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69-637: The oil field is south of the town of New Cuyama in the portion of the Cuyama Valley that slopes gently into the northern foothills of the Sierra Madre Mountains. Parts of the field are on hilly terrain, and some is within the Los Padres National Forest . The field can be reached from California State Route 166 via Aliso Canyon Road on the northwest, and Perkins Road on the northeast; Perkins Road joins 166 at

138-434: A consequence of improving the water/oil mobility ratio. Surfactants may be used in conjunction with polymers and hyperbranched polyglycerols ; they decrease the interfacial tension between the oil and water. This reduces the residual oil saturation and improves the macroscopic efficiency of the process. Primary surfactants usually have co-surfactants, activity boosters, and co-solvents added to them to improve stability of

207-523: A lower salinity allows for greater oil removal, and greater geochemical interactions. In this approach, various methods are used to heat the crude oil in the formation to reduce its viscosity and/or vaporize part of the oil and thus decrease the mobility ratio. The increased heat reduces the surface tension and increases the permeability of the oil. The heated oil may also vaporize and then condense forming improved oil. Methods include cyclic steam injection , steam flooding and combustion. These methods improve

276-471: A means of boosting domestic oil production, the US federal tax code began to include incentives for EOR in 1979. Crude oil development and production can include up to three distinct phases: primary, secondary, and tertiary (or enhanced) recovery. During primary recovery, the natural pressure of the reservoir or gravity drive oil into the wellbore, combined with artificial lift techniques (such as pumps) which bring

345-421: A reduction in the surface tension with the reservoir rock. In the case of low pressure reservoirs or heavy oils, CO 2 will form an immiscible fluid, or will only partially mix with the oil. Some oil swelling may occur, and oil viscosity can still be significantly reduced. In these applications, between one-half and two-thirds of the injected CO 2 returns with the produced oil and is usually re-injected into

414-520: Is a census-designated place in the Cuyama Valley , Santa Barbara County, California . It was named after the Chumash word for " clams ", most likely due to the millions of petrified prehistoric clamshell fossils that are found in the surrounding areas. The town is home to the majority of the utility infrastructure for its residents, including nearby neighbor Cuyama, California . New Cuyama

483-476: Is a general term for injection processes that introduce miscible gases into the reservoir. A miscible displacement process maintains reservoir pressure and improves oil displacement because the interfacial tension between oil and gas is reduced. This refers to removing the interface between the two interacting fluids. This allows for total displacement efficiency. Gases used include CO 2 , natural gas or nitrogen. The fluid most commonly used for miscible displacement

552-414: Is captured from industrial facilities such as natural gas processing plants , using carbon capture technology. CO 2 is particularly effective in reservoirs deeper than 2,000 ft., where CO 2 will be in a supercritical state. In high pressure applications with lighter oils, CO 2 is miscible with the oil, with resultant swelling of the oil, and reduction in viscosity, and possibly also with

621-421: Is carbon dioxide because it reduces the oil viscosity and is less expensive than liquefied petroleum gas . Oil displacement by carbon dioxide injection relies on the phase behavior of the mixtures of that gas and the crude, which are strongly dependent on reservoir temperature, pressure and crude oil composition. Using CO 2 for enhanced oil recovery was first investigated and patented in 1952. The process

690-462: Is controversy over whether the overall process is beneficial for the climate. EOR operations are energy-intensive, which leads to more emissions, and further emissions are produced when the oil is burned. EOR adds to the cost of producing oil but can be economically attractive if the price of oil is high. The U.S. Department of Energy estimates that 20 billion tons of captured CO 2 could produce 67 billion barrels of economically recoverable oil. As

759-541: Is located very close to the intersection points for Santa Barbara , San Luis Obispo , Ventura and Kern counties. The town is served by Highway 166 (connecting U.S. Route 101 and Interstate 5 ) and the public-use New Cuyama Airport . The population was 542 at the 2020 census. The area was considered territory of the Yokuts people, but Chumash Indians from the Pacific Coast are also known to have frequented

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828-466: Is of generally medium to high API gravity , ranging from 28 to 36 API, so it flows easily. A small pool in the Dibblee Sand in the now-abandoned Southeast Area of the field had oil of even higher gravity and lower viscosity; a well drilled there in 1975 was abandoned in 1978 after producing 42,000 barrels (6,700 m). Richfield Oil Co., later part of Atlantic Richfield Company ( ARCO ), drilled

