Sample records for bouri oil field

  1. Environment and Behavior of 2.5-Million-Year-Old Bouri Hominids

    Microsoft Academic Search

    Jean de Heinzelin; J. Desmond Clark; Tim White; William Hart; Paul Renne; Giday Woldegabriel; Yonas Beyene; Elisabeth Vrba

    1999-01-01

    The Hata Member of the Bouri Formation is defined for Pliocene sedimentary outcrops in the Middle Awash Valley, Ethiopia. The Hata Member is dated to 2.5 million years ago and has produced a new species of Australopithecus and hominid postcranial remains not currently assigned to species. Spatially asso- ciated zooarchaeological remains show that hominids acquired meat and mar- row by

  2. San Clemente oil field

    Microsoft Academic Search

    Lang

    1972-01-01

    San Clemente oil field is in S. Orange County, 4 miles north of the City of San Clemente. San Clemente oil field is significant because it contributed the first oil production in California south of the Los Angeles Basin. In a stratigraphic sense, it is radically different from any field in the Los Angeles Basin. The dominant structural feature is

  3. Abandoned Texas oil fields

    SciTech Connect

    Not Available

    1980-12-01

    Data for Texas abandoned oil fields were primarily derived from two sources: (1) Texas Railroad Commission (TRRC), and (2) Dwight's ENERGYDATA. For purposes of this report, abandoned oil fields are defined as those fields that had no production during 1977. The TRRC OILMASTER computer tapes were used to identify these abandoned oil fields. The tapes also provided data on formation depth, gravity of oil production, location (both district and county), discovery date, and the cumulative production of the field since its discovery. In all, the computer tapes identified 9211 abandoned fields, most of which had less than 250,000 barrel cumulative production. This report focuses on the 676 abandoned onshore Texas oil fields that had cumulative production of over 250,000 barrels. The Dwight's ENERGYDATA computer tapes provided production histories for approximately two-thirds of the larger fields abandoned in 1966 and thereafter. Fields which ceased production prior to 1966 will show no production history nor abandonment date in this report. The Department of Energy hopes the general availability of these data will catalyze the private sector recovery of this unproduced resource.

  4. Oil field management system

    DOEpatents

    Fincke, James R.

    2003-09-23

    Oil field management systems and methods for managing operation of one or more wells producing a high void fraction multiphase flow. The system includes a differential pressure flow meter which samples pressure readings at various points of interest throughout the system and uses pressure differentials derived from the pressure readings to determine gas and liquid phase mass flow rates of the high void fraction multiphase flow. One or both of the gas and liquid phase mass flow rates are then compared with predetermined criteria. In the event such mass flow rates satisfy the predetermined criteria, a well control system implements a correlating adjustment action respecting the multiphase flow. In this way, various parameters regarding the high void fraction multiphase flow are used as control inputs to the well control system and thus facilitate management of well operations.

  5. Physicochemical methods for enhancing oil recovery from oil fields

    Microsoft Academic Search

    L K Altunina; V A Kuvshinov

    2007-01-01

    Physicochemical methods for enhancing oil recovery from oil fields that are developed using water flooding and thermal steam treatment are considered. The results of pilot testing of processes based on these methods carried out at West Siberian and Chinese oil fields are analysed. The attention is focused on the processes that make use of surfactant blends and alkaline buffer solutions

  6. Minimizing Casing Corrosion in Kuwait Oil Fields

    Microsoft Academic Search

    M. N. Agiza; S. A. Awar

    1983-01-01

    Corrosion in production strings is a well known problem in Kuwait oil fields. Failure to remedy the affected wells results mainly in undesirable dump flooding of the oil reservoirs, or in oil seepage and hydrocarbon contamination in shallow water bearing strata. Any of these situations (unless properly handled) leads to a disastrous waste of oil resources. This study discusses casing

  7. Russian-English oil-field dictionary

    SciTech Connect

    Stoliarov, D.E.

    1983-01-01

    This dictionary covers approximately 30,000 terms with particular emphasis on those phrases most commonly used in the Soviet oil and gas industry, including such areas as construction of wells, development of offshore oil and gas fields, construction of oil and gas field facilities, pipeline construction and transportation. Includes reference to the latest Soviet achievements in oil field technology and oil-field equipment design. Alternative translations are given with an indication of correct usage in particular situations. Also includes an appendix of conversion tables, units and abbreviations.

  8. Economical Evaluation of an Oil Field Reservoir

    Microsoft Academic Search

    M. V. Kok

    2011-01-01

    In this study, economical evaluation of an oil field reservoir was performed using software. The software used in this study consists of different sub-programs to determine recoverable oil, recovery factor, initial and final productions, production rates, and original oil and gas in place for different types of reservoirs. Recovery efficiency was found to be 29% for water drive and 4.78%

  9. HYDROLOGIC CONTROLS ON THE SUBSURFACE TRANSPORT OF OIL-FIELD

    E-print Network

    in Osage County, Oklahoma. Salt and crude oil from oil well waste pits and accidental releases from oil formations. However, even today oil-field brine and oil are often spilled on the soil surfaceHYDROLOGIC CONTROLS ON THE SUBSURFACE TRANSPORT OF OIL-FIELD BRINE AT THE OSAGE-SKIATOOK PETROLEUM

  10. Azerbaijan field to step up oil flow

    SciTech Connect

    Not Available

    1992-10-19

    This paper reports that a unit of Pennzoil Co., Houston, is scheduled to operate a development program that could more than double oil production from Guneshli field off Azerbaijan in the southern Caspian Sea. Under agreements signed in Baku, Pennzoil Caspian Corp., Ramco Energy Ltd. of Aberdeen, Scotland, and state oil company Azerneft will have exclusive right to jointly develop the field. Partners' shares and other project details are to be laid out in the final development plan, expected by yearend.

  11. Giant oil field decline rates and their influence on world oil production

    Microsoft Academic Search

    Mikael Höök; Robert Hirsch; Kjell Aleklett

    2009-01-01

    The most important contributors to the world's total oil production are the giant oil fields. Using a comprehensive database of giant oil field production, the average decline rates of the world's giant oil fields are estimated. Separating subclasses was necessary, since there are large differences between land and offshore fields, as well as between non-OPEC and OPEC fields. The evolution

  12. Electrical field distribution in transformer oil

    Microsoft Academic Search

    Uno Gafvert; Albert Jaksts; C. Tornkvist; L. Walfridsson

    1992-01-01

    Developments in Kerr electro-optic measurement technology at the laboratory have made possible high resolution electric field measurements in nonpolar liquids. The electric field distribution in transformer oil has been studied at service stress levels in both the transient and steady state. The field distributions observed are well described by a one-dimensional quantitative model (with measurable parameters) based on charge carrier

  13. Methanogenic Oil Degradation in the Dagang Oil Field

    NASA Astrophysics Data System (ADS)

    Jiménez, Núria; Cai, Minmin; Straaten, Nontje; Yao, Jun; Richnow, Hans Hermann; Krüger, Martin

    2014-05-01

    Anaerobic biodegradation is one of the main in situ oil transformation processes in subsurface oil reservoirs. Recent studies have provided evidence of biodegradation of residual oil constituents under methanogenic conditions. Methane, like other biogenic gases, may contribute to reduce the viscosity of oil and enhance its flow characteristics (making it more available) but it can also be used as a energy source. So the aim of the present study was to provide reliable information on in situ biotransformation of oil under methanogenic conditions, and to assess the feasibility of implementing a MEOR strategy at this site. For this reason, chemical and isotopic analyses of injection and production fluids of the Dagang oil field (Hebei province, China) were performed. Microbial abundances were assessed by qPCR, and clone libraries were performed to study the diversity. In addition, microcosms with either oil or 13C-labelled hydrocarbons were inoculated with injection or production waters to characterize microbial processes in vitro. Geochemical and isotopic data were consistent with in situ biogenic methane production linked to aliphatic and aromatic hydrocarbon degradation: GC-MS profiles of petroleum samples were nearly devoid of n-alkanes, linear alkylbenzenes, and alkyltoluenes, and light PAH, confirming that Dagang oil is mostly highly weathered. In addition, carbon and hydrogen isotopic signatures of methane (?13CCH4 and ?DCH4, respectively), and the bulk isotopic discrimination (??13C) between methane and CO2 (between 32 and 65 ) were in accordance with previously reported values for methane formation during hydrocarbon degradation. Furthermore, methane-producing Archaea and hydrocarbon-degrading Bacteria were abundant in produced oil-water samples. On the other hand, our laboratory degradation experiments revealed that autochthonous microbiota are capable of significantly degrade oil within several months, with biodegradation patterns resembling those observed in situ, and of producing heavy methane from 13C-labelled n-hexadecane or 2-methylnaphthalene (?13C > 550 and 300, respectively). These results suggest that in situ methanogenesis may occur from the aliphatic and polyaromatic fractions of Dagang reservoir fluids. In summary, the studied areas of the Dagang oilfield may have a significant potential for the in situ conversion of oil into methane as a possible way to increase total hydrocarbon recovery.

  14. Ubarana Oil Field, offshore Brazil: case history

    SciTech Connect

    Chagas, L.S.; Stringhini, A.V.; Gontijo, J.E.

    1981-05-01

    Ubarana is the first commercial oil field on the northern continental shelf of Brazil. Discovery well No. 1-RNS-3, drilled in 1973, was located on a seismic structural high in the offshore extension of the Potiguar Basin, about 13 km from the coast and 160 km northwest of Natal. The well penetrated oil-bearing, fluvio-deltaic sandstones of the Cretaceous acu formation. Five outpost wells, also located on the mapping of seismic horizons adjacent to the producing interval, helped to extend the limits of the accumulation. A total of 1.4 million cu m of oil has been produced between 1976 and Oct. 1980. The surface area of Ubarana Field is approximately 35 sq km with oil-bearing reservoirs at an average depth of approximately 2400 m. Permeability and porosity of the sandstones generally are poor. Pressure is normal and the main production mechanism is solution gas drive. The volume of oil in place is approximately 37 million cu m; estimated recovery factor is 29%. There are presently 4 platforms in the Ubarana Field active in drilling and production with 32 producing wells, and 14 locations to be drilled.

  15. Innovative technologies for managing oil field waste.

    SciTech Connect

    Veil, J. A.; Environmental Assessment

    2003-09-01

    Each year, the oil industry generates millions of barrels of wastes that need to be properly managed. For many years, most oil field wastes were disposed of at a significant cost. However, over the past decade, the industry has developed many processes and technologies to minimize the generation of wastes and to more safely and economically dispose of the waste that is generated. Many companies follow a three-tiered waste management approach. First, companies try to minimize waste generation when possible. Next, they try to find ways to reuse or recycle the wastes that are generated. Finally, the wastes that cannot be reused or recycled must be disposed of. Argonne National Laboratory (Argonne) has evaluated the feasibility of various oil field waste management technologies for the U.S. Department of Energy. This paper describes four of the technologies Argonne has reviewed. In the area of waste minimization, the industry has developed synthetic-based drilling muds (SBMs) that have the desired drilling properties of oil-based muds without the accompanying adverse environmental impacts. Use of SBMs avoids significant air pollution from work boats hauling offshore cuttings to shore for disposal and provides more efficient drilling than can be achieved with water-based muds. Downhole oil/water separators have been developed to separate produced water from oil at the bottom of wells. The produced water is directly injected to an underground formation without ever being lifted to the surface, thereby avoiding potential for groundwater or soil contamination. In the area of reuse/recycle, Argonne has worked with Southeastern Louisiana University and industry to develop a process to use treated drill cuttings to restore wetlands in coastal Louisiana. Finally, in an example of treatment and disposal, Argonne has conducted a series of four baseline studies to characterize the use of salt caverns for safe and economic disposal of oil field wastes.

  16. Field evaluations of marine oil spill bioremediation.

    PubMed Central

    Swannell, R P; Lee, K; McDonagh, M

    1996-01-01

    Bioremediation is defined as the act of adding or improving the availability of materials (e.g., nutrients, microorganisms, or oxygen) to contaminated environments to cause an acceleration of natural biodegradative processes. The results of field experiments and trials following actual spill incidents have been reviewed to evaluate the feasibility of this approach as a treatment for oil contamination in the marine environment. The ubiquity of oil-degrading microorganisms in the marine environment is well established, and research has demonstrated the capability of the indigenous microflora to degrade many components of petroleum shortly after exposure. Studies have identified numerous factors which affect the natural biodegradation rates of oil, such as the origin and concentration of oil, the availability of oil-degrading microorganisms, nutrient concentrations, oxygen levels, climatic conditions, and sediment characteristics. Bioremediation strategies based on the application of fertilizers have been shown to stimulate the biodegradation rates of oil in aerobic intertidal sediments such as sand and cobble. The ratio of oil loading to nitrogen concentration within the interstitial water has been identified to be the principal controlling factor influencing the success of this bioremediation strategy. However, the need for the seeding of natural environments with hydrocarbon-degrading bacteria has not been clearly demonstrated under natural environmental conditions. It is suggested that bioremediation should now take its place among the many techniques available for the treatment of oil spills, although there is still a clear need to set operational limits for its use. On the basis of the available evidence, we have proposed preliminary operational guidelines for bioremediation on shoreline environments. PMID:8801437

  17. Development of a mature giant offshore oil field

    SciTech Connect

    Lantz, J.R.; Ali, N. (Amoco Production Co. (US))

    1991-04-01

    The Teak field, a mature oil field offshore southeast Trinidad, has produced 266 million bbl oil since 1972. Production is from Pliocene sandstone reservoirs in a complexly faulted anticline. This paper summarizes the history and geology of Teak field, describes its oil-producing reservoirs, and discusses the mature-field development strategy used since 1988, including case histories of two 1989 development prospects.

  18. Oil field water handling: qualitative separation equals theory plus judgment

    SciTech Connect

    Bradley, B.W.

    1985-10-14

    One of the most prevalent problems in oil field operations is the coproduction of oil and formation water, and the resulting problem of qualitative separation of water and oil. This article discusses the separation and handling of oil field brines. Oil dispersions can be cleaned up by a variety of devices which use gravity as the principal separating mechanism. Acceptable practices for disposing of oil-field brine produced with the crude oil include: injection into permeable underground formations containing saline water; reuse for supplementary recovery operations; and deoiling treatment acceptable for ocean disposal.

  19. Assessment of remaining recoverable oil in selected major oil fields of the San Joaquin Basin, California

    USGS Publications Warehouse

    Tennyson, Marilyn E.; Cook, Troy A.; Charpentier, Ronald R.; Gautier, Donald L.; Klett, Timothy R.; Verma, Mahendra K.; Ryder, Robert T.; Attanasi, Emil D.; Freeman, Philip A.; Le, Phoung A.

    2012-01-01

    The U.S. Geological Survey (USGS) recently completed an estimate of volumes of technically recoverable, conventional oil that could eventually be added to reserves in nine selected major oil fields in the San Joaquin Basin in central California. The mean total volume of potential oil reserves that might be added in the nine fields using improved oil-recovery technologies was estimated to be about 6.5 billion barrels of oil.

  20. Oil and gas field code master list, 1993

    SciTech Connect

    Not Available

    1993-12-16

    This document contains data collected through October 1993 and provides standardized field name spellings and codes for all identified oil and/or gas fields in the United States. Other Federal and State government agencies, as well as industry, use the EIA Oil and Gas Field Code Master List as the standard for field identification. A machine-readable version of the Oil and Gas Field Code Master List is available from the National Technical Information Service.

  1. Bayesian Networks in the Management of Oil Field Piracy Risk

    E-print Network

    Paris-Sud XI, Université de

    and the installation of security equipment. These additional costs directly affect the international price of oil [1Bayesian Networks in the Management of Oil Field Piracy Risk A. Bouejla 1 , X. Chaze 1 , F In recent years, pirate attacks against shipping and oil field installations have become more frequent

  2. OPTIMAL DEVELOPMENT PLANNING OF OFFSHORE OIL AND GAS FIELD

    E-print Network

    Grossmann, Ignacio E.

    OPTIMAL DEVELOPMENT PLANNING OF OFFSHORE OIL AND GAS FIELD INFRASTRUCTURE UNDER COMPLEX FISCAL Pittsburgh, PA 15213 Abstract The optimal development planning of offshore oil and gas fields has received, well drilling schedule and production profiles of oil, water and gas in each time period. The model can

  3. Kuwait City and Fire Scars in the Oil Fields

    NASA Technical Reports Server (NTRS)

    1992-01-01

    This view of the northern Persian Gulf shows Kuwait City and the Tigris and Euphrates River Deltas (29.5N, 48.5E). The oil laden sands and oil lakes of the Kuwait Oil Fields to the north and south of the city are clearly visible as dark patches surrounded by oil free desert sands. Comparison with earlier photos indicate that the oil laden sands are slowly being covered with clean sand carried by strong NW winds called Shmals.

  4. Gullfaks oil field - From challenge to success

    SciTech Connect

    Carlsen, H.; Nygaard, O. (Statoil A.S., Stavanger (Norway))

    1990-09-01

    The giant Gullfaks oil field was discovered in 1978. The field contains oil reserves in excess of 1.3 billion bbl. The field is located in the northeastern past of Block 34/10 in the Norwegian sector of the North Sea. Gullfaks represents the shallowest structural element of the Tampen Spur and was formed during the Late Jurassic to Early Cretaceous as a sloping high with a westerly structural dip gradually decreasing toward the east. The major north-south-striking faults, with easterly sloping fault planes, divided the field into several rotated fault blocks. Central and eastern parts of the structure have been eroded by the Early Cretaceous transgression. The reservoir sandstones are comprised of the Middle Jurassic to Early Cretaceous as a sloping high with a westerly structural dip gradually decreasing toward the east. The major north-south-striking faults, with easterly sloping fault planes, divided the field into several rotated fault blocks. Central and eastern parts of the structure have been eroded by the Early Cretaceous transgression. The reservoir sandstones are comprised of the Middle Jurassic delta-deposited Brent Group, the Lower Jurassic shallow-marine sandstones of the Cook Formation, and the Lower Jurassic shallow-marine sandstones of the Cook Formation, and the Lower Jurassic fluvial channel and delta-plain deposits of the Statfjord Formation. The presence of gas in the post-Jurassic section and a variable water depth have complicated seismic interpretation. However, the improved quality of the 1985 three dimensional seismic survey and deliberate deepening of the development wells have resulted in a more accurate and complete structural interpretation. The Brent reserves in the western part of the field currently are being developed by the Gullfaks A and B platforms. The eastern part of the field is developed by a third platform, Gulflaks C. Water injection is the major drive mechanism maintaining reservoir pressure above the bubble point.

  5. Dependence of Uniform\\/Nonuniform Field Transformer Oil Breakdown on Oil Composition

    Microsoft Academic Search

    C. Hosticka

    1979-01-01

    The 60-Hz and impulse breakdown characteristics of two oils, A and B, which differed markedly in needle-sphere (N-S)impulse strength were determined in uniform and divergent fieldgeometries. Oil A, which had the higher N-S strength, was acommercial transformer oil, and Oil B was this same oil dopedwith anthracene. In the uniform field tests, the two oilshad essentially equal bare-electrode 60 Hz

  6. The Long March of the Chinese Giant Oil Fields

    Microsoft Academic Search

    Mikael Höök; Tang Xu; Pang Xiongqi; Kjell Aleklett

    Over 70% of China's domestic oil production is obtained from nine giant oilfields. Understanding the behaviour of these fields is essential to both domestic oil production and future Chinese oil imports. This study utilizes decline curves and depletion rate analysis to create some future production outlooks for the Chinese giants. Based on our study, we can only conclude that China's

  7. Maturity assessment of oils from the Sakhalin oil fields in Russia: phenanthrene content as a tool

    Microsoft Academic Search

    K Stojanovi?; G. S Pevneva; J. A Golovko; A. K Golovko; P Pfendt

    2001-01-01

    A correlation analysis of maturation parameters was carried out on 14 crude oil samples from nine oil fields on Sakhalin Island (Russia). The oils were taken from reservoir rocks of Miocene age at depths ranging from 73 to 2841 m. On the basis of GC analysis of the alkane fraction (n-alkanes and the isoprenoid alkanes pristane and phytane) as well

  8. Lock for an oil field valve

    SciTech Connect

    Michon, J.M.

    1987-05-05

    A locking device is described for oil field valves or the like including: a lock base member having a recessed portion extending from a bottom surface of the base member. The recessed portion is configured to fit over a valve flange and to a body of a valve. An opening in the base member extends through the base member so that when the base member is located on a valve body, a valve stem of a valve can project through the base member and be manipulated with the base member in position on a valve body. At least two first locking bores extend downwardly from an upper surface of the base member. At least two second locking bores extend inwardly from the respective sides of the base member and partially intersect the locking bores.

  9. Landslide oil field, San Joaquin Valley, California

    SciTech Connect

    Collins, B.P.; March, K.A.; Caballero, J.S.; Stolle, J.M.

    1988-03-01

    The Landslide field, located at the southern margin of the San Joaquin basin, was discovered in 1985 by a partnership headed by Channel Exploration Company, on a farm out from Tenneco Oil Company. Initial production from the Tenneco San Emidio 63X-30 was 2064 BOPD, making landslide one of the largest onshore discoveries in California during the past decade. Current production is 7100 BOPD from a sandstone reservoir at 12,500 ft. Fifteen wells have been drilled in the field, six of which are water injectors. Production from the Landslide field occurs from a series of upper Miocene Stevens turbidite sandstones that lie obliquely across an east-plunging structural nose. These turbidite sandstones were deposited as channel-fill sequences within a narrowly bounded levied channel complex. Both the Landslide field and the larger Yowlumne field, located 3 mi to the northwest, comprise a single channel-fan depositional system that developed in the restricted deep-water portion of the San Joaquin basin. Information from the open-hole logs, three-dimensional surveys, vertical seismic profiles, repeat formation tester data, cores, and pressure buildup tests allowed continuous drilling from the initial discovery to the final waterflood injector, without a single dry hole. In addition, the successful application of three-dimensional seismic data in the Landslide development program has helped correctly image channel-fan anomalies in the southern Maricopa basin, where data quality and severe velocity problems have hampered previous efforts. New exploration targets are currently being evaluated on the acreage surrounding the Landslide discovery and should lead to an interesting new round of drilling activity in the Maricopa basin.

  10. Oil and Gas Field Code Master List 1990

    SciTech Connect

    Not Available

    1991-01-04

    This is the ninth annual edition of the Energy Information Administration's (EIA) Oil and Gas Field Code Master List. It reflects data collected through October 1990 and provides standardized field name spellings and codes for all identified oil and/or gas fields in the United States. There are 54,963 field records in this year's Oil and Gas Field Code Master List (FCML). This amounts to 467 more than in last year's report. As it is maintained by EIA, the Master List includes: Field records for each state and county in which a field resides; field records for each offshore area block in the Gulf of Mexico in which a field resides;field records for each alias field name; fields crossing state boundaries that may be assigned different names by the respective state naming authorities.

  11. Microbial processes in oil fields: culprits, problems, and opportunities.

    PubMed

    Youssef, Noha; Elshahed, Mostafa S; McInerney, Michael J

    2009-01-01

    Our understanding of the phylogenetic diversity, metabolic capabilities, ecological roles, and community dynamics of oil reservoir microbial communities is far from complete. The lack of appreciation of the microbiology of oil reservoirs can lead to detrimental consequences such as souring or plugging. In contrast, knowledge of the microbiology of oil reservoirs can be used to enhance productivity and recovery efficiency. It is clear that (1) nitrate and/or nitrite addition controls H2S production, (2) oxygen injection stimulates hydrocarbon metabolism and helps mobilize crude oil, (3) injection of fermentative bacteria and carbohydrates generates large amounts of acids, gases, and solvents that increases oil recovery particularly in carbonate formations, and (4) nutrient injection stimulates microbial growth preferentially in high permeability zones and improves volumetric sweep efficiency and oil recovery. Biosurfactants significantly lower the interfacial tension between oil and water and large amounts of biosurfactant can be made in situ. However, it is still uncertain whether in situ biosurfactant production can be induced on the scale needed for economic oil recovery. Commercial microbial paraffin control technologies slow the rate of decline in oil production and extend the operational life of marginal oil fields. Microbial technologies are often applied in marginal fields where the risk of implementation is low. However, more quantitative assessments of the efficacy of microbial oil recovery will be needed before microbial oil recovery gains widespread acceptance. PMID:19203651

  12. The evolution of giant oil field production behaviour

    Microsoft Academic Search

    Mikael Höök; Bengt Söderbergh; Kristofer Jakobsson; Kjell Aleklett

    2009-01-01

    The giant oil fields of the world are only a small fraction of the total number of fields, but their importance is huge. Over 50% of the world oil production came from giants by 2005 and more than haft of the worlds ultimate reserves are found in giants. Based on this it is reasonable to assume that the future development

  13. Reevaluation of Virgin oil field, Washington County, Utah

    Microsoft Academic Search

    C. J. Brandt; D. B. Swindel; K. M. Clem

    1986-01-01

    Virgin field, located in the western part of the Kaiparowits basin, may hold the key to exploration in south-central Utah and northwestern Arizona. In 1907, Virgin field was the site of the first oil production in the state of Utah. Production was established 3 mi west of the present-day boundary of Zion National Park, near oil seeps and oily tar

  14. A reservoir management study of a mature oil field

    E-print Network

    Peruzzi, Tave

    1995-01-01

    An integrated geological, petrophysical and reservoir engineering review was performed for a mature, producing oil field. Like many older fields, important data are missing or were not collected. The techniques used in this thesis may be applied...

  15. Saving diesel fuel in the oil field

    SciTech Connect

    Elder, B.

    1982-11-01

    Describes how diesel electric SCR (silicon controlled rectifier) drilling rigs are helping drillers save fuel expense in the oil fields, along with other energy conservation methods. Compares SCR to conventional drilling rigs. Points out that on conventional rigs, diesel engines drive rig components directly, while on the SCR electric rigs, diesel engines turn a.c. electric generators which supply energy to d.c. electric motors for rig component power. Components of the SCR rigs include drawworks, mud pumps, rotary table, compressors, shakers, blenders and the camp load. Recommends economic principles such as supplying generators large enough to handle the low p.f. (power factor) as well as peak power requirements; and keeping the work load on diesel engines as high as possible for fuel economy. Presents tables of fuel consumed per 100 kW at various load factors; effect of power factor on engine hp required; electric drilling rig power modules; and engine and generator selection guide. Emphasizes consideration of the competitive difference in diesel engine economy.

  16. Assessment of remaining recoverable oil in selected major oil fields of the Permian Basin, Texas and New Mexico

    USGS Publications Warehouse

    Tennyson, Marilyn E.; Cook, Troy A.; Charpentier, Ronald R.; Gautier, Donald L.; Klett, Timothy R.; Verma, Mahendra K.; Ryder, Robert T.; Attanasi, Emil D.; Freeman, Philip A.; Le, Phoung A.

    2012-01-01

    The U.S. Geological Survey (USGS) recently completed an estimate of technically recoverable, conventional oil in selected oil fields in the Permian Basin in west Texas and southeastern New Mexico. The mean total volume of potential additional oil resources that might be added using improved oil-recovery technologies was estimated to be about 2.7 billion barrels of oil.

  17. Kuwait Oil Fields as seen from STS-58

    NASA Technical Reports Server (NTRS)

    1993-01-01

    A clear view of the northern Kuwait coast shows the southern part of Kuwait City, and the major oil fields to the south. Oil laden sands, where wells were set ablaze during the Gulf War in 1991, are visible south of Kuwait City as a dark, elongated patch surrounded by light-colored sand. Oil-stained sandbetween well sites (dots) and criss-crossing roads is gradually being covered by clean sand carried by strong, seasonal northwest winds.

  18. Environmental contamination in the oil fields of western Pennsylvania

    USGS Publications Warehouse

    Albers, P.H.; Belisle, A.A.; Swineford, D.M.; Hall, R.J.

    1985-01-01

    The effects on freshwater wildlife of chronic exposure to oil field discharges are not well known. Collections of wastewater, aquatic invertebrates, fish, salamanders, and small mammals were made in several streams in the oil fields of western Pennsylvania during 1980-81. Estimates of the petroleum content of two wastewater discharges were high (21.9 and 8.4 ppm) and one was low (0.3 ppm). Water conductivity was inversely related to aquatic invertebrate biomass. Hydrocarbons accumulated in significantly greater amounts in crayfish, fish, and small mammals from collection sites with oil extraction activity than from sites without oil extraction activity. Estimates of total petroleum in invertebrates, trout, and suckers averaged between 200 and 280 ppm for oil extraction sites and between 8 and 80 ppm for sites without oil extraction activity: Oil extraction activity did not affect metal accumulation by fish. Oil and wastewater discharges in oil fields disrupt community composition and can cause an overall reduction in stream productivity.

  19. Excess Water Production Diagnosis in Oil Fields Using Ensemble Classifiers

    Microsoft Academic Search

    Minou Rabiei; Ritu Gupta; Yaw Peng Cheong; G. A. S. Soto

    2009-01-01

    Excessive water production in oil fields is a challenging problem affecting oil production and entailing high handling and disposing costs as well as environmental issues. Accurate and timely diagnosis of the water production problem will significantly increase the success of the remedial actions taken. The traditional approaches in production data analysis by means of empirical techniques for proper diagnosis of

  20. Study on Environmental Costs of Chinese Oil Field Companies

    Microsoft Academic Search

    Tian Xuefeng; Song jia Wangcong

    2011-01-01

    The environmental and social problems existing in Chinese oil field companies are very serious and environmental management becomes more and more exigent in business management. Environmental cost is one key part of environmental management accounting. Different environmental cost definitions and methods exist in different organizations and even in different countries. What will be the most suitable one for Chinese oil

  1. Oil and Gas field code master list 1995

    SciTech Connect

    NONE

    1995-12-01

    This is the fourteenth annual edition of the Energy Information Administration`s (EIA) Oil and Gas Field Code Master List. It reflects data collected through October 1995 and provides standardized field name spellings and codes for all identified oil and/or gas fields in the US. The Field Code Index, a listing of all field names and the States in which they occur, ordered by field code, has been removed from this year`s publications to reduce printing and postage costs. Complete copies (including the Field Code Index) will be available on the EIA CD-ROM and the EIA World-Wide Web Site. Future editions of the complete Master List will be available on CD-ROM and other electronic media. There are 57,400 field records in this year`s Oil and Gas Field Code Master List. As it is maintained by EIA, the Master List includes the following: field records for each State and county in which a field resides; field records for each offshore area block in the Gulf of Mexico in which a field resides; field records for each alias field name (see definition of alias below); and fields crossing State boundaries that may be assigned different names by the respective State naming authorities. Taking into consideration the double-counting of fields under such circumstances, EIA identifies 46,312 distinct fields in the US as of October 1995. This count includes fields that no longer produce oil or gas, and 383 fields used in whole or in part for oil or gas Storage. 11 figs., 6 tabs.

  2. Pretest studies for a microbially enhanced oil recovery field pilot in a hypersaline oil reservoir

    Microsoft Academic Search

    Vishvesh K. Bhupathiraju; Michael J. McInerney; Roy M. Knapp

    1993-01-01

    The ecological and physiological factors governing microbial activity in the Southeast Vassar Vertz Sand Unit (SEWSU), Payne County, OK, an oil reservoir selected for a microbially enhanced oil recovery field pilot, were studied. Analysis of the brines from the reservoir showed that the SEWSU reservoir is a hypersaline environment rich in calcium and magnesium cations, and contains most of the

  3. Tengiz oil field, Kazakstan: A carbonate platform and supergiant field

    SciTech Connect

    Wood, W.R. (Chevron Overseas Petroleum, Inc., San Ramon, CA (United States)); Garber, R.A. (Chevron USA, Midland, TX (United States))

    1996-01-01

    The Tengiz oil field was discovered in 1979 on the northeastern shore of the Caspian Sea in western Kazakstan. The Carboniferous and Devonian age carbonate reservoir is more than 2000 in, thick, 270 km[sup 2] in area extent and buried to a depth of 4000 m (13,120 ft.). The oil column exceeds 1450 m in length and is highly overpressured. The Tengiz reservoir resembles a modem day constructional-type carbonate platform in size, shape and lithofacies. The top of the platform is relatively flat, except for structural highs along the northern, eastern and southern platform margins that developed during post-depositional down-faulting of the platform interior. The platform edge is a depositional escarpment along which subsequent faulting has occurred. Debris-slope conglomerates, shed off the platform during growth, surround the platform escarpment. Bashkirian age ootitic, crinoidal, algal grainstones comprise the upper 100 m of the platform and overlie 350 m of Serpukhovian and Okskian age brachiopodal, crinoidal, algal packstones. Lithofacies are a really widespread and show little variation in composition and stratigraphic thickness across the entire platform. Depositional cycle thicknesses are less than 5 meters for the Bashkirian grainstones and up to 30 meters for the Serpukhovian/Oksky packstones. Lagoonal and reefal lithofacies have not been identified in core to date. Porosity is highly variable and includes interparticle, moldic, channel, vuggy and fracture pore types. Solid bitumen is present in much of the pore space. Secondary porosity formed both before and after bitumen precipitation. Production logs and core data reveal that zones with secondary porosity provide fluid entry into the wellbore.

  4. Tengiz oil field, Kazakstan: A carbonate platform and supergiant field

    SciTech Connect

    Wood, W.R. [Chevron Overseas Petroleum, Inc., San Ramon, CA (United States); Garber, R.A. [Chevron USA, Midland, TX (United States)

    1996-12-31

    The Tengiz oil field was discovered in 1979 on the northeastern shore of the Caspian Sea in western Kazakstan. The Carboniferous and Devonian age carbonate reservoir is more than 2000 in, thick, 270 km{sup 2} in area extent and buried to a depth of 4000 m (13,120 ft.). The oil column exceeds 1450 m in length and is highly overpressured. The Tengiz reservoir resembles a modem day constructional-type carbonate platform in size, shape and lithofacies. The top of the platform is relatively flat, except for structural highs along the northern, eastern and southern platform margins that developed during post-depositional down-faulting of the platform interior. The platform edge is a depositional escarpment along which subsequent faulting has occurred. Debris-slope conglomerates, shed off the platform during growth, surround the platform escarpment. Bashkirian age ootitic, crinoidal, algal grainstones comprise the upper 100 m of the platform and overlie 350 m of Serpukhovian and Okskian age brachiopodal, crinoidal, algal packstones. Lithofacies are a really widespread and show little variation in composition and stratigraphic thickness across the entire platform. Depositional cycle thicknesses are less than 5 meters for the Bashkirian grainstones and up to 30 meters for the Serpukhovian/Oksky packstones. Lagoonal and reefal lithofacies have not been identified in core to date. Porosity is highly variable and includes interparticle, moldic, channel, vuggy and fracture pore types. Solid bitumen is present in much of the pore space. Secondary porosity formed both before and after bitumen precipitation. Production logs and core data reveal that zones with secondary porosity provide fluid entry into the wellbore.

  5. Oil Refining: Google Earth Virtual Field Trip Activity

    NSDL National Science Digital Library

    This page provides a Google Earth virtual field trip activity. Students will learn about oil refining in this short activity from the 2008 ATEEC Fellows Institute. A teacher's guide is included. In this virtual field trip, students learn about the process of oil refining and pose the question to students of alternative sources of fuel. Take a trip to the Petrostar Oil Refinery near the North Pole in Alaska. Learn how oil is refined and discover where oil is refined all around the world. Includes video of a tour taken at the refinery along with questions geared towards critical thinking. This resource is free to download. Users must first create a login with ATEEC's website to access the file.

