO{sub 2}I No.1 and CO{sub 2} No.13 was performed over the period 08/20/03 through 09/05/03. Observed response in CO{sub 2} 13 production rates to changes in CO{sub 2}I No.1 injection rates are consistent with sufficient permeability between CO{sub 2}I No.1 and CO{sub 2} No.13 for a viable CO{sub 2} flood with a sufficient Process Pore Volume Rate (PPV). Based on the permeabilities near the CO{sub 2} No.16, a 2-producing well pattern has been determined to be optimal but may be changed during the flood depending on the response observed in the CO{sub 2} No.16. Present inter-well test results indicate there is greater permeability architecture complexity than originally predicted and that a low-permeability region or barrier that restricts but does stop flow may exist between the CO{sub 2}I No.1 and the CO{sub 2} No.13. Pilot area repressurization began on 09/05/03, immediately after CO{sub 2}I No.1-CO{sub 2} No.13 conductivity testing was complete, by increasing injection in the CO{sub 2}I No.1, CO{sub 2} No.10, and CO{sub 2} No.18. Adequate reservoir pressure in the portion of the pilot area needed to be above minimum miscibility pressure should be reached in November at which time initial CO{sub 2} injection could begin. It is estimated the 2-producing well, 10+-acre (4.05 ha) producing pattern will produce 18,000-21,000 BO (barrels oil; 2,880-3,360 m{sup 3}). Depending primarily on surface facilities costs, operating expenses, and the price of oil, for the predicted range of oil recovery the pilot is estimated to either break-even or be profitable from this point forward. Final arrangements and agreements for CO{sub 2} supply and delivery are being worked on and will be finalized in the next month

Field Demonstration of Carbon Dioxide Miscible Flooding in the Lansing-Kansas City Formation, Central Kansas

Progress is reported for the period from October 1, 2002 to December 31, 2002. On September 27, 2002 the US DOE approved the proposed modified plan to flood a 10+-acre pattern. On November 1, 2002 Murfin Drilling Company purchased the 70-acre pilot area and will continue as the operator of the pilot. Murfin is seeking working interest partners and meetings with local small independents were conducted. To date, White Eagle Resources and John O. Farmer Oil Company have committed to working interest in the project. Arrangements have been made with Rein Operating to test the Rein No. 7 water supply well on the neighboring lease. Based on review of wellbore conditions in the Colliver No. 9 and No. 16 it has been decided to use the No. 16 in the pilot. A new tank battery was installed near the Colliver No. 10 well and the existing producers plumbed to the new tank battery to isolate production from the pilot area. Reservoir simulations have indicated that the low-permeability interval in the Carter-Colliver CO2I No. 1 injection well below 2,900 ft does not exhibit sufficient injectivity to warrant special stimulation or conformance treatment programs at the present time. Discussions have been initiated with FLOCO2 and preliminary conditions have been agreed upon for the exchange of CO2 for the use of storage and pump equipment at the pilot. A short-term injection test and the well reworks have been scheduled. Proposed modifications to the project plan were reviewed in the previous quarterly technical progress report. A presentation was given at the DOE Class II Review Meeting in Midland, TX on December 12, 2002