897-601: Is provided for regional CCS hubs that focus on the broader capture, transport, and either storage or use of captured CO 2 . Hundreds of millions more are dedicated annually to loan guarantees supporting CO 2 transport infrastructure. The Inflation Reduction Act of 2022 (IRA) updates tax credit law to encourage the use of carbon capture and storage. Tax incentives under the law provide up to $ 85/tonne for CO 2 capture and storage in saline geologic formations or up to $ 60/tonne for CO 2 used for enhanced oil recovery. The Internal Revenue Service relies on documentation from

966-454: Is still in use and easily seen due south of New Cuyama, though ARCO has since sold off interest in the facility. The town of New Cuyama, at its founding, was considered the pearl of eastern Santa Barbara County, due to the flow of oil that was coming out of the region. During this time Richfield Oil Company built the town funded schools and provided all the important utilities other than electricity. Now that oil and gas production have declined,

1035-438: Is the most common method. In this method, CO2 is injected into a depleted oil field and is mostly left underground. CO 2 -EOR is usually performed using CO 2 from naturally-occurring underground deposits. It is also sometimes performed using CO 2 captured from the flue gas of industrial facilities. When EOR is done using CO 2 captured from flue gas, the process can prevent some emissions from escaping. However, there

1104-646: Is used to address the problem of paraffin wax components of the crude oil, which tend to precipitate as the crude flows to the surface, since the Earth's surface is considerably cooler than the petroleum deposits (a temperature drop of 9–10–14 °C per thousand feet of depth is usual). In 2013, a technique called plasma-pulse technology was introduced into the United States from Russia. This technique can result in another 50 percent of improvement in existing well production. Adding oil recovery methods adds to

1173-474: Is usually found to increase overall emissions compared to not using carbon capture at all. If the emissions from burning extracted oil are excluded from calculations, carbon capture with EOR is found to decrease emissions. In arguments for excluding these emissions, it is assumed that oil produced by EOR displaces conventionally-produced oil instead of adding to the global consumption of oil. A 2020 review found that scientific papers were roughly evenly split on

1242-440: Is usually limited by the cost of the chemicals and their adsorption and loss onto the rock of the oil containing formation. In all of these methods the chemicals are injected into several wells and the production occurs in other nearby wells. Polymer flooding consists in mixing long chain polymer molecules with the injected water in order to increase the water viscosity. This method improves the vertical and areal sweep efficiency as

1311-585: The Clean Air Act , which dictates reporting guidelines for any Carbon Dioxide sequestration operations. Beyond the atmospheric concerns, most of these federal guidelines are to ensure that the Carbon Dioxide injection causes no major damage to America's waterways. Overall, the locality of EOR regulation can make EOR projects more difficult, as different standards in different regions can slow down construction and force separate approaches to utilize

1380-595: The Miocene -age Dibblee Sand and the Colgrove Sand, porous units in the Vaqueros Formation underneath the largely impermeable Monterey Formation . The sedimentary Cuyama Basin is cut by many small faults, and the oil exists in a series of stratigraphic traps , where it is in most cases blocked in its upward motion by impermeable blocks of Monterey, often offset by faults. The average depth of oil in

1449-675: The Rancho Cuyama (Lataillade) and Rancho Cuyama (Rojo) , were granted in the 1840s by Governors Manuel Micheltorena and Pío Pico in the lower Cuyama Valley along the Cuyama River , where present-day New Cuyama is, privatizing ownership of the land. Following the 1949 discovery of oil at the South Cuyama Oil Field , in 1952 the Atlantic Richfield Company (ARCO) settled and developed

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1518-582: The United States Census Bureau , the CDP covers an area of 0.7 square miles (1.8 km ), all of it land. New Cuyama has a steppe climate ( BSk ). This region experiences hot and dry summers, with the warmest month having a daily mean of 75 degrees. The 2010 United States Census reported that New Cuyama had a population of 517. The population density was 732.7 inhabitants per square mile (282.9/km ). The racial makeup of New Cuyama

1587-532: The Colgrove and Dibblee formations. The field operators used waterflooding between 1956 and 1973 in the Colgrove, with some success, and both gas injection and waterflooding have been used in the Dibblee Formation commencing in 1964 and 1955, respectively. As of 2008, E&B Resources still uses waterflooding to assist in flow of oil to pumping wells; other wells are designated for water disposal. At

1656-472: The Cuyama Valley from an almost uninhabited region with a few cattle ranches into a mini-boom area; ARCO built the town of New Cuyama in the years after the oil discovery to house the oil workers and provide associated services. ARCO was only the first of several companies to work the New Cuyama Field. In 1990, they sold off their interest in the field to Stream Energy. The next company to operate