  6. The Evolution of Giant Oil Field Production Behavior

    Microsoft Academic Search

    Mikael Höök; Bengt Söderbergh; Kristofer Jakobsson; Kjell Aleklett

    2009-01-01

    The giant oil fields of the world are only a small fraction of the total number of fields, but their importance is huge. Over\\u000a 50% of the world’s oil production came from giants by 2005 and more than half of the world’s ultimate reserves are found in\\u000a giants. Based on this, it is reasonable to assume that the future development

  7. Spectral anomaly over Railroad Valley oil field, Nevada

    Microsoft Academic Search

    S. C. Feldman; F. R. Honey; G. I. Ballew

    1990-01-01

    Oil was first discovered in Railroad Valley, south-central Nevada in 1954. Since that time, over 195 wells have been drilled and six oil fields have been found: Bacon Flat, Currant, Trap Spring, Eagle Springs, Grant Canyon and Kate Spring. Two wells in the Grant Canyon field had flows between 2,480 and 4,108 bbl\\/day in 1987 and may be the most

  8. Two dimensional measurements of electrical fields in transformer oil

    Microsoft Academic Search

    U. Gafvert

    1990-01-01

    It is demonstrated that the electro-optical Kerr effect with field modulation can be used for angularly resolved field mapping of two-dimensional objects in transformer oils. This technique can determine the amplitude as well as the direction of the electric field in liquid insulation systems relevant for converter transformers. As an example, the technique was applied to two overlapping Macrolon barriers

  9. Largest US oil and gas fields, August 1993

    SciTech Connect

    Not Available

    1993-08-06

    The Largest US Oil and Gas Fields is a technical report and part of an Energy Information Administration (EIA) series presenting distributions of US crude oil and natural gas resources, developed using field-level data collected by EIA`s annual survey of oil and gas proved reserves. The series` objective is to provide useful information beyond that routinely presented in the EIA annual report on crude oil and natural gas reserves. These special reports also will provide oil and gas resource analysts with a fuller understanding of the nature of US crude oil and natural gas occurrence, both at the macro level and with respect to the specific subjects addressed. The series` approach is to integrate EIA`s crude oil and natural gas survey data with related data obtained from other authoritative sources, and then to present illustrations and analyses of interest to a broad spectrum of energy information users ranging from the general public to oil and gas industry personnel.

  10. Repair wind field in oil contaminated areas with SAR images

    NASA Astrophysics Data System (ADS)

    Guo, Jie; He, Yijun; Long, Xiao; Hou, Chawei; Liu, Xin; Meng, Junmin

    2015-03-01

    In this paper, we compared the normalized radar cross section in the cases of oil spill, biogenic slicks, and clean sea areas with image samples made from 11-pixel NRCS average, and determined their thresholds of the NRCS of the synthetic aperture radar. The results show that the thresholds of oil and biogenic slicks exhibit good consistency with the corresponding synthetic aperture radar images. In addition, we used the normalized radar cross section of clean water from adjacent patches of oil or biogenic slicks areas to replace that of oil or biogenic slicks areas, and retrieve wind field by CMOD5.n and compare wind velocity mending of oil and biogenic slicks areas with Weather Research and Forecasting modeled data, from which the root mean squares of wind speed (wind direction) inversion are 0.89 m/s (20.26°) and 0.88 m/s (7.07°), respectively. Therefore, after the occurrence of oil spill or biogenic slicks, the real wind field could be repaired using the method we introduced in this paper. We believe that this method could improve the accuracy in assessment of a real wind field on medium and small scales at sea, and enhance effectively the monitoring works on similar oil or biogenic slicks incidents at sea surface.

  11. Repair wind field in oil contaminated areas with SAR images

    NASA Astrophysics Data System (ADS)

    Guo, Jie; He, Yijun; Long, Xiao; Hou, Chawei; Liu, Xin; Meng, Junmin

    2014-12-01

    In this paper, we compared the normalized radar cross section in the cases of oil spill, biogenic slicks, and clean sea areas with image samples made from 11-pixel NRCS average, and determined their thresholds of the NRCS of the synthetic aperture radar. The results show that the thresholds of oil and biogenic slicks exhibit good consistency with the corresponding synthetic aperture radar images. In addition, we used the normalized radar cross section of clean water from adjacent patches of oil or biogenic slicks areas to replace that of oil or biogenic slicks areas, and retrieve wind field by CMOD5.n and compare wind velocity mending of oil and biogenic slicks areas with Weather Research and Forecasting modeled data, from which the root mean squares of wind speed (wind direction) inversion are 0.89 m/s (20.26°) and 0.88 m/s (7.07°), respectively. Therefore, after the occurrence of oil spill or biogenic slicks, the real wind field could be repaired using the method we introduced in this paper. We believe that this method could improve the accuracy in assessment of a real wind field on medium and small scales at sea, and enhance effectively the monitoring works on similar oil or biogenic slicks incidents at sea surface.

  12. Oil and gas field code master list 1994

    SciTech Connect

    Not Available

    1995-01-01

    This is the thirteenth annual edition of the Energy Information Administration`s (EIA) Oil and Gas Field Code Master List. It reflects data collected through October 1994 and provides standardized field name spellings and codes for all identified oil and/or gas fields in the United States. The master field name spellings and codes are to be used by respondents when filing the following Department of Energy (DOE) forms: Form EIA-23, {open_quotes}Annual Survey of Domestic Oil and Gas Reserves,{close_quotes} filed by oil and gas well operators (field codes are required from larger operators only); Forms FERC 8 and EIA-191, {open_quotes}Underground Gas Storage Report,{close_quotes} filed by natural gas producers and distributors who operate underground natural gas storage facilities. Other Federal and State government agencies, as well as industry, use the EIA Oil and Gas Field Code Master List as the standard for field identification. A machine-readable version of the Oil and Gas Field Code Master List is available from the National Technical Information Service, 5285 Port Royal Road, Springfield, Virginia 22161, (703) 487-4650. In order for the Master List to be useful, it must be accurate and remain current. To accomplish this, EIA constantly reviews and revises this list. The EIA welcomes all comments, corrections, and additions to the Master List. All such information should be given to the EIA Field Code Coordinator at (214) 953-1858. EIA gratefully acknowledges the assistance provides by numerous State organizations and trade associations in verifying the existence of fields and their official nomenclature.

  13. Oil and gas field code master list 1997

    SciTech Connect

    NONE

    1998-02-01

    The Oil and Gas Field Code Master List 1997 is the sixteenth annual listing of all identified oil and gas fields in the US. It is updated with field information collected through October 1997. The purpose of this publication is to provide unique, standardized codes for identification of domestic fields. Use of these field codes fosters consistency of field identification by government and industry. As a result of their widespread adoption they have in effect become a national standard. The use of field names and codes listed in this publication is required on survey forms and other reports regarding field-specific data collected by EIA. There are 58,366 field records in this year`s FCML, 437 more than last year. The FCML includes: field records for each State and county in which a field resides; field records for each offshore area block in the Gulf of Mexico in which a field resides; field records for each alias field name (definition of alias is listed); fields crossing State boundaries that may be assigned different names by the respective State naming authorities. This report also contains an Invalid Field Record List of 4 records that have been removed from the FCML since last year`s report. These records were found to be either technically incorrect or to represent field names which were never recognized by State naming authorities.

  14. Laboratory studies of oil spill bioremediation; toward understanding field behavior

    SciTech Connect

    Prince, R.C.; Hinton, S.M.; Elmendorf, D.L.; Lute, J.R.; Grossman, M.J.; Robbins, W.K.; Hsu, Chang S.; Richard, B.E.; Haith, C.E.; Senius, J.D.; Minak-Bernero, V.; Chianelli, R.R. [Exxon Research and Engineering Co., Annandale, NJ (United States); Bragg, J.R. [Exxon Production Research Co., Houston, TX (United States); Douglas, G.S. [Battelle Ocean Sciences, Duxbury, MA (United States)

    1993-12-31

    Oil spill remediation aims to enhance the natural process of microbial hydrocarbon biodegradation. The microbial foundations have been studied throughout this century, but the focus of most of this work has been on the degradation of well defined compounds by well defined microbial species. This paper addresses laboratory studies on crude oil biodegradation by microbial consortia obtained from oiled beaches in Prince William Sound, Alaska following the spill from the Exxon Valdez. It demonstrates that oil degradation is indeed likely to be nitrogen-limited in Prince William Sound, the different molecular classes in crude oil that are subjected to biodegradation, the identification of conserved species in the oil that can be used for assessing biodegradation and bioremediation in the field, the effectiveness of fertilizers in stimulating sub-surface biodegradation, the role of the olephilic fertilizer Inipol EAP22, and the identification of the oil-degrading microorganisms in Prince William Sound. Together, these laboratory studies provided guidance and important insights into the microbial phenomena underlying the successful bioremediation of the oiled shorelines.

  15. Verifying a Simplified Fuel Oil Flow Field Measurement Protocol

    SciTech Connect

    Henderson, H.; Dentz, J.; Doty, C.

    2013-07-01

    The Better Buildings program is a U.S. Department of Energy program funding energy efficiency retrofits in buildings nationwide. The program is in need of an inexpensive method for measuring fuel oil consumption that can be used in evaluating the impact that retrofits have in existing properties with oil heat. This project developed and verified a fuel oil flow field measurement protocol that is cost effective and can be performed with little training for use by the Better Buildings program as well as other programs and researchers.

  16. MODELING OF ROYALTY RELIEF FOR MATURE OIL FIELDS

    Microsoft Academic Search

    Rafael Felipe; Saul Barisnik

    The operation of mature petroleum fields is frequently uneconomic due to the low production volume and to the excessive load of taxes and governmental participations that these fields are submitted to. This work presents a deterministic model for royalty relief, using a combination of different types of decline curves, operational costs, and prices of several oil types, making an analysis

  17. Geology of oil fields of west Siberian lowland

    Microsoft Academic Search

    Dickey

    1972-01-01

    Since 1959, more than 114 oil and gas fields estimated to contain more than 4 billion tons (28 billion bbl) have been discovered in the W. Siberian Lowland, a topographic and structural basin east of the Ural Mt. All fields discovered to 1970 are on anticlinal structures, found mainly by geophysical work, including magnetic, gravity, and seismic profiling. Detailed seismic

  18. Environmental assessment of an oil field prior to redevelopment

    SciTech Connect

    Ferguson, E. Jr.; Smith, E.A. [McLaren/Hart Environmental Engineering, Irvine, CA (United States)

    1995-09-01

    A statistical and directed soil sampling approach, using {open_quotes}spot trenching{close_quotes} and GeoProbe techniques, to characterize an active oil field prior to redevelopment. As land uses change, environmental characterization of the subject area is often required to assess future development opportunities. This is evident in areas that have been historically used for oil production but declining oil production in the field has produced undeveloped land available for future development. The area discussed in this paper is a 63-acre section, within an oil field in Southern California, expected to be developed in the next three to five years as a golf course. The purpose of this remedial investigation was to assess the soil conditions and determine the most advantageous remediation techniques, if needed, for future land use. The methodology of the investigation needed to complement the redevelopment goals for an effective property transfer. Use of aerial photographs to identify potential source areas combined with aggressive and innovative field sampling strategies reduced the cost and increased the effectiveness of the investigation. Spot trenching and sampling of oil sumps and tank batteries identified on aerial photographs was used to identify the crude oil and benzene, toluene, ethylbenzene and xylenes (BTEX) aspect of the oil production. Statistical sampling using a {open_quotes}GeoProbe{close_quotes},an in situ sampling method, for the remainder of the site identified chemicals not commonly associated with oil production (organic compounds and metals). These techniques of sampling achieved a 90 percent confidence level that the entire site had characterized. The results allowed the McLaren/Hart to determine impacted areas and volumes of soil affected. Thus allowing cost of development to be projected prior to development of the property.

  19. Distribution of Thermophilic Marine Sulfate Reducers in North Sea Oil Field Waters and Oil Reservoirs

    PubMed Central

    Nilsen, R. K.; Beeder, J.; Thorstenson, T.; Torsvik, T.

    1996-01-01

    The distribution of thermophilic marine sulfate reducers in produced oil reservoir waters from the Gullfaks oil field in the Norwegian sector of the North Sea was investigated by using enrichment cultures and genus-specific fluorescent antibodies produced against the genera Archaeoglobus, Desulfotomaculum, and Thermodesulforhabdus. The thermophilic marine sulfate reducers in this environment could mainly be classified as species belonging to the genera Archaeoglobus and Thermodesulforhabdus. In addition, some unidentified sulfate reducers were present. Culturable thermophilic Desulfotomaculum strains were not detected. Specific strains of thermophilic sulfate reducers inhabited different parts of the oil reservoir. No correlation between the duration of seawater injection and the numbers of thermophilic sulfate reducers in the produced waters was observed. Neither was there any correlation between the concentration of hydrogen sulfide and the numbers of thermophilic sulfate reducers. The results indicate that thermophilic and hyperthermophilic sulfate reducers are indigenous to North Sea oil field reservoirs and that they belong to a deep subterranean biosphere. PMID:16535321

  20. [Production of oil-processing compounds by microorganisms from the Daqing oil field, China].

    PubMed

    Nazina, T N; Sokolova, D Sh; Grigor'ian, A A; Xue, Y F; Beliaev, S S; Ivanov, M V

    2003-01-01

    Twenty pure cultures isolated from formation waters of the Daqing oil field were studied with respect to their capacity to produce surface-active compounds in media with individual hydrocarbons, lower alcohols, and fatty acids. Aerobic saprotrophic bacteria belonging to the genera Bacillus, Brevibacillus, Rhodococcus, Dietzia, Kocuria, Gordonia, Cellulomonas, Clavibacter, Pseudomonas, and Acinetobacter decreased the surface tension of cultivation media from 55-63 to 28-44 mN/m. Strains of Bacillus cereus, Rhodococcus ruber, and Bacillus licheniformis produced biosurfactants most actively. Bacteria of the genera Rhodococcus, Dietzia, Kocuria, and Gordonia produced exopolysaccharides in media with hydrocarbons. Culture liquids of the strains of R. ruber and B. licheniformis exhibited oil-releasing effect. Thus, the Daqing oil field is inhabited by aerobic bacteria capable of producing effective oil-releasing agents. PMID:12751245

  1. CO2 Enhanced Oil Recovery Feasibility Evaluation for East Texas Oil Field

    E-print Network

    Lu, Ping

    2012-08-31

    CO2 ENHANCED OIL RECOVERY FEASIBILITY EVALUATION FOR EAST TEXAS OIL FIELD BY PING LU Submitted to the graduate degree program in Petroleum Engineering and the Graduate Faculty of the University of Kansas in partial fulfillment... of the requirements for the degree of Master of Science Chairperson: Jenn-Tai Liang Jyun-Syung Tsau Russ Ostermann Date Defended: 07-23-2012 ii The Thesis Committee for PING LU certifies...

  2. Cretaceous petroleum system of the Khasib and Tannuma oil reservoir, East Baghdad oil field, Iraq

    Microsoft Academic Search

    Thamer Khazal Al-Ameri

    Gas chromatography, palynomorph constituents, and maturation are analyzed for oil samples of the Campanian Khasib and Tannuma\\u000a Formations in the wells of East Baghdad oil field for biomarker studies, while palynomorph constituents and their maturation,\\u000a Rock Eval pyrolysis, total organic carbon (TOC) analysis are carried on for the Upper Jurassic and the Cretaceous Formations\\u000a of core samples from the same

  3. Transformation of residual oil in producing formations of the Romashkino oil field during hydrothermal treatment

    Microsoft Academic Search

    G. P. Kayukova; A. M. Kiyamova; L. Z. Nigmedzyanova; Sh. M. Rakmankulov; N. S. Sharipova; V. M. Smelkov

    2007-01-01

    Changes in the composition of organic matter of rocks and residual oil from multiage deposits of the Romashkino oil field\\u000a in a reducing environment in a continuous-flow aqueous system were studied. It was shown that, as a result of the action of\\u000a hydrothermal factors, the amount of hydrocarbon fractions increases and the amounts of alcohol-benzene-extractable resins,\\u000a asphaltenes, and total sulfur

  4. Kerr electro-optic field mapping and charge dynamics in impurity-doped transformer oil

    Microsoft Academic Search

    M. Hikita; M. Matsuoka; R. Shimizu; K. Kato; N. Hayakawa; H. Okubo

    1996-01-01

    We measured dc electric field distribution in transformer oil mixed with different impurities and additives so as to simulate practical degradation conditions of transformer oil. The electric field in the oil doped with asphalt was reduced near the cathode and enhanced near the anode. On the other hand, electric field in oil with copper oleate was enhanced near both electrodes

  5. Measuring marine oil spill extent by Markov Random Fields

    NASA Astrophysics Data System (ADS)

    Moctezuma, Miguel; Parmiggiani, Flavio; Lopez Lopez, Ludwin

    2014-10-01

    The Deepwater Horizon oil spill of the Gulf of Mexico in the spring of 2010 was the largest accidental marine oil spill in the history of the petroleum industry. An immediate request, after the accident, was to detect the oil slick and to measure its extent: SAR images were the obvious tool to be employed for the task. This paper presents a processing scheme based on Markov Random Fields (MRF) theory. MRF theory describes the global information by probability terms involving local neighborhood representations of the SAR backscatter data. The random degradation introduced by speckle noise is dealt with a pre-processing stage which applies a nonlinear diffusion filter. Spatial context attributes are structured by the Bayes equation derived from a Maximum-A-Posteriori (MAP) estimation. The probability terms define an objective function of a MRF model whose goal is to detect contours and fine structures. The markovian segmentation problem is solved with a numerical optimization method. The scheme was applied to an Envisat/ASAR image over the Gulf of Mexico of May 9, 2010, when the oil spill was already fully developed. The final result was obtained with 51 recursion cycles, where, at each step, the segmentation consists of a 3-class label field (open sea and two oil slick thicknesses). Both the MRF model and the parameters of the stochastic optimization procedure will be provided, together with the area measurement of the two kinds of oil slick.

  6. Thermal field of an oil bed in a nonstationary pressure field

    Microsoft Academic Search

    A. R. Sabitov; R. F. Sharafutdinov

    1999-01-01

    We carried out a numerical investigation of the temperature field arising in an oil bed due to the Joule-Thomson effect and\\u000a the heat of deaeration of the liquid in the nonstationary pressure field in displacement of oil by water. The formation of\\u000a the temperature field depends substantially on the initial flooding of the bed and the approach of the front

  7. The Application Of Microbial Enhanced Oil Recovery On Unconventional Oil: A Field Specific Approach

    NASA Astrophysics Data System (ADS)

    Goodman, Sean; Millar, Andrew; Allison, Heather; McCarthy, Alan

    2014-05-01

    A substantial amount of the world's recoverable oil reserves are made from unconventional or heavy resources. However, great difficulty has been had in recovering this oil after primary and secondary recovery methods have been employed. Therefore, tertiary methods such as microbial enhanced oil recovery (MEOR) have been employed. MEOR involves the use of bacteria and their metabolic products to alter the oil properties or rock permeability within a reservoir in order to promote the flow of oil. Although MEOR has been trialed in the past with mixed outcomes, its feasibility on heavier oils has not been demonstrated. The aim of this study is to show that MEOR can be successfully applied to unconventional oils. By using an indigenous strain of bacteria isolated from a reservoir of interest and applied to field specific microcosms, we will look into the effect of these bacteria compared to variant inoculums to identify which mechanisms of action the bacteria are using to improve recovery. Using this information, we will be able to identify genes of interest and groups of bacteria that may be beneficial for MEOR and look accurately identify favorable bacteria within a reservoir.

  8. Processing of coal, oil sand and heavy oil in situ by electric and magnetic fields

    NASA Astrophysics Data System (ADS)

    Fisher, S. T.

    1980-07-01

    Improvements to a previously proposed (Fisher, 1979) means for the underground processing of coal, oil sand and heavy oil using eddy currents induced by an alternating magnetic field are presented. Consideration is given to the injection into the fuel layer by pressure from the surface of a hot, saturated high-conductivity aqueous electrolyte solution, which would allow induction heating to depend entirely on low-frequency eddy currents, and to the use of an outer tube of copper welded to an inner tube of steel for the tunnel and shaft casings and electrical conductors of the underground eddy-current heating installation. The physical and operational parameters of the proposed modifications are given, and it is shown that these improvements would increase the performance margin of the eddy-current heating method over the proposed dielectric heating method for oil shale and oil sand deposits.

  9. Tar Creek study, Sargent oil field, Santa Clara County, California

    USGS Publications Warehouse

    Wagner, David L.; Fedasko, Bill; Carnahan, J.R.; Brunetti, Ross; Magoon, Leslie B.; Lillis, Paul G.; Lorenson, Thomas D.; Stanley, Richard G.

    2002-01-01

    Field work in the Tar Creek area of Sargent oil field was performed June 26 to 28, 2000. The Santa Clara County study area is located in Sections, 30, 31, and 32, Township 11 South, Range 4 East, M.D.B&M; and in Sections 25 and 36, Township 11 South, Range 3 East, M.D.B.&M., north and south of Tar Creek, west of Highway 101. The work was a cooperative effort of the California Department of Conservation's Division of Oil, Gas, and Geothermal Resources (DOGGR), California Geological Survey (CGS), and the United States Geological Survey (USGS). The purpose of the project was to map the stratigraphy and geologic structure (David Wagner, CGS); sample oil for age dating (Les Magoon, USGS); and search for undocumented wells plus conduct a GPS survey of the area (Bill Fedasko, J.P. Carnahan, and Ross Brunetti, DOGGR)

  10. Pyrolysis of oil shales of the Turov field

    NASA Astrophysics Data System (ADS)

    Falyushin, P. L.; Dobrego, K. V.; Kraiko, V. M.; Anufrieva, E. V.

    2011-05-01

    The results of investigations of the chemical composition, properties, and thermotechnical characteristics of the technological sample of oil shales of the Turov field of Belarus have been given. The results of experimental works on shale pyrolysis on laboratory setups in stationary and moving beds for obtaining high-calorific energy carriers have been shown.

  11. Extraction of Field Pennycress Seed Oil by Full Pressing

    Technology Transfer Automated Retrieval System (TEKTRAN)

    Field pennycress (Thlasphi arvense L., Brassicaceae) is a winter annual that grows widely in the temperate North America. Its seeds contain up to 36% oil (db) with the major fatty acid as erucic acid (38%). With an estimated seed production of 1,700 – 2,200 kg/ha, pennycress can be a major source of...

  12. Oil

    NSDL National Science Digital Library

    Brieske, Joel A.

    2002-01-01

    The first site, offered by the Institute of Petroleum, is called Fossils into Fuel (1). It describes how oil and gas are formed and processed, as well as offering short quizzes on each section. The second site (2) is maintained by the Department of Energy. Visitors can learn about the history of oil use, how itâ??s found and extracted, and more. The next site, called Picture an Oil Well (3), is a one-page illustration and description of the workings of an oil well, offered by the California Department of Conservation. The fourth site, hosted by the Minerals Management Service, is called Stacey Visits an Offshore Oil Rig (4). It tells the story of a girl taking a field trip on an offshore oil rig and what she finds when sheâ??s there. The Especially for Kids Web site (5) is presented by NOAA and explores facts about the effects of oil spills. Kids can do experiments, get help writing a report, find further information on the provided additional links, and more. From the Environmental Protection Agency, the sixth site is called Oil Spill Program (6), and it also delves into the topic of oil spills. It provides information about the EPA's program for preventing, preparing for, and responding to oil spills that occur in and around inland waters of the United States. The next site, offered by How Stuff Works.com, is called How Oil Refining Works (7). Descriptions of crude oil, fractional distillation, chemical processing, and more is presented in a succinct but informative way. The last site is from The Center for Subsurface Modeling (CSM) of the Texas Institute for Computational and Applied Mathematics and is called CSMâ??s Picture Gallery (8). After clicking the Gallery link, visitors will find animations and images that represent CSMâ??s work such as oil spill simulations, discontinuous galerkin, the tyranny of scale, contaminant remediation, etc.

  13. Reevaluation of Virgin oil field, Washington County, Utah

    SciTech Connect

    Brandt, C.J.; Swindel, D.B.; Clem, K.M.

    1986-08-01

    Virgin field, located in the western part of the Kaiparowits basin, may hold the key to exploration in south-central Utah and northwestern Arizona. In 1907, Virgin field was the site of the first oil production in the state of Utah. Production was established 3 mi west of the present-day boundary of Zion National Park, near oil seeps and oily tar commonly known by pioneers and the Paiute Indians. This field has continued to produce since 1907 but has not been commercially important. Approximately 60 wells have cumulatively produced 209,182 bbl of oil and 3760 mcf of gas. Typically, individual wells produce only 1 to 5 BOPD. Virgin field produces from discontinuous, porous carbonate zones in the Timpoweap, the basal member of the Triassic Moenkopi Formation. It has been questioned whether more than one well has ever penetrated the same pool. Stratigraphic components, porosity, fracturing, and diagenetic trends, in tandem with hydrodynamic forces, have caused hydrocarbons to pool in a syncline, as there is no positive structural closure in the vicinity of Virgin field. Drilling depths are shallow, 550 ft average, appealing to small operators. Because of new ideas and innovative production techniques, activity continues in this old field.

  14. Reverse osmosis process successfully converts oil field brine into freshwater

    SciTech Connect

    Tao, F.T.; Curtice, S.; Hobbs, R.D.; Sides, J.L.; Wieser, J.D. (Texaco Inc., Bellaire, TX (United States)); Dyke, C.A.; Tuohey, D. (Texaco Inc., Beacon, NY (United States)); Pilger, P.F. (Texaco E and P Inc., Denver, CO (United States))

    1993-09-20

    A state-of-the-art process in the San Ardo oil field converted produced brine into freshwater. The conversion process used chemical clarification, softening, filtration, and reverse osmosis (RO). After extensive testing resolved RO membrane fouling problems, the pilot plant successfully handled water with about 7,000 mg/l. of total dissolved solids, 250 mg/l. silica, and 170 mg/l. soluble oil. The treated water complies with the stringent California drinking water standard. The paper describes water reclamation, the San Ardo process, stability, reverse osmosis membrane fouling, membranes at high pH, water quality, and costs.

  15. Formation of oil and gas fields

    Microsoft Academic Search

    A. A. Marakushev; S. A. Marakushev

    2008-01-01

    Cycles of the geosynclinal-orogenic-platformal development of the continental crust are separated by natural phases of crustal\\u000a destruction. They are determined by pulses of degassing of the Earth’s core marked by decelerated inversions of the magnetic\\u000a field. Such pulses occur under the influence of fluid flows that ascend from the core and loss hydrogen. Consequently, the\\u000a fluids acquire acidic properties and

  16. Exxon Valdez Oil Spill: Google Earth Virtual Field Trip Activity

    NSDL National Science Digital Library

    The 2008 ATEEC Fellows Institute brought 18 community college and high school instructors from the environmental sciences to Alaska. They created virtual field trips using Google Earth. In this beautifully designed virtual field trip your students will take a trip through the Prince William Sound from the Alyeska Marine Terminal. From there the class will explore the path that the oil took as it made its way hundreds of miles down the coasts of Alaska. Learn about the environmental impacts of the spill and more. A great resource for learning about this disaster. In 1989 the Exxon Valdez oil tanker hit Bligh Reef through the passage of Prince William sound near Valdez Alaska. This dumped millions of gallons of crude oil into the Pacific. In this nicely designed virtual field trip learn about the path that the oil took and the impacts it had on the the communities wildlife and the world. Explore the spill like never before. Teachers guide included. This resource is free to download. Users must first create a login with ATEEC's website to access the file.

  17. Bird Mortality in Oil Field Wastewater Disposal Facilities

    NASA Astrophysics Data System (ADS)

    Ramirez, Pedro

    2010-11-01

    Commercial and centralized oilfield wastewater disposal facilities (COWDFs) are used in the Western United States for the disposal of formation water produced from oil and natural gas wells. In Colorado, New Mexico, Utah, and Wyoming, COWDFs use large evaporation ponds to dispose of the wastewater. Birds are attracted to these large evaporation ponds which, if not managed properly, can cause wildlife mortality. The U.S. Fish and Wildlife Service (USFWS) and the U.S. Environmental Protection Agency (EPA) conducted 154 field inspections of 28 COWDFs in Wyoming from March 1998 through September 2008 and documented mortality of birds and other wildlife in 9 COWDFs. Of 269 bird carcasses recovered from COWDFs, grebes (Family Podicipedidae) and waterfowl (Anatidae) were the most frequent casualties. Most mortalities were attributed to oil on evaporation ponds, but sodium toxicity and surfactants were the suspected causes of mortality at three COWDFs. Although the oil industry and state and federal regulators have made much progress in reducing bird mortality in oil and gas production facilities, significant mortality incidents continue in COWDFs, particularly older facilities permitted in the early 1980’s. Inadequate operation and management of these COWDFs generally results in the discharge of oil into the large evaporation ponds which poses a risk for birds and other wildlife.

  18. Strategies for field application of foams in heavy oil reservoirs

    SciTech Connect

    Isaacs, E.E.; Ivory, J.; Law, D.H.S. [Alberta Research Council, Edmonton (Canada)

    1995-12-31

    Steam-based processes in heavy oil reservoirs that are not stabilized by gravity have poor vertical and areal conformance. This is because gases are more mobile within the pore space than liquids and steam tends to override or channel through oil in a formation. The steam-foam process which consists of adding surfactant with or without non-condensible gas to the injected steam, was developed to improve the sweep efficiency of steam drive and cyclic steam processes. The foam-forming components injected with the steam stabilize the liquid lamellae and cause some of the steam to exist as a discontinuous phase. The steam mobility (gas relative permeability) is thereby reduced resulting in an increased pressure gradient in the steam-swept region, to divert steam to the unheated interval and displace the heated oil better. The propagation of surfactant in the reservoir is determined by its thermal stability, adsorption, precipitation, and oil partitioning behaviour. The propagation of the foam is determined by the mechanisms that generate and destroyfoam in the reservoir, including gas and liquid velocities, condensation and evaporation, non-condensible gas, and the presence of oil. Strategies were developed to minimize the chemical requirements for generating effective steam-foams. Economic steam-foam processes requires that surfactant losses are minimized, foam propagation and foam stability is maximized at surfactant concentrations lower than has hereto been used in the field. This paper, based on laboratory finding and field experience, discusses the important considerations which affect the efficient application of steam-foam in the field.

  19. Archaeoglobus fulgidus Isolated from Hot North Sea Oil Field Waters

    PubMed Central

    Beeder, Janiche; Nilsen, Roald Kåre; Rosnes, Jan Thomas; Torsvik, Terje; Lien, Torleiv

    1994-01-01

    A hyperthermophilic sulfate reducer, strain 7324, was isolated from hot (75°C) oil field waters from an oil production platform in the Norwegian sector of the North Sea. It was enriched on a complex medium and isolated on lactate with sulfate. The cells were nonmotile, irregular coccoid to disc shaped, and 0.3 to 1.0 ?m wide. The temperature for growth was between 60 and 85°C with an optimum of 76°C. Lactate, pyruvate, and valerate plus H2 were utilized as carbon and energy sources with sulfate as electron acceptor. Lactate was completely oxidized to CO2. The cells contained an active carbon monoxide dehydrogenase but no 2-oxoglutarate dehydrogenase activity, indicating that lactate was oxidized to CO2 via the acetyl coenzyme A/carbon monoxide dehydrogenase pathway. The cells produced small amounts of methane simultaneously with sulfate reduction. F420 was detected in the cells which showed a blue-green fluorescence at 420 nm. On the basis of morphological, physiological, and serological features, the isolate was classified as an Archaeoglobus sp. Strain 7324 showed 100% DNA-DNA homology with A. fulgidus Z, indicating that it belongs to the species A. fulgidus. Archaeoglobus sp. has been selectively enriched and immunomagnetically captured from oil field waters from three different platforms in the North Sea. Our results show that strain 7324 may grow in oil reservoirs at 70 to 85°C and contribute to hydrogen sulfide formation in this environment. Images PMID:16349231

  20. Monitoring Microseismicity in a Carbonate Oil Field, North Oman

    NASA Astrophysics Data System (ADS)

    El-Hussain, I.; Al-Lazki, A.; Al-Hashmi, S.; Al-Toubi, K.; Al-Shijbi, Y.; Al-Saifi, M.; Al-Kindy, F.; Ibi, O.

    2006-12-01

    Microseismicity was monitored continuously for 2003 and 2004 years using shallow downhole seismic network in a carbonate oil field in Northern Oman. A total of 406 microearthquake events were analyzed to assess events location relative to producing horizons. The depth of the microearthquakes ranges from 0 to 2.95 km below the ground surface. The events location is confined to the carbonate reservoir boundary and temporally correlates well with the gas production, total fluid productions and water injection for the 2003 year. There is no temporal correlation between oil production and seismic activity for the 2003. Direct month to month temporal correlation is not apparent between any of oil, gas, fluid productions/water injections and the microseismic activity for the 2004 year. However, a strong temporal correlation between gas production and the number of events and an improved correlation between the oil production and the number of events were obtained when applying a time lag of one month. The focal plane solutions for the largest events in the 2003 indicate normal faulting with extensional stress is in the NW-SE directions. The spatial and temporal distribution of seismic events in the carbonate field fit the characteristics of reservoir induced seismicity and the triggering mechanism can be explained by the Mohr envelope criterion. This indicates that the reservoir layers are critically stressed and the pore pressure is changing at variable rate.

  1. Increasing Heavy Oil Reserves in the Wilmington Oil Field Through Advanced Reservoir Characterization and Thermal Production Technologies, Class III

    SciTech Connect

    City of Long Beach; Tidelands Oil Production Company; University of Southern California; David K. Davies and Associates

    2002-09-30

    The objective of this project was to increase the recoverable heavy oil reserves within sections of the Wilmington Oil Field, near Long Beach, California through the testing and application of advanced reservoir characterization and thermal production technologies. It was hoped that the successful application of these technologies would result in their implementation throughout the Wilmington Field and, through technology transfer, will be extended to increase the recoverable oil reserves in other slope and basin clastic (SBC) reservoirs.

  2. Structural evolution of Harmaliyah oil field, eastern Saudi Arabia

    SciTech Connect

    Ibrahim, M.W. (Kenton Court, London, England); Khan, M.S.; Khatib, H.

    1981-11-01

    The history of structural growth of the Harmaliyah oil field in eastern Saudi Arabia was studied by means of a series of paleostructural maps to determine if early entrapment of hydrocarbons played an important role in preserving the high porosity of the Kimmeridgian (Upper Jurassic) Arab D reservoir. The Arab D has been affected by shallow or preburial diagenesis - a common feature in Arabian Upper Jurassic calcarenitic reservoirs. Closure forming the structural trap in the Arab D at Harmaliyah oil field developed principally during the late Turonian (Late Cretaceous). During Kimmeridgian (Late Jurassic)-early Turonian (Late Cretaceous) time, shallow or preburial diagenesis of the calcarenitic Arab D reservoir rocks seems to have played a major part in preservation of porosity before the porosity was filled with hydrocarbons.

  3. Niger delta oil production, reserves, field sizes assessed

    SciTech Connect

    Thomas, D. [Thomas and Associates, Hastings (United Kingdom)

    1995-11-13

    The article presents tables and figures showing the reserve estimates and production histories of the 252 fields in the Niger delta, then makes forecasts of the likelihood of discoveries above a given size. The paper discusses oil reserves, development programs, drilling and 3D seismic surveying, secondary and tertiary EOR, reserve incentives, production facilities, capital spending required, Nigerian export blends, and the trend in these blends.

  4. Methane leaks from oil and gas fields detected from space

    NASA Astrophysics Data System (ADS)

    Rosen, Julia

    2014-11-01

    A few years ago, while poring over satellite images of the Earth at night, scientists spotted the bright glow of natural gas flares burning in the oil and gas fields that have fueled America's recent energy boom. Now they have spotted something else from space: large plumes of fugitive methane gas liberated from these formations by unconventional extraction methods like horizontal drilling and hydraulic fracturing.

  5. Crosshole EM for oil field characterization and EOR monitoring: Field examples from Lost Hills, California

    SciTech Connect

    Wilt, M.; Schenkel, C.; Wratcher, M.; Lambert, I.; Torres-Verdin, C.; Tseng H.W.

    1996-07-16

    A steamflood recently initiated by Mobil Development and Production U.S. at the Lost Hills No 3 oil field in California is notable for its shallow depth and the application of electromagnetic (EM) geophysical techniques to monitor the subsurface steam flow. Steam was injected into three stacked eastward-dipping unconsolidated oil sands at depths from 60 to 120 m; the plume is expected to develop as an ellipsoid aligned with the regional northwest-southeast strike. Because of the shallow depth of the sands and the high viscosity of the heavy oil, it is important to track the steam in the unconsolidated sediments for both economic and safety reasons. Crosshole and surface-to-borehole electromagnetic imaging were applied for reservoir characterization and steamflood monitoring. The crosshole EM data were collected to map the interwell distribution of the high-resistivity oil sands and to track the injected steam and hot water. Measurements were made in two fiberglass-cased observation wells straddling the steam injector on a northeast-southwest profile. Field data were collected before the steam drive, to map the distribution of the oil sands, and then 6 and 10 months after steam was injected, to monitor the expansion of the steam chest. Resistivity images derived from the collected data clearly delineated the distribution and dipping structure of the target oil sands. Difference images from data collected before and during steamflooding indicate that the steam chest has developed only in the middle and lower oil sands, and it has preferentially migrated westward in the middle oil sand and eastward in the deeper sand. Surface-to-borehole field data sets at Lost Hills were responsive to the large-scale subsurface structure but insufficiently sensitive to model steam chest development in the middle and lower oil sands. As the steam chest develops further, these data will be of more use for process monitoring.

  6. Sulfide mineralization and magnetization, Cement oil field, Oklahoma

    USGS Publications Warehouse

    Reynolds, Richard L.; Fishman, Neil S.; Webring, Michael W.; Wanty, Richard B.; Goldhaber, Martin B.

    1989-01-01

    Geochemical, petrographic, and rock-magnetic studies were undertaken to investigate possible sources for reported positive aeromagnetic anomalies over the Cement oil field, Oklahoma. Ferrimagnetic pyrrhotite (monoclinic, Fe7S8 ), intergrown with more-abundant, nonmagnetic pyrite (FeS2), is present in well-cutting, core, and quarry samples at Cement, and it is the only identified source of possible enhanced magnetization in rocks over the field. Magnetite, found only in well cuttings from Cement, is contamination from drilling. Magnetite was considered previously by others to be the source of magnetic anomalies at Cement.

  7. Monitoring Induced Seismicity at an Oil/Gas Field

    NASA Astrophysics Data System (ADS)

    Kuleli, H. S.; Sarkar, S.; Toksoz, M. N.; Al-Kindy, F.; El Hussain, I. W.; Al-Hashmi, S.

    2009-12-01

    Seismicity at an oil/gas field has been monitored with surface and borehole seismic networks. Since the seismic monitoring started in 1999, thousands of events have been recorded, located and analyzed. The “surface” seismic network consists of five stations with seismometers in shallow boreholes at 125-150 m depth. The deep network is made up of five downhole geophone arrays, each with 8 sensors, at depths between 650 m and 1200 m. The shallow network has been in constant operation since 1999 and has recorded about 1500 events. The deep network recorded more than 10,000 events between October 2002 and August 2003. To locate the events, a detailed 1-D velocity model derived from sonic logs was used. Various location methods including NonLinLoc, multi-event grid search and time-difference method were used. The latest uses a library of pre-computed travel time differences for all station pairs and for all potential source locations (Sarkar and Toksoz, 2008). An advantage of using the travel time differences between station pairs is that it eliminates origin time from the location algorithms, thus resolving the depth-origin tradeoff issue. There is no record of any seismic events at the site prior to the initiation of oil field activities. The induced events are more strongly correlated with the gas production rates than with oil production. Events mostly occur on preexisting faults, mapped by 3-D surface seismic. There are two (conjugate) sets of faults in the field. The hypocenters are primarily on the NE-SW striking faults oriented parallel to the maximum regional horizontal stress direction. All events recorded are shallow with focal depth of 400 m to 3000 m. A great majority of the events occur between 800 m and 1100 m depth, closer to the depth of the gas reservoir than to the deeper oil reservoir.

  8. Geochemical Specific Characters of the Oil and the Origin of the Oil and Gas Fields

    NASA Astrophysics Data System (ADS)

    Gottikh, Rimma; Pisotskiy, Bogdan; Plotnikova, Irina

    2010-05-01

    It is generally assumed that the fluid regime of the basement of ancient platforms is not associated with that of the sedimentary cover. This assumption is mainly due to the substantial time gap between the formation of the crystalline and sedimentary rocks as well as the evolutionary differences between the thermal regime of the interior and the redox potentials of fluid systems. The presence of loosely aggregated zones filled with salt-water solutions, oil or gas in the upper basement is explained by downward fluid flows from sedimentary rocks through tectonic faults into the disintegrated crystalline rocks. The formation of such zones is believed to be due to the crustal stratification due to Earth's pulsation, periodic variations of its rotational rate, hydrogenic deconsolidation, burial of the post-Early Proterozoic disintegration zones, etc. This pattern suggests that the matter and energy exchange between the Earth's spheres in the late stages of the platform development could only take place with the help of magmatic melts and the associated fluids during the tectonomagmatic cycles of the Earth's crust transformation. Gas and liquid hydrocarbon components mainly occur in crystalline basement rocks of ancient platforms penetrated to a depth of more than 3000 m due to deep degassing processes. The traces of the upward migration of fluids are sealed in the geological sequence, including the sedimentary cover, within secondary inclusions of rocks and minerals. The fluids are complex, reduced, multicomponent systems that transport lithophilous, chalcophilous and siderophilous elements. The presence of microelements in the bituminous phase of inclusions indicates that metals mainly occur in the complexes containing organic ligands. During the evolution of the fluid systems under new pressure and temperature conditions, low-solubility substances were separated out of the fluid to form hard bitumen, and the lighter components migrated into the overlying fractured and porous rocks. The high metal content of carbonaceous substances and their compositional variations governed by homogenisation temperatures of the inclusions suggest that they are not the products of the decomposition of oil fields. The constant presence of uranium in the fluid and its differentiation products allows the tracing of the systems' migration ways from the crystalline basement to oil-saturated reservoir zones of the sedimentary cover The known geochemical properties of bitumen and oil - high platinum content, specific distributions of rare earth elements, that are not characteristic of the upper crust formations, as well as 143Nd/144Nd and 87Sr/86Sr isotopic compounds, which are out of balance with the organic matter of sedimentary rocks - suggest that hydrocarbons are accumulated in the presence of cooling high-alkalinity mafite-ultramafite intrusions. This logically corresponds to the distribution of seismic anomalies and magnetic and gravity fields in the consolidated crust below the various petroleum fields (for example, South Tatarstan and Nepsky arches of the Romashkino and Verkhne-Chonskoye oil fields). The acquired geochemical and thermodynamic characteristics of the reduced fluids and their differentiation products from the crystalline basement and the sedimentary cover of the southern Siberian and eastern East European platforms indicate that these were formed outside of the sedimentary cover and that the migration was directed upwards. The analysis of the magmatic evolution on platforms reveals its alkaline trend due to the impeded degassing of magmatic sources at depth and the inflow of new doses of alkaline fluids or melts into them. Further evolution of the zones of partial melting of the substratum led, in the authors' view, to the generation of oil-forming fluids and their transportation into the Earth's upper crust. Their interaction with the surrounding rocks in turn led to the formation of oil accumulations. Thus, oil is the product of the interaction of deep, reduced fluids. Oil, graphite of the Archaean crystalline complexes a

  9. Geology of Terra Nova oil field, Grand Banks, Newfoundland

    SciTech Connect

    Dwyer, J.D.; Sullivan, G.W.; Park, J.

    1986-05-01

    Oil was discovered at the Petro-Canada et al Terra Nova K-08 well in May 1984. The well was drilled in the Jeanne d'Arc subbasin, 340 km east of St. John's, Newfoundland, and 35 km southeast of the giant Hibernia oil field. Follow-up wells provided log correlations and core data that have been used with a three-dimensional seismic survey to construct a geologic model. Mapping the field demonstrated a combination structural-stratigraphic trap. The reservoir is within the lower part of the Jeanne d'Arc sequence (Upper Jurassic). This conglomeratic sandstone is interpreted as having been deposited in a nearshore to fluvial setting by basinward, northward progradation of fan-delta systems. The reservoir has a depositional limit updip to the south, and is overstepped and sealed by transgressive shales of the upper Jeanne d'Arc. Oil source is from the underlying Egret (Oxfordian-Kimmeridgian) argillaceous limestones. The geologic model and seismic interpretation have been tested by appraisal drilling.

  10. Genesis and formation oil and gas fields (Azerbaijan)

    NASA Astrophysics Data System (ADS)

    Poletayev, Alexander

    2010-05-01

    The large amount of material of HC isotope composition of over 330 samples allow to restore the history of oil and gas deposits formation within the South-Caspian Depression. Maps of isotope composition changes according to area extent, as well as graphs of HC distribution depending upon stratigraphic age, including rocks, graphs of isotope composition change on sampling depth were compiled for HC study and oil-gas deposits formation. Comparison of mud volcanoes gases, oil and gas fields, gas-hydrates and bottom sediments were conducted. Gases genesis according to M. Shoelle and A. James methodic were studied. Model of area paleoconstruction was studied. Two stages of formation were distinguished as a result of gases study of various forms of their manifestation (gases of mud volcanoes, oil and gas fields, gas hydrate, bottom sediments) as well as isotope gases composition distribution in area of extent including stratigraphic age of deposits, depth of sampling and application of M. Shoelle and A. James. There were determined basic ways of HC migration as well as estimated oil-gas content prospective. The first stage has begun in the underlying PS deposits and continued up to PS deposits. At this stage one various kind of tectonic fluctuations can observed. The second stage of HC formation has started from PS and characterised with a change of geodynamic conditions in region. Avalanche sedimentation, predominance of descending movements over ascending ones promoted the accumulation of thick sediments in PS age. As a result of sediments accumulation and tectonic processes (down warping) in the deep-seated basin led to the complication of thermobaric conditions in the sedimentary series. The studied chemical and HC gases isotope composition showed that basic source of oil and gas formation is located in the deep areas of central and near-flank parts of depression. HC migration has mainly occurred upward. Study of HC migration trend in time and area as well as areas of generation etc. allows to reveal some structures where there is evidence of HC accumulation with large and gigantic reserves.

  11. Oil above the Arctic circle. [Milne Point Field

    SciTech Connect

    Dresner, S.

    1985-01-01

    Conoco is developing the company's first Arctic production venture, the Milne Point Field, on Alaska's North Slope. Development will proceed in several phases, with production being maintained. For over 20 years: an initial drilling and production program for the Kuparuk formation, followed by additional drilling to maintain productions as flow from the first wells slows. Subsequent phases in the early 90s would tap the vast reserves of thick oil in another, shallower reservoir. When the project is fully developed, total cost is expected to be near $800 million.

  12. Relationship between lithofacies and reservoir quality in giant oil field: Long Beach unit, Wilmington field, California

    SciTech Connect

    Slatt, R.M.

    1989-04-01

    Long Beach unit is part of the giant Wilmington oil field, Los Angeles basin. Detailed examination of six cores totaling more than 1500 m, 900 core-plug porosity and permeability measurements, and 85 grain size analyses from the major producing interval (the more than 300-m thick Range zone) provided an excellent data set for relating reservoir quality to lithofacies.

  13. Geochemistry of oil-field water from the North Slope

    SciTech Connect

    Kharaka, Y.K.; Carothers, W.W.

    1989-01-01

    Knowledge of the chemical composition of oil-field water is important in understanding the origin and migration of petroleum as well as the water mineral reactions that affect the porosity and permeability of the reservoir rocks. This knowledge is essential in interpreting electric logs and in determining potential pollution, corrosion, and disposal problems of water produced with oil and gas. Finally, the chemical composition of water is an important factor in determining the conditions (temperature, pressure) for the formation of clathrates. This chapter reports detailed chemical analyses of seven formation-water samples from wells within the NPRA and one surface-and two formation-water samples from the Prudhoe Bay oil field. The authors also report {delta}D and {delta}{sup 18}O values for eight of the water samples as well as analyses for gases from six wells. The formation-water samples were obtained from depths ranging from about 700 to 2800 m and from reservoir rocks ranging in age from Mississippian (Lisburne Group) to Triassic. The reservoir rocks are sandstone except for sample 79-AK-5, which was obtained from a limestone interbedded with sandstone. Generally, the pre-Cretaceous sandstone reservoir rocks on the North Slope have a similar mineral composition. Van de Kamp (1979) gave the following description of these sandstones: Quartz (usually monocrystalline) and chert are the major components; carbonate and clay are variable. Carbonate occurs as detrital grains and as cement, siderite being the most common type. Siderite can form as much as 30 percent of the rock. Clay occurs as a common matrix, generally making up less than 10 percent of the rock. Accessory minerals include pyrite, plagioclase, microcline, glauconite, zircon, sphene, tourmaline, and muscovite.

  14. Mathematical simulation of oil fields probing using shock impulse loading

    NASA Astrophysics Data System (ADS)

    Shorr, B. F.; Mel'nikova, G. V.; Khanyan, G. S.

    2007-12-01

    Capabilities of approximate mathematical modeling of the sounding oil fields with use of shock impulses are studied. To this goal, a multilayered column-waveguide extracted from a solid half-space is considered. The analysis is carried out with reference to plane waves propagating in the multilayered medium with arbitrary located layers of various rheological properties. As a source of signals both surface impulses and underwater or underground explosions, single and periodic, and also harmonious excitation are considered, and displacements of a free surface—as the response. The process of wave propagation under repeated reflections from the layer borders is computed numerically with use of the authors' wave finite element method. The amplitude-frequency spectrum of the reflected signals is analyzed both qualitatively and using an original method of "focusing". It is shown, that the analysis of the response for a shock impulse loading allows receiving sufficiently full information about layers' location and thickness. The considered approaches can be used at processing and analyzing the reflected signals obtained experimentally during investigations of oil fields.

  15. Silverthread oil field, Ventura County, California: a hydrodynamic trap

    SciTech Connect

    Hacker, R.N.; Hester, R.L.

    1987-05-01

    Silverthread oil field is located in west-central Ventura County, California. An unusual combination of Miocene turbidite sand deposition, tight folding, faulting, and hydrodynamics have created an accumulation of over 6 million bbl of oil from 33 wells. This field is also unique in that it lies beneath the convergence of several opposing major thrust faults which effectively hide any surface indication of structure at depth. Though previously and often explored by majors and other operators, the remarkable deduction and perseverance by Harry Browne and Argo Petroleum Corporation geologists led to the main area discovery in 1971. Of exceptional interest is the interaction of classic hydrodynamic flow on the distribution of fluids within the reservoir. Thirteen contour maps and numerous structure and stratigraphic sections were required to unravel the sand sequence, faulting, structure, and hydrodynamics. Because of high surface relief, most wells were directionally drilled from islands, and subsequent electric logs had to be unstretched using the Dental Dam technique to facilitate their correlation. A large, lighted, three-dimensional model consisting of thirty-six 2 x 5-ft transparent plexiglas plates was constructed to show a simple resolution of the complexities of this area and will be part of the poster session. This display, they believe, will generate considerable interest in their presentation.

  16. Increasing Heavy Oil Reserves in the Wilmington Oil Field Through Advanced Reservoir Characterization and Thermal Production Technologies, Class III

    SciTech Connect

    City of Long Beach; Tidelands Oil Production Company; University of Southern California; David K. Davies and Associates

    2002-09-30

    The objective of this project was to increase the recoverable heavy oil reserves within sections of the Wilmington Oil Field, near Long Beach, California through the testing and application of advanced reservoir characterization and thermal production technologies. The successful application of these technologies would result in expanding their implementation throughout the Wilmington Field and, through technology transfer, to other slope and basin clastic (SBC) reservoirs.

  17. Petroleum geology of the West Siberian Basin and a detailed description of the Samotlor oil field

    Microsoft Academic Search

    J. W. Clarke; O. W. Jr. Girard; J. Peterson; J. Rachlin

    1977-01-01

    This is the first in a series of planned studies of important oil-gas regions of the world. It is a compilation, along with some interpretation, of the geology of the West Siberian Basin and a description of the Samotlor oil field, the largest field of USSR. The Samotlor oil field produced 2,200,000 bbl\\/day in 1976, about 20% of total USSR

  18. South American oil and gas fields: Reasons for their presence and distribution

    Microsoft Academic Search

    1993-01-01

    South American oil and gas fields occur in geographic clusters. Their concentration in relatively small producing areas depends on the present location of the hydrocarbon generating depocenter and results from the basinal oil and gas migration history. By defining both, existing field locations can be explained and new field occurrences can be predicted, including those in overthrust plays. One-and two-stage

  19. Chemical Characterization of Brines from Selected Oil Fields, Tabasco, México

    NASA Astrophysics Data System (ADS)

    Méndez-Ortiz, B.; Carrillo-Chavez, A.; Tritlla, J.; Levresse, G.; Gonzalez-Partida, E.; Oviedo-Perez, A.; Martinez-Kepm, H.; Gonzalez-Posadas, F.; Clara-Valdes, L.

    2004-12-01

    Thirteen brine samples were recovered from nine oil-producing wells in the Agave (Cretaceous) and Saramako (Cretaceous and Tertiary) oil fields. These samples were analyzed for major and trace elements as well as O and D isotopic compositions. The goal of this study was to compare the possible links between oil-related brines enclosed within Cretaceous and Tertiary productive horizons that were thought to have similar origin oils. The salinity of the Saramako Cretaceous and Tertiary horizons is very constant, around 30000 ppm, one to six times lower than the salinities found in the Agave Cretaceous Field (from 45000 to 170000 ppm). Major ion chemistry suggests that brines are in equilibrium with the host rock. One of the main difference, besides Mg, resides in the S concentrations, were Agave samples present lower concentrations, probably related to the presence of abundant sulfides in the aquifer's rock. Halogen (Br, Cl) systematics indicates a different origin for the Saramako and Agave brines. The Saramako samples halogen composition plot near normal seawater both in the Na/Cl vs Cl/Br (molar ratios) and the Cl vs Br (ppm) plots. The Agave halogen data scatter near and underneath the seawater evaporation line in the Na/Cl vs Cl/Br (molar ratios), suggesting that these fluids could represent seawater evolved past the point of halite precipitation. The Cl vs Br (ppm) plot indicates that these fluids undergone some degree of mixing with low-salinity fluids, probably seawater. The presence of two different groups of data suggests the compartment of the aquifer. The \\deltaD and \\delta18O data show strong differences between the Saramako and Agave brines. The Saramako brine \\delta18O and \\deltaD isotopic compositions are +2.1% (VSMOW) and -13.8% respectively. The Agave samples have a \\delta18O composition from +4.3% to +6.0% and \\deltaD isotopic composition from -20.0% to -12.6%. Differences in \\delta18O compositions between Saramako and Agave brines indicate that the latter fluids were in equilibrium with the host dolostones at certain temperature. Saramako brine composition indicates a near-pristine seawater origin. Agave brines chemical composition suggests an origin related with a bittern formed after evaporation of seawater past the point of halite precipitation, subsequently mixed with seawater. Oxygen isotopic compositions reflect both different host rock and water to rock interaction phenomena, whereas hydrogen isotopic composition can be modified by diagenetic reactions.

  20. Forces and movement of water droplets in oil caused by applied electric field

    Microsoft Academic Search

    A. Pedersen; E. Ildstad; A. Nysveen

    2004-01-01

    The effect of applying an electric field to an emulsion of water and oil is to induce attractive forces and enhance the coalescence of adjacent water droplets. In the oil industry, it is common to utilize this process, called electrocoalescense, to enhance oil-water separation by enlarging the water droplets. The work presented here describes the forces influencing the kinematics of

  1. Optimal Dynamic Production Policy: The Case of a Large Oil Field in Saudi Arabia

    Microsoft Academic Search

    Weiyu Gao; Peter Hartley; Robin C. Sickles

    We model the optimal dynamic oil production decisions for a stylized oilfield resembling the largest developed light oil field in Saudi Arabia, Ghawar. We use data from a number of sources to estimate the cost and revenue functions used in the dynamic programming model. We also pay particular attention to the dynamic aspects of oil production. We use a nonparametric

  2. Integrated Reservoir Characterization and Simulation Studies in Stripper Oil and Gas Fields

    E-print Network

    Wang, Jianwei

    2010-01-14

    The demand for oil and gas is increasing yearly, whereas proven oil and gas reserves are being depleted. The potential of stripper oil and gas fields to supplement the national energy supply is large. In 2006, stripper wells accounted for 15% and 8...

  3. Field studies of leaf gas exchanges in oil palm tree (Elaeis guineensis Jacq.)

    E-print Network

    Paris-Sud XI, Université de

    Field studies of leaf gas exchanges in oil palm tree (Elaeis guineensis Jacq.) E. Dufrene B This study is part of a larger research pro- gram on climatic and biological factors affecting oil palm yield (A) in oil palm. Most of them have used young plants under laboratory conditions to study effects

  4. Genomic and Genotoxic Responses to Controlled Weathered-Oil Exposures Confirm and Extend Field

    E-print Network

    Whitehead, Andrew

    Studies on Impacts of the Deepwater Horizon Oil Spill on Native Killifish Whitney Pilcher1 , Scott Miles2 To understand the ecotoxicological impacts of the Deepwater Horizon oil spill, field studies provide a context of the Deepwater Horizon Oil Spill on Native Killifish. PLoS ONE 9(9): e106351. doi:10.1371/journal.pone.0106351

  5. FIELD TEST KIT FOR CHARACTERIZING OIL-BRINE EFFLUENTS FROM OFFSHORE DRILLING PLATFORMS

    EPA Science Inventory

    This research program was initiated to evaluate test methods for characterizing oil-brine effluents from offshore oil production platforms and to package and deliver a field test kit for on-site oil-brine analyses. After an initial laboratory evaluation and selection of test meth...

  6. Examination of eastern oil shale disposal problems - the Hope Creek field study

    SciTech Connect

    Koppenaal, D.W.; Kruspe, R.R.; Robl, T.L.; Cisler, K.; Allen, D.L.

    1985-02-01

    A field-based study of problems associated with the disposal of processed Eastern oil shale was initiated in mid-1983 at a private research site in Montgomery County, Kentucky. The study (known as the Hope Creek Spent Oil Shale Disposal Project) is designed to provide information on the geotechnical, revegetation/reclamation, and leachate generation and composition characteristics of processed Kentucky oil shales. The study utilizes processed oil shale materials (retorted oil shale and reject raw oil shale fines) obtained from a pilot plant run of Kentucky oil shale using the travelling grate retort technology. Approximately 1000 tons of processed oil shale were returned to Kentucky for the purpose of the study. The study, composed of three components, is described. The effort to date has concentrated on site preparation and the construction and implementation of the field study research facilities. These endeavors are described and the project direction in the future years is defined.

  7. Detection of Virgin Olive Oil Adulteration Using Low Field Unilateral NMR

    PubMed Central

    Xu, Zheng; Morris, Robert H.; Bencsik, Martin; Newton, Michael I.

    2014-01-01

    The detection of adulteration in edible oils is a concern in the food industry, especially for the higher priced virgin olive oils. This article presents a low field unilateral nuclear magnetic resonance (NMR) method for the detection of the adulteration of virgin olive oil that can be performed through sealed bottles providing a non-destructive screening technique. Adulterations of an extra virgin olive oil with different percentages of sunflower oil and red palm oil were measured with a commercial unilateral instrument, the profile NMR-Mouse. The NMR signal was processed using a 2-dimensional Inverse Laplace transformation to analyze the transverse relaxation and self-diffusion behaviors of different oils. The obtained results demonstrated the feasibility of detecting adulterations of olive oil with percentages of at least 10% of sunflower and red palm oils. PMID:24469355

  8. Detection of virgin olive oil adulteration using low field unilateral NMR.

    PubMed

    Xu, Zheng; Morris, Robert H; Bencsik, Martin; Newton, Michael I

    2014-01-01

    The detection of adulteration in edible oils is a concern in the food industry, especially for the higher priced virgin olive oils. This article presents a low field unilateral nuclear magnetic resonance (NMR) method for the detection of the adulteration of virgin olive oil that can be performed through sealed bottles providing a non-destructive screening technique. Adulterations of an extra virgin olive oil with different percentages of sunflower oil and red palm oil were measured with a commercial unilateral instrument, the profile NMR-Mouse. The NMR signal was processed using a 2-dimensional Inverse Laplace transformation to analyze the transverse relaxation and self-diffusion behaviors of different oils. The obtained results demonstrated the feasibility of detecting adulterations of olive oil with percentages of at least 10% of sunflower and red palm oils. PMID:24469355

  9. Chemically bonded phosphate ceramic sealant formulations for oil field applications

    DOEpatents

    Wagh, Arun S. (Naperville, IL); Jeong, Seung-Young (Taejon, KR); McDaniel, Richard (Crest Hill, IL)

    2008-10-21

    A sealant for an oil or geothermal well capable of setting within about 3 to about 6 hours at temperatures less than about 250.degree. F. for shallow wells less than about 10,000 feet and deep wells greater than about 10,000 feet having MgO present in the range of from about 9.9 to about 14.5%, KH.sub.2PO.sub.4 present in the range of from about 29.7 to about 27.2%, class C fly ash present in the range of from about 19.8 to about 36.3%, class F fly ash present in the range of from about 19.8 to about 0%, boric acid or borax present in the range of from about 0.39 to about 1.45%, and water present in the range of from about 20.3 to about 21.86% by weight of the sealant.A method of sealing wells is disclosed as are compositions for very high temperature wells is disclosed as is a composition for treating oil field wastes.

  10. Oil field waste disposal in salt caverns: An information website

    SciTech Connect

    Tomasko, D.; Veil, J. A.

    1999-12-10

    Argonne National Laboratory has completed the construction of a Website for the US Department of Energy (DOE) that provides detailed information on salt caverns and their use for disposing of nonhazardous oil field wastes (NOW) and naturally occurring radioactive materials (NORM). Specific topics in the Website include the following: descriptions of salt deposits and salt caverns within the US, salt cavern construction methods, potential types of wastes, waste emplacement, regulatory issues, costs, carcinogenic and noncarcinogenic human health risks associated with postulated cavern release scenarios, new information on cavern disposal (e.g., upcoming meetings, regulatory issues, etc.), other studies supported by the National Petroleum Technology Office (NPTO) (e.g., considerations of site location, cavern stability, development issues, and bedded salt characterization in the Midland Basin), and links to other associated Web sites. In addition, the Website allows downloadable access to reports prepared on the topic that were funded by DOE. Because of the large quantities of NOW and NORM wastes generated annually by the oil industry, information presented on this Website is particularly interesting and valuable to project managers, regulators, and concerned citizens.

  11. Functional gene diversity of soil microbial communities from five oil-contaminated fields in China

    PubMed Central

    Liang, Yuting; Van Nostrand, Joy D; Deng, Ye; He, Zhili; Wu, Liyou; Zhang, Xu; Li, Guanghe; Zhou, Jizhong

    2011-01-01

    To compare microbial functional diversity in different oil-contaminated fields and to know the effects of oil contaminant and environmental factors, soil samples were taken from typical oil-contaminated fields located in five geographic regions of China. GeoChip, a high-throughput functional gene array, was used to evaluate the microbial functional genes involved in contaminant degradation and in other major biogeochemical/metabolic processes. Our results indicated that the overall microbial community structures were distinct in each oil-contaminated field, and samples were clustered by geographic locations. The organic contaminant degradation genes were most abundant in all samples and presented a similar pattern under oil contaminant stress among the five fields. In addition, alkane and aromatic hydrocarbon degradation genes such as monooxygenase and dioxygenase were detected in high abundance in the oil-contaminated fields. Canonical correspondence analysis indicated that the microbial functional patterns were highly correlated to the local environmental variables, such as oil contaminant concentration, nitrogen and phosphorus contents, salt and pH. Finally, a total of 59% of microbial community variation from GeoChip data can be explained by oil contamination, geographic location and soil geochemical parameters. This study provided insights into the in situ microbial functional structures in oil-contaminated fields and discerned the linkages between microbial communities and environmental variables, which is important to the application of bioremediation in oil-contaminated sites. PMID:20861922

  12. Evidence for a palaeo-oil column and alteration of residual oil in a gas-condensate field: Integrated oil inclusion and experimental results

    NASA Astrophysics Data System (ADS)

    Bourdet, Julien; Burruss, Robert C.; Chou, I.-Ming; Kempton, Richard; Liu, Keyu; Hung, Nguyen Viet

    2014-10-01

    In the Phuong Dong gas condensate field, Cuu Long Basin, Vietnam, hydrocarbon inclusions in quartz trapped a variety of petroleum fluids in the gas zone. Based on the attributes of the oil inclusion assemblages (fluorescence colour of the oil, bubble size, presence of bitumen), the presence of a palaeo-oil column is inferred prior to migration of gas into the reservoir. When a palaeo-oil column is displaced by gas, a residual volume fraction of oil remains in pores. If the gas does not completely mix with the oil, molecular partitioning between the residual oil and the new gas charge may change the composition and properties of the residual oil (gas stripping or gas washing). To simulate this phenomenon in the laboratory, we sealed small amounts of crude oil (42 and 30 °API) and excess pure gas (methane, ethane, or propane) in fused silica capillary capsules (FSCCs), with and without water. These mixtures were characterized with the same methods used to characterize the fluid inclusions, heating and cooling stage microscopy, fluorescence spectroscopy, synchrotron FT-IR, and Raman spectroscopy. At room temperature, mixtures of ethane and propane with the 30 °API oil formed a new immiscible fluorescent liquid phase with colour that is visually more blue than the initial oil. The fluorescence of the original oil phase shifted to yellow or disappeared with formation of semi-solid residues. The blue-shift of the fluorescence of the immiscible phases and strong CH stretching bands in FT-IR spectra are consistent with stripping of hydrocarbon molecules from the oil. In experiments in FSCCs with water solid residues are common. At elevated temperature, reproducing geologic reservoir conditions, the fluorescence changes and therefore the molecular fractionation are enhanced. However, the precipitation of solid residues is responsible of more complex changes. Mixing experiments with the 42 °API oil do not form a new immiscible hydrocarbon liquid although the fluorescence displays a similar yellow shift when gas is added. Solid residues rarely form in mixtures with 42 °API oil. FT-IR spectra suggest that the decrease of fluorescence intensity of the original oil at short wavelengths to be due to the partitioning of low molecular weight aromatic molecules into the vapour phase and/or the new immiscible liquid phase. The decrease of fluorescence intensity at long wavelengths appears to be due to loss of high molecular weight aromatics during precipitation of solid residues by desorption of aromatics and resins from asphaltenes. Desorption of low molecular weight aromatics and resins from asphaltenes during precipitation can also increase the fluorescence intensity at short wavelengths of the residual oil. Water clearly affects the precipitation of semi-solid residues from the oil phase of the lowest API gravity oil. The change of hydrocarbon phase(s) in UV-visible fluorescence and FT-IR enclosed within the FSCCs were compared with the fluorescence patterns of natural fluid inclusions at Phuong Dong gas condensate field. The experimental results support the concept of gas-washing of residual oil and are consistent with the oil inclusion attributes from the current gas zone at Phuong Dong field. The hydrocarbon charge history of the fractured granite reservoir is interpreted to result from the trapping of residual oil after drainage of a palaeo-oil column by gas.

  13. Tax effects upon oil field development in Venezuela

    E-print Network

    Manzano, Osmel

    2000-01-01

    Important reforms have been made to the oil sector tax code in Venezuela. Given its diversity of oil resources, there was a concern that some resources were not being exploited because of the structure of the tax code. ...

  14. Electric field in transformer oil measured with the Kerr-effect technique

    Microsoft Academic Search

    Y. Nonaka; H. Sato; T. Maeno; T. Takada

    1991-01-01

    The electric field distribution in transformer insulating oil was measured as a function of time, both after application of a DC step voltage and after polarity change of the DC voltage, using a highly sensitive advanced Kerr electro-optic technique. The lower limit of the applied electric field intensity was 100 V\\/cm in insulating oil with an electrode length of 8

  15. CUMULATIVE IMPACTS OF OIL FIELDS ON NORTHERN ALASKAN LANDSCAPES (JOURNAL VERSION)

    EPA Science Inventory

    Proposed further developments on Alaska's Arctic Coastal Plain raise questions about cumulative effects on arctic tundra ecosystems of development of multiple large oil fields. Maps of historical changes to the Prudhoe Bay Oil Field show indirect impacts can lag behind planned de...

  16. Integrated reservoir study of the Appleton Oil Field, Escambia County, Alabama

    E-print Network

    Chijuka, Ekene F

    2002-01-01

    The objective of this study is the development of a reservoir characterization of the Appleton Oil Field, Escambia County, Alabama, using petrophysical data, reservoir performance data and reservoir simulation. Appleton Field is comprised of two...

  17. Using biomarkers to improve heavy oil reservoir management: An example from the cymric field, Kern County, California

    Microsoft Academic Search

    M. A. McCaffrey; H. A. Legarre; S. J. Johnson

    1996-01-01

    For biodegraded oil accumulations, field development can be optimized by using geochemical indicators of variations in the extent of bacterial alteration. Biodegradation typically reduces oil producibility by increasing oil viscosity. In the Cymric field (Kern County, California), sidewall core extracts reveal that the extent of oil biodegradation changes substantially over extremely short vertical distances in a shallow, low-permeability reservoir. Zones

  18. Basement reservoir in Zeit Bay oil field, Gulf of Suez

    SciTech Connect

    Zahran, I.; Askary, S.

    1988-02-01

    Fractured basement, one of the most important reservoirs of Zeit Bay field, contains nearly one-third of oil in place of the field. The flow rates per well vary from 700 to 9,000 BOPD. Due to its well-established production potential, 60% of the wells for the development of the field were drilled down to basement. The Zeit Bay basement consists of granitic rocks of pegmatitic to coarse porphyritic texture and has equal proportions of alkali feldspars. Dykes of various compositions are present, traversing the granite at different intervals. Dykes include aplite, microsyenite, diabase and lamprophyre. The last two pertain to the post-granitic dykes of late Proterozoic age. The main granitic pluton is related to one of the final stages of the tectonic-magmatic cycle of the Arabo-Nubian shield. The Zeit Bay area was a significant paleohigh until the Miocene, hence its structural picture is very complicated due to the impact of different tectonic movements from the late Precambrian to Cenozoic. The resulting structural elements were carefully investigated and statistically analyzed to decipher the influence of various tectonic events. The presence of high porosity in some intervals and low porosity in others could be tied to the presence of new fractures and the nature of cementing minerals. The relation of mineralized fractures and their depths lead to zonation of porous layers in the granitic pluton. Diagenetic processes on the granitic body and the alteration/resedimentation of the diagenetic products controlled the magnitude and amplitude of the porosity layers. A model has been constructed to illustrate the changes in the primary rock texture and structure with sequential diagenetic processes, taking into consideration the fracture distribution and their opening affinities as related to their depths.

  19. Basement reservoir in Zeit Bay oil field, Gulf of Suez

    SciTech Connect

    Zahran, I.; Askary, S.

    1988-01-01

    Fractured basement, one of the most important reservoirs of Zeit Bay field, contains nearly one-third of oil in place of the field. The flow rates per well vary from 700 to 9,000 BOPD. Due to its well-established production potential, 60% of the wells for the development of the field were drilled down to basement. The Zeit Bay basement consist of granitic rocks of pegmatitic to coarse porphyritic texture and has equal proportions of alkali feldspars. Dykes of various compositions are present, traversing the granite at different intervals. Dykes include aplite, microsyenite, diabase and lamprophyre. The last two pertain to the post-granitic dykes of later Proterozoic age. The main granitic luton is related to one of the final stages of the tectonic-magmatic cycle of the Arabo-Nubian sheild. The Zeit Bay area was a significant paleohigh until the Miocene, hence its structural picture is very complicated due to the impact of different tectonic movements from the late Precambrian to Cenozoic. The resulting structural elements were carefully investigated and statistically analyzed to decipher the influence of various tectonic events. The presence of high porosity in some intervals and low porosity in others could be tied to the presence of new fractures and the nature of cementing minerals. The relation of mineralized fractures and their depths lead to zonation of porous layers in the granitic pluton. Diagenetic processes on the granitic body and the alternation/resedimentation of the diagenetic products controlled the magnitude and amplitude of the porosity layers.