1725-658: The Dibblee and Colgrove pools. Production has declined steadily since, with around 820,000 barrels (130,000 m) pumped in 1977, 500,000 in 1987, 390,000 in 1997, and 270,000 in 2007. At the end of 2008, there were only 87 oil wells still in production. Some enhanced recovery projects have been undertaken on the field. Since the oil in the South Cuyama Field is not heavy, steam injection has not been necessary to reduce viscosity and improve flow; however, both gas injection and waterflooding have been used, both in

1794-532: The Perkins Fire, which burned 15,000 acres (61 km) on the north side of the Sierra Madre Mountains. Native vegetation in the vicinity of the field ranges from grassland to chaparral to oak woodland . Drainage is to the north, towards the Cuyama River , along Bitter Creek, Branch Canyon Wash, and several ephemeral drainages. Oil in the South Cuyama Basin comes from two primary pools,

1863-438: The US federal tax code began to include incentives for EOR in 1979, when crude oil was still under federal price controls. A 15 percent tax credit was codified with the U.S. Federal EOR Tax Incentive in 1986, and oil production from EOR using CO 2 subsequently grew rapidly. In the U.S., the 2021 Infrastructure Investment and Jobs Act designates over $ 3 billion for a variety of CCS demonstration projects. A similar amount

1932-698: The Vaqueros Formation. Overlying the faulted and broken Miocene rocks, which include the Monterey , Branch Canyon , and Santa Margarita Formations , and separated by an unconformity , is about 2,000 to 2,500 feet (760 m) of the Pliocene Morales Formation . None of these upper rocks are oil-bearing, although gas has been produced from the Santa Margarita Formation. Oil from the South Cuyama Field

2001-420: The age of 18 living in them, 95 (53.7%) were opposite-sex married couples living together, 15 (8.5%) had a female householder with no husband present, 12 (6.8%) had a male householder with no wife present. There were 15 (8.5%) unmarried opposite-sex partnerships , and 1 (0.6%) same-sex married couples or partnerships . 45 households (25.4%) were made up of individuals, and 20 (11.3%) had someone living alone who

2070-547: The amount of oil recovered in some formations. Dilute solutions of surfactants such as petroleum sulfonates or biosurfactants such as rhamnolipids may be injected to lower the interfacial tension or capillary pressure that impedes oil droplets from moving through a reservoir, this is analyzed in terms of the bond number , relating capillary forces to gravitational ones. Special formulations of oil, water and surfactant, microemulsions , can be particularly effective in reducing interfacial tension. Application of these methods

2139-509: The area. The imprint of an old Indian trail can still be seen leading over the hills of present-day Ventura County to the headwaters of Piru Creek . The name "Cuyama" comes from an Indian village named for the Chumash word kuyam , meaning "clam" or "freshwater mollusk". The area's recorded history dates to 1822, when Mexico won independence from Spain and took over the Spanish colony of Alta California . Two Mexican land grants ,

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2208-470: The climate. The EOR process is energy-intensive because of the need to separate and re-inject CO 2 multiple times to minimize losses. If CO 2 losses are kept at 1%, the energy required for EOR operations results in around 0.23 tonnes of CO 2 emissions per tonne of CO 2 sequestered. Furthermore, when the oil that is extracted using EOR is subsequently burned, CO 2 is released. If these emissions are included in calculations, carbon capture with EOR

2277-508: The corporation to substantiate claims on how much CO 2 is being sequestered, and does not perform independent investigations. In 2020, a federal investigation found that claimants for the 45Q tax credit failed to document successful geological storage for nearly $ 900 million of the $ 1 billion they had claimed. One of the primary regulations governing EOR is the Safe Drinking Water Act of 1974 (SDWA), which gives most of

2346-400: The cost of oil—in the case of CO 2 typically between 0.5–8.0 US$ per tonne of CO 2 . The increased extraction of oil on the other hand, is an economic benefit with the revenue depending on prevailing oil prices . Onshore EOR has paid in the range of a net 10–16 US$ per tonne of CO 2 injected for oil prices of 15–20 US$ / barrel . Prevailing prices depend on many factors but can determine

2415-415: The economic suitability of any procedure, with more procedures and more expensive procedures being economically viable at higher prices. Example: With oil prices at around 90 US$ /barrel, the economic benefit is about 70 US$ per tonne CO 2 . The U.S. Department of Energy estimates that 20 billion tons of captured CO 2 could produce 67 billion barrels of economically recoverable oil. From 1986 to 2008,