  20. Increasing Heavy Oil Reserves in the Wilmington Oil Field through Advanced Reservoir Characterization and Thermal Production Technologies

    SciTech Connect

    City of Long Beach; David K.Davies and Associates; Tidelands Oil Production Company; University of Southern California

    1999-06-25

    The objective of this project is to increase the recoverable heavy oil reserves within sections of the Wilmington Oil Field, near Long Beach, California. This is realized through the testing and application of advanced reservoir characterization and thermal production technologies. It is hoped that the successful application of these technologies will result in their implementation throughout the Wilmington Field and through technology transfer, will be extended to increase the recoverable oil reserves in other slope and basin clastic (SBC) reservoirs. The existing steamflood in the Tar zone of Fault Block (FB) II-A has been relatively insufficient because of several producability problems which are common in SBC reservoir; inadequate characterization of the heterogeneous turbidite sands, high permeability thief zones, low gravity oil and non-uniform distribution of the remaining oil. This has resulted in poor sweep efficiency, high steam-oil ratios, and early breakthrough. Operational problems related to steam breakthrough, high reservoir pressure, and unconsolidated sands have caused premature well and downhole equipment failures. In aggregate, these reservoir and operational constraints have resulted in increased operating costs and decreased recoverable reserves.

  1. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2001-06-27

    The objective of this project is to increase the recoverable heavy oil reserves within sections of the Wilmington Oil Field, near Long Beach, California through the testing and application of advanced reservoir characterization and thermal production technologies. The successful application of these technologies will result in expanding their implementation throughout the Wilmington Field and, through technology transfer, to other slope and basin clastic (SBC) reservoirs. The existing steamflood in the Tar zone of Fault Block II-A (Tar II-A) has been relatively inefficient because of several producibility problems which are common in SBC reservoirs: inadequate characterization of the heterogeneous turbidite sands, high permeability thief zones, low gravity oil and non-uniform distribution of the remaining oil. This has resulted in poor sweep efficiency, high steam-oil ratios, and early steam breakthrough. Operational problems related to steam breakthrough, high reservoir pressure, and unconsolidated sands have caused premature well and downhole equipment failures. In aggregate, these reservoir and operational constraints have resulted in increased operating costs and decreased recoverable reserves. A suite of advanced reservoir characterization and thermal production technologies are being applied during the project to improve oil recovery and reduce operating costs.

  2. 77 FR 40637 - Wyatt VI, Inc., A Division of Wyatt Field Service Company, Working On-Site at Hovensa Oil...

    Federal Register 2010, 2011, 2012, 2013, 2014

    2012-07-10

    ...Wyatt Field Service Company, Working On-Site at Hovensa Oil Refinery, Christiansted, St. Croix, VI; Notice of Affirmative Determination...Wyatt Field Service Company, working on-site at Hovensa Oil Refinery, Christiansted, St. Croix, Virgin Islands (subject...

  3. INCREASED OIL RECOVERY FROM MATURE OIL FIELDS USING GELLED POLYMER TREATMENTS

    SciTech Connect

    G.P. Willhite; D.W. Green; C.S. McCool

    2003-05-01

    Gelled polymer treatments are applied to oil reservoirs to increase oil production and to reduce water production by altering the fluid movement within the reservoir. This report describes the results of a three-year research program aimed at reducing barriers to the widespread use of gelled polymer treatments by (1) developing methods to predict gel behavior during placement in matrix rock and fractures, (2) determining the persistence of permeability reduction after gel placement, and (3) developing methods to design production well treatments to control water production. The work focused on the gel system composed of polyacrylamide and chromium acetate. The molar mass of the polymer was about six million. Chromium(III) acetate reacted and formed crosslinks between polymer molecules. The crosslinked polymer molecules, or pre-gel aggregates, combine and grow to eventually form a 3-dimensional gel. A fundamental study to characterize the formation and growth of pre-gel aggregates was conducted. Two methods, flow field-flow fractionation (FFFF) and multi-angle laser light scattering (MALLS) were used. Studies using FFFF were inconclusive. Data taken using MALLS showed that at the gel time the average molar mass of gel aggregates increased by a factor of about three while the average size increase was approximately 50%. Increased acetate concentration in the gelant increases the gel time. The in situ performance of an added-acetate system was investigated to determine the applicability for in-depth treatments. Increased acetate concentrations delayed the development of increased flow resistance during gelant injection in short sandpacks. The development of increased flow resistance (in situ gelation) was extended from 2 to 34 days by increasing the acetate-to-chromium ratio from 38 to 153. In situ gelation occurred at a time that was approximately 22% of the bulk gelation time. When carbonate rocks are treated with gel, chromium retention in the rock may limit in-depth treatment. Chromium retention due to precipitation was investigated by flowing chromium acetate solutions through carbonate rock. Chromium precipitated faster in the rocks than in beaker experiments at similar conditions. A mathematical model previously developed fit the precipitation data reasonably well. The stability of gels when subjected to stress was investigated by experiments with gels placed in tubes and in laboratory-scale fractures. Rupture pressures for gels placed in small diameter tubes were correlated with the ratio of tube length to tube ID. In fractures, fluid leakoff from the fracture to adjacent matrix rock affected gel formation and gel stability in a positive way. Disproportionate permeability reduction (DPR) was studied in unconsolidated sandpacks and in Berea sandstone cores. A conceptual model was developed to explain the presence of DPR. The effect of a pressure gradient, imposed by injection of oil or brine, on the permeability of gel-treated cores was investigated. DPR increased significantly as the pressure gradient was decreased. The magnitude of the pressure gradient had a much larger effect on water permeability than on oil permeability.

  4. Petroleum degradation by aerobic microbiota from the Pampo Sul Oil Field, Campos Basin, Brazil

    Microsoft Academic Search

    Georgiana F. da Cruz; Eugênio V. dos Santos Neto; Anita J. Marsaioli

    2008-01-01

    Aerobic degradation of a crude oil (sample P1), collected from a deep water reservoir from the Pampo Sul Field (Campos Basin, RJ) at 82°C and 2405–2588m, by indigenous bacteria in the oil and formation water was monitored for 60 days. Degradation parameters, measured using gas chromatography–mass spectrometry (GC–MS) of the crude oil degraded in the laboratory for periods of 0,

  5. Magnetic enhancement caused by hydrocarbon migration in the Mawangmiao Oil Field, Jianghan Basin, China

    Microsoft Academic Search

    Qingsheng Liu; Qingsong Liu; Lungsang Chan; Tao Yang; Xianghua Xia; Tongjin Cheng

    2006-01-01

    Magnetic parameters (volume-specific susceptibility ?, and hysteresis parameters and ratios) of 47 samples, collected from an oil-producing well (M36) and a dry well (M46) from the oil-bearing II-You Formation of Paleogene Xingouzui Group in the Mawangmiao Oil Field in China, were measured to address the secondary alteration of iron-bearing minerals associated with hydrocarbon migration. Our results indicated that both ?

  6. The application of oil and gas wells intelligent wireless monitoring system in oil field system

    Microsoft Academic Search

    Qinglin Zhao; Xinchun Gao; Hui Wang; Yapei Yang

    2008-01-01

    In this paper, oil and gas wells intelligent wireless monitoring system can real-time on-line and remotely monitor the information of flux, pressure and temperature in the oil pipelines fluid, can achieve the efficient management of data and sharing of resources, and can realize the enterprise managementpsilas automation and information. The users have shown that the system is running in good

  7. CO 2 sequestration through enhanced oil recovery in a mature oil field

    Microsoft Academic Search

    A. T. F. S. Gaspar Ravagnani; E. L. Ligero; S. B. Suslick

    2009-01-01

    Recent advances in enhanced oil recovery (EOR) technology create new opportunities for CO2 sequestration. This paper proposes a technical–economic model for underground storage of CO2 emitted by a fertilizer industry in the Northeast of Brazil, in a hypothetical mature oil reservoir through EOR operation. Simulations based on mass, energy and entropy balances, as well as economic analysis, were assessed for

  8. Petroleum, oil field waters, and authigenic mineral assemblages: Are they in metastable equilibrium in hydrocarbon reservoirs

    Microsoft Academic Search

    H. C. Helgeson; A. M. Knox; C. E. Owens; E. L. Shock

    1993-01-01

    Although the presence of carboxylic acids and carboxylate anions in oil field waters is commonly attributed to the thermal maturation of kerogen or bacterial degradation of hydrocarbons during water-washing of petroleum in relatively shallow reservoirs, they may have also been produced in deeper reservoirs by the hydrolysis of hydrocarbons in petroleum at the oil-water interface. To test this hypothesis, calculations

  9. Geology and geothermal origin of Grant Canyon and Bacon Flat Oil Fields, Railroad Valley, Nevada

    SciTech Connect

    Hulen, J.B. (Univ. of Utah Research Institute, Salt Lake City, UT (United States)); Goff, F. (Los Alamos National Laboratory, NM (United States)); Ross, J.R. (Apache Corporation, Denver, CO (United States)); Bortz, L.C. (Advantage Resources, Denver, CO (United States)); Bereskin, S.R. (Terra Tek, Inc., Salt Lake City, UT (United States))

    1994-04-01

    Eastern Nevada's Grant Canyon and Bacon Flat oil fields show strong evidence of formation in a still-active, moderate-temperature geothermal system. Modern manifestations of this system include unusually elevated oil-reservoir temperature at shallow depth, 116-122[degrees]C at 1.1-1.6 km, and dilute Na-HCO[sub 3]Cl thermal waters directly associated with hot oil. Hydrogen and oxygen isotopic compositions indicate that these thermal waters are meteoric in origin, but were probably recharged prior to the Holocene (before 10 ka). The waters apparently ascended to oil-reservoir elevations after deep heating in response to the normal regional thermal gradient; there is no evidence for a modern magmatic heat source. The beginning of oil-reservoir evolution at both fields is recorded by late-stage, fracture-filling quartz in the vuggy, brecciated, Paleozoic dolostone reservoir rocks. Oil and aqueous solutions were trapped as fluid inclusions in the quartz at temperatures comparable to those now prevailing in the reservoirs. Present day and fluid-inclusion temperatures define essentially coincident isothermal profiles through and beneath the oil-reservoir interval, a phenomenon consistent with near-constant convective heat transfer since inception of the geothermal system. Some basin and range oil fields have arisen as valuable byproducts of actively circulating geothermal systems and blending this concept into current exploration stratigies could hasten discovery of the 100 mbbl fields many geologists believe remain to be found in this region. 100 refs., 13 figs., 5 tabs.

  10. 108 Florida Entomologist 97(1) March 2014 FIELD EVALUATION OF PETROLEUM SPRAY OIL AND CARBARYL

    E-print Network

    Reddy, Gadi VP

    108 Florida Entomologist 97(1) March 2014 Proof FIELD EVALUATION OF PETROLEUM SPRAY OIL in the West Indies, Bahamas, southern USA, Nicara- gua, Argentina, Brazil and Southeast Asia. Eggplant growers shown petroleum spray oil (PSO) to be effective against T. marianae. We therefore examined

  11. Lessons in microbial geochemistry from the Coal Oil Point seep field: progress as prospects

    Microsoft Academic Search

    D. L. Valentine; F. Kinnaman; G. Wardlaw; M. Redmond; H. Ding; J. Kimball; L. Busso; A. Larson

    2005-01-01

    The hydrocarbon seeps located offshore Coal Oil Point, Santa Barbara, CA, are estimated to emit 1010 grams of methane and 50 thousand barrels of oil annually, and are among the most prolific in the world. The seep field spans a range of shelf depths and many of the seeps are accessible by SCUBA, making this an ideal location to investigate

  12. Energy Conservation and Efficiency Improvement for the Electric Motors Operating in U.S. Oil Fields

    E-print Network

    Ula, S.; Cain, W.; Nichols, T.

    energy use in the U.S. is comparable to all auto energy use. Electric motors are the largest users of energy in all mineral extraction activities. In oil fields, electric motors drive the pumping units used for lifting the oil and water to the surface...

  13. Production and Evaluation of Biodiesel from Field Pennycress (Thlaspi Arvense L.) Oil

    Technology Transfer Automated Retrieval System (TEKTRAN)

    Field pennycress (Thlaspi arvense L.) oil is evaluated for the first time as a potential feedstock for biodiesel production. Biodiesel was obtained in 82 wt % yield by a standard transesterification procedure with methanol and sodium methoxide catalyst at 60 deg C and an alcohol to oil ratio of 6:1...

  14. Aromatic hydrocarbons in distillate cuts of crude oils from new fields of Belorussia

    Microsoft Academic Search

    Yu. G. Egiazarov; V. I. Kulikov; A. M. Smol'skii; E. B. Barkovskaya

    1978-01-01

    In this article we are presenting results from an investigation of the quantitative distribution of aromatic hydrocarbons in the distillate cuts of crude oils from new commercial fields in Belorussia: Zolotukhino (Well 7), Tishkovichi (Well 95), and Barsukovsk (Well 9). The distribution of low-molecular-weight homologs of benzene in these crude oils had been established previously [i] in a determination of

  15. Composition and physical properties of cress ( Lepidium sativum L.) and field pennycress ( Thlaspi arvense L .) oils

    Microsoft Academic Search

    Bryan R. Moser; Shailesh N. Shah; Jill K. Winkler-Moser; Steven F. Vaughn; Roque L. Evangelista

    2009-01-01

    The fatty acid profiles and tocopherol and phytosterol contents of crude oils of cress (Lepidium sativum L.) and field pennycress (Thlaspi arvense L.) are reported, along with yields from the corresponding seeds. The physical properties of these oils were also determined, which included oxidative stability, kinematic viscosity, viscosity index, low temperature fluidity, specific gravity, acid value, lubricity, and iodine value.

  16. Composition and Physical Properties of Cress (Lepidium sativum L.) and Field Pennycress (Thlaspi arvense L.) Oils

    Technology Transfer Automated Retrieval System (TEKTRAN)

    The fatty acid profile and tocopherol, and phytosterol contents of crude cress (Lepidium sativum L.) and field pennycress (Thlaspi arvense L.) oils are reported, along with yields from the corresponding seeds. The physical properties of these oils were also determined, which included oxidative stab...

  17. Washing of field weathered crude oil contaminated soil with an environmentally compatible surfactant, alkyl polyglucoside

    Microsoft Academic Search

    Mei Han; Guodong Ji; Jinren Ni

    2009-01-01

    Weathered crude oil contaminated soils (COCSs), which are much more difficult to remediate than those freshly contaminated, are widespread especially at the sites of oil fields and industries. Surfactant enhanced ex situ soil washing could be used to remediate COCSs, but surfactant toxicity becomes one of the major concerns. In this study, a class of green surfactants, alkyl polyglucosides (APGs),

  18. Department of Mechanical Engineering Spring 2011 Oil Field Spill Containment System

    E-print Network

    Demirel, Melik C.

    PENNSTATE Department of Mechanical Engineering Spring 2011 Oil Field Spill Containment System Overview Fluids associated with Oil and Gas drilling and fracturing operations must be contained at well to contain spills but their mats are very expensive, difficult to install, and most importantly, not leak

  19. ORIGINAL ARTICLE On the origin of oil-field water in the Biyang Depression of China

    E-print Network

    Zhan, Hongbin

    ORIGINAL ARTICLE On the origin of oil-field water in the Biyang Depression of China Yong Fu Æ in the Biyang Depression of China and quantitatively analyzed the chemical features of those samples using to be very low in the groundwater of the Biyang Depression. The concentration of anion in the oil

  20. UK Oil and Gas Collaborative Doctoral Training Centre (2014 start) Project Title: Environmental assessment of deep-water sponge fields in relation to oil and gas

    E-print Network

    Henderson, Gideon

    assessment of deep-water sponge fields in relation to oil and gas activity: a west of Shetland case study, but their sensitivity to oil spills remains a significant knowledge gap[2,3] . This project aims to fill this gap to naturally recover from an oil spill or whether dispersants will facilitate or hinder this recovery

  1. An Analysis of the Distribution and Economics of Oil Fields for Enhanced Oil Recovery-Carbon Capture and Storage

    NASA Astrophysics Data System (ADS)

    Hall, Kristyn Ann

    The rising carbon dioxide emissions contributing to climate change has lead to the examination of potential ways to mitigate the environmental impact. One such method is through the geological sequestration of carbon (CCS). Although there are several different forms of geological sequestration (i.e. Saline Aquifers, Oil and Gas Reservoirs, Unminable Coal Seams) the current projects are just initiating the large scale-testing phase. The lead entry point into CCS projects is to combine the sequestration with enhanced oil recovery (EOR) due to the improved economic model as a result of the oil recovery and the pre-existing knowledge of the geological structures. The potential scope of CCS-EOR projects throughout the continental United States in terms of a systematic examination of individual reservoir storage potential has not been examined. Instead the majority of the research completed has centered on either estimating the total United States storage potential or the potential of a single specific reservoir. The purpose of this paper is to examine the relationship between oil recovery, carbon dioxide storage and cost during CCS-EOR. The characteristics of the oil and gas reservoirs examined in this study from the Nehring Oil and Gas Database were used in the CCS-EOR model developed by Sean McCoy to estimate the lifting and storage costs of the different reservoirs throughout the continental United States. This allows for an examination of both technical and financial viability of CCS-EOR as an intermediate step for future CCS projects in other geological formations. One option for mitigating climate change is to store industrial CO2 emissions in geologic reservoirs as part of a process known as carbon capture and storage (CCS). There is general consensus that large-scale deployment of CCS would best be initiated by combining geologic sequestration with enhanced oil recovery (EOR), which can use CO2 to improve production from declining oil fields. Revenues from the produced oil could help offset the current high costs of CCS. The cumulative potential of CCS-EOR in the continental U.S. has been evaluated in terms of both CO2 storage capacity and additional oil production. This thesis examines the same potential, but on a reservoir-by-reservoir basis. Reservoir properties from the Nehring Oil and Gas Database are used as inputs to a CCS-EOR model developed by McCoy (YR) to estimate the storage capacity, oil production and CCS-EOR costs for over 10,000 oil reservoirs located throughout the continental United States. We find that 86% of the reservoirs could store ?1 y or CO2 emissions from a single 500 MW coal-fired power plant (i.e., 3 Mtons CO2). Less than 1% of the reservoirs, on the other hand, appear capable of storing ?30 y of CO2 emissions from a 500 MW plan. But these larger reservoirs are also estimated to contain 48% of the predicted additional oil that could be produced through CCS-EOR. The McCoy model also predicts that the reservoirs will on average produce 4.5 bbl of oil for each ton of sequestered CO2, a ratio known as the utilization factor. This utilization factor is 1.5 times higher that arrived at by the U.S. Department of Energy, and leads to a cumulative production of oil for all the reservoirs examined of ˜183 billion barrels along with a cumulative storage capacity of 41 Mtons CO2. This is equivalent to 26.5 y of current oil consumption by the nation, and 8.5 y of current coal plant emissions.

  2. ALASKA NORTH SLOPE OIL-FIELD RESTORATION RESEARCH STRATEGY (ANSORRS)

    EPA Science Inventory

    This document provides a research strategy to support ecological restoration of disturbances related to oil and gas developments on the North Slope of Alaska that is mutually beneficial to the arctic ecorestoration research community and the arctic regulatory community (including...

  3. Influence of Temperature and Oil Content on the Soil\\/Air Partition Coefficient for Hexachlorobenzene in Oil-Contaminated Rice Paddy Field Soil

    Microsoft Academic Search

    Xin He; Shuo Chen; Xie Quan; Huimin Zhao; Yazhi Zhao

    2011-01-01

    The soil\\/air partition coefficients (KSA) for hexachlorobenzene (HCB) in oil-contaminated (crude oil and diesel) rice paddy field soils were measured in a solid fugacity meter at different oil concentrations over the temperature range of 5 to 30°C at 100% relative humidity. The results showed that values of KSA increased with a decrease of temperature. As for oil content, there is

  4. Petroleum geology of Sespe field: new oil from an old field

    SciTech Connect

    Lankford, S.M.; Pasquini, D.E.

    1986-04-01

    The Sespe field, discovered 100 years ago, is situated along the north flank of the Ventura basin on the upthrown side of the San Cayetano fault. Production zones range from Eocene to Miocene in age and include the Matilija, Coldwater, and Vaqueros Formations. The Oligocene Sespe Formation is the primary producing zone. Fractured shale of the Miocene Rincon formation also produced but is no longer considered a target. Recent developments demonstrate how additional reserves can be established and produced from an old and nearly fully developed field. A multi-tiered exploitation program ultimately should establish significant new reserves. The field has been drilled on 10-ac spacing, but several recently drilled wells demonstrated that production can be enhanced by infill drilling on 5-ac spacing. The infill wells not only decrease recovery time of proved reserves, but also increase the recoverability of in-place oil from 9% to about 14%. Waterflooding may enhance recoverability even further. After at least nine infill patterns have been drilled, a pilot waterflood project has been planned to determine if displacement can be conducted economically. The authors believe the incremental increase in recoverable reserves of the projects discussed may ultimately exceed all the petroleum produced in the past 100 years. The Sespe field serves as an example of an example of an old field that can be made to yield important new reserves at relatively low risk.

  5. Inversion of field-scale partitioning tracer response for characterizing oil saturation distribution: a streamline approach

    E-print Network

    Iliassov, Pavel Alexandrovich

    2000-01-01

    through 13 production wells. We first determined the permeability distribution in the field by matching conservative tracer responses and then matched partitioning tracer responses to determine oil saturation distribution. The results of our work agree...

  6. Geologic control of natural marine hydrocarbon seep emissions, Coal Oil Point seep field, California

    Microsoft Academic Search

    Ira Leifer; Marc J. Kamerling; Bruce P. Luyendyk; Douglas S. Wilson

    2010-01-01

    High-resolution sonar surveys, and a detailed subsurface model constructed from 3D seismic and well data allowed investigation of the relationship between the subsurface geology and gas-phase (methane) seepage for the Coal Oil Point (COP) seep field, one of the world's largest and best-studied marine oil and gas seep fields, located over a producing hydrocarbon reservoir near Santa Barbara, California. In

  7. Geologic control of natural marine hydrocarbon seep emissions, Coal Oil Point seep field, California

    Microsoft Academic Search

    Ira Leifer; Marc J. Kamerling; Bruce P. Luyendyk; Douglas S. Wilson

    2010-01-01

    High-resolution sonar surveys, and a detailed subsurface model constructed from 3D seismic and well data allowed investigation\\u000a of the relationship between the subsurface geology and gas-phase (methane) seepage for the Coal Oil Point (COP) seep field,\\u000a one of the world’s largest and best-studied marine oil and gas seep fields, located over a producing hydrocarbon reservoir\\u000a near Santa Barbara, California. In

  8. Hydrodynamic effect on oil accumulation in a stratigraphic trap, Kitty Field, Powder River Basin, Wyoming

    E-print Network

    Larberg, Gregory Martin

    1976-01-01

    HYDRODYNAMIC EFFECT ON OIL ACCUMULATION IN A STRATIGRAPHIC TRAP, KITTY FIELD, POWDER RIVER BASIN, WYOMING A Thesis by GREGORY MARTIN LARBERG "I Submitted to the Graduate College of Texas A8M University in partial fulfillment... of the requirement for the degree of MASTER OF SCIENCE August 1976 Major Subject: Geology HYDRODYNAMIC EFFECT ON OIL ACCUMULATION IN A STRATIGRAPHIC TRAP, KITTY FIELD, POWDER RIVER BASIN, WYOMING A Thesis by GREGORY MARTIN LARBERG Approved as to style...

  9. The space-time structure of oil and gas field growth in a complex depositional system

    USGS Publications Warehouse

    Drew, L.J.; Mast, R.F.; Schuenemeyer, J.H.

    1994-01-01

    Shortly after the discovery of an oil and gas field, an initial estimate is usually made of the ultimate recovery of the field. With the passage of time, this initial estimate is almost always revised upward. The phenomenon of the growth of the expected ultimate recovery of a field, which is known as "field growth," is important to resource assessment analysts for several reasons. First, field growth is the source of a large part of future additions to the inventory of proved reserves of crude oil and natural gas in most petroliferous areas of the world. Second, field growth introduces a large negative bias in the forecast of the future rates of discovery of oil and gas fields made by discovery process models. In this study, the growth in estimated ultimate recovery of oil and gas in fields made up of sandstone reservoirs formed in a complex depositional environment (Frio strand plain exploration play) is examined. The results presented here show how the growth of oil and gas fields is tied directly to the architectural element of the shoreline processes and tectonics that caused the deposition of the individual sand bodies hosting the producible hydrocarbon. ?? 1994 Oxford University Press.

  10. IMPROVED APPROACHES TO DESIGN OF POLYMER GEL TREATMENTS IN MATURE OIL FIELDS: FIELD DEMONSTRATION IN DICKMAN FIELD, NESS COUNTY, KANSAS

    SciTech Connect

    Ronald Fowler

    2004-11-30

    This report describes the results of the one-year project entitled ''Improved Approaches to Design of Polymer Gel Treatments in Mature Oil Fields: Field Demonstration in Dickman Field, Ness County, Kansas''. The project was a 12-month collaboration of Grand Mesa Operating Company (a small independent), TIORCO Inc. (a company focused on improved recovery technology) and the University of Kansas. The study undertook tasks to determine an optimum polymer gel treatment design in Mississippian reservoirs, demonstrate application, and evaluate the success of the program. The project investigated geologic and engineering parameters and cost-effective technologies required for design and implementation of effective polymer gel treatment programs in the Mississippian reservoir in the Midcontinent. The majority of Mississippian production in Kansas occurs at or near the top of the Mississippian section just below the regional sub-Pennsylvanian unconformity and karst surface. Dickman Field with the extremely high water cuts and low recovery factors is typical of Mississippian reservoirs. Producibility problems in these reservoirs include inadequate reservoir characterization, drilling and completion design problems, and most significantly extremely high water cuts and low recovery factors that place continued operations at or near their economic limits. Geologic, geophysical and engineering data were integrated to provide a technical foundation for candidate selection and treatment design. Data includes core, engineering data, and 3D seismic data. Based on technical and economic considerations a well was selected for gel-polymer treatment (Grand Mesa Operating Company Tilley No.2). The treatment was not successful due to the small amount of polymer that could be injected. Data from the initial well and other candidates in the demonstration area was analyzed using geologic, geophysical and engineering data. Based on the results of the treatment and the integrated reservoir characterization it was determined that a second polymer-gel treatment could not be justified. The Mississippian reservoir at Dickman Field is much more complex than originally anticipated with numerous reservoir compartments and potential attic oil beneath the irregular Mississippian karst. It appears that remaining oil in place could be best recovered using improved oil recovery techniques such as target infill drilling and horizontal wells.

  11. The discovery and development of the El Dorado (Kansas) oil field

    USGS Publications Warehouse

    Skelton, L.H.

    1997-01-01

    Pioneers named El Dorado, Kansas, in 1857 for the beauty of the site and the promise of future riches but not until 58 years later was black rather than mythical yellow gold discovered when the Stapleton No. 1 oil well came in on October 5, 1915. El Dorado's leaders were envious when nearby towns found huge gas fields and thrived. John Donley, an El Dorado barber, had tried to find either gas or oil in 1878 at a nearby site selected by a spiritualist. He staked out a townsite, spudded a well and drilled 200 feet before running out of money. Wells in 1879 and 1882 produced only brine. In June, 1914, chafed over discovery of oil in nearby Augusta, El Dorado city fathers contracted with Erasmus Haworth, soon to retire from his position as State Geologist, to perform a geological study of the area. His field work outlined the El Dorado Anticline, which unsuccessfully was drilled first in August, 1915. On abandonment, the Wichita Natural Gas Company purchased the lease and drilled the Stapleton No. 1 oil well. More success followed and by 1918, the El Dorado produced 29 million barrels, almost 9% of the nation's oil. Entrepreneurs came and prospered: the Cities Service Oil Company, A.L. Derby, Jack Vickers, and Bill Skelly all became familiar names in Midcontinent oil marketing. Earlier giant fields had hurt the price of crude oil but the El Dorado came in as both World War I and the rapid popularization of motor transport made a market for both light and heavy ends of the refinery stream. The giant gas field never materialized as hoped but in late 1995, the El Dorado Field produced its 300 millionth barrel of oil.

  12. Repellency of aerosol and cream products containing fennel oil to mosquitoes under laboratory and field conditions.

    PubMed

    Kim, Soon-Il; Chang, Kyu-Sik; Yang, Young-Cheol; Kim, Byung-Seok; Ahn, Young-Joon

    2004-11-01

    The repellency of fennel (Foeniculum vulgare Miller)-containing products (5% aerosol and 8% cream) against mosquitoes was compared with those of citronella oil, geranium oil and deet, as well as three commercial repellents, Baby Keeper cream containing IR3535, MeiMei cream containing citronella and geranium oils, and Repellan S aerosol containing 19% N,N-diethyl-m-toluamide (deet) under laboratory and field conditions. In a laboratory study with female Aedes aegypti (L), fennel oil exhibited good repellency in a release-in-cage test and repellency in skin and patch tests of the oil was comparable with those of citronella and geranium oils. In paddy field tests with five human volunteers, 5% and 8% fennel oil-containing aerosol and cream produced 84% and 70% repellency, respectively, at 90 min after exposure, whereas Baby Keeper cream and MeiMei cream gave 71% and 57% repellency at 90 min after exposure, respectively, and Repellan S aerosol gave 89% repellency at 210 min. The species and ratio of mosquitoes collected were the genera Culex (44.1%), Anopheles (42.2%), Aedes (7.8%) and Armigeres (5.9%). Fennel oil-containing products could be useful for protection from humans and domestic animals from vector-borne diseases and nuisance caused by mosquitoes. PMID:15532688

  13. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Unknown

    2001-08-08

    The objective of this project is to increase the recoverable heavy oil reserves within sections of the Wilmington Oil Field, near Long Beach, California, through the testing and application of advanced reservoir characterization and thermal production technologies. The hope is that successful application of these technologies will result in their implementation throughout the Wilmington Field and, through technology transfer, will be extended to increase the recoverable oil reserves in other slope and basin clastic (SBC) reservoirs. The existing steamflood in the Tar zone of Fault Block II-A (Tar II-A) has been relatively inefficient because of several producibility problems which are common in SBC reservoirs: inadequate characterization of the heterogeneous turbidite sands, high permeability thief zones, low gravity oil and non-uniform distribution of the remaining oil. This has resulted in poor sweep efficiency, high steam-oil ratios, and early steam breakthrough. Operational problems related to steam breakthrough, high reservoir pressure, and unconsolidated sands have caused premature well and downhole equipment failures. In aggregate, these reservoir and operational constraints have resulted in increased operating costs and decreased recoverable reserves. A suite of advanced reservoir characterization and thermal production technologies are being applied during the project to improve oil recovery and reduce operating costs, including: (1) Development of three-dimensional (3-D) deterministic and stochastic reservoir simulation models--thermal or otherwise--to aid in reservoir management of the steamflood and post-steamflood phases and subsequent development work. (2) Development of computerized 3-D visualizations of the geologic and reservoir simulation models to aid reservoir surveillance and operations. (3) Perform detailed studies of the geochemical interactions between the steam and the formation rock and fluids. (4) Testing and proposed application of a novel alkaline-steam well completion technique for the containment of the unconsolidated formation sands and control of fluid entry and injection profiles. (5) Installation of a 2100 ft, 14 inch insulated, steam line beneath a harbor channel to supply steam to an island location. (6) Testing and proposed application of thermal recovery technologies to increase oil production and reserves: (a) Performing pilot tests of cyclic steam injection and production on new horizontal wells. (b) Performing pilot tests of hot water-alternating-steam (WAS) drive in the existing steam drive area to improve thermal efficiency. (7) Perform a pilot steamflood with the four horizontal injectors and producers using a pseudo steam-assisted gravity-drainage (SAGD) process. (8) Advanced reservoir management, through computer-aided access to production and geologic data to integrate reservoir characterization, engineering, monitoring and evaluation.

  14. Preliminary technical and legal evaluation of disposing of nonhazardous oil field waste into salt caverns

    SciTech Connect

    Veil, J.; Elcock, D.; Raivel, M.; Caudle, D.; Ayers, R.C. Jr.; Grunewald, B.

    1996-06-01

    Caverns can be readily formed in salt formations through solution mining. The caverns may be formed incidentally, as a result of salt recovery, or intentionally to create an underground chamber that can be used for storing hydrocarbon products or compressed air or disposing of wastes. The purpose of this report is to evaluate the feasibility, suitability, and legality of disposing of nonhazardous oil and gas exploration, development, and production wastes (hereafter referred to as oil field wastes, unless otherwise noted) in salt caverns. Chapter 2 provides background information on: types and locations of US subsurface salt deposits; basic solution mining techniques used to create caverns; and ways in which salt caverns are used. Later chapters provide discussion of: federal and state regulatory requirements concerning disposal of oil field waste, including which wastes are considered eligible for cavern disposal; waste streams that are considered to be oil field waste; and an evaluation of technical issues concerning the suitability of using salt caverns for disposing of oil field waste. Separate chapters present: types of oil field wastes suitable for cavern disposal; cavern design and location; disposal operations; and closure and remediation. This report does not suggest specific numerical limits for such factors or variables as distance to neighboring activities, depths for casings, pressure testing, or size and shape of cavern. The intent is to raise issues and general approaches that will contribute to the growing body of information on this subject.

  15. Assessment of Alaska's North Slope Oil Field Capacity to Sequester CO{sub 2}

    SciTech Connect

    Umekwe, Pascal, E-mail: wpascals@gmail.com [Baker Hughes (United States)] [Baker Hughes (United States); Mongrain, Joanna, E-mail: Joanna.Mongrain@shell.com [Shell International Exploration and Production Co (United States)] [Shell International Exploration and Production Co (United States); Ahmadi, Mohabbat, E-mail: mahmadi@alaska.edu [University of Alaska Fairbanks, Petroleum Engineering Department (United States)] [University of Alaska Fairbanks, Petroleum Engineering Department (United States); Hanks, Catherine, E-mail: chanks@gi.alaska.edu [University of Alaska Fairbanks, Geophysical Institute (United States)] [University of Alaska Fairbanks, Geophysical Institute (United States)

    2013-03-15

    The capacity of 21 major fields containing more than 95% of the North Slope of Alaska's oil were investigated for CO{sub 2} storage by injecting CO{sub 2} as an enhanced oil recovery (EOR) agent. These fields meet the criteria for the application of miscible and immiscible CO{sub 2}-EOR methods and contain about 40 billion barrels of oil after primary and secondary recovery. Volumetric calculations from this study indicate that these fields have a static storage capacity of 3 billion metric tons of CO{sub 2}, assuming 100% oil recovery, re-pressurizing the fields to pre-fracturing pressure and applying a 50% capacity reduction to compensate for heterogeneity and for water invasion from the underlying aquifer. A ranking produced from this study, mainly controlled by field size and fracture gradient, identifies Prudhoe, Kuparuk, and West Sak as possessing the largest storage capacities under a 20% safety factor on pressures applied during storage to avoid over-pressurization, fracturing, and gas leakage. Simulation studies were conducted using CO{sub 2} Prophet to determine the amount of oil technically recoverable and CO{sub 2} gas storage possible during this process. Fields were categorized as miscible, partially miscible, and immiscible based on the miscibility of CO{sub 2} with their oil. Seven sample fields were selected across these categories for simulation studies comparing pure CO{sub 2} and water-alternating-gas injection. Results showed that the top two fields in each category for recovery and CO{sub 2} storage were Alpine and Point McIntyre (miscible), Prudhoe and Kuparuk (partially miscible), and West Sak and Lisburne (immiscible). The study concludes that 5 billion metric tons of CO{sub 2} can be stored while recovering 14.2 billion barrels of the remaining oil.

  16. Field evaluation of essential oils for reducing attraction by the Japanese beetle (Coleoptera: Scarabaeidae).

    PubMed

    Youssef, Nadeer N; Oliver, Jason B; Ranger, Christopher M; Reding, Michael E; Moyseenko, James J; Klein, Michael G; Pappas, Robert S

    2009-08-01

    Forty-one plant essential oils were tested under field conditions for the ability to reduce the attraction of adult Japanese beetles, Popillia japonica Newman (Coleoptera: Scarabaeidae), to attractant-baited or nonbaited traps. Treatments applied to a yellow and green Japanese beetle trap included a nonbaited trap, essential oil alone, a Japanese beetle commercial attractant (phenethyl proprionate:eugenol:geraniol, 3:7:3 by volume) (PEG), and an essential oil plus PEG attractant. Eight of the 41 oils reduced attractiveness of the PEG attractant to the Japanese beetle. When tested singly, wintergreen and peppermint oils were the two most effective essential oils at reducing attractiveness of the PEG attractant by 4.2x and 3.5x, respectively. Anise, bergamont mint, cedarleaf, dalmation sage, tarragon, and wormwood oils also reduced attraction of the Japanese beetle to the PEG attractant. The combination of wintergreen oil with ginger, peppermint, or ginger and citronella oils reduced attractiveness of the PEG attractant by 4.7x to 3.1x. Seventeen of the 41 essential oils also reduced attraction to the nonbaited yellow and green traps, resulting in 2.0x to 11.0x reductions in trap counts relative to nonbaited traps. Camphor, coffee, geranium, grapefruit, elemi, and citronella oils increased attractiveness of nonbaited traps by 2.1x to 7.9x when tested singly, but none were more attractive than the PEG attractant. Results from this study identified several plant essential oils that act as semiochemical disruptants against the Japanese beetle. PMID:19736768

  17. Oil Spill Prevention Response and Cleanup: Google Earth Virtual Field Trip Activity

    NSDL National Science Digital Library

    In this well thought out virtual field trip your students will learn about oil spill prevention response and cleanup methods at various sites in Alaska. It is an excellent activity to teach students about policy and procedures needed to make oil transportation safe. In addition, it is a great science activity to learn about the microbiology methods behind cleaning up oil spills. The 2008 ATEEC Fellows Institute brought 18 community college and high school instructors from the environmental sciences to Alaska. They created virtual field trips using Google Earth. Learn from the experts in this interactive tour complete with video offering expert insight into the world of the oil industry. In this well thought out Google Earth virtual field trip you will learn about oil spill prevention response and cleanup methods at various sites in Alaska highlighting the Alyeska Marine Terminal. An excellent activity to teach students about policy and procedures needed to make oil transportation safe. In addition it is a great science activity to learn about the microbiology methods behind cleaning up oil spills. An excellent teachers guide is included as well. This resource is free to download. Users must first create a login with ATEEC's website to access the file.

  18. Complete Moment Tensor Determination of Induced Seismicity in Unconventional and Conventional Oil/Gas Fields

    NASA Astrophysics Data System (ADS)

    Gu, C.; Li, J.; Toksoz, M. N.

    2013-12-01

    Induced seismicity occurs both in conventional oil/gas fields due to production and water injection and in unconventional oil/gas fields due to hydraulic fracturing. Source mechanisms of these induced earthquakes are of great importance for understanding their causes and the physics of the seismic processes in reservoirs. Previous research on the analysis of induced seismic events in conventional oil/gas fields assumed a double couple (DC) source mechanism. However, recent studies have shown a non-negligible percentage of a non-double-couple (non-DC) component of source moment tensor in hydraulic fracturing events (Šílený et al., 2009; Warpinski and Du, 2010; Song and Toksöz, 2011). In this study, we determine the full moment tensor of the induced seismicity data in a conventional oil/gas field and for hydrofrac events in an unconventional oil/gas field. Song and Toksöz (2011) developed a full waveform based complete moment tensor inversion method to investigate a non-DC source mechanism. We apply this approach to the induced seismicity data from a conventional gas field in Oman. In addition, this approach is also applied to hydrofrac microseismicity data monitored by downhole geophones in four wells in US. We compare the source mechanisms of induced seismicity in the two different types of gas fields and explain the differences in terms of physical processes.

  19. Study on charge behavior in flowing transformer oil\\/pressboard composite insulation system using electro-optic field measurement

    Microsoft Academic Search

    K. Kato; Y. Hashiba; Y. Nakaganii; M. Miyamoto; H. Okubo

    1999-01-01

    In this paper, we measured the electric field in transformer oil\\/pressboard composite system, using a Kerr electro-optic method to discuss the electric field distribution and charge behavior induced by flow electrification. We investigated electric field in both uncharged and charged oil, under different flowing conditions. From the experiments, we could quantitatively estimate and analyze the time transition of electric field

  20. The Tengiz oil field, Pri-Caspian basin, USSR, a super giant of the '80s

    SciTech Connect

    Lisovsky, N.N.; Gogonenkov, G.N.; Petzuukha, Y.A. (Ministry of Oil and Gas, Moscow (USSR))

    1990-05-01

    The supergiant Tengiz oil field, located near the southeastern edge of the Pri-Caspian basin is one of the most important new discoveries made in the last decade. The Tengiz oil field occurs in a desert climate on the edge of the Caspian Sea and experiences extreme temperature variations along with other harsh environmental conditions. The structure was first identified by seismic surveys in 1975 when it became possible to map the base of thick Permian salt. The first exploration well was drilled on the top of the pre-salt structure in 1979 and encountered important oil-bearing carbonates. The drilling of additional appraisal wells and the acquisition of three-dimensional seismic with improved seismic velocities contributed to the development of the Tengiz seismic-geologic model and confirmed the presence of a super-giant oil accumulation. The amplitude of the structure is approximately 1,000 m and covers an area of 400 mi{sup 2}. The oil column exceeds 1,500 m without having encountered an oil-water contact. Proven plus probable reserves are estimated to exceed 18 billion bbl. Oil production rates up to 8,000 bbl/day per well have been experienced. The reservoir rocks, which range from Upper Devonian to Middle Carboniferous, are comprised of biohermal and nodular limestones and characterized by variable porosity and permeability. The best reservoir quality is attributed to widespread fractures, vugs, and solution cavities that supplement the primary porosity. Recrystallization and healed fractures with substantial amounts of solid bitumen are observed throughout the reservoir. The reservoir pressure is abnormally high. The oil gravity is approximately 45{degree} API and the sulfur content is low. There is no gas cap on the Tengiz field, and the oil is highly undersaturated. The associated gas contains a high percentage of H{sub 2}S, which must be considered in field development.

  1. Seed oil development of pennycress under field conditions

    Technology Transfer Automated Retrieval System (TEKTRAN)

    Pennycress (Thlaspi sp) has been targeted as a potential oilseed for the biofuels industry. Its seeds contain ~36% oil, where erucic acid is the major fatty acid presented with 38.1%. Additionally, the physical proprieties of the methyl esters are in the range to satisfy the needs of the biodiesel m...

  2. Recovery Calculations of Oil Fields Using Predictive Models

    Microsoft Academic Search

    Mustafa Versan Kok

    2006-01-01

    Oil reservoirs are often candidates for secondary and tertiary recovery processes. These recovery processes are needed to be screened for priority ranking due to budget, manpower, development, capabilities and permitting limitations. Sensitivity studies also need to be made in order to determine the effects of various operating strategies on project performance and economic feasibility. In this research, the application of

  3. Reservoir Characterization of Plover Lake Heavy-Oil Field

    Microsoft Academic Search

    Larry Lines; Joan Embleton; Mathew Fay; Steve Larter; Tony Settari; Bruce Palmiere; Carl Reine; Douglas Schmitt

    Enhanced production of heavy oil from the Cretaceous and Mississippian sands of Eastern Alberta and Western Saskatchewan presents many challenges - requiring a more complete description of lithology, porosity, permeability and changes in reservoir fluid composition and physical properties. Our reservoir projects near Plover Lake, Saskatchewan seek to produce reservoir models that are consistent with all available data including well

  4. Genesis and formation oil and gas fields (Azerbaijan)

    Microsoft Academic Search

    Alexander Poletayev

    2010-01-01

    The large amount of material of HC isotope composition of over 330 samples allow to restore the history of oil and gas deposits formation within the South-Caspian Depression. Maps of isotope composition changes according to area extent, as well as graphs of HC distribution depending upon stratigraphic age, including rocks, graphs of isotope composition change on sampling depth were compiled

  5. Petroleum geology of Giant oil and gas fields in Turpan Basin Xinjiang China

    SciTech Connect

    Boliang, Hu; Jiajing, Yang, [Lanzhou, Gansu (China)

    1995-08-01

    Turpan Basin is the smallest and the last development basin in three big basins of Xinjiang autonomous region, P.R. China. Since April, 1989, the Shanshan oilfield was discovered, the Oinling, Wenjisang, Midang, Baka, Qiudong and North Putaogou fields were discovered. In 1994, the crude oil productivity of Turpan Basin was a Million tons, with an estimated output of 3 million tons per year by 1995; obviously a key oil productive base in the west basins of China, Tarim, Jungar, Chaidam, Hexi, Erduos and Sichuan Basins. The Turpan Basin is an intermontane basin in a eugeosyncline foldbelt of the north Tianshan Mountains. The oil and gas was produced from the payzone of the Xishanyao, Sanjianfang and Qiketai Formatiosn of the Middle Jurassic series. The geochemical characteristics of the crude oil and gas indicate they derive from the Middle to Lower Jurassic coal series, in which contains the best oil-prone source rocks in the basin.

  6. Oil, gas field growth projections: Wishful thinking or reality?

    USGS Publications Warehouse

    Attanasi, E.D.; Mast, R.F.; Root, D.H.

    1999-01-01

    The observed `field growth' for the period from 1992 through 1996 with the US Geological Survey's (USGS) predicted field growth for the same period are compared. Known field recovery of field size is defined as the sum of past cumulative field production and the field's proved reserves. Proved reserves are estimated quantities of hydrocarbons which geologic and engineering data demonstrate with reasonable certainty to recoverable from known fields under existing economic and operating conditions. Proved reserve estimates calculated with this definition are typically conservative. The modeling approach used by the USGS to characterize `field growth phenomena' is statistical rather that geologic in nature.

  7. Genomic and Genotoxic Responses to Controlled Weathered-Oil Exposures Confirm and Extend Field Studies on Impacts of the Deepwater Horizon Oil Spill on Native Killifish

    PubMed Central

    Pilcher, Whitney; Miles, Scott; Tang, Song; Mayer, Greg; Whitehead, Andrew

    2014-01-01

    To understand the ecotoxicological impacts of the Deepwater Horizon oil spill, field studies provide a context for ecological realism but laboratory-based studies offer power for connecting biological effects with specific causes. As a complement to field studies, we characterized genome-wide gene expression responses of Gulf killifish (Fundulus grandis) to oil-contaminated waters in controlled laboratory exposures. Transcriptional responses to the highest concentrations of oiled water in the laboratory were predictive of field-observed responses that coincided with the timing and location of major oiling. The transcriptional response to the low concentration (?10-fold lower than the high concentration) was distinct from the high concentration and was not predictive of major oiling in the field. The high concentration response was characterized by activation of the molecular signaling pathway that facilitates oil metabolism and oil toxicity. The high concentration also induced DNA damage. The low concentration invoked expression of genes that may support a compensatory response, including genes associated with regulation of transcription, cell cycle progression, RNA processing, DNA damage, and apoptosis. We conclude that the gene expression response detected in the field was a robust indicator of exposure to the toxic components of contaminating oil, that animals in the field were exposed to relatively high concentrations that are especially damaging to early life stages, and that such exposures can damage DNA. PMID:25208076

  8. Rapid subsidence over oil fields measured by SAR

    NASA Technical Reports Server (NTRS)

    Fielding, E. J.; Blom, R. G.; Goldstein, R. M.

    1998-01-01

    The Lost Hills and Belridge oil felds are in the San Joaquin Valley, California. The major oil reservoir is high porosity and low permeability diatomite. Extraction of large volumes from shallow depths causes reduction in pore pressure and subsequent compaction, forming a surface subsidence bowl. We measure this subsidence from space using interferometric analysis of SAR (Synthetic Aperture Radar) data collected by the European Space Agency Remote Sensing Satellites (ERS-1 and ERS-2). Maximum subsidence rates are as high as 40 mm in 35 days or > 400 mm/yr, measured from interferograms with time separations ranging from one day to 26 months. The 8- and 26-month interferograms contain areas where the subsidence gradient exceeds the measurement possible with ERS SAR, but shows increased detail in areas of less rapid subsidence. Synoptic mapping of subsidence distribution from satellite data powerfully complements ground-based techniques, permits measurements where access is difficult, and aids identification of underlying causes.

  9. Process and economic model of in-field heavy oil upgrading using aqueous pyrolysis

    SciTech Connect

    Thorsness, C. B., LLNL

    1997-01-21

    A process and economic model for aqueous pyrolysis in-field upgrading of heavy oil has been developed. The model has been constructed using the ASPEN PLUS chemical process simulator. The process features cracking of heavy oil at moderate temperatures in the presence of water to increase oil quality and thus the value of the oil. Calculations with the model indicate that for a 464 Mg/day (3,000 bbl/day) process, which increases the oil API gravity of the processed oil from 13.5{degree} to 22.4{degree}, the required value increase of the oil would need to be at least $2.80/Mg{center_dot}{degree}API($0.40/bbl{center_dot}{degree}API) to make the process economically attractive. This level of upgrading has been demonstrated in preliminary experiments with candidate catalysts. For improved catalysts capable of having the coke make and increasing the pyrolysis rate, a required price increase for the oil as low as $1.34/Mg{center_dot}{degree}API ($0.21/bbl{center_dot}{degree}API)has been calculated.

  10. Bird Mortality in Oil Field Wastewater Disposal Facilities

    Microsoft Academic Search

    Pedro Ramirez Jr

    2010-01-01

    Commercial and centralized oilfield wastewater disposal facilities (COWDFs) are used in the Western United States for the\\u000a disposal of formation water produced from oil and natural gas wells. In Colorado, New Mexico, Utah, and Wyoming, COWDFs use\\u000a large evaporation ponds to dispose of the wastewater. Birds are attracted to these large evaporation ponds which, if not managed\\u000a properly, can cause

  11. Derivative-Free Optimization for Oil Field Operations

    Microsoft Academic Search

    David Ciaurri; Tapan Mukerji; Louis J. Durlofsky

    \\u000a A variety of optimization problems associated with oil production involve cost functions and constraints that require calls\\u000a to a subsurface flow simulator. In many situations gradient information cannot be obtained efficiently, or a global search\\u000a is required. This motivates the use of derivative-free (non-invasive, blackbox) optimization methods. This chapter describes\\u000a the use of several derivative-free techniques, including generalized pattern search,

  12. Livestock poisoning from oil field drilling fluids, muds and additives

    SciTech Connect

    Edwards, W.C.; Gregory, D.G. (Oklahoma Animal Disease Diagnostic Laboratory, College of Veterinary Medicine, Oklahoma State University, Stillwater (Unites States))

    1991-10-01

    The use and potential toxicity of various components of oil well drilling fluids, muds and additives are presented. Many components are extremely caustic resulting in rumenitis. Solvent and petroleum hydrocarbon components may cause aspiration pneumonia and rumen dysfunction. Some additives cause methemoglobinemia. The most frequently encountered heavy metals are lead, chromium, arsenic, lithium and copper. Considerations for investigating livestock poisoning cases and several typical cases are reviewed.

  13. Observed oil and gas field size distributions: A consequence of the discovery process and prices of oil and gas

    USGS Publications Warehouse

    Drew, L.J.; Attanasi, E.D.; Schuenemeyer, J.H.

    1988-01-01

    If observed oil and gas field size distributions are obtained by random samplings, the fitted distributions should approximate that of the parent population of oil and gas fields. However, empirical evidence strongly suggests that larger fields tend to be discovered earlier in the discovery process than they would be by random sampling. Economic factors also can limit the number of small fields that are developed and reported. This paper examines observed size distributions in state and federal waters of offshore Texas. Results of the analysis demonstrate how the shape of the observable size distributions change with significant hydrocarbon price changes. Comparison of state and federal observed size distributions in the offshore area shows how production cost differences also affect the shape of the observed size distribution. Methods for modifying the discovery rate estimation procedures when economic factors significantly affect the discovery sequence are presented. A primary conclusion of the analysis is that, because hydrocarbon price changes can significantly affect the observed discovery size distribution, one should not be confident about inferring the form and specific parameters of the parent field size distribution from the observed distributions. ?? 1988 International Association for Mathematical Geology.

  14. Economic Implementation and Optimization of Secondary Oil Recovery Process: St. Mary West Field, Lafayette County, Arkansas

    SciTech Connect

    Brock P.E., Cary D.

    2003-03-10

    The purpose of this study was to investigate the economic appropriateness of several enhanced oil recovery processes that are available to a small mature oil field located in southwest Arkansas and to implement the most economic efficient process evaluated. The State of Arkansas natural resource laws require that an oilfield is to be unitized before conducting a secondary recovery project. This requires all properties that can reasonably be determined to include the oil productive reservoir must be bound together as one common lease by a legal contract that must be approved to be fair and equitable to all property owners within the proposed unit area.

  15. An Efficient Multiperiod MINLP Model for Optimal Planning of Offshore Oil and Gas Field Infrastructure

    E-print Network

    Grossmann, Ignacio E.

    1 An Efficient Multiperiod MINLP Model for Optimal Planning of Offshore Oil and Gas Field model for offshore oilfield development problem that is fairly generic and can be extended to include the fields and FPSOs, well drilling schedule and production rates of these three components in each time

  16. Field performance of a laser fluorosensor for the detection of oil spills

    Microsoft Academic Search

    R. A. ONeil; L. Buja-Bijunas; D. M. Rayner

    1980-01-01

    An airborne laser fluorosensor is described that was designed to detect and identify targets by means of the characteristic fluorescence emission spectrum. The first field trials of the sensor over marine oil and dye spills are reported. A correlation technique has been developed that, when applied to the data collected during these field trials, clearly differentiated among dye, the two

  17. Underdeveloped oil fields — Upper Pennsylvanian and lower Wolfcampian carbonate reservoirs of southeast New Mexico

    Microsoft Academic Search

    Ronald F. Broadhead

    1999-01-01

    Carbonate reservoirs in the Cisco and Canyon (Upper Pennsylvanian) and lower Wolfcampian (Permian) sections in the Permian\\u000a Basin of southeast New Mexico, U.S.A. are significant reservoirs for oil and gas. The approximately 400 fields that have produced\\u000a from these reservoirs have yielded a cumulative production of 490 million bbls oil (MMBO; 78 million m3) and 3.2 trillion ft3 (91 billion

  18. De-convoluting mixed crude oil in Prudhoe Bay Field, North Slope, Alaska

    Microsoft Academic Search

    Kenneth E. Peters; L. Scott Ramos; John E. Zumberge; Zenon C. Valin; Kenneth J. Bird

    2008-01-01

    Seventy-four crude oil samples from the Barrow arch on the North Slope of Alaska were studied to assess the relative volumetric contributions from different source rocks to the giant Prudhoe Bay Field. We applied alternating least squares to concentration data (ALS-C) for 46 biomarkers in the range C19–C35 to de-convolute mixtures of oil generated from carbonate rich Triassic Shublik Formation

  19. Evolution of hydrodynamic field, oil-gas migration and accumulation in Songliao Basin, China

    Microsoft Academic Search

    Zhanghua Lou; Rong Zhu; Aimin Jin; Maoming Sun; Xiyuan Cai; Yuanlin Chi

    2004-01-01

    The oil-gas migration and accumulation in the Songliao Basin were analyzed in the view of fluid dynamics by the authors. The\\u000a key point of fluid dynamics is hydrodynamics. Oil-gas migration and accumulation are related closely with formation and evolution\\u000a of hydrodynamic field. Based on abundant data, initial formation pressure and other parameters, such as water head were studied.\\u000a They can

  20. The Phylogenetic Diversity of Aerobic Organotrophic Bacteria from the Dagang High-Temperature Oil Field

    Microsoft Academic Search

    T. N. Nazina; D. Sh. Sokolova; N. M. Shestakova; A. A. Grigoryan; E. M. Mikhailova; T. L. Babich; A. M. Lysenko; T. P. Tourova; A. B. Poltaraus; Qingxian Feng; Fangtian Ni; S. S. Belyaev

    2005-01-01

    The distribution and species diversity of aerobic organotrophic bacteria in the Dagang high-temperature oil field (China), which is exploited with water-flooding, have been studied. Twenty-two strains of the most characteristic thermophilic and mesophilic aerobic organotrophic bacteria have been isolated from the oil stratum. It has been found that, in a laboratory, the mesophilic and thermophilic isolates grow in the temperature,

  1. Planning and management of the Nido Reef Complex Oil Field development, Philippines

    SciTech Connect

    Harry, R.Y.

    1981-01-01

    As Operator for the Northeast Palawan consortium, Philippines-Cities Service, Inc., commenced the Philippines first commercial offshore oil production from the Nido Reef Complex Oil Field on February 1, 1979, some 11 months after a decision by management to start development. The relative speed at which design, fabrication, and construction were accomplished is attributed to the use of the concepts of project planning, task force approach, and project management. This paper presents the above concepts as applied to the Nido Complex.

  2. Finite element simulation of Wilmington oil field subsidence: I. Linear modelling

    NASA Astrophysics Data System (ADS)

    Kosloff, D.; Scott, R. F.; Scranton, J.

    1980-06-01

    The Wilmington oil field in Long Beach California has been a site of large ground subsidence since the onset of production. The cause of the subsidence has been attributed to the lowering of pore fluid pressures in the formations of the field. In this study the subsidence in the Wilmington field is simulated numerically by solving the equilibrium equations for a region of the earth's crust containing the oil field. The input parameters for the calculation include a linearly elastic rheological mode for the formations of the field and pore pressure values at the producing zones at specified times. It is found that the numerical simulations can reproduce reasonably well most field observations. There remain however a few observations which the present model cannot explain, a fact which suggests that the material response of the field is more complicated than that of the linearly elastic model adopted in the present study.

  3. Optical measurement of electric field in transformer oil\\/pressboard composite insulation system and discussion on charge dynamics

    Microsoft Academic Search

    M. Hikita; Atsushi SAWADA; Katsumi KATO; Hitoshi OKUBO

    1997-01-01

    We measured an electric field in transformer oil\\/pressboard composite insulation system under dc voltage application using Kerr effect in the oil. When a pressboard was inserted between two parallel-plane electrodes, the electric field between the pressboard and the cathode decreased monotonously with time. On the other hand, the electric field between the pressboard and the anode increased with time, reached

  4. Reserve Growth in Oil Fields of West Siberian Basin, Russia

    Microsoft Academic Search

    Mahendra K. Verma; Gregory F. Ulmishek

    2003-01-01

    Although reserve (or field) growth has proved to be an important contributing factor in adding new reserves in mature petroleum basins, it is a poorly understood phenomenon. Although several papers have been published on the U.S. fields, there are only a few publications on fields in other petroleum provinces. This paper explores the reserve growth in the 42 largest West

  5. Methane-forming bacteria of oil-fields

    SciTech Connect

    Laurinavichus, K.S.; Obraztsova, A.Ya.; Belyaev, S.S.; Ivanov, M.V.

    1983-03-01

    Pure cultures of the methanogenic bacteria, Methanobacterium bryantii and M. formicicum have been isolated, for the first time from oil deposits and their morphological, physiological and biochemical properties studied. All strains grow of H/sub 2//CO/sub 2/ and two of the three M. formicicum also utilize formate as a role source of carbon and energy. In no case could methanol, acetate, methylamine or glucose serve as an energy source for these autotrophs. All strains were resistant to penicillin and streptomycin and neither sulfate or sulfide inhibited their growth. Medium salinity inhibited the growth of M. bryantii but not that of M. formicicum.

  6. The Tengis oil field, Pri-Caspian basin, USSR - A super giant of the 1980s

    SciTech Connect

    Petzoukha, Y.A. (Ministry of Petroleum Industry, Moscow (USSR))

    1990-09-01

    The super giant Tengiz oil field, located near the southeastern edge of the Pri-Caspian basin, is one of the most important new discoveries in the world made in the last decade. The field is in a desert climate on the edge of the Caspian Sea and experiences extreme temperature variations along with other harsh environmental conditions. The structure was first identified by seismic surveys in 1975 when it became possible to map the base of thick Permian salt. The first exploration well was drilled on the top of the presalt structure in 1979 and encountered important oil-bearing carbonates. The drilling of additional appraisal wells and the acquisition of three-dimensional seismic with improved seismic velocities led to the development of the Tengiz seismic-geologic model and confirmed the presence of a super giant oil accumulation. The amplitude of the structure is approximately 1,000 m and covers an area of 400 km{sup 2} . The oil column exceeds 1,500 m without having encountered an oil-water contact. The total original oil and gas in place of the Tengiz field are estimated at 25 billion bbl of oil and 46 tcf of associated gas. Oil production rates up to 8,000 bbl/day per well have been experienced. The reservoir rocks, which range in age from Upper Devonian to Middle Carboniferous, are comprised of biohermal and nodular limestones and characterized by variable porosity and permeability. The best reservoir quality is attributed to widespread fractures, vugs, and solution cavities that supplement the primary porosity. Recrystallization and healed fractures with substantial amounts of solid bitumen are observed throughout the reservoir. The reservoir pressure is abnormally high. The oil gravity is approximately 45{degree} API and the sulfur content is low. There is no gas cap on the Tengiz field, and the oil is highly undersaturated. The associated gas contains a high percentage of H{sub 2}S, which must be considered in field development.

  7. Pilot test of alkaline surfactant polymer flooding in Daqing Oil Field

    SciTech Connect

    Wang Demin; Zhang Zhenhua; Cheng Jiecheng; Yang Jingchun; Gao Shutang; Li Lin

    1996-12-31

    After the success of polymer flooding in Daqing, two alkaline-surfactant-polymer (ASP) floods have been conducted to (1) increase oil recovery further (2) study the feasibility of ASP flooding (3) provide technical and practical experience for expanding the ASP pilots. Inverted five spot pattern is adopted in both pilots. Pilot 1 (PO) is located in the West Central area of Daqing Oil Field and consists of 4 injectors and 9 producers. Pilot 2 (XF) is located in the South area of Daqing Oil Field and has 1 injector and 4 producers. The crude oil of both pilots have high paraffin content and low acid value. Compared to PO, XF has characteristics of lower heterogeneity, lighter oil and higher recovery by water flooding. For each pilot, after extensive screening, an ASP system has been determined. The ASP systems all feature very low surfactant concentration and wide range of ultra low interfacial tension with change of concentration of any of the three components. Core flooding and numerical simulation show more than 20% OOIP incremental recovery by ASP over water flooding for both pilots. By the end of May, 1995, 100% of ASP slug and 100% of the polymer buffer have been injected in the pilots. Production wells showed good responses in terms of large decrease in water cut and increase in oil production. The performance of each pilot has followed the numerical simulation predication very well, or even a bit better. Emulsions showed up in producers, but the emulsions are easy to be broken by a special de-emulsifier. No formation damage and scaling have been detected. The ASP flood pilot tests are technically successful and, based on the preliminary evaluation, economically feasible. Therefore, in the near future, much larger scale ASP flood field tests are going to be performed at several districts in Daqing Oil Field.

  8. Polarity characterization of crude oils predicts treatment trends in field development

    SciTech Connect

    Andrade Bruening, I.M.R. de

    1995-11-01

    A method for determining crude oil polarity using inverse gas chromatography proved successful for classifying crudes as well as for assessing their ability to form stable emulsions with water. Polarity determinations have been applied to the formation test crude oil samples collected in Albacora and Marlim deepwater fields of the Campos Basin, Rio de Janeiro, Brazil. The results have been compared with the polarities of the first produced crudes of the Basin and showed that the emulsion separation problems tend to increase. Polarity results provided substantial data to help production field development decisions.

  9. NAFTA opportunities: Oil and gas field drilling machinery and services sector

    SciTech Connect

    Not Available

    1993-01-01

    The North American Free Trade Agreement (NAFTA) significantly improves market access in Mexico and Canada for U.S. exports of oil and gas field equipment. Foreign markets account for more than 80 percent of U.S. shipments of oil and gas field machinery. Foreign markets are expected to continue their importance to this industry, in the long term. Mexico and Canada are moderate-sized markets for U.S. exports of oilfield products. In 1992, U.S. exports of this equipment amounted to about $113 million to Mexico and $11 million to Canada.

  10. Hydro geochemistry Study of Yamama formation water in southern Iraqi oil Fields, Migration,Diagensis

    NASA Astrophysics Data System (ADS)

    Ali, A. A.; SOC Team

    2013-05-01

    Yamama Formation (Lower Cretaceous) form one of the main oil reservoir in southern Iraq, the present study deals with the general physical and chemical characteristics of Yamama formation water in selected oil fields - southern Iraq. Via the collecting the available water analysis data in in selected 10 wells in southern Iraqi oil fields, Well Logs, as well as, the technical final well reports. The task of this study is to illustrate the chemical and physical variation among the study oil wells, and their relation with the depositional environment, the grading of temperature and pressure, the reason behind of over pressure phenomenon, besides the delineation of oil migration and water reservoir movement direction. The study confirms the occurrences of two types of formation water; the first one is the connate water, which is brine, hypersaline, and marine in nature reflects the possibility of hydrocarbon accumulations. And the second is mixing water reflects the mixing of original marine water with percolating meteoric water for various degree. Regarding the hydrochemical ratios, the direction of water movement and oil migration is from northeast toward west and south west starting from Messan oil Fields, moreover, the secondary migration of oil is in the same direction. The western migration of oil and water attributed to the enhancement of porosity and permeability in this direction, which in turn means the possibility of finding new stratigraphic traps in this direction mainly western of Nasiriya and Garraf areas. The relationship between depositional environment and diagenetic processes in one hand, and the sediment logical units; tidal lime granular unit revealed the occurrences of khidar al-may which extends up to Al-Managish in Kuwait and Nahar Umar - Majnoon, Nasiriya - Abu Amood, as well as the clayey units represented by isolated and semi isolated lagoonal deposits. Based on the ionic ratios in AlZubair, Nahar Umer and Al-Kifil oil fields, outer shelf clay units was identified as zones extends from Kumait - Halfaia - Noor. This study also showed the major role of diagenetic processes such as dissolution and low dolomitization in granular units in changing the chemical composition of Yamama Formation water under study. The ionic ratios and concentration pointed out the occurrences of many sub-basins within the Yamama main basin. The present study showed the movement of formation water is from the centre of the basin toward the periphery, furthermore, the sulphate index clarify the increases in hydrocarbone preservation toward east and northeast direction. .

  11. FIELD MANUAL FOR OIL SPILLS IN COLD CLIMATES

    EPA Science Inventory

    This manual documents the state-of-the-art response techniques as of early 1979. The manual has been divided into two basic parts: A field manual and supporting data. The field manual consists of a set of matrices that summarizes applicable techniques for various conditions. The ...

  12. Field experiments of multi-channel oceanographic fluorescence lidar for oil spill and chlorophyll- a detection

    NASA Astrophysics Data System (ADS)

    Li, Xiaolong; Zhao, Chaofang; Ma, Youjun; Liu, Zhishen

    2014-08-01

    A Multi-channel Oceanographic Fluorescence Lidar (MOFL), with a UV excitation at 355 nm and multiple receiving channels at typical wavelengths of fluorescence from oil spills and chlorophyll- a (Chl- a), has been developed using the Laser-induced Fluorescence (LIF) technique. The sketch of the MOFL system equipped with a compact multi-channel photomultiplier tube (MPMT) is introduced in the paper. The methods of differentiating the oil fluorescence from the background water fluorescence and evaluating the Chl- a concentration are described. Two field experiments were carried out to investigate the field performance of the system, i.e., an experiment in coastal areas for oil pollution detection and an experiment over the Yellow Sea for Chl- a monitoring. In the coastal experiment, several oil samples and other fluorescence substances were used to analyze the fluorescence spectral characteristics for oil identification, and to estimate the thickness of oil films at the water surface. The experiment shows that both the spectral shape of fluorescence induced from surface water and the intensity ratio of two channels ( I 495/ I 405) are essential to determine oil-spill occurrence. In the airborne experiment, MOFL was applied to measure relative Chl- a concentrations in the upper layer of the ocean. A comparison of relative Chl- a concentration measurements by MOFL and the Moderate Resolution Imaging Spectroradiometer (MODIS) indicates that the two datasets are in good agreement. The results show that the MOFL system is capable of monitoring oil spills and Chl- a in the upper layer of ocean water.

  13. Elastomers in mud motors for oil field applications

    SciTech Connect

    Hendrik, J. [Baker Hughes INTEQ GmbH, Celle (Germany)

    1997-08-01

    Mud motors, the most frequently used downhole drilling motors in modern drilling systems, are described in their application and function. The elastomeric liner in a mud motor acts as a huge continuous seal. Important properties of elastomers such as chemical resistance, fatigue resistance, mechanical strength, abrasion resistance, bonding to steel and processability are discussed. Advantages and disadvantages of NBR, HNBR, FKM, TFEP, and EPDM elastomers for mud motor applications are briefly described. The importance of drilling fluids and their physical and chemical impact on motor elastomers are described. Drilling fluids are categorized in: oil based-, synthetic-, and water based. Results of compatibility tests in the different drilling muds of the presented categories demonstrate the complexity of elastomer development. Elastomers with an equally good performance in all drilling muds are not available. Future developments and improvements are directed towards higher chemical resistance at higher service temperatures. This will be possible only with improved elastomer-to-metal bonding, increased mechanical and better dynamic properties.

  14. Programed oil generation of the Zubair Formation, Southern Iraq oil fields: Results from Petromod software modeling and geochemical analysis

    USGS Publications Warehouse

    Al-Ameri, T. K.; Pitman, J.; Naser, M.E.; Zumberge, J.; Al-Haydari, H. A.

    2011-01-01

    1D petroleum system modeling was performed on wells in each of four oil fields in South Iraq, Zubair (well Zb-47), Nahr Umr (well NR-9), West Qurna (well WQ-15 and 23), and Majnoon (well Mj-8). In each of these fields, deposition of the Zubair Formation was followed by continuous burial, reaching maximum temperatures of 100??C (equivalent to 0. 70%Ro) at depths of 3,344-3,750 m of well Zb-47 and 3,081. 5-3,420 m of well WQ-15, 120??C (equivalent to 0. 78%Ro) at depths of 3,353-3,645 m of well NR-9, and 3,391-3,691. 5 m of well Mj-8. Generation of petroleum in the Zubair Formation began in the late Tertiary, 10 million years ago. At present day, modeled transformation ratios (TR) indicate that 65% TR of its generation potential has been reached in well Zb-47, 75% TR in well NR-9 and 55-85% TR in West Qurna oil field (wells WQ-15 and WQ-23) and up to 95% TR in well Mj-8, In contrast, younger source rocks are immature to early mature (<20% TR), whereas older source rocks are mature to overmature (100% TR). Comparison of these basin modeling results, in Basrah region, are performed with Kifle oil field in Hilla region of western Euphrates River whereas the Zubair Formation is immature within temperature range of 65-70??C (0. 50%Ro equivalent) with up to 12% (TR = 12%) hydrocarbon generation efficiency and hence poor generation could be assessed in this last location. The Zubair Formation was deposited in a deltaic environment and consists of interbedded shales and porous and permeable sandstones. In Basrah region, the shales have total organic carbon of 0. 5-7. 0 wt%, Tmax 430-470??C and hydrogen indices of up to 466 with S2 = 0. 4-9. 4 of kerogen type II & III and petroleum potential of 0. 4-9. 98 of good hydrocarbon generation, which is consistent with 55-95% hydrocarbon efficiency. These generated hydrocarbons had charged (in part) the Cretaceous and Tertiary reservoirs, especially the Zubair Formation itself, in the traps formed by Alpine collision that closed the Tethys Ocean between Arabian and Euracian Plates and developed folds in Mesopotamian Basin 15-10 million years ago. These traps are mainly stratigraphic facies of sandstones with the shale that formed during the deposition of the Zubair Formation in transgression and regression phases within the main structural folds of the Zubair, Nahr Umr, West Qurna and Majnoon Oil fields. Oil biomarkers of the Zubair Formation Reservoirs are showing source affinity with mixed oil from the Upper Jurassic and Lower Cretaceous strata, including Zubair Formation organic matters, based on presentation of GC and GC-MS results on diagrams of global petroleum systems. ?? 2010 Saudi Society for Geosciences.