2484-473: The end of 2008, the average water cut – the percentage of liquid pumped from oil wells that was water – was running at 98.4 percent, indicating a field very close to the end of its useful life. Wells on the field were producing an average of 7.9 barrels of oil per day, and the operators have been reinjecting the enormous quantities of water produced with the oil back into the formation through approximately 50 water disposal and water flood wells scattered throughout

2553-540: The field is about 4,200 feet (1,300 m) below ground surface, and the thickness of the oil-bearing units rarely exceeds 200 feet (61 m); in the separate southeastern area of the field, where the Colgrove sand is 5,840 feet (1,780 m) below ground surface, the oil bearing rock is only 50 feet (15 m) thick. The source rock for the South Cuyama oil is most likely the Soda Lake Shale member of

2622-411: The field to enhance recovery, or used as fuel for oilfield operations. NGLs are sent to a tank farm where they are mixed with the oil. Santa Barbara County gave the plant its first permit to operate in 1988. 34°53′52″N 119°42′20″W  /  34.8977°N 119.7055°W  / 34.8977; -119.7055 New Cuyama, California New Cuyama ( Chumash : Kuyam , meaning "Clam")

2691-476: The field was Hallador Petroleum, which continued operations until 2005, at which time it sold its interest to E&B Natural Resources Management Corporation, the current operator, which also runs the Russell Ranch field four miles (6 km) to the northwest. Peak production for the field was in 1951, shortly after discovery, during which over 14 million barrels (2,200,000 m) of oil were pumped from

2760-434: The field. E&B also maintains a gas processing plant, known as Gas Plant 10, on the eastern side of the oil field; all natural gas production from the oil wells goes there. The purpose of the gas plant is to strip out hydrogen sulfide, nitrogen, carbon dioxide, water, and natural gas liquids (NGLs) from the gas, making it acceptable for commercial use. After processing at the plant it is sent on for sale, reinjected into

2829-416: The first approach, bacterial cultures mixed with a food source (a carbohydrate such as molasses is commonly used) are injected into the oil field. In the second approach, used since 1985, nutrients are injected into the ground to nurture existing microbial bodies; these nutrients cause the bacteria to increase production of the natural surfactants they normally use to metabolize crude oil underground. After

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2898-450: The first well in the area to hit oil, on the advice of Thomas Dibblee , in May 1949. Richfield named the oil-bearing unit, the Dibblee Sand, in his honor. This single well initially produced 525 barrels per day (83.5 m/d), a large find for a region previously written off as being without petroleum potential. The discovery of oil here and in the nearby Russell Ranch Oil Field transformed

2967-439: The flame front. As the fire burns, it moves through the reservoir toward production wells. Heat from the fire reduces oil viscosity and helps vaporize reservoir water to steam. The steam, hot water, combustion gas and a bank of distilled solvent all act to drive oil in front of the fire toward production wells. There are three methods of combustion: Dry forward, reverse and wet combustion. Dry forward uses an igniter to set fire to

3036-833: The formulation. Caustic flooding is the addition of sodium hydroxide to injection water. It does this by lowering the surface tension, reversing the rock wettability, emulsification of the oil, mobilization of the oil and helps in drawing the oil out of the rock. EOR processes can be enhanced with nanoparticles in three ways: nanocatalysts, nanofluids , and nanoemulsions. Nanofluids are base fluids that contain nanoparticles in colloidal suspensions. Nanofluids perform many functions in EOR of oil fields, including pore disjoining pressure, channel plugging, interfacial tension reduction, mobility ratio, wettability alteration, and asphaltene precipitation prevention. Nanofluids facilitates disjoining pressure to remove sediment entrapped oil via aggregation at

3105-641: The injected nutrients are consumed, the microbes go into near-shutdown mode, their exteriors become hydrophilic , and they migrate to the oil-water interface area, where they cause oil droplets to form from the larger oil mass, making the droplets more likely to migrate to the wellhead. This approach has been used in oilfields near the Four Corners and in the Beverly Hills Oil Field in Beverly Hills, California . The third approach

3174-631: The interface. Alternatively, wettability alteration and interfacial surface tension reduction are other alternative mechanism of EOR. Microbial injection is part of microbial enhanced oil recovery and is rarely used because of its higher cost and because the development is not widely accepted. These microbes function either by partially digesting long hydrocarbon molecules, by generating biosurfactants , or by emitting carbon dioxide (which then functions as described in Gas injection above). Three approaches have been used to achieve microbial injection. In

3243-532: The oil to the surface. But only about 10 percent of a reservoir's original oil in place is typically produced during primary recovery. Secondary recovery techniques extend a field's productive life generally by injecting water or gas to displace oil and drive it to a production wellbore, resulting in the recovery of 20 to 40 percent of the original oil in place. Producers have attempted several tertiary, or enhanced oil recovery (EOR), techniques that offer prospects for ultimately producing 30 to 60 percent, or more, of

3312-421: The oil well for larger recovery, as they typically have low miscibility with oil. Use of both water and carbon dioxide also lowers the mobility of carbon dioxide, making the gas more effective at displacing the oil in the well. According to a study done by Kovscek, using small slugs of both carbon dioxide and water allows for quick recovery of the oil. Additionally, in a study done by Dang in 2014, using water with

3381-429: The oil. As the fire progresses the oil is pushed away from the fire toward the producing well. In reverse the air injection and the ignition occur from opposite directions. In wet combustion water is injected just behind the front and turned into steam by the hot rock. This quenches the fire and spreads the heat more evenly. The injection of various chemicals, usually as dilute solutions, have been used to aid mobility and

3450-402: The population) lived in owner-occupied housing units and 204 people (39.5%) lived in rental housing units. Enhanced oil recovery Enhanced oil recovery (abbreviated EOR ), also called tertiary recovery , is the extraction of crude oil from an oil field that cannot be extracted otherwise. Whereas primary and secondary recovery techniques rely on the pressure differential between

3519-476: The principal industry is once again agriculture. In 2024, Santa Barbara County approved the construction of a mixed-use development project, including 33 residential units, in New Cuyama. New Cuyama is located at 34°56′53″N 119°41′21″W  /  34.947933°N 119.68915°W  / 34.947933; -119.68915 (34.947933, -119.68915). It is situated in the Cuyama Valley . According to

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3588-413: The produced water deep underground. Carbon dioxide can be captured from the flue gas of an industrial facility such as natural gas processing plant or a coal power plant. If captured CO2 is used for EOR, the process is known as carbon capture-EOR (CC-EOR) and is a form of carbon capture and storage . There is controversy over whether carbon capture followed by enhanced oil recovery is beneficial for

3657-478: The question of whether carbon capture with EOR increased or decreased emissions. When the CO 2 used in EOR is sourced from underground CO 2 deposits, which is usually the case, EOR provides no climate benefit. In the US, regulations can both assist and slow down the development of EOR for use in carbon capture & utilization, as well as general oil production. As a means of boosting domestic oil production,

3726-539: The quote oil production deriving from EOR has increased from 0.3% to 5%, thanks to an increasing oil demand and a reduction of oil supply. Enhanced oil recovery wells typically pump large quantities of produced water to the surface. This water contains brine and may also contain toxic heavy metals and radioactive substances . This can be very damaging to drinking water sources and the environment generally if not properly controlled. Disposal wells are used to prevent surface contamination of soil and water by injecting

3795-400: The reduction in surface tension . Injection of alkaline or caustic solutions into reservoirs with oil that have organic acids naturally occurring in the oil will result in the production of soap that may lower the interfacial tension enough to increase production. Injection of a dilute solution of a water-soluble polymer to increase the viscosity of the injected water can increase

3864-598: The regulatory power over EOR and similar oil recovery operations to the EPA . The agency in turn delegated some of this power to its own Underground Injection Control Program, and much of the rest of this regulatory authority to state and tribal governments, making much of EOR regulation a localized affair under the minimum requirements of the SDWA. The EPA then collects information from these local governments and individual wells to ensure they follow overall federal regulation, such as

3933-507: The reservoir to minimize operating costs. The remainder is trapped in the oil reservoir by various means. Carbon dioxide as a solvent has the benefit of being more economical than other similarly miscible fluids such as propane and butane . Water-alternating-gas (WAG) injection is another technique employed in EOR. Water is used in addition to carbon dioxide. A saline solution is used here so that carbonate formations in oil wells are not disturbed. Water and carbon dioxide are injected into

4002-401: The reservoir's original oil in place. The main classes of EOR technologies are: In 2017, there were 374 EOR projects worldwide. Of these, 44% were CO 2 -EOR, 12% were other gas injection EOR, 32% were thermal EOR, 9% were chemical EOR, and 2% were other EOR methods. Gas injection or miscible flooding is presently the most-commonly used approach in enhanced oil recovery. Miscible flooding