  15. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2003-09-04

    The overall objective of this project is to increase heavy oil reserves in slope and basin clastic (SBC) reservoirs through the application of advanced reservoir characterization and thermal production technologies. The project involves improving thermal recovery techniques in the Tar Zone of Fault Blocks II-A and V (Tar II-A and Tar V) of the Wilmington Field in Los Angeles County, near Long Beach, California. A primary objective is to transfer technology which can be applied in other heavy oil formations of the Wilmington Field and other SBC reservoirs, including those under waterflood. The thermal recovery operations in the Tar II-A and Tar V have been relatively inefficient because of several producibility problems which are common in SBC reservoirs. Inadequate characterization of the heterogeneous turbidite sands, high permeability thief zones, low gravity oil, and nonuniform distribution of remaining oil have all contributed to poor sweep efficiency, high steam-oil ratios, and early steam breakthrough. Operational problems related to steam breakthrough, high reservoir pressure, and unconsolidated formation sands have caused premature well and downhole equipment failures. In aggregate, these reservoir and operational constraints have resulted in increased operating costs and decreased recoverable reserves. The advanced technologies to be applied include: (1) Develop three-dimensional (3-D) deterministic and stochastic geologic models. (2) Develop 3-D deterministic and stochastic thermal reservoir simulation models to aid in reservoir management and subsequent development work. (3) Develop computerized 3-D visualizations of the geologic and reservoir simulation models to aid in analysis. (4) Perform detailed study on the geochemical interactions between the steam and the formation rock and fluids. (5) Pilot steam injection and production via four new horizontal wells (2 producers and 2 injectors). (6) Hot water alternating steam (WAS) drive pilot in the existing steam drive area to improve thermal efficiency. (7) Installing an 2400 foot insulated, subsurface harbor channel crossing to supply steam to an island location. (8) Test a novel alkaline steam completion technique to control well sanding problems and fluid entry profiles. (9) Advanced reservoir management through computer-aided access to production and geologic data to integrate reservoir characterization, engineering, monitoring, and evaluation.

  16. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2004-03-05

    The overall objective of this project is to increase heavy oil reserves in slope and basin clastic (SBC) reservoirs through the application of advanced reservoir characterization and thermal production technologies. The project involves improving thermal recovery techniques in the Tar Zone of Fault Blocks II-A and V (Tar II-A and Tar V) of the Wilmington Field in Los Angeles County, near Long Beach, California. A primary objective is to transfer technology which can be applied in other heavy oil formations of the Wilmington Field and other SBC reservoirs, including those under waterflood. The thermal recovery operations in the Tar II-A and Tar V have been relatively inefficient because of several producibility problems which are common in SBC reservoirs. Inadequate characterization of the heterogeneous turbidite sands, high permeability thief zones, low gravity oil, and nonuniform distribution of remaining oil have all contributed to poor sweep efficiency, high steam-oil ratios, and early steam breakthrough. Operational problems related to steam breakthrough, high reservoir pressure, and unconsolidated formation sands have caused premature well and downhole equipment failures. In aggregate, these reservoir and operational constraints have resulted in increased operating costs and decreased recoverable reserves. The advanced technologies to be applied include: (1) Develop three-dimensional (3-D) deterministic and stochastic geologic models. (2) Develop 3-D deterministic and stochastic thermal reservoir simulation models to aid in reservoir management and subsequent development work. (3) Develop computerized 3-D visualizations of the geologic and reservoir simulation models to aid in analysis. (4) Perform detailed study on the geochemical interactions between the steam and the formation rock and fluids. (5) Pilot steam injection and production via four new horizontal wells (2 producers and 2 injectors). (6) Hot water alternating steam (WAS) drive pilot in the existing steam drive area to improve thermal efficiency. (7) Installing an 2400 foot insulated, subsurface harbor channel crossing to supply steam to an island location. (8) Test a novel alkaline steam completion technique to control well sanding problems and fluid entry profiles. (9) Advanced reservoir management through computer-aided access to production and geologic data to integrate reservoir characterization, engineering, monitoring, and evaluation.

  17. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2003-06-04

    The overall objective of this project is to increase heavy oil reserves in slope and basin clastic (SBC) reservoirs through the application of advanced reservoir characterization and thermal production technologies. The project involves improving thermal recovery techniques in the Tar Zone of Fault Blocks II-A and V (Tar II-A and Tar V) of the Wilmington Field in Los Angeles County, near Long Beach, California. A primary objective is to transfer technology which can be applied in other heavy oil formations of the Wilmington Field and other SBC reservoirs, including those under waterflood. The thermal recovery operations in the Tar II-A and Tar V have been relatively inefficient because of several producibility problems which are common in SBC reservoirs. Inadequate characterization of the heterogeneous turbidite sands, high permeability thief zones, low gravity oil, and nonuniform distribution of remaining oil have all contributed to poor sweep efficiency, high steam-oil ratios, and early steam breakthrough. Operational problems related to steam breakthrough, high reservoir pressure, and unconsolidated formation sands have caused premature well and downhole equipment failures. In aggregate, these reservoir and operational constraints have resulted in increased operating costs and decreased recoverable reserves. The advanced technologies to be applied include: (1) Develop three-dimensional (3-D) deterministic and stochastic geologic models. (2) Develop 3-D deterministic and stochastic thermal reservoir simulation models to aid in reservoir management and subsequent development work. (3) Develop computerized 3-D visualizations of the geologic and reservoir simulation models to aid in analysis. (4) Perform detailed study on the geochemical interactions between the steam and the formation rock and fluids. (5) Pilot steam injection and production via four new horizontal wells (2 producers and 2 injectors). (6) Hot water alternating steam (WAS) drive pilot in the existing steam drive area to improve thermal efficiency. (7) Installing an 2400 foot insulated, subsurface harbor channel crossing to supply steam to an island location. (8) Test a novel alkaline steam completion technique to control well sanding problems and fluid entry profiles. (9) Advanced reservoir management through computer-aided access to production and geologic data to integrate reservoir characterization, engineering, monitoring, and evaluation.

  18. Map Showing Geology, Oil and Gas Fields and Geologic Provinces of Africa, Ver. 2.0

    NSDL National Science Digital Library

    Ahlbrandt, Thomas S.

    The US Geological Survey offers the Map Showing Geology, Oil and Gas Fields and Geologic Provinces of Africa Web site and report. The agency's goal for the pieces includes assessing the undiscovered and technically recoverable oil and gas resources of the world. The site includes various descriptions of what the map depicts and how data was processed using Geographic Information Systems. Once the interactive map is activated, users can search and click the map of Africa to view geologic provinces, oil and gas fields, as well as the various surface geological classifications. Although the interface is a bit cumbersome and works best with a fast Internet connection, the unique information provided should draw the attention of those interested in geology. [JAB

  19. Exploration and development of oil and gas field on the shelf of Sakhalin

    SciTech Connect

    Bogdanchikov, S.M.; Astafiev, V.N.; Bojarshin, E.K. [JSC Sakhalinmorneftegas, Okha (Russian Federation)

    1995-12-31

    The paper describes the level of investigation of Sakhalin shelf for 17 years of prospecting and exploration. 8 oil and gas fields have been discovered with the total recoverable reserves ca. 272 million tons of crude oil and 819 billion m{sup 3} of gas. In the nearest 5--7 years the intensive exploration of these sectors by the companies-winners of tenders is expected. The volumes of drilling can reach 45,000-50,000 m/year. The deterrents are severe environmental conditions on the Sakhalin shelf, which are characterized by a short summer season and complicated ice conditions in winter. Offshore fields of Sakhalin can become one of the most promising sources of import of crude oil and LNG to the countries of Asia Pacific region.

  20. [The phylogenetic diversity of aerobic organotrophic bacteria from the Dagan high-temperature oil field].

    PubMed

    Nazina, T N; Sokolova, D Sh; Shestakova, N M; Grigor'ian, A A; Mikha?lova, E M; Babich, T L; Lysenko, A M; Turova, T P; Poltaraus, A B; Feng, Tsin'syan; Ni, Fangtian; Beliaev, S S

    2005-01-01

    The distribution and species diversity of aerobic organotrophic bacteria in the Dagan high-temperature oil field (China), which is exploited via flooding, have been studied. Twenty-two strains of the most characteristic thermophilic and mesophilic aerobic organotrophic bacteria have been isolated from the oil stratum. It has been found that, in a laboratory, the mesophilic and thermophilic isolates grow in the temperature, pH, and salinity ranges characteristic of the injection well near-bottom zones or of the oil stratum, respectively, and assimilate a wide range of hydrocarbons, fatty acids, lower alcohols, and crude oil, thus exhibiting adaptation to the environment. Using comparative phylogenetic 16S rRNA analysis, the taxonomic affiliation of the isolates has been established. The aerobic microbial community includes gram-positive bacteria with a high and low G+C content of DNA, and gamma and beta subclasses of Proteobacteria. The thermophilic bacteria belong to the genera Geobacillus and Thermoactinomyces, and the mesophilic strains belong to the genera Bacillus, Micrococcus, Cellulomonas, Pseudomonas, and Acinetobacter. The microbial community of the oil stratum is dominated by known species of the genus Geobacillus (G. subterraneus, G. stearothermophilus, and G. thermoglucosidasius) and a novel species "Geobacillus jurassicus." A number of novel thermophilic oil-oxidizing bacilli have been isolated. PMID:16119855

  1. Costs and indices for domestic oil and gas field equipment and production operations 1994 through 1997

    SciTech Connect

    NONE

    1998-03-01

    This report presents estimated costs and cost indices for domestic oil and natural gas field equipment and production operations for 1994, 1995, 1996, and 1997. The costs of all equipment and services are those in effect during June of each year. The sums (aggregates) of the costs for representative leases by region, depth, and production rate were averaged and indexed. This provides a general measure of the increased or decreased costs from year to year for lease equipment and operations. These general measures do not capture changes in industry-wide costs exactly because of annual variations in the ratio of the total number of oil wells to the total number of gas wells. The detail provided in this report is unavailable elsewhere. The body of this report contains summary tables, and the appendices contain detailed tables. Price changes for oil and gas, changes in taxes on oil and gas revenues, and environmental factors (compliance costs and lease availability) have a significant impact on the number and cost of oil and gas wells drilled. These changes also impact the cost of oil and gas equipment and production operations.

  2. Costs and indices for domestic oil and gas field equipment and production operations 1990 through 1993

    SciTech Connect

    Not Available

    1994-07-08

    This report presents estimated costs and indice for domestic oil and gas field equipment and production operations for 1990, 1991, 1992, and 1993. The costs of all equipment and serives were those in effect during June of each year. The sums (aggregates) of the costs for representative leases by region, depth, and production rate were averaged and indexed. This provides a general measure of the increased or decreased costs from year to year for lease equipment and operations. These general measures do not capture changes in industry-wide costs exactly because of annual variations in the ratio of oil wells to gas wells. The body of the report contains summary tables, and the appendices contain detailed tables. Price changes for oil and gas, changes in taxes on oil and gas revenues, and environmental factors (costs and lease availability) have significant impact on the number and cost of oil and gas wells drilled. These changes also impact the cost of oil and gas production equipment and operations.

  3. An innovative geostatistical approach to oil volumetric calculations: Rock Creek Field, West Virginia

    Microsoft Academic Search

    R. R. McDowell; D. L. Matchen; M. E. Hohn; A. G. Vargo

    1994-01-01

    Detailed analysis of production trends in heterogeneous reservoirs requires local estimates of production, original, oil in place (OOIP), and recovery efficiency. In older fields, calculating these values is hampered by incomplete well records, inconsistent reporting of production (well by well vs. lease by lease), unknown effective drainage radius, and poorly constrained completion interval. Accepted methods of estimation rely heavily on

  4. Quality of field pennycress oil obtained by screw pressing and solvent extraction

    Technology Transfer Automated Retrieval System (TEKTRAN)

    Field pennycress (Thlasphi arvense L., Brassicaceae) is a winter annual that grows widely in temperate North America. Its seeds contain up to 36% oil (dry basis, db) with the major fatty acid being erucic acid (38 %). With an estimated seed production of 1,700 – 2,200 kg/ha, pennycress can be a majo...

  5. Enhanced biodegradation of transformer oil in soils with cyclodextrin – from the laboratory to the field

    Microsoft Academic Search

    Mónika Molnár; Laura Leitgib; Katalin Gruiz; Éva Fenyvesi; Nikoletta Szaniszló; József Szejtli; Fabio Fava

    2005-01-01

    The use cyclodextrins for the intensification of bioremediation by improving the mobility and bioavailability of contaminants has recently been studied. In this work, the role of randomly methylated ß-cyclodextrin in the bioremediation of soils contaminated with transformer oil was studied both in bench scale bioreactors and through field experiments. The aims of this research were to (a) establish the scientific

  6. Behavior of streamers under divergent AC fields in transformer oils at large gaps

    Microsoft Academic Search

    P. Rain; C. Boisdon; O. Lesaint; R. Tobazeon

    1991-01-01

    Results of investigations on prebreakdown phenomena in transformer oils under various divergent AC fields at large gaps are presented. The direct visualization of the light emitted by streamers was performed with a highly sensitive video device. Streamers of both polarities were observed, but it is found that positive streamers play a dominant role since their ability to propagate is much

  7. Preliminary Technical and Legal Evaluation of Disposing of Nonhazardous Oil Field Waste into Salt Caverns

    SciTech Connect

    Ayers, Robert C.; Caudle, Dan; Elcock, Deborah; Raivel, Mary; Veil, John; and Grunewald, Ben

    1999-01-21

    This report presents an initial evaluation of the suitability, feasibility, and legality of using salt caverns for disposal of nonhazardous oil field wastes. Given the preliminary and general nature of this report, we recognize that some of our findings and conclusions maybe speculative and subject to change upon further research on this topic.

  8. Dehydration Efficiency of Water-in-Crude Oil Emulsions in Alternating Current Electrical Fields

    Microsoft Academic Search

    Simone Less; Andreas Hannisdal; Johan Sjöblom

    2010-01-01

    The influence of several operational variables on the electrostatic separation of water-in-crude oil emulsions is investigated in a concentric cylinder rheometer equipped with an alternating current (AC) generator. Shear rate, temperature, emulsion water content, electric field strength, and application time are all found to play a role in the process. The droplet size distributions achieved across some of the experiments

  9. Integrated Field Study of Heavy Oil Reservoirs using Integrated Geophysics, Geochemistry, and Numerical Modeling Techniques

    Microsoft Academic Search

    Mathew Fay; Tingge Wang; Fereidoon Vasheghani; Hussain Sheikha; Joan Embleton; Larry Lines; Antonin Settari; Jin Wang; Douglas Schmitt

    Summary The complete reservoir characterization of cold production reservoirs involves the integration of geochemistry, geology, geophysics, and numerical modeling of reservoir production. This procedure should optimize enhanced oil recovery. The following talk describes progress of such integrated studies for a field study at Plover Lake, Saskatchewan.

  10. Geologic control of natural marine hydrocarbon seep emissions, Coal Oil Point seep field, California

    E-print Network

    Luyendyk, Bruce

    with open access at Springerlink.com Abstract High-resolution sonar surveys, and a detailed subsurface model geology and gas-phase (methane) seepage for the Coal Oil Point (COP) seep field, one of the world near Santa Barbara, California. In general, the relationship between terrestrial gas seepage, migration

  11. FIELD MANUAL FOR PLUNGING WATER JET USE IN OIL SPILL CLEANUP

    EPA Science Inventory

    The use of plunging water jets can often make possible the control (and, as a consequence, the cleanup) of spilled oil and other floating pollutants in currents too swift for conventional equipment. This short, illustrated manual provides practical information for field and plann...

  12. Reservoir characterization, three-dimensional geological modeling, and reservoir simulation of North Blowhorn Creek Oil Field, Lamar County, Alabama

    Microsoft Academic Search

    Brian Panetta

    2004-01-01

    North Blowhorn Creek Oil Field is located in northeastern Lamar County, Alabama. The field was unitized and a water flood project started in 1983. In 1992, a microbial permeability profile modification project began as a result of continued declining production. The original oil in place was estimated to be 16 million barrels. The Carter sandstone lies within the Carter interval

  13. A look at Bacon Flat, Grant Canyon oil fields of Railroad Valley, Nevada

    SciTech Connect

    Johnson, E.H. (EREC-Balcron Oil Division, Billings, MT (United States))

    1993-05-17

    The prolific wells at Grant Canyon, and the puzzling geology, have intrigued explorationists and promoters. Many a Nevada prospect has been touted as 'another Grand Canyon.' But what processes formed Grant Canyon, and can others be found Last August, Equitable Resources Energy Co,'s Balcron Oil Division spudded a well at Bacon Flat, a mile west of Grant Canyon. A one well field, Bacon Flat had been abandoned in 1988. But just 900 ft north of the field opener, Balcron's well tested oil at a rate or 5,400 b/d. It turns out that Bacon Flat and Grant Canyon fields have a common geological history and, in fact, share the same faulted horst. However, they formed by an unusual combination of events that may be unique to those fields. This paper describes the geologic history, well logging interpretations, structures, the Jebco C seismic line, a geologic cross section, and the author's conclusions.

  14. Rapid assessment of redevelopment potential in marginal oil fields, application to the cut bank field

    E-print Network

    Chavez Ballesteros, Luis Eladio

    2005-02-17

    involving numerous wells, and different production and completion practices. The most accurate way to estimate infill potential is to conduct a detailed integrated reservoir study, which is often time-consuming and expensive for operators of marginal oil...

  15. The significance of large variations in oil properties of the Dai Hung field, Vietnam

    SciTech Connect

    Behrenbruch, P.; Du, P.Q.

    1995-10-01

    The Dai Hung Oil field, offshore Vietnam, is comprised of a complex subsurface structure containing stacked reservoir sequences typically found in many other Southeast Asian fields. Combined with areal fault compartmentalization, this situation has led to the observed, large variations in oil properties. Furthermore, the depositional environment in terms of burial history has created a unique overpressure situation which also had an affect, particularly on the crude saturation conditions of individual reservoirs. For commercial and technical reasons, this situation required a detailed analysis, both in terms of variation in crude assay and live oil properties. For whole crude properties: gravity, K factor, wax content and pour point-graphs were drawn up using a large data base of worldwide crudes against which the Dai Hung data could be validated. In case of PVT properties (bubble point and formation volume factor) existing industry correlations were examined. It could be concluded that the sweet, medium gravity and moderately waxy Dai Hung crude has whole crude properties which are comparable to other, similar crudes. The general framework of crude properties established is suitable to type other crudes, even if limited information is available. Of the existing PVT correlations tested, it was found that Standing`s correlation for the oil formation volume factor and the Kartoatmodjo-Schmidt correlation for the bubble point fitted the Dai Hung crude data the best. For the lower shrinkage Dai Hung crudes the Malaysian oil formation volume factor correlation by Omar-Todd gave the best data fit.

  16. Geology of the undeveloped oil and gas fields of Central Offshore Santa Maria Basin, California

    SciTech Connect

    Milton, J.D. [CalResources LLC, Bakersfield, CA (United States); Edwards, E.B. [ Ogle & Heck, Carpinteria, CA (United States); Heck, R.G. [Ogle & Heck, Santa Barbara, CA (United States)] [and others

    1996-12-31

    Two prominent subsurface structural features of the Central Offshore Santa Maria Basin are the Hosgri fault system and the associated anticlinal fold trend. Exploratory drilling and 3D seismic mapping have delineated a series of oil and gas fields along this trend which underlie four federal units and one non-unitized lease. The units are named after local geography and are called the Lion Rock, Point Sal, Purisima Point and Santa Maria Units. The individual lease, OCS P-0409, overlies the San Miguel field. The Hosgri fault system trends northwest-southeast and effectively forms the eastern boundary of the oil and gas province. Lying semi-parallel with the fault are several anticlinal culminations which have trapped large volumes of oil and gas in the fractured Montery Formation. The Monterey is both source and reservoir rock, averaging 300 meters n thickness throughout the Central Basin. Development of the Monterey Formation as a reservoir rock was through diagensis and tectonism with resulting porosities-from 15 to 20% and permeability up to one Darcy. These parameters coupled with a high geothermal gradient facilitate the inflow rates of the viscous Monterey oil. Some 24 exploration and delineation wells have been drilled in this area and tested at rates ranging from a few hundred to several thousand barrels per day. Estimated oil reserves in the Central Offshore Santa Maria Basin total approximately 1 billion barrels.

  17. Geology of the undeveloped oil and gas fields of Central Offshore Santa Maria Basin, California

    SciTech Connect

    Milton, J.D. (CalResources LLC, Bakersfield, CA (United States)); Edwards, E.B. ( Ogle Heck, Carpinteria, CA (United States)); Heck, R.G. (Ogle Heck, Santa Barbara, CA (United States)) (and others)

    1996-01-01

    Two prominent subsurface structural features of the Central Offshore Santa Maria Basin are the Hosgri fault system and the associated anticlinal fold trend. Exploratory drilling and 3D seismic mapping have delineated a series of oil and gas fields along this trend which underlie four federal units and one non-unitized lease. The units are named after local geography and are called the Lion Rock, Point Sal, Purisima Point and Santa Maria Units. The individual lease, OCS P-0409, overlies the San Miguel field. The Hosgri fault system trends northwest-southeast and effectively forms the eastern boundary of the oil and gas province. Lying semi-parallel with the fault are several anticlinal culminations which have trapped large volumes of oil and gas in the fractured Montery Formation. The Monterey is both source and reservoir rock, averaging 300 meters n thickness throughout the Central Basin. Development of the Monterey Formation as a reservoir rock was through diagensis and tectonism with resulting porosities-from 15 to 20% and permeability up to one Darcy. These parameters coupled with a high geothermal gradient facilitate the inflow rates of the viscous Monterey oil. Some 24 exploration and delineation wells have been drilled in this area and tested at rates ranging from a few hundred to several thousand barrels per day. Estimated oil reserves in the Central Offshore Santa Maria Basin total approximately 1 billion barrels.

  18. Injection halos of hydrocarbons above oil-gas fields with super-high pressures

    Microsoft Academic Search

    V. V. Bakhtin

    1979-01-01

    We studied the origin of injection halos of hydrocarbons above oil-gas fields with anomalously high formation pressures (AHFP). Using fields in Azerbaydzhan and Chechen-Ingushetiya as an example, we demonstrate the effect of certain factors (in particular, faults and zones of increased macro- and micro-jointing) on the morpholoy of the halos. The intensity of micro-jointing (jointing permeability, three-dimensional density of micro-jointing)

  19. The field pilot of microbial enhanced oil recovery in a high temperature petroleum reservoir

    Microsoft Academic Search

    Liu Jinfeng; Ma Lijun; Mu Bozhong; Liu Rulin; Ni Fangtian; Zhou Jiaxi

    2005-01-01

    To evaluate the technical feasibility and effectiveness of improving oil recovery by microbial enhanced water-flooding techniques in high temperature petroleum reservoirs, a field project was initiated with the nature-occurring microorganisms and nutrient injected into an integrated, close Unit with temperature of 73 °C and salinity of 16,790 mg\\/L in 2001 in Dagang Oilfield, PetroChina. This paper presents the field design

  20. An efficient and user friendly investment optimization system for large scale oil field development

    E-print Network

    Ding, Zixuan

    1992-01-01

    of investment in drilling and construction facilities is a critical factor affecting the economic feasibility of oil field operations. A number of researchers have attempted to develop mathematical programming techniques to solve the field development... Restriction ? Shipping Lane 13 6 Target Grid Cell 7 Type 1 Directional Drilling Hole Profile . . 8 Type 2 Directional Drilling Hole Profile 9 Type 3 Directional Drilling Hole Profile 14 17 18 10 A Network Presentation Of The Surface Sites And Target...

  1. Modeling an electromagnetic telemetry system for signal transmission in oil fields

    Microsoft Academic Search

    Poh Kheong Vong; David Rodger; Andrew Marshall

    2005-01-01

    Some finite element techniques for modeling an electromagnetic-based telemetry device known as the EM-MWD (electromagnetic measurement-while-drilling) used in oil fields are described. Results obtained from field tests at the test rig of GTI Gas Research Facility, Catoosa, OK, are compared with numerical results obtained using finite-element methods. The finite element technique used is based on the 2D-Axisymmetric H formulation.

  2. Development of Improved Oil Field Waste Injection Disposal Techniques

    SciTech Connect

    Terralog Technologies

    2002-11-25

    The goals of this project have was to: (1) assemble and analyze a comprehensive database of past waste injection operations; (2) develop improved diagnostic techniques for monitoring fracture growth and formation changes; (3) develop operating guidelines to optimize daily operations and ultimate storage capacity of the target formation; and (4) to apply these improved models and guidelines in the field.

  3. Development of Improved Oil Field Waste Injection Disposal Techniques

    SciTech Connect

    Terralog Technologies USA Inc.

    2001-12-17

    The goals of this DOE sponsored project are to: (1) assemble and analyze a comprehensive database of past waste injection operations; (2) develop improved diagnostic techniques for monitoring fracture growth and formation changes; (3) develop operating guidelines to optimize daily operations and ultimate storage capacity of the target formation; and (4) to test these improved models and guidelines in the field.

  4. Structural setting and validation of direct hydrocarbon indicators for Amauligak oil field, Canadian Beaufort Sea

    SciTech Connect

    Enachescu, M.E. (Husky Oil Operations Ltd., Calgary, Alberta (Canada))

    1990-01-01

    The recent discovery of a giant oil field in the southeastern Beaufort-Mackenzie basin has brought this frontier area closer to oil production despite severe environmental conditions. The Amauligak field is a fault-bounded growth structure developed in the Kugmallit Trough, within deltaic deposits of the Beaufort Sea Shelf. Shelf construction occurred during the Late Cretaceous-Tertiary by repeated progradation of the Mackenzie River delta in response to rift-induced opening of the Canada basin and extension of the Kugmallit Trough. The Amauligak field contains oil and gas in multiple sandstone reservoirs of the Oligocene Kugmallit sequence. The upper sandstones are truncated by an unconformity and sealed by the overlying shales of the Miocene Mackenzie Bay sequence. Based on two-dimensional seismic coverage, the field was initially described as structurally simple. Interactive interpretation on Landmark and SIDIS workstations of a three-dimensional seismic program revealed the local structural complications, spatial configuration, and detailed structural elements of the field. Direct hydrocarbon indicators (DHIs), including amplitude anomaly, phase change, flat spot, and low-frequency zone, associated with a large gas cap were investigated using full amplitude-range and attribute-extraction methods. Interpretation of seismic data and correlation with well results suggest that a combination of structural, stratigraphic, and hydrodynamic factors are responsible for the appearance and distribution of Amauligak DHIs. On the amplitude displays, a fluid contact is seismically mappable over the field, clearly separating the gas cap from the wet reservoir. 16 figs.

  5. Low-Salinity Waterflooding to Improve Oil Recovery - Historical Field Evidence

    SciTech Connect

    Eric P. Robertson

    2007-11-01

    Waterflooding is by far the most widely applied method of improved oil recovery. Crude oil/brine/rock interactions can lead to large variations in the displacement efficiency of wa-terfloods. Laboratory water-flood tests and single-well tracer tests have shown that injection of dilute brine can increase oil recovery, but work designed to test the method on a field scale has not yet been undertaken. Historical waterflood records could unintentionally provide some evidence of improved recovery from waterflooding with lower salinity brine. Nu-merous fields in the Powder River basin of Wyoming have been waterflooded using low salinity brine (about 500 ppm) obtained from the Madison limestone or Fox Hills sandstone. Three Minnelusa formation fields in the basin were identified as potential candidates for waterflood comparisons based on the salinity of the connate and injection water. Historical pro-duction and injection data for these fields were obtained from the public record. Field waterflood data were manipulated to be displayed in the same format as laboratory coreflood re-sults. Recovery from fields using lower salinity injection wa-ter was greater than that using higher salinity injection wa-ter—matching recovery trends for laboratory and single-well tests.

  6. Increasing heavy oil reserves in the Wilmington Oil Field through advanced reservoir characterization and thermal production technologies. Annual report, March 30, 1995--March 31, 1996

    SciTech Connect

    NONE

    1997-09-01

    The objective of this project is to increase heavy oil reserves in a portion of the Wilmington Oil Field, near Long Beach, California, by implementing advanced reservoir characterization and thermal production technologies. Based on the knowledge and experience gained with this project, these technologies are intended to be extended to other sections of the Wilmington Oil Field, and, through technology transfer, will be available to increase heavy oil reserves in other slope and basin clastic (SBC) reservoirs. The project involves implementing thermal recovery in the southern half of the Fault Block II-A Tar zone. The existing steamflood in Fault Block II-A has been relatively inefficient due to several producibility problems which are common in SBC reservoirs. Inadequate characterization of the heterogeneous turbidite sands, high permeability thief zones, low gravity oil, and nonuniform distribution of remaining oil have all contributed to poor sweep efficiency, high steam-oil ratios, and early steam breakthrough. Operational problems related to steam breakthrough, high reservoir pressure, and unconsolidated formation sands have caused premature well and downhole equipment failures. In aggregate, these reservoir and operational constraints have resulted in increased operating costs and decreased recoverable reserves. A suite of advanced reservoir characterization and thermal production technologies are being applied during the project to improve oil recovery efficiency and reduce operating costs.

  7. Selection of chemical products for oil field applications in arctic environments

    SciTech Connect

    Powell, D.E.; VanderWende, E. [ARCO, Alaska, Inc., Anchorage, AK (United States)

    1996-08-01

    The Kuparuk Oil Field is located on the North Slope of Alaska, well above the Arctic Circle. Kuparuk uses chemicals for a variety of different oil production needs, including corrosion inhibition, emulsion breaking, defoaming, biofouling control, and scale inhibition. The North Slope`s isolated location demands unique logistical support, but it is otherwise accessible by unpaved road and has extensive air service. The Arctic climate provides difficult challenges and requirements for any chemical selection. This paper describes some criteria and practical experiences related to selecting the proper chemical products to be used in the Arctic environment.

  8. Sisterhood in the oil field: informal support networks, gender roles and adaptation among women in the Oklahoma oil field

    SciTech Connect

    Walsh, A.C.

    1988-01-01

    The petroleum drilling industry exhibits a number of definitive characteristics, which combined with the most recent boom/bust drilling cycle, affect women in much the same manner as factors commonly associated with the eroding of women's social and economic positions within modernizing societies. Recognizing that modernization has a negative impact on women, this study focuses on strategies of adaptation employed by women associated both directly and indirectly with the petroleum drilling industry in an oil boom/bust town in western Oklahoma. Utilizing the traditional techniques of ethnographic interview and participant observation, it was shown that informal support networks formed by women enhanced women's adaptation by extending their resource base beyond the nuclear family and encouraging solidarity. Gender-based division of labor was also modified by western energy development. Boom times facilitated a rigid division of labor that gave way to a more flexible arrangement during bust times without a concomitant change in gender-based ideology. This was accounted for by differences in the rates of change for the underlying habits and values associated with the public and private sectors.

  9. Brine contamination of shallow ground water and streams in the Brookhaven Oil Field, Lincoln County, Mississippi

    USGS Publications Warehouse

    Kalkhoff, S.J.

    1986-01-01

    A hydrologic investigation to define areas of brine contamination in shallow freshwater aquifers commonly used for streams that drain the Brookhaven Oil Field, was conducted from October 1983 to September 1984. The Brookhaven Oil Field covers approximately 15 sq mi in northwestern Lincoln County, Mississippi. Since 1943, disposal of approximately 544.2 million barrels of brine pumped from the oil producing zone (lower part of the Tuscaloosa Formation) has contaminated the Citronelle aquifer, the Hattiesburg aquifers, and streams that drain the oil field. Approximately 5 sq mi of the shallow Citronelle aquifer contain water with chloride concentrations higher than normal for this area ( > 20 mg/L). Brine contamination has moved from the source laterally through the Citronelle aquifer to discharge into nearby streams and vertically into the underlying Hattiesburg aquifers. Contamination is most noticeable in Shaws Creek when streamflow originates primarily from groundwater inflow (approximately 87% of the time during the study). Additional study is required to define contaminant plumes, rates of groundwater movement and geohydrochemical reactions between the contaminant and aquifer materials. These data would allow accurate predictions of location, extent and degree of contamination in the study area. (Author 's abstract)

  10. Kinetics of lead and copper removal from oil-field brine by potential sorption.

    PubMed

    Nourafkan, E; Asachi, M; Marandi, R

    2014-01-01

    The present study investigates the kinetics of lead and copper removal from oil-field brine by potential sorption. A population balance equation, coupled with a mass balance equation, was used in the estimation of kinetic parameters. Metal removal was performed by potential sorption of lead and copper through CaCO3 precipitates induced by the reaction of Na2CO3 and CaCl2. The oil-field brine was selected from an oil well in Gachsaran, Iran. The crystal size distribution of the solid phase was measured by dynamic laser scattering analyzer, and the liquor phase was analyzed using atomic adsorption. The morphology of calcium carbonate particles was illustrated using scanning electron microscopy and X-ray diffraction. The results showed that the presence of copper and lead decreases the average size distribution of calcium carbonate particles by influencing the kinetic parameters. Lead and copper concentrations were reduced from 2.911 to 0.127 ppm (95.63% removal) and 0.476 to 0.025 ppm (94.74% removal), respectively, in exchange for 12 g CaCO3 consumption per 100 ml oil-field brine. PMID:25521137

  11. Immunomagnetically Captured Thermophilic Sulfate-Reducing Bacteria from North Sea Oil Field Waters

    PubMed Central

    Christensen, Bjørn; Torsvik, Terje; Lien, Torleiv

    1992-01-01

    Immunomagnetic beads (IMB) were used to recover thermophilic sulfate-reducing bacteria from oil field waters from oil production platforms in the Norwegian sector of the North Sea. IMB coated with polyclonal antibodies against whole-cell antigens of the thermophilic Thermodesulfobacterium mobile captured strains GFA1, GFA2, and GFA3. GFA1 was serologically and morphologically identical to T. mobile. GFA2 and GFA3 were spore forming and similar to the Desulfotomaculum strains T90A and T93B previously isolated from North Sea oil field waters by a classical enrichment procedure. Western blots (immunoblots) of whole cells showed that GFA2, GFA3, T90A, and T93B are different serotypes of the same Desulfotomaculum species. Monoclonal antibodies (MAb) against T. mobile type strain cells were produced and used as capture agents on IMB. These MAb, named A4F4, were immunoglobulin M; they were specific to T. mobile and directed against lipopolysaccharides. The prevailing cells immunocaptured with MAb A4F4 were morphologically and serologically similar to T. mobile type strain cells. T. mobile was not detected in these oil field waters by classical enrichment procedures. Furthermore, extraction with antibody-coated IMB allowed pure strains to be isolated directly from primary enrichment cultures without prior time-consuming subculturing and consecutive transfers to selective media. Images PMID:16348693

  12. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2001-05-07

    The project involves using advanced reservoir characterization and thermal production technologies to improve thermal recovery techniques and lower operating and capital costs in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., CA. Through September 2000, project work has been completed on the following activities: data preparation; basic reservoir engineering; developing a deterministic three dimensional (3-D) geologic model, a 3-D deterministic reservoir simulation model and a rock-log model; well drilling and completions; and surface facilities on the Fault Block II-A Tar Zone (Tar II-A). Work is continuing on improving core analysis techniques, final reservoir tracer work, operational work and research studies to prevent thermal-related formation compaction in the Tar II-A steamflood area, and operational work on the Tar V steamflood pilot and Tar II-A post steamflood projects. Work was discontinued on the stochastic geologic model and developing a 3-D stochastic thermal reservoir simulation model of the Tar II-A Zone so the project team could use the 3-D deterministic reservoir simulation model to provide alternatives for the Tar II-A post steamflood operations and shale compaction studies. The project team spent the fourth quarter 2000 performing well work and reservoir surveillance on the Tar II-A post-steamflood project and the Tar V horizontal well steamflood pilot. Expanding thermal recovery operations to other sections of the Wilmington Oil Field, including the Tar V horizontal well pilot steamflood project, is a critical part of the City of Long Beach and Tidelands Oil Production Company's development strategy for the field. The current steamflood operations in the Tar V pilot are economical, but recent performance is below projections because of wellbore mechanical limitations that are being evaluated.

  13. Bluebell Field, Uinta Basin: reservoir characterization for improved well completion and oil recovery

    USGS Publications Warehouse

    Montgomery, S.L.; Morgan, C.D.

    1998-01-01

    Bluefield Field is the largest oil-producing area in the Unita basin of northern Utah. The field inclucdes over 300 wells and has produced 137 Mbbl oil and 177 bcf gas from fractured Paleocene-Eocene lacustrine and fluvial deposits of the Green River and Wasatch (Colton) formations. Oil and gas are produced at depths of 10 500-13 000 ft (3330-3940 m), with the most prolific reservoirs existing in over-pressured sandstones of the Colton Formation and the underlying Flagstaff Member of the lower Green River Formation. Despite a number of high-recovery wells (1-3 MMbbl), overall field recovery remains low, less than 10% original oil in place. This low recovery rate is interpreted to be at least partly a result of completion practices. Typically, 40-120 beds are perforated and stimulated with acid (no proppant) over intervals of up to 3000 ft (900 m). Little or no evaluation of individual beds is performed, preventing identification of good-quality reservoir zones, water-producing zones, and thief zones. As a result, detailed understanding of Bluebell reservoirs historically has been poor, inhibiting any improvements in recovery strategies. A recent project undertaken in Bluebell field as part of the U.S. Department of Energy's Class 1 (fluvial-deltaic reservoir) Oil Demonstration program has focused considerable effort on reservoir characterization. This effort has involved interdisciplinary analysis of core, log, fracture, geostatistical, production, and other data. Much valuable new information on reservoir character has resulted, with important implications for completion techniques and recovery expectations. Such data should have excellent applicability to other producing areas in the Uinta Basin withi reservoirs in similar lacustrine and related deposits.Bluebell field is the largest oil-producing area in the Uinta basin of northern Utah. The field includes over 300 wells and has produced 137 MMbbl oil and 177 bcf gas from fractured Paleocene-Eocene lacustrine and fluvial deposits of the Green River and Wasatch (Colton) formations. Oil and gas are produced at depths of 10,500-13,000 ft (3330-3940 m), with the most prolific reservoirs existing in over-pressured sandstones of the Colton Formation and the underlying Flagstaff Member of the lower Green River Formation. Despite a number of high-recovery wells (1-3 MMbbl), overall field recovery remains low, less than 10% original oil in place. This low recovery rate is interpreted to be at least partly a result of completion practices. Typically, 40-120 beds are perforated and stimulated with acid (no proppant) over intervals of up to 3000 ft (900 m). Little or no evaluation of individual beds is performed, preventing identification of good-quality reservoir zones, water-producing zones, and thief zones. As a result, detailed understanding of Bluebell reservoirs historically has been poor, inhibiting any improvements in recovery strategies. A recent project undertaken in Bluebell field as part of the U.S. Department of Energy's Class 1 (fluvial-deltaic reservoir) Oil Demonstration program has focused considerable effort on reservoir characterization. This effort has involved interdisciplinary analysis of core, log, fracture, geostatistical, production, and other data. Much valuable new information on reservoir character has resulted, with important implications for completion techniques and recovery expectations. Such data should have excellent applicability to other producing areas in the Uinta basin with reservoirs in similar lacustrine and related deposits.

  14. Increasing Heavy Oil Reserves in the Wilmington Oil Field Through Advanced Reservoir Characterization and Thermal Production Technologies

    SciTech Connect

    Scott Hara

    1997-08-08

    The project involves improving thermal recovery techniques in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., Calif. using advanced reservoir characterization and thermal production technologies. The existing steamflood in the Tar zone of Fault Block (FB) II-A has been relatively inefficient because of several producibility problems which are common in SBC reservoirs. Inadequate characterization of the heterogeneous turbidite sands, high permeability thief zones, low gravity oil, and nonuniform distribution of remaining oil have all contributed to poor sweep efficiency, high steam-oil ratios, and early steam breakthrough. Operational problems related to steam breakthrough, high reservoir pressure, and unconsolidated formation sands have caused premature well and downhole equipment failures. In aggregate, these reservoir and operational constraints have resulted in increased operating costs and decreased recoverable reserves. The advanced technologies to be applied include: (1) Develop three-dimensional (3-D) deterministic and stochastic geologic models. (2) Develop 3-D deterministic and stochastic thermal reservoir simulation models to aid in reservoir management and subsequent development work. (3) Develop computerized 3-D visualizations of the geologic and reservoir simulation models to aid in analysis. (4) Perform detailed study on the geochemical interactions between the steam and the formation rock and fluids. (5) Pilot steam injection and production via four new horizontal wells (2 producers and 2 injectors). (6) Hot water alternating steam (WAS) drive pilot in the existing steam drive area to improve thermal efficiency. (7) Installing a 2100 foot insulated, subsurface harbor channel crossing to supply steam to an island location. (8) Test a novel alkaline steam completion technique to control well sanding problems and fluid entry profiles. (9) Advanced reservoir management through computer-aided access to production and geologic data to integrate reservoir characterization, engineering, monitoring, and evaluation. Summary of Technical Progress

  15. Oil-field emissions of volatile organic compounds. Final report, April 1988-March 1989

    SciTech Connect

    Viswanath, R.S.; Van Sandt, J.H.

    1989-04-01

    This report presents data that determine the composition of volatile organic compound emissions from oil production fields in Tulsa County, Oklahoma. Five points in the crude-oil production process were samples: well heads, gathering tasks, oilfield pipeline tanks, pipeline terminal tanks, and refinery crude-oil storage tanks. The samples were collected in Summa polished stainless steel canisters and analyzed by a gas chromatograph with dual flame ionization detectors. The analytical technique looked for ninety specific compounds; thirty were detected and are reported. In general the compounds in greatest abundance were ethane, propane, n-butane, 2-methyl butane, and n-pentane. The data developed are for the composition of the volatile organic compounds; volatile organic-compound emission rates were not determined.

  16. Electric-field-induced turbulent energy cascade in an oil-in-oil emulsion

    E-print Network

    Atul Varshney; Mayur Sathe; Shankar Ghosh; Anand Yethiraj; S. Bhattacharya; J. B. Joshi

    2014-12-11

    We observe electro-hydrodynamically driven turbulent flows at low Reynolds numbers in a two-fluid emulsion consisting of micron-scale droplets. In the presence of electric fields, the droplets produce interacting hydrodynamic flows which result in a dynamical organization at a spatial scale much larger than the size of the individual droplets. We characterize the dynamics associated with these structures by both video imaging and a simultaneous, in situ, measurement of the time variation of the bulk Reynolds stress with a rheometer. The results display scale invariance in the energy spectra in both space and time.

  17. Cost effective modular unit for cleaning oil and gas field waste water

    SciTech Connect

    Zinberg, M.B.; Nenasheva, M.N.; Gafarov, N.A.

    1996-12-31

    Problems of environmental control involving conservation of water resources are vital for the development of giant oil and gas condensate fields near Caspian Sea (Russia) characterized by water shortages. One of the urgent tasks of oil production industry is to use all field waste water consisting of underground, processing and rain water. It was necessary to construct a new highly effective equipment which could be used in local waste water treatment. Now we have at our disposal a technology and equipment to meet the requirements to the treated water quality. Thus we have installed a modular unit of 100 m{sup 3}/a day capacity to clean waste water from oil products, suspended matter and other organic pollutants at Orenburg oil and gas condensate field, Russia. The unit provides with a full treatment of produced water and comprises a settling tank with adhesive facility, the number of sorption filters, Trofactor bioreactors and a disinfecting facility. The equipment is fitted into three boxes measuring 9 x 3.2 x 2.7 in each. The equipment is simple in design that enables to save money, time and space. Sorption filters, bioreactors as well as the Trofactor process are a part of know-how. While working on the unit construction we applied well known methods of settling and sorption. The process of mechanic cleaning is undergoing in the following succession: (1) the gravitational separation in a settling tank where the floated film oil products are constantly gathered and the sediment is periodically taken away, (2) the settled water treatment in sorption Filters of a special kind.

  18. Spore-Forming Thermophilic Sulfate-Reducing Bacteria Isolated from North Sea Oil Field Waters

    PubMed Central

    Rosnes, Jan Thomas; Torsvik, Terje; Lien, Torleiv

    1991-01-01

    Thermophilic sulfate-reducing bacteria were isolated from oil field waters from oil production platforms in the Norwegian sector of the North Sea. Spore-forming rods dominated in the enrichments when lactate, propionate, butyrate, or a mixture of aliphatic fatty acids (C4 through C6) was added as a carbon source and electron donor. Representative strains were isolated and characterized. The isolates grew autotrophically on H2-CO2 and heterotrophically on fatty acids such as formate, propionate, butyrate, caproate, valerate, pyruvate, and lactate and on alcohols such as methanol, ethanol, and propanol. Sulfate, sulfite, and thiosulfate but not nitrate could be used as an electron acceptor. The temperature range for growth was 43 to 78°C; the spores were extremely heat resistant and survived 131°C for 20 min. The optimum pH was 7.0. The isolates grew well in salt concentrations ranging from 0 to 800 mmol of NaCl per liter. Sulfite reductase P582 was present, but cytochrome c and desulfoviridin were not found. Electron micrographs revealed a gram-positive cell organization. The isolates were classified as a Desulfotomaculum sp. on the basis of spore formation, general physiological characteristics, and submicroscopic organization. To detect thermophilic spore-forming sulfate-reducing bacteria in oil field water, polyvalent antisera raised against antigens from two isolates were used. These bacteria were shown to be widespread in oil field water from different platforms. The origin of thermophilic sulfate-reducing bacteria in the pore water of oil reservoirs is discussed. Images PMID:16348538

  19. Determination of hexaconazole in field samples of an oil palm plantation.

    PubMed

    Muhamad, Halimah; Zainol, Maznah; Sahid, Ismail; Abu Seman, Idris

    2012-08-01

    In oil palm plantations, the fungicide hexaconazole is used to control Ganoderma infection that threatens to destroy or compromisethe palm. The application of hexaconazole is usually through soil drenching, trunk injection, or a combination of these two methods. It is therefore important to have a method to determine the residual amount of hexaconazole in the field such as in samples of water, soil, and leaf to monitor the use and fate of the fungicide in oil palm plantations. This study on the behaviour of hexaconazole in oil palm agro-environment was carried out at the UKM-MPOB Research Station, Bangi Lama, Selangor. Three experimental plots in this estate with 7-year-old Dura x Pisifera (DxP) palms were selected for the field trial. One plot was sprayed with hexaconazole at the manufacturer's recommended dosage, one at double the recommended dosage, and the third plot was untreated control. Hexaconazole residues in the soil, leaf, and water were determined before and after fungicide treatment. Soil samples were randomly collected from three locations at different depths (0-50 cm) and soil collected fromthe same depth were bulked together. Soil, water, and palm leaf were collected at -1 (day before treatment), 0 (day of treatment), 1, 3, 7, 14, 21, 70, 90, and 120 days after treatment. Hexaconazole was detected in soil and oil palm leaf, but was not detected in water from the nearby stream. PMID:22851367

  20. Raman distributed temperature sensor for oil leakage detection in soil: a field trial and future trends

    NASA Astrophysics Data System (ADS)

    Signorini, Alessandro; Nannipieri, Tiziano; Gabella, Luca; Di Pasquale, Fabrizio; Latini, Gilberto; Ripari, Daniele

    2014-05-01

    In this paper we perform field validation of distributed Raman temperature sensing (RDTS) for oil leakage detection in soil. The capability of the distributed Raman sensor in detecting and locating, with high accuracy and spatial resolution, drop leakages in soil is demonstrated through a water leakage simulation in a field trial. The future trends and the high potential of the Raman DTS technology for oil and gas leakage detection in long pipelines is then outlined in this paper by reporting lab experiments demonstrating accurate meter scale temperature measurement over more than 50 km of standard single mode fiber. The proposed solution, based on distributed Simplex coding techniques, can be competitive in terms of cost and performance with respect to other distributed sensing technologies.

  1. Jurassic Haynesville oil production unfolds in Mississippi's mature Bay Springs field

    SciTech Connect

    Sticker, E.E. (Mississippi Office of Geology, Jackson, MS (US))

    1992-07-13

    This paper discusses Bay Springs field in western jasper Country, Miss., about 1 mile east of the town of Bay Springs. The field was discovered in 1965 after seismic work conducted by Shell Oil Co. led to the drilling of the Shell 1 C.E. Brown in 27-2n-10e. After initial completion attempts in Jurassic Upper and Lower Smackover yielded unsatisfactory results, a completion was made in a Jurassic Lower Cotton Valley sand later to be named the Bay Springs sand. The well was officially tested through perforations at about 14,500 ft in the Bay Springs sand at a rate of 585 b/d of oil through a 10/64 in. choke with a flowing tubing pressure of 1,850 psi. The gravity of the crude was 47.5{degrees} with a GOR of 630:1.

  2. Particle-initiated breakdown in a quasi-uniform field in transformer oil

    Microsoft Academic Search

    F. Carraz; P. Rain; R. Tobazeon

    1995-01-01

    The breakdown voltage induced by single metallic cylinders of millimeter lengths in a quasi-uniform AC field are reported. A particular electrode arrangement, including forced oil circulation, has been designed in order to avoid particle ejection out of the gap. Breakdown occurred in the range 25 to 80 kV\\/cm depending on the particle dimensions, and always when the particle was in

  3. Phylogenetic Diversity of Aerobic Saprotrophic Bacteria Isolated from the Daqing Oil Field

    Microsoft Academic Search

    T. N. Nazina; A. A. Grigor'yan; Yan-Fen Xue; D. Sh. Sokolova; E. V. Novikova; T. P. Tourova; A. B. Poltaraus; S. S. Belyaev; M. V. Ivanov

    2002-01-01

    A diverse and active microbial community in the stratal waters of the Daqing oil field (China), which is exploited with the use of water-flooding, was found to contain aerobic chemoheterotrophic bacteria (including hydrocarbon-oxidizing ones) and anaerobic fermentative, sulfate-reducing, and methanogenic bacteria. The aerobic bacteria were most abundant in the near-bottom zones of injection wells. Twenty pure cultures of aerobic saprotrophic

  4. Disposal of NORM-Contaminated Oil Field Wastes in Salt Caverns

    SciTech Connect

    Blunt, D.L.; Elcock, D.; Smith, K.P.; Tomasko, D.; Viel, J.A.; and Williams, G.P.

    1999-01-21

    In 1995, the U.S. Department of Energy (DOE), Office of Fossil Energy, asked Argonne National Laboratory (Argonne) to conduct a preliminary technical and legal evaluation of disposing of nonhazardous oil field waste (NOW) into salt caverns. That study concluded that disposal of NOW into salt caverns is feasible and legal. If caverns are sited and designed well, operated carefully, closed properly, and monitored routinely, they can be a suitable means of disposing of NOW (Veil et al. 1996). Considering these findings and the increased U.S. interest in using salt caverns for NOW disposal, the Office of Fossil Energy asked Argonne to conduct further research on the cost of cavern disposal compared with the cost of more traditional NOW disposal methods and on preliminary identification and investigation of the risks associated with such disposal. The cost study (Veil 1997) found that disposal costs at the four permitted disposal caverns in the United States were comparable to or lower than the costs of other disposal facilities in the same geographic area. The risk study (Tomasko et al. 1997) estimated that both cancer and noncancer human health risks from drinking water that had been contaminated by releases of cavern contents were significantly lower than the accepted risk thresholds. Since 1992, DOE has funded Argonne to conduct a series of studies evaluating issues related to management and disposal of oil field wastes contaminated with naturally occurring radioactive material (NORM). Included among these studies were radiological dose assessments of several different NORM disposal options (Smith et al. 1996). In 1997, DOE asked Argonne to conduct additional analyses on waste disposal in salt caverns, except that this time the wastes to be evaluated would be those types of oil field wastes that are contaminated by NORM. This report describes these analyses. Throughout the remainder of this report, the term ''NORM waste'' is used to mean ''oil field waste contaminated by NORM''.

  5. The drilling of a horizontal well in a mature oil field

    SciTech Connect

    Rougeot, J.E.; Lauterbach, K.A.

    1991-01-01

    This report documents the drilling of a medium radius horizontal well in the Bartlesville Sand of the Flatrock Field, Osage County, Oklahoma by Rougeot Oil and Gas Corporation (Rougeot) of Sperry, Oklahoma. The report includes the rationale for selecting the particular site, the details of drilling the well, the production response, conclusions reached, and recommendations made for the future drilling of horizontal wells. 11 figs., 2 tabs.

  6. Risk assessment of nonhazardous oil-field waste disposal in salt caverns.

    SciTech Connect

    Elcock, D.

    1998-03-05

    In 1996, Argonne National Laboratory (ANL) conducted a preliminary technical and legal evaluation of disposing of nonhazardous oil-field wastes (NOW) into salt caverns. Argonne determined that if caverns are sited and designed well, operated carefully, closed properly, and monitored routinely, they could be suitable for disposing of oil-field wastes. On the basis of these findings, Argonne subsequently conducted a preliminary evaluation of the possibility that adverse human health effects (carcinogenic and noncarcinogenic) could result from exposure to contaminants released from the NOW disposed of in domal salt caverns. Steps used in this evaluation included the following: identifying potential contaminants of concern, determining how humans could be exposed to these contaminants, assessing contaminant toxicities, estimating contaminant intakes, and calculating human cancer and noncancer risk estimates. Five postclosure cavern release scenarios were assessed. These were inadvertent cavern intrusion, failure of the cavern seal, failure of the cavern through cracks, failure of the cavern through leaky interbeds, and a partial collapse of the cavern roof. Assuming a single, generic, salt cavern and generic oil-field wastes, potential human health effects associated with constituent hazardous substances (arsenic, benzene, cadmium, and chromium) were assessed under each of these scenarios. Preliminary results provided excess cancer risk and hazard index (referring to noncancer health effects) estimates that were well within the US Environmental Protection Agency (EPA) target range for acceptable exposure risk levels. These results led to the preliminary conclusion that from a human health perspective, salt caverns can provide an acceptable disposal method for nonhazardous oil-field wastes.

  7. Formation of seep bubble plumes in the Coal Oil Point seep field

    Microsoft Academic Search

    Ira Leifer; Daniel Culling

    2010-01-01

    The fate of marine seep gases (transport to the atmosphere or dissolution, and either bacterial oxidation or diffusion to\\u000a the atmosphere) is intimately connected with bubble and bubble-plume processes, which are strongly size-dependent. Based on\\u000a measurements with a video bubble measurement system in the Coal Oil Point seep field in the Santa Barbara Channel, California,\\u000a which recorded the bubble-emission size

  8. Flexible Riser and Mooring System Develops Small Oil Fields in the North Sea

    Microsoft Academic Search

    A. M. Thompson; G. A. A. H. Holmes; P. J. Benstead

    1991-01-01

    This paper reports on the flexible riser and mooring system (FRAMS) which provides a technically straightforward, commercially attractive method of developing small oil fields. A passively moored 60,000-deadweight-ton (60,000-DWT) tanker with deck-mounted equipment provides a swivelless well fluid and injection water path from and to the wellheads. The system can be disconnected rapidly in severe weather.

  9. Flexible riser and mooring system develops small oil fields in the North Sea

    SciTech Connect

    Thompson, A.M.; Holmes, G. (BP Exploration (GB)); Benstead, P.J. (BP Engineering (GB))

    1991-11-01

    This paper reports on the flexible riser and mooring system (FRAMS) which provides a technically straightforward, commercially attractive method of developing small oil fields. A passively moored 60,000-deadweight-ton (60,000-DWT) tanker with deck-mounted equipment provides a swivelless well fluid and injection water path from and to the wellheads. The system can be disconnected rapidly in severe weather.

  10. A revised model for compressor design and scheduling in gas-lifted oil fields

    Microsoft Academic Search

    Eduardo Camponogara; Luiz F. Nazari; Claudio N. Meneses

    2012-01-01

    The design and real-time scheduling of lift-gas compressors in oil fields entails solving a mixed-integer non-linear problem that generalizes the facility location problem. This article presents a revised formulation that represents the constraints on compressor discharge pressure as a family of linear inequalities, which is shown to be tighter than a previous formulation. Mixed-integer linear approximations for these formulations are

  11. A Revised Model for Compressor Design and Scheduling in Gas-Lifted Oil Fields

    Microsoft Academic Search

    Eduardo Camponogara; Luiz F. Nazari; Claudio N. Meneses

    2011-01-01

    The design and real-time scheduling of lift-gas compressors in oil fields entails solving a mixed-integer nonlinear problem that generalizes the facility location problem. This paper presents a revised formulation that represents the constraints on compressor discharge pressure as a family of linear inequalities, which is shown to be tighter than a previous formulation. Mixed-integer linear approximations for these formulations are

  12. INCREASING WATERFLOOD RESERVES IN THE WILMINGTON OIL FIELD THROUGH IMPROVED RESERVOIR CHARACTERIZATION AND RESERVOIR MANAGEMENT

    SciTech Connect

    Scott Walker; Chris Phillips; Roy Koerner; Don Clarke; Dan Moos; Kwasi Tagbor

    2002-02-28

    This project increased recoverable waterflood reserves in slope and basin reservoirs through improved reservoir characterization and reservoir management. The particular application of this project is in portions of Fault Blocks IV and V of the Wilmington Oil Field, in Long Beach, California, but the approach is widely applicable in slope and basin reservoirs. Transferring technology so that it can be applied in other sections of the Wilmington Field and by operators in other slope and basin reservoirs is a primary component of the project. This project used advanced reservoir characterization tools, including the pulsed acoustic cased-hole logging tool, geologic three-dimensional (3-D) modeling software, and commercially available reservoir management software to identify sands with remaining high oil saturation following waterflood. Production from the identified high oil saturated sands was stimulated by recompleting existing production and injection wells in these sands using conventional means as well as a short radius redrill candidate. Although these reservoirs have been waterflooded over 40 years, researchers have found areas of remaining oil saturation. Areas such as the top sand in the Upper Terminal Zone Fault Block V, the western fault slivers of Upper Terminal Zone Fault Block V, the bottom sands of the Tar Zone Fault Block V, and the eastern edge of Fault Block IV in both the Upper Terminal and Lower Terminal Zones all show significant remaining oil saturation. Each area of interest was uncovered emphasizing a different type of reservoir characterization technique or practice. This was not the original strategy but was necessitated by the different levels of progress in each of the project activities.

  13. Determination of hydrocarbon emissions from oil-field-production sump; evaluation report

    SciTech Connect

    Castronovo, C.L.

    1986-12-01

    Hydrocarbon emissions from seven oil-field-production sumps were determined using a flux box draft-test method developed by the Engineering Evaluation Branch of the California Air Resources Board. The method involves drawing a measured amount of air through the open face of an open-bottom containment vessel which is floated on the sump. The total hydrocarbon and methane concentrations of the air entering and leaving the containment vessel are determined using both continuous analyzer and Tedlar bag sample analysis techniques. The field tests took place during the spring and summer of 1986 in Kern County, California. The sumps tested were characterized as primary, secondary or tertiary sumps as defined by their stage in the oil-water separation process. Average emission rates were found to range from 4.6 times ten to the sixth power to 186 x ten to sixth power lbs/min/sq. ft. Calculated daily emissions from individual sumps ranged from 26 to 1080 lbs/day. Because of known and unknown factors causing variability in the data, it is not recommended that an overall average emission factor be applied to predict hydrocarbon emissions from oil field production sumps.

  14. Risk analyses for disposing nonhazardous oil field wastes in salt caverns

    SciTech Connect

    Tomasko, D.; Elcock, D.; Veil, J.; Caudle, D.

    1997-12-01

    Salt caverns have been used for several decades to store various hydrocarbon products. In the past few years, four facilities in the US have been permitted to dispose nonhazardous oil field wastes in salt caverns. Several other disposal caverns have been permitted in Canada and Europe. This report evaluates the possibility that adverse human health effects could result from exposure to contaminants released from the caverns in domal salt formations used for nonhazardous oil field waste disposal. The evaluation assumes normal operations but considers the possibility of leaks in cavern seals and cavern walls during the post-closure phase of operation. In this assessment, several steps were followed to identify possible human health risks. At the broadest level, these steps include identifying a reasonable set of contaminants of possible concern, identifying how humans could be exposed to these contaminants, assessing the toxicities of these contaminants, estimating their intakes, and characterizing their associated human health risks. The contaminants of concern for the assessment are benzene, cadmium, arsenic, and chromium. These were selected as being components of oil field waste and having a likelihood to remain in solution for a long enough time to reach a human receptor.

  15. Souring in low-temperature surface facilities of two high-temperature Argentinian oil fields.

    PubMed

    Agrawal, Akhil; An, Dongshan; Cavallaro, Adriana; Voordouw, Gerrit

    2014-09-01

    Produced waters from the Barrancas and Chihuido de la Salina (CHLS) fields in Argentina had higher concentrations of sulfate than were found in the injection waters, suggesting that the formation waters in these reservoirs had a high sulfate concentration and that sulfate-reducing bacteria were inactive downhole. Incubation of produced waters with produced oil gave rapid reduction of sulfate to sulfide (souring) at 37 °C, some at 60 °C, but none at 80 °C. Alkylbenzenes and alkanes served as electron donor, especially in incubations with CHLS oil. Dilution with water to decrease the ionic strength or addition of inorganic phosphate did not increase souring at 37 or 60 °C. These results indicate that souring in these reservoirs is limited by the reservoir temperature (80 °C for the Barrancas and 65-70 °C for the CHLS field) and that souring may accelerate in surface facilities where the oil-water mixture cools. As a result, significant sulfide concentrations are present in these surface facilities. The activity and presence of chemolithotrophic Gammaproteobacteria of the genus Thiomicrospira, which represented 85% of the microbial community in a water plant in the Barrancas field, indicated reoxidation of sulfide and sulfur to sulfate. The presence of these bacteria offers potential for souring control by microbial oxidation in aboveground facilities, provided that formation of corrosive sulfur can be avoided. PMID:24903813

  16. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2001-05-08

    The project involves using advanced reservoir characterization and thermal production technologies to improve thermal recovery techniques and lower operating and capital costs in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., CA. Through March 2001, project work has been completed on the following activities: data preparation; basic reservoir engineering; developing a deterministic three dimensional (3-D) geologic model, a 3-D deterministic reservoir simulation model and a rock-log model; well drilling and completions; and surface facilities on the Fault Block II-A Tar Zone (Tar II-A). Work is continuing on research to understand the geochemistry and process regarding the sand consolidation well completion technique, final reservoir tracer work, operational work and research studies to prevent thermal-related formation compaction in the Tar II-A steamflood area, and operational work on the Tar V steamflood pilot and Tar II-A post-steamflood projects. The project team spent the Second Quarter 2001 performing well work and reservoir surveillance on the Tar II-A post-steamflood project. The Tar II-A steamflood reservoirs have been operated over fifteen months at relatively stable pressures, due in large part to the bimonthly pressure monitoring program enacted at the start of the post-steamflood phase in January 1999. Starting in the Fourth Quarter 2000, the project team has ramped up activity to increase production and injection. This work will continue through 2001 as described in the Operational Management section. Expanding thermal recovery operations to other sections of the Wilmington Oil Field, including the Tar V horizontal well pilot steamflood project, is a critical part of the City of Long Beach and Tidelands Oil Production Company's development strategy for the field. The current steamflood operations in the Tar V pilot are economical, but recent performance is below projections because of wellbore mechanical limitations that are being addressed in 2001. Much of the second quarter was spent writing DOE annual and quarterly reports to stay current with contract requirements.

  17. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2001-11-01

    The project involves using advanced reservoir characterization and thermal production technologies to improve thermal recovery techniques and lower operating and capital costs in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., Calif. Through June 2001, project work has been completed on the following activities: data preparation; basic reservoir engineering; developing a deterministic three dimensional (3-D) geologic model, a 3-D deterministic reservoir simulation model and a rock-log model; well drilling and completions; and surface facilities on the Fault Block II-A Tar Zone (Tar II-A). Work is continuing on research to understand the geochemistry and process regarding the sand consolidation well completion technique, final reservoir tracer work, operational work and research studies to prevent thermal-related formation compaction in the Tar II-A steamflood area, and operational work on the Tar V steamflood pilot and Tar II-A post-steamflood projects. The project team spent the Third Quarter 2001 performing well work and reservoir surveillance on the Tar II-A post-steamflood project. The Tar II-A post-steamflood operation started in February 1999 and steam chest fillup occurred in September-October 1999. The targeted reservoir pressures in the ''T'' and ''D'' sands are maintained at 90 {+-} 5% hydrostatic levels by controlling water injection and gross fluid production and through the bimonthly pressure monitoring program enacted at the start of the post-steamflood phase. The project team ramped up well work activity from October 2000 to September 2001 to increase production and injection. This work will continue through 2001 as described in the Operational Management section. Expanding thermal recovery operations to other sections of the Wilmington Oil Field, including the Tar V horizontal well pilot steamflood project, is a critical part of the City of Long Beach and Tidelands Oil Production Company's development strategy for the field. The current steamflood operations in the Tar V pilot are economical, but recent performance is below projections because of wellbore mechanical limitations that are being addressed in 2001.

  18. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2002-01-31

    The project involves using advanced reservoir characterization and thermal production technologies to improve thermal recovery techniques and lower operating and capital costs in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., Calif. Through September 2001, project work has been completed on the following activities: data preparation; basic reservoir engineering; developing a deterministic three dimensional (3-D) geologic model, a 3-D deterministic reservoir simulation model and a rock-log model; well drilling and completions; and surface facilities on the Fault Block II-A Tar Zone (Tar II-A). Work is continuing on research to understand the geochemistry and process regarding the sand consolidation well completion technique, final reservoir tracer work, operational work and research studies to prevent thermal-related formation compaction in the Tar II-A steamflood area, and operational work on the Tar V steamflood pilot and Tar II-A post-steamflood projects. The project team spent the Fourth Quarter 2001 performing routine well work and reservoir surveillance on the Tar II-A post-steamflood and Tar V pilot steamflood projects. The Tar II-A post-steamflood operation started in February 1999 and steam chest fillup occurred in September-October 1999. The targeted reservoir pressures in the ''T'' and ''D'' sands are maintained at 90 {+-} 5% hydrostatic levels by controlling water injection and gross fluid production and through the bimonthly pressure monitoring program enacted at the start of the post-steamflood phase. The project team ramped up well work activity from October 2000 through November 2001 to increase production and injection. In December, water injection well FW-88 was plug and abandoned and replaced by new well FW-295 into the ''D'' sands to accommodate the Port of Long Beach at their expense. Well workovers are planned for 2002 as described in the Operational Management section. Expanding thermal recovery operations to other sections of the Wilmington Oil Field, including the Tar V horizontal well pilot steamflood project, is a critical part of the City of Long Beach and Tidelands Oil Production Company's development strategy for the field. The steamflood operation in the Tar V pilot project is mature and profitable. Recent production performance is below projections because of wellbore mechanical limitations that were being addressed in 2001. As the fluid production is hot, the pilot steamflood was converted to a hot waterflood project in June 2001.

  19. Recent glacial events in the Norwegian North Sea - implications towards a better understanding of charging/leakage of oil fields and its impact oil exploration

    NASA Astrophysics Data System (ADS)

    Stoddart, Daniel

    2014-05-01

    Recent drilling and appraisal on the Southern Utsira High, Norwegian North Sea, has proved several large oil/gas discoveries, including the giant Johan Sverdrup, Edvard Grieg, Draupne, Ragnarrock and Apollo oil fields, making this a prolific petroleum area. The Southern Utsira High contains a variety of hydrocarbon density fluids found at several stratigraphic levels illustrating the compartmentalized nature of accumulations and charge history. The Southern Utsira High has been in a position to receive an oil/gas charge for a considerable period of time, with the basin towards the west most likely generating petroleum from early Eocene (50M Mabp) to its maximum present day burial depth. However, reservoir temperatures on the Southern Utsira High are just above the threshold for biodegradation (80°C). The Southern Utsira High oils are non-biodegraded suggesting that the majority of the oil charged relatively late - ca.3 million years ago to present day. The effects of the glaciation on the filling history of the Southern Utsira High are currently being assessed. It is clear that several erosional surfaces in the Pliocene can be identified, as well as glacial channels and moraine deposits, indicating that significant deposition and erosion occurred in the last five million years. Importantly, the effects of glacial rebound mean that the Southern Utsira High more than likely underwent tilting and possible leakage, not just once, but several times in the last 1 million years. The effects of tilting/leakage of geological areas on oil migration have been recognized by several authors. However, the detailed integration of geological mapping and geochemical evidence has not previously been published. The implications of a detailed assessment of tilting of a ''high' through time are; 1) opening up areas where oil migration is thought to be high risk or impossible; 2) identify possible paleo-oil columns aiding the de-risking of discovery appraisal strategies. The evidence of tilting/leakage of oil accumulations through time can be recognized in several oil fields on the Utsira High. The giant Johan Sverdrup discovery oil columns contain paleo-OWC, residual oil zones/paleo-oil columns, and oil shows considerably deeper than the current OWC or residual oil columns. Lundin has performed detailed mapping of the seabed and water column in the Alvheim/Utsira High areas in order to identify areas of gas leakage and its geological manifestations on the seabed and ultimately resulting in the collection of high quality samples. Results shows that gas leakage is prominent over the Alvheim and Utsira High areas and the implications of this to oil exploration will be discussed. In summary, Lundin's approach to oil migration is to better understand the fluid/gas movement throughout the whole basin through time. The talk will focus on the role of glaciations on the timing of charge from the South Viking Graben, fill-spill directions on the Southern Utsira High, the effects of late tilting/leakage on the charge/re-distribution of oil, and seabed / water column characterization and sampling. All placed in the context of oil exploration.

  20. Field experiences with rotordynamic instability in high-performance turbomachinery. [oil and natural gas recovery

    NASA Technical Reports Server (NTRS)

    Doyle, H. E.

    1980-01-01

    Two field situations illustrate the consequences of rotordynamic instability in centrifugal compressors. One involves the reinjection of produced gas into a North Sea oil formation for the temporary extraction of crude. The other describes on-shore compressors used to deliver natural gas from off-shore wells. The problems which developed and the remedies attempted in each case are discussed. Instability problems resulted in lost production, extended construction periods and costs, and heavy maintenance expenditures. The need for effective methods to properly identify the problem in the field and in the compressor design stage is emphasized.

  1. Increasing Waterflood Reserves in the Wilmington Oil Field Through Reservoir Characterization and Reservoir Management

    SciTech Connect

    Chris Phillips; Dan Moos; Don Clarke; John Nguyen; Kwasi Tagbor; Roy Koerner; Scott Walker

    1997-04-10

    This project is intended to increase recoverable waterflood reserves in slope and basin reservoirs through improved reservoir characterization and reservoir management. The particular application of this project is in portions of Fault Blocks IV and V of the Wilmington Oil Field, in Long Beach, California, but the approach is widely applicable in slope and basin reservoirs. Transferring technology so that it can be applied in other sections of the Wilmington Field and by operators in other slope and basin reservoirs is a primary component of the project.

  2. Residual-oil-saturation-technology test, Bell Creek Field, Montana. Final report

    SciTech Connect

    Not Available

    1981-06-01

    A field test was conducted of the technology available to measure residual oil saturation following waterflood secondary oil recovery processes. The test was conducted in a new well drilled solely for that purpose, located immediately northwest of the Bell Creek Micellar Polymer Pilot. The area where the test was conducted was originally drilled during 1968, produced by primary until late 1970, and was under line drive waterflood secondary recovery until early 1976, when the area was shut in at waterflood depletion. This report presents the results of tests conducted to determine waterflood residual oil saturation in the Muddy Sandstone reservoir. The engineering techniques used to determine the magnitude and distribution of the remaining oil saturation included both pressure and sidewall cores, conventional well logs (Dual Laterolog - Micro Spherically Focused Log, Dual Induction Log - Spherically Focused Log, Borehole Compensated Sonic Log, Formation Compensated Density-Compensated Neutron Log), Carbon-Oxygen Logs, Dielectric Logs, Nuclear Magnetism Log, Thermal Decay Time Logs, and a Partitioning Tracer Test.

  3. A field experiment to assess impact of chemically dispersed oil on Arabian Gulf corals

    SciTech Connect

    Le Gore, R.S.; Cuddeback, J.E.; Hofmann, J.E.; Marszalek, D.S.

    1983-03-01

    Field experiments were conducted on a coral reef at Jurayd Island (Saudi Arabia) in the Arabian Gulf to study the effects of chemically dispersed oil on local corals. Portions of the reef were exposed to predetermined concentrations of oil alone, dispersant alone, and oil-plus-dispersant mixtures. Areas of the reef not exposed to any of the toxicants were used as controls. Arabian Light Crude and Corexit 9527 dispersant were the test toxicants. Two series of experiments were conducted beginning in September 1981, one with a 24-hour exposure period and the other with a 5-day (120-hour) exposure period. Corals were stained for growth rate studies and extensively photographed to document any observed effects. Corals were examined for biological impacts immediately after the exposures, and then at 3-month intervals for 1 year. Water temperature, salinity, dissolved oxygen, and hydrocarbon content were recorded during the exposure periods. Coral growth appeared unaffected by exposure to the toxicants. Some Acropora species corals exposed to dispersed oil for 5 days exhibited delayed effects, which became apparent during the relatively cold winter season.

  4. Structure of pre-Caspian depression and major oil and gas fields of the region

    SciTech Connect

    Krylov, N.A. (Amoco Production Co., Houston, TX (United States)); Avrov, V.P. (Igirgi, Moscow (USSR)); Lisovsky, N.N.

    1991-03-01

    As a single unified depression, the pre-Caspian basin has been formed from Paleozoic to Cenozoic time. The basin is superimposed on two large pre-Permian depressions. On the Astrakhan-Aktyubinsk zone of uplifts between them is found sharply reduced Carboniferous and Devonian sections. Modern structural plan clearly displays two major structural stages: Subsalt (Paleozoic) and post (post-Kungurian). The post-salt stage is characterized by wide development of salt dome tectonics. It corresponds with its own petroliferous stage containing numerous, mostly small oil accumulations in terrigenous Mesozoic reservoirs. Large recent discoveries-Astrakhan condensate, Karachaganak and Kanazhol-Sinelnikov oil/condensate, Tengiz oil, and other fields-are associated with the Subsalt Paleozoic complex ranging from Lower Permian to the top of Upper Devonian. The Subsalt stage has its own regularities in hydrocarbon phase differentiation; large reserves concentration; dominantly productive carbonates with various reservoirs; and presence of structural, depositional, and erosional factors controlling formation of oil and gas traps. The paper describes major distributional features of the various arc-and-type Permian and Carboniferous formations, which in conjunction with Subsalt paleotemperature data and geochemistry of organic matter represents a basis for the forecast of new discoveries.

  5. Gas, water, and oil production from Wattenberg field in the Denver Basin, Colorado

    USGS Publications Warehouse

    Nelson, Philip H.; Santus, Stephen L.

    2011-01-01

    Gas, oil, and water production data were compiled from selected wells in two tight gas reservoirs-the Codell-Niobrara interval, comprised of the Codell Sandstone Member of the Carlile Shale and the Niobrara Formation; and the Dakota J interval, comprised mostly of the Muddy (J) Sandstone of the Dakota Group; both intervals are of Cretaceous age-in the Wattenberg field in the Denver Basin of Colorado. Production from each well is represented by two samples spaced five years apart, the first sample typically taken two years after production commenced, which generally was in the 1990s. For each producing interval, summary diagrams and tables of oil-versus-gas production and water-versus-gas production are shown with fluid-production rates, the change in production over five years, the water-gas and oil-gas ratios, and the fluid type. These diagrams and tables permit well-to-well and field-to-field comparisons. Fields producing water at low rates (water dissolved in gas in the reservoir) can be distinguished from fields producing water at moderate or high rates, and the water-gas ratios are quantified. The Dakota J interval produces gas on a per-well basis at roughly three times the rate of the Codell-Niobrara interval. After five years of production, gas data from the second samples show that both intervals produce gas, on average, at about one-half the rate as the first sample. Oil-gas ratios in the Codell-Niobrara interval are characteristic of a retrograde gas and are considerably higher than oil-gas ratios in the Dakota J interval, which are characteristic of a wet gas. Water production from both intervals is low, and records in many wells are discontinuous, particularly in the Codell-Niobrara interval. Water-gas ratios are broadly variable, with some of the variability possibly due to the difficulty of measuring small production rates. Most wells for which water is reported have water-gas ratios exceeding the amount that could exist dissolved in gas at reservoir pressure and temperature. The Codell-Niobrara interval is reported to be overpressured (that is, pressure greater than hydrostatic) whereas the underlying Dakota J interval is underpressured (less than hydrostatic), demonstrating a lack of hydraulic communication between the two intervals despite their proximity over a broad geographical area. The underpressuring in the Dakota J interval has been attributed by others to outcropping strata east of the basin. We agree with this interpretation and postulate that the gas accumulation also may contribute to hydraulic isolation from outcrops immediately west of the basin.

  6. Focal mechanism determination of induced microearthquakes in an oil field using full waveforms from shallow and deep seismic networks

    E-print Network

    Li, Junlun

    A new, relatively high frequency, full waveform matching method was used to study the focal mechanisms of small, local earthquakes induced in an oil field, which are monitored by a sparse near-surface network and a deep ...

  7. A Fuzzy Feed-Forward/Feedback Control System for a Three-Phase Oil Field Centrifuge.

    SciTech Connect

    Parkinson, W. J. (William Jerry),; Smith, R. E. (Ronald E.); Mortensen, F. N. (Fred N.); Wantuck, P. J. (Paul J.); Ross, Timothy J.; Jamshidi, Mohammad; Miller, N. (Neal)

    2002-01-01

    A set of fuzzy controllers was designed and applied to a commercial three-phase oil field centrifuge. This centrifuge is essentially a one of a kind unit. It is used to recover oil from tank bottoms and oil field and/or refinery sludge. It is unique because it can separate oily emulsions into three separate phases, oil, water, and solids, in one operation. The centrifuge is a large but portable device. It is moved form site to site and is used to separate a large variety of waste emulsions. The centrifuge feedstock varies significantly from site to site and often varies significantly during the daily operation. In this application, fuzzy logic was used on a class of problems not easily solved by classical control techniques. The oil field centrifuge is a highly nonlinear system, with a time varying input. We have been unable to develop a physical-mathematical model of the portion of the centrifuge operation that actually separates the oil, water, and solids. For this portion of the operation we developed a fuzzy feedback control system that modeled a skilled operator's knowledge and actions as opposed to the physical model of the centrifuge itself. Because of the variable feed we had to develop a feed-forward controller that would sense and react to feed changes prior to the time that the actual change reached the centrifuge separation unit. This portion of the control system was also a fuzzy controller designed around the knowledge of a skilled operator. In addition to the combined feed-forward and feedback control systems, we developed a soft-sensor that was used to determine the value of variables needed for the feed-forward control system. These variables could not actually be measured but were calculated from the measurement of other variables. The soft-sensor was developed with a combination of a physical model of the feed system and a skilled operator's expert knowledge. Finally the entire control system is tied together with a fuzzy-SPC (Statistical Process Control) filter, used to filter process and instrument noise and a fuzzy conflict resolution code used to keep the feed-forward and feedback control systems working well together.

  8. NMR measurement of oil shale magnetic relaxation at high magnetic field

    USGS Publications Warehouse

    Seymour, Joseph D.; Washburn, Kathryn E.; Kirkland, Catherine M.; Vogt, Sarah J.; Birdwell, Justin E.; Codd, Sarah L.

    2013-01-01

    Nuclear magnetic resonance (NMR) at low field is used extensively to provide porosity and pore-size distributions in reservoir rocks. For unconventional resources, due to low porosity and permeability of the samples, much of the signal exists at very short T2 relaxation times. In addition, the organic content of many shales will also produce signal at short relaxation times. Despite recent improvements in low-field technology, limitations still exist that make it difficult to account for all hydrogen-rich constituents in very tight rocks, such as shales. The short pulses and dead times along with stronger gradients available when using high-field NMR equipment provides a more complete measurement of hydrogen-bearing phases due to the ability to probe shorter T2 relaxation times (-5 sec) than can be examined using low-field equipment. Access to these shorter T2 times allows for confirmation of partially resolved peaks observed in low-field NMR data that have been attributed to solid organic phases in oil shales. High-field (300 MHz or 7 T) NMR measurements of spin-spin T2 and spin-lattice T1 magnetic relaxation of raw and artificially matured oil shales have potential to provide data complementary to low field (2 MHz or 0.05T) measurements. Measurements of high-field T2 and T1-T2 correlations are presented. These data can be interpreted in terms of organic matter phases and mineral-bound water known to be present in the shale samples, as confirmed by Fourier transform infrared spectroscopy, and show distributions of hydrogen-bearing phases present in the shales that are similar to those observed in low field measurements.

  9. Regularities of changes in fluid composition and properties in Vankor field pools: from light to heavy oil

    NASA Astrophysics Data System (ADS)

    Goncharov, I. V.; Oblasov, N. V.

    2015-02-01

    Oil in layers Nkh 3-4, Nkh 1, Sd 9, Yak 3-7 and vYak 2-4 of the Vankor field occurs at the depth of -2,767 to -1,357 meters at strongly different temperatures: from 62 to 26 °C. Such temperature conditions contribute to oil biodegradation processes in the pool. Therefore, oils in different pools significantly differ from each other in terms of composition and properties depending on the intensity of biodegradation. At the same time, pools might embrace both oils that have practically been not exposed to biodegradation processes and significantly biodegraded oils. The most seriously altered oils are found in vYak 2-4 layer pools. They are the heaviest and the most viscous oils among the samples under study. Many typical oil components (alkanes, alkylbenzenes, naphthalenes, phenanthrenes, dibenzothiophenes) are absent in their composition. Besides, the initial distribution of hopanes in the composition of biomarkers is altered. Apart from the molecular composition of degassed oil samples, the work also studies the effect of biodegradation on the properties and the component and isotopic composition of oils, gases and formation fluid samples.

  10. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2002-11-08

    The project involves using advanced reservoir characterization and thermal production technologies to improve thermal recovery techniques and lower operating and capital costs in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., CA. Through June 2002, project work has been completed on the following activities: data preparation; basic reservoir engineering; developing a deterministic three dimensional (3-D) geologic model, a 3-D deterministic reservoir simulation model and a rock-log model; well drilling and completions; and surface facilities on the Fault Block II-A Tar Zone (Tar II-A). Work is continuing on research to understand the geochemistry and process regarding the sand consolidation well completion technique, final reservoir tracer work, operational work and research studies to prevent thermal-related formation compaction in the Tar II-A steamflood area, and operational work on the Tar V post-steamflood pilot and Tar II-A post-steamflood projects. During the Third Quarter 2002, the project team essentially completed implementing the accelerated oil recovery and reservoir cooling plan for the Tar II-A post-steamflood project developed in March 2002 and is proceeding with additional related work. The project team has completed developing laboratory research procedures to analyze the sand consolidation well completion technique and will initiate work in the fourth quarter. The Tar V pilot steamflood project terminated hot water injection and converted to post-steamflood cold water injection on April 19, 2002. Proposals have been approved to repair two sand consolidated horizontal wells that sanded up, Tar II-A well UP-955 and Tar V well J-205, with gravel-packed inner liner jobs to be performed next quarter. Other well work to be performed next quarter is to convert well L-337 to a Tar V water injector and to recomplete vertical well A-194 as a Tar V interior steamflood pattern producer. Plans have been approved to drill and complete well A-605 in Tar V in the first quarter 2003. Plans have been approved to update the Tar II-A 3-D deterministic reservoir simulation model and run sensitivity cases to evaluate the accelerated oil recovery and reservoir cooling plan. The Tar II-A post-steamflood operation started in February 1999 and steam chest fillup occurred in September-October 1999. The targeted reservoir pressures in the ''T'' and ''D'' sands are maintained at 90 {+-} 5% hydrostatic levels by controlling water injection and gross fluid production and through the bimonthly pressure monitoring program enacted at the start of the post-steamflood phase. Well work related to the Tar II-A accelerated oil recovery and reservoir cooling plan began in March 2002 with oil production increasing from 1009 BOPD in the first quarter to 1145 BOPD in the third quarter. Reservoir pressures have been increased during the quarter from 88% to 91% hydrostatic levels in the ''T'' sands and from 91% to 94% hydrostatic levels in the ''D'' sands. Well work during the quarter is described in the Reservoir Management section. The post-steamflood production performance in the Tar V pilot project has been below projections because of wellbore mechanical limitations and the loss of a horizontal producer a second time to sand inflow that are being addressed in the fourth quarter. As the fluid production temperatures exceeded 350 F, our self-imposed temperature limit, the pilot steamflood was converted to a hot waterflood project in June 2001 and converted to cold water injection on April 19, 2002.

  11. Effect of leachability on environmental risk assessment for naturally occurring radioactive materials (NORM) in petroleum oil fields

    Microsoft Academic Search

    G. Rajaretnam; C. Blasio; K. Lovins; H. B. Spitz

    1996-01-01

    Elevated concentrations of NORM often occur in petroleum oil fields. The NORM generated by oil field operations comes from ²³⁸U and ²³²Th contained in geologic materials. The predominant NORM radionuclide brought to the surface by produced water is radium, which co-precipitates with barium in the form of complex compounds of sulfates, carbonates, and silicates in sludge and scale. These NORM

  12. A quantitative study of fish populations associated with a platform within Buccaneer Oil Field, northwestern Gulf of Mexico

    E-print Network

    Putt, Russell Eugene

    1982-01-01

    A QUANTITATIVE STUDY OF FISH POPULATIONS ASSOCIATED WITH A PLATFORM WITHIN BUCCANEER OIL FIELD, NORTHWESTERN GULF OF MEXICO A Thesis by RUSSELL EUGENE PUTT, JR. Submitted to the Graduate College of Texas A&M University in partial fulfillment... of the requirement for the degree of MASTER OF SCIENCE August 1982 Major Subject: Oceanography A QUANTITATIVE STUDY OF FISH POPULATIONS ASSOCIATED WITH A PLATFORM WITHIN BUCCANEER OIL FIELD, NORTHWESTERN GULF OF MEXICO A Thesis by RUSSELL EUGENE PUTT, JR...

  13. Water rock interaction during the process of steam stimulation exploitation of viscous crude oil in Liaohe Shuguang Oil Field, Liaoning, China

    NASA Astrophysics Data System (ADS)

    Hui, Qian; Zhenghua, Yang; Yunfeng, Li; Wancai, Xu; Yaqiao, Sun

    2006-05-01

    In the process of steam stimulation exploitation of viscous crude oil, the injected water, at high temperature and under high pressure, reacts intensively with the host rock. This kind of water rock interaction in Liaohe Shuguang Oil Field was studied on the basis of analysis of water composition changes, laboratory experiments, mineral saturation indices analysis, and mass balance calculation. Compared with the injected water, the changes of the composition of discharged water are mainly the distinct decrease of pH, Na+, SiO2 and Cl-, as well as the increase of K+, Ca2+, Mg2+, SO{4/2-} and HCO{3/-}. Laboratory experiments under field conditions showed: the dissolution sequence of minerals quantitatively is quartz>potassium feldspar>albite, and the main change of clay minerals is the conversion of kaolinite to analcime. Mass balance calculation indicated during the process of steam stimulation, large quantities of analcime are precipitated with the dissolution of large amounts of quartz, kaolinite, potassium feldspar, and CO2. These results correlated very well with the experimental results. The calculated results of Liaohe Shuguang Oil Field showed that during the steam stimulation for viscous crude oil, the amounts of minerals dissolved (precipitated) are huge. To control the clogging of pore spaces of oil reservoirs, increased study of water rock interaction is needed.

  14. A fortran program for Monte Carlo simulation of oil-field discovery sequences

    USGS Publications Warehouse

    Bohling, G.C.; Davis, J.C.

    1993-01-01

    We have developed a program for performing Monte Carlo simulation of oil-field discovery histories. A synthetic parent population of fields is generated as a finite sample from a distribution of specified form. The discovery sequence then is simulated by sampling without replacement from this parent population in accordance with a probabilistic discovery process model. The program computes a chi-squared deviation between synthetic and actual discovery sequences as a function of the parameters of the discovery process model, the number of fields in the parent population, and the distributional parameters of the parent population. The program employs the three-parameter log gamma model for the distribution of field sizes and employs a two-parameter discovery process model, allowing the simulation of a wide range of scenarios. ?? 1993.

  15. Biological treatment process for removing petroleum hydrocarbons from oil field produced waters

    SciTech Connect

    Tellez, G.; Khandan, N.

    1995-12-31

    The feasibility of removing petroleum hydrocarbons from oil fields produced waters using biological treatment was evaluated under laboratory and field conditions. Based on previous laboratory studies, a field-scale prototype system was designed and operated over a period of four months. Two different sources of produced waters were tested in this field study under various continuous flow rates ranging from 375 1/D to 1,800 1/D. One source of produced water was an open storage pit; the other, a closed storage tank. The TDS concentrations of these sources exceeded 50,000 mg/l; total n-alkanes exceeded 100 mg/l; total petroleum hydrocarbons exceeded 125 mg/l; and total BTEX exceeded 3 mg/l. Removals of total n-alkanes, total petroleum hydrocarbons, and BTEX remained consistently high over 99%. During these tests, the energy costs averaged $0.20/bbl at 12 bbl/D.

  16. Use of Ambersorb{reg_sign} carbonaceous adsorbent for removal of BTEX compounds from oil-field produced water

    Microsoft Academic Search

    D. L. Gallup; E. G. Isacoff; D. N. Smith

    1996-01-01

    The removal of high concentrations of BTEX compounds (benzene, toluene, ethylbenzene and xylenes) from oil-field produced waters using a carbonaceous adsorbent was successfully demonstrated in the field. The carbonaceous adsorbent was much more effective in removing BTEX compounds from produced water than activated carbon or modified clays. The primary objectives of the field studies were to evaluate the efficiency of

  17. Hydrocarbon-water interactions during brine migration: Evidence from hydrocarbon inclusions in calcite cements from Danish North Sea oil fields

    USGS Publications Warehouse

    Jensenius, J.; Burruss, R.C.

    1990-01-01

    Crude oils in primary and secondary fluid inclusions in calcite from fractures in seven offshore oil fields associated with diapiric salt structures in the Danish sector of the North Sea were analyzed by capillary column gas chromatography and compared with crude oils produced from the same reservoirs. Oils from fluid inclusions in all fields show evidence of biodegradation (decreased n-C17/pristane and n-C18/phytane ratios and loss of n-C7, 2-methyl hexane, and 3-methyl hexane relative to methyl cyclohexane) and water washing (absence of benzene and depletion of toluene). Some oils in inclusions are extremely enriched in C6 and C7 cyclic alkanes suggesting that these samples contain hydrocarbons exsolved from ascending, hotter formation waters. Compared to inclusion oils the produced oils are less biodegraded, but are water washed, indicating that both types of oil interacted with large volumes of formation water. The carbon isotopic composition of the calcite host of the fluid inclusions in the Dagmar and Skjold fields is as light as -16.5%. PDB and the sulfur isotopic composition of pyrite in and adjacent to the calcite veins in the Skjold field is as light as -39.6%. CDT, indicating that biodegradation of the oils was a source of some of the carbon in the calcite and sulfate reduction was the source of sulfur for the pyrite. The evidence for microbial degradation of petroleum is consistent with present-day reservoir temperatures (65??-96??C) but is not consistent with previous estimates of the temperatures of calcite vein filling (95??-130??C) which are much higher than the temperatures of known occurrences of biodegraded oil. ?? 1990.

  18. Hydrocarbon-water interactions during brine migration: Evidence from hydrocarbon inclusions in calcite cements from Danish North Sea oil fields

    NASA Astrophysics Data System (ADS)

    Jensenius, Jørgen; Burruss, Robert C.

    1990-03-01

    Crude oils in primary and secondary fluid inclusions in calcite from fractures in seven offshore oil fields associated with diapiric salt structures in the Danish sector of the North Sea were analyzed by capillary column gas chromatography and compared with crude oils produced from the same reservoirs. Oils from fluid inclusions in all fields show evidence of biodegradation (decreased n- C17/pristane and n- C18/phytane ratios and loss of n-C 7, 2-methyl hexane, and 3-methyl hexane relative to methyl cyclohexane) and water washing (absence of benzene and depletion of toluene). Some oils in inclusions are extremely enriched in C 6 and C 7 cyclic alkanes suggesting that these samples contain hydrocarbons exsolved from ascending, hotter formation waters. Compared to inclusion oils the produced oils are less biodegraded, but are water washed, indicating that both types of oil interacted with large volumes of formation water. The carbon isotopic composition of the calcite host of the fluid inclusions in the Dagmar and Skjold fields is as light as -16.5%. PDB and the sulfur isotopic composition of pyrite in and adjacent to the calcite veins in the Skjold field is as light as -39.6%. CDT, indicating that biodegradation of the oils was a source of some of the carbon in the calcite and sulfate reduction was the source of sulfur for the pyrite. The evidence for microbial degradation of petroleum is consistent with present-day reservoir temperatures (65°-96°C) but is not consistent with previous estimates of the temperatures of calcite vein filling (95°-130°C) which are much higher than the temperatures of known occurrences of biodegraded oil.

  19. Effect of leachability on environmental risk assessment for naturally occurring radioactive materials in petroleum oil fields.

    PubMed

    Rajaretnam, G; Spitz, H B

    2000-02-01

    Elevated concentrations of naturally occurring radioactive material (NORM), including 238U, 232Th, and their progeny found in underground geologic deposits, are often encountered during crude oil recovery. Radium, the predominant radionuclide brought to the surface with the crude oil and produced water, co-precipitates with barium in the form of complex compounds of sulfates, carbonates, and silicates found in sludge and scale. These NORM deposits are highly stable and very insoluble under ambient conditions at the earth's surface. However, the co-precipitated radium matrix is not thermodynamically stable at reducing conditions which may enable a fraction of the radium to eventually be released to the environment. Although the fate of radium in uranium mill tailings has been studied extensively, the leachability of radium from crude oil NORM deposits exposed to acid-rain and other aging processes is generally unknown. The leachability of radium from NORM contaminated soil collected at a contaminated oil field in eastern Kentucky was determined using extraction fluids having wide range of pH reflecting different extreme environmental conditions. The average 226Ra concentration in the samples of soil subjected to leachability testing was 32.56 Bq g(-1) +/- 0.34 Bq g(-1). The average leaching potential of 226Ra observed in these NORM contaminated soil samples was 1.3% +/- 0.46% and was independent of the extraction fluid. Risk assessment calculations using the family farm scenario show that the annual dose to a person living and working on this NORM contaminated soil is mainly due to external gamma exposure and radon inhalation. However, waterborne pathways make a non-negligible contribution to the dose for the actual resident families living on farmland with the type of residual NORM contamination due to crude oil recovery operations. PMID:10647985

  20. Use of oil-emulsion mud in the Sivells Bend Field: Gas and gas condensate operations for the independent producer.

    E-print Network

    Echols, Walter Harlan

    1954-01-01

    obtained between oil-emulsion mud and water-base mud as used in the develop- ment of Strawn sand wells iu a North Texas field. (Presented at the New York Meeting of the A. I. PL E. , March 1947; ublished in Petroleum Technolo@r, tuIF 1947~ end..., consisting of a mixture of oil-base mud and bentonitic water-base mud, has been used experimentally in drilling 8 of the 35 wells in the Sivells Bend field, Cooke County, Texas. Experience indicates the oil-emulsion mud can be controlled in much...

  1. Sedimentation, zoning of reservoir rocks in W. Siberian basin oil fields

    SciTech Connect

    Kliger, J.A. (Enforce Energy Corp., New York, NY (United States))

    1994-02-07

    A line pattern of well cluster spacing was chosen in western Siberia because of taiga, marshes, etc., on the surface. The zoning of the oil pools within productive Upper Jurassic J[sub 3] intervals is complicated. This is why until the early 1990s almost each third well drilled in the Shaimsky region on the western edge of the West Siberian basin came up dry. The results of development drilling would be much better if one used some sedimentological relationships of zoning of the reservoir rocks within the oil fields. These natural phenomena are: Paleobasin bathymetry; Distances from the sources of the clastic material; and Proximity of the area of deposition. Using the diagram in this article, one can avoid drilling toward areas where the sandstone pinch out, area of argillization of sand-stones, or where the probability of their absence is high.

  2. A fuzzy control system for a three-phase oil field centrifuge

    SciTech Connect

    Parkinson, W.J.; Smith, R.E.; Wantuck, P.J. [Los Alamos National Lab., NM (United States); Miller, N. [Centech Inc., Casper, WY (United States)

    1998-12-31

    The three-phase centrifuge discussed here is an excellent device for cleaning up oil field and refinery wastes. These wastes are typically composed of hydrocarbons, water, and solids. This technology converts waste, which is often classified as hazardous, into salable oil, reusable water, and solids that can be placed in landfills. No secondary waste is produced. A major problem is that only one person can set up and run the equipment well enough to provide an optimal cleanup. Demand for this technology has far exceeded a one-man operation. The solution to this problem is an intelligent control system that can replace a highly skilled operator so that several centrifuges can be operated at different locations at the same time.

  3. Costs and indices for domestic oil and gas field equipment and production operations, 1992--1995

    SciTech Connect

    NONE

    1996-08-01

    This report presents estimated costs and cost indices for domestic oil and natural gas field equipment and production operations for 1992, 1993, 1994, and 1995. The costs of all equipment and services are those in effect during June of each year. The sum (aggregates) of the costs for representative leases by region, depth, and production rate were averaged and indexed. This provides a general measure of the increased or decreased costs from year to year for lease equipment and operations. These general measured do not capture changes in industry-wide costs exactly because of annual variations in the ratio of the total number of oil wells to the total number of gas wells. The detail provided in this report is unavailable elsewhere. The body of this report contains summary tables, and the appendices contain detailed tables.

  4. Increased Oil Production and Reserves from Improved Completion Techniques in the Bluebell Field, Uinta Basin, Utah.

    SciTech Connect

    Morgan, C.D.

    1997-12-31

    The objective of this project is to increase oil production and reserves in the Uinta Basin by demonstrating improved completion techniques. Low productivity of Uinta Basin wells is caused by gross production intervals of several thousand feet that contain perforated thief zones, water-bearing zones, and unperforated oil-bearing intervals. Geologic and engineering characterization and computer simulation of the Green River and Wasatch Formations in the Bluebell field will determine reservoir heterogeneities related to fractures and depositional trends. This will be followed by drilling and recompletion of several wells to demonstrate improved completion techniques based on the reservoir characterization. Transfer of the project results will be an ongoing component of the project.

  5. Increased Oil Production and Reserves from Improved Completion Techniques in the Bluebell Field, Uinta Basin, Utah

    SciTech Connect

    Morgan, Craig

    1999-11-01

    The objective of this project is to increase oil production and reserves in the Uinta Basin by demonstrating improved completion techniques. Low productivity of Uinta Basin wells is caused by gross production intervals of several thousand feet that contain perforated thief zones, water-bearing zones, and unperforated oil-bearing intervals. Geologic and engineering characterization and computer simulation of the Green River and Wasatch Formations in the Bluebell field will determine reservoir heterogeneities related to fractures and depositional trends. This will be followed by drilling and recompletion of several wells to demonstrate improved completion techniques based on the reservoir characterization. Transfer of the project results will be an ongoing component of the project.

  6. VSP Monitoring of CO2 Injection at the Aneth Oil Field in Utah

    NASA Astrophysics Data System (ADS)

    Huang, L.; Rutledge, J.; Zhou, R.; Denli, H.; Cheng, A.; Zhao, M.; Peron, J.

    2008-12-01

    Remotely tracking the movement of injected CO2 within a geological formation is critically important for ensuring safe and long-term geologic carbon sequestration. To study the capability of vertical seismic profiling (VSP) for remote monitoring of CO2 injection, a geophone string with 60 levels and 96 channels was cemented into a monitoring well at the Aneth oil field in Utah operated by Resolute Natural Resources and Navajo National Oil and Gas Company. The oil field is located in the Paradox Basin of southeastern Utah, and was selected by the Southwest Regional Partnership on Carbon Sequestration, supported by the U.S. Department of Energy, to demonstrate combined enhanced oil recovery (EOR) and CO2 sequestration. The geophones are placed at depths from 805 m to 1704 m, and the oil reservoir is located approximately from 1731 m to 1786 m in depth. A baseline VSP dataset with one zero-offset and seven offset source locations was acquired in October, 2007 before CO2 injection. The offsets/source locations are approximately 1 km away from the monitoring well with buried geophone string. A time-lapse VSP dataset with the same source locations was collected in July, 2008 after five months of CO2/water injection into a horizontal well adjacent to the monitoring well. The total amount of CO2 injected during the time interval between the two VSP surveys was 181,000 MCF (million cubic feet), or 10,500 tons. The time-lapse VSP data are pre-processed to balance the phase and amplitude of seismic events above the oil reservoir. We conduct wave-equation migration imaging and interferometry analysis using the pre-processed time-lapse VSP data. The results demonstrate that time-lapse VSP surveys with high-resolution migration imaging and scattering analysis can provide reliable information about CO2 migration. Both the repeatability of VSP surveys and sophisticated time-lapse data pre-processing are essential to make VSP as an effective tool for monitoring CO2 injection.

  7. Hydrologic data for the East Poplar oil field, Fort Peck Indian Reservation, Northeastern Montana

    USGS Publications Warehouse

    Thamke, J.N.; Craigg, S.D.; Mendes, T.M.

    1996-01-01

    This report presents selected hydrologic data for the East Poplar oil field, located in the south-central part of the Fort Peck Indian Reservation in northeastern Montana. Data about the occurrence, quantity, and quality of ground and surface water are presented in tabular form. The tables contain records of privately owned wells (active and abandoned), monitoring wells installed by the U.S. Geological Survey and Montana Bureau of Mines and Geology, oil wells, and brine-injection wells; lithologic descriptions of drill cuttings and well-completion data from monitoring wells; data from two aquifer tests conducted in Quaternary alluvial and glacial deposits; chemical quality of ground water; and information on the quantity and chemical quality of surface water. Records of electromagnetic geophysical measurements collected throughout an area of about 20 square miles of the study area are compiled and included on a floppy disk. Illustrations in this report contain information about study area location, site- numbering system, general physical and cultural features, and construction of monitoring wells installed by the U.S. Geological Survey. plate-sized map presents additional information about privately owned wells, monitoring wells, oil wells, brine-injections wells, surface-water data-collection sites, and area of electromagnetic data collection. The data presented in this report provide a base with which to better define and interpret the occurrence, quantity, and quality of ground and surface water in the vicinity of the Poplar River Valley in the south-central part of the Fort Peck Indian Reservation. The data can be used to help delineate the occurrence of brine and saline water in Quaternary alluvial and glacial deposits in the East Poplar oil field.

  8. Spatial statistical analysis of basal stem root disease under natural field epidemic of oil palm

    NASA Astrophysics Data System (ADS)

    Kamu, Assis; Phin, Chong Khim; Seman, Idris Abu; Wan, Hoong Hak; Mun, Ho Chong

    2015-02-01

    Oil palm or scientifically known as Elaeis guineensis Jacq. is the most important commodity crop in Malaysia and has greatly contributed to the economy growth of the country. As far as disease is concerned in the industry, Basal Stem Rot (BSR) caused by Ganoderma boninence remains the most important disease. BSR disease is the most widely studied with information available for oil palm disease in Malaysia. However, there is still limited study on the spatial as well as temporal pattern or distribution of the disease especially under natural field epidemic condition in oil palm plantation. The objective of this study is to spatially identify the pattern of BSR disease under natural field epidemic using two geospatial analytical techniques, which are quadrat analysis for the first order properties of partial pattern analysis and nearest-neighbor analysis (NNA) for the second order properties of partial pattern analysis. Two study sites were selected with different age of tree. Both sites are located in Tawau, Sabah and managed by the same company. The results showed that at least one of the point pattern analysis used which is NNA (i.e. the second order properties of partial pattern analysis) has confirmed the disease is complete spatial randomness. This suggests the spread of the disease is not from tree to tree and the age of palm does not play a significance role in determining the spatial pattern of the disease. From the spatial pattern of the disease, it would help in the disease management program and for the industry in the future. The statistical modelling is expected to help in identifying the right model to estimate the yield loss of oil palm due to BSR disease in the future.

  9. Monitoring Subsidence Changes over the Lost Hills Diatomite Oil Field, California*

    NASA Astrophysics Data System (ADS)

    Fielding, E. J.; Brink, J. L.; Patzek, T. W.; Silin, D. B.; Blom, R. G.

    2003-12-01

    SAR, GPS and LiDAR monitoring of the Lost Hills giant oil field in central California shows dramatic changes of subsidence over the last 15 years. Subsidence is caused by fluid withdrawal and subsequent compaction of the diatomite petroleum reservoir and in some areas has reached cumulative subsidence of 2 meters since 1989. Measurements of the surface elevation changes with semi-annual GPS surveys and SAR interferometry (using ERS-1 and ERS-2 satellite data) show subsidence rates exceeded 1 mm/day during 1995-1996 in the central part of the oil field. By 1999-2000, increased injection of water to replace the extracted fluids meant that no part of the Lost Hills field was subsiding faster than 0.5 mm/day and some areas that had extremely rapid subsidence before were slower than 0.2 mm/day. We increased the temporal resolution of the subsidence measurements for late 2002 and early 2003 by analyzing more frequent SAR acquisitions from the Radarsat-1 satellite to better understand the compaction response to changes in the oil field operations. The Radarsat-1 orbit-repeat period is 24 days but individual interferograms with short time intervals of only 24 days can have substantial errors due to atmospheric variations. Errors can be reduced by making interferograms with longer time intervals or by averaging multiple independent interferograms over a shorter interval. The Radarsat-1 satellite can image Lost Hills from up to six different tracks every 24-day cycle, potentially allowing six independent interferograms. *Part of this work was performed at the Jet Propulsion Lab, Caltech under contract with the National Aeronautics and Space Administration.

  10. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2002-04-30

    The project involves using advanced reservoir characterization and thermal production technologies to improve thermal recovery techniques and lower operating and capital costs in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., Calif. Through December 2001, project work has been completed on the following activities: data preparation; basic reservoir engineering; developing a deterministic three dimensional (3-D) geologic model, a 3-D deterministic reservoir simulation model and a rock-log model; well drilling and completions; and surface facilities on the Fault Block II-A Tar Zone (Tar II-A). Work is continuing on research to understand the geochemistry and process regarding the sand consolidation well completion technique, final reservoir tracer work, operational work and research studies to prevent thermal-related formation compaction in the Tar II-A steamflood area, and operational work on the Tar V steamflood pilot and Tar II-A post-steamflood projects. During the First Quarter 2002, the project team developed an accelerated oil recovery and reservoir cooling plan for the Tar II-A post-steamflood project and began implementing the associated well work in March. The Tar V pilot steamflood project will be converted to post-steamflood cold water injection in April 2002. The Tar II-A post-steamflood operation started in February 1999 and steam chest fillup occurred in September-October 1999. The targeted reservoir pressures in the ''T'' and ''D'' sands are maintained at 90 {+-} 5% hydrostatic levels by controlling water injection and gross fluid production and through the bimonthly pressure monitoring program enacted at the start of the post-steamflood phase. Most of the 2001 well work resulted in