4071-497: The steam zone the oil evaporates, and in the hot water zone the oil expands. As a result, the oil expands, the viscosity drops, and the permeability increases. To ensure success the process has to be cyclical. This is the principal enhanced oil recovery program in use today. Fire flooding works best when the oil saturation and porosity are high. Combustion generates the heat within the reservoir itself. Continuous injection of air or other gas mixture with high oxygen content will maintain

4140-588: The surface and the underground well, enhanced oil recovery functions by altering the physical or chemical properties of the oil itself in order to make it easier to extract. When EOR is used, 30% to 60% or more of a reservoir's oil can be extracted, compared to 20% to 40% using only primary and secondary recovery . There are four main EOR techniques: carbon dioxide (CO 2 ) injection, other gas injection, thermal EOR, and chemical EOR. More advanced, speculative EOR techniques are sometimes called quaternary recovery . Carbon dioxide injection, known as CO 2 -EOR,

4209-493: The sweep efficiency and the displacement efficiency. Steam injection has been used commercially since the 1960s in California fields. In solar thermal enhanced oil recovery , a solar array is used to produce the steam. Steam flooding (see sketch) is one means of introducing heat to the reservoir by pumping steam into the well with a pattern similar to that of water injection. Eventually the steam condenses to hot water; in

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4278-437: The total productive area as reported by DOGGR is 2,650 acres (10.7 km). The climate is semi-arid, with occasional marine influence, as the Cuyama Valley is open to the sea, although through a narrow gap. Summers are hot with temperatures commonly exceeding 100 °F (38 °C); winters are cool, with the mean freeze-free period being about 250 days. Average annual rainfall is about 12 inches, almost all of it falling in

4347-517: The town of New Cuyama, building housing and associated commercial business – including the New Cuyama Airport (L88), reopened in May 2015, which bears the distinction of being the only public-use paved airport within easy flying range of Los Angeles for more than 50 miles (80 km). Much of the infrastructure from ARCO's settling of the town still exists today and is used by town residents. The original ARCO-built gas processing plant

4416-441: The town of New Cuyama. While these roads run roughly north-south, Foothill Road crosses through the field from east to west, eventually reaching Santa Barbara Canyon Road on the east and State Route 33 . Elevations on the field range from approximately 2,200 to 3,000 feet (670 to 910 meters). The productive area of the field is approximately 4 miles (6.4 km) long by two across, with the long axis running northwest to southeast;

4485-512: The winter in the form of rain, although occasional snowfall has occurred. All streams are dry in the summer, and even the Cuyama River dries up by the late summer in most years. The area is prone to brushfires in the summer and fall; indeed a fire in 1994 caused a loss of $ 76,000 to the operators, and in July 2006 an accident on the oil field involving a metal plate crossing power lines started

4554-407: Was 35.1 years. For every 100 females, there were 105.2 males. For every 100 females age 18 and over, there were 97.2 males. There were 215 housing units at an average density of 304.7 units per square mile (117.6 units/km ), of which 119 (67.2%) were owner-occupied, and 58 (32.8%) were occupied by renters. The homeowner vacancy rate was 1.7%; the rental vacancy rate was 9.2%. 313 people (60.5% of

4623-504: Was 418 (80.9%) White , 3 (0.6%) African American , 14 (2.7%) Native American , 3 (0.6%) Asian , 0 (0.0%) Pacific Islander , 53 (10.3%) from other races , and 26 (5.0%) from two or more races. Hispanic or Latino of any race were 234 persons (45.3%). The Census reported that 517 people (100% of the population) lived in households, 0 (0%) lived in non-institutionalized group quarters, and 0 (0%) were institutionalized. There were 177 households, out of which 69 (39.0%) had children under

4692-403: Was 65 years of age or older. The average household size was 2.92. There were 122 families (68.9% of all households); the average family size was 3.54. The population was spread out, with 160 people (30.9%) under the age of 18, 43 people (8.3%) aged 18 to 24, 125 people (24.2%) aged 25 to 44, 126 people (24.4%) aged 45 to 64, and 63 people (12.2%) who were 65 years of age or older. The median age

4761-622: Was first commercially attempted in 1977 in Scurry County , Texas . Since then, the process has become extensively used in the Permian basin region of the US and is now more recently is being pursued in many different states. It is now being more actively pursued in China and throughout the rest of the world. Most CO 2 injected in CO 2 -EOR projects comes from naturally occurring underground CO 2 deposits. Some CO 2 used in EOR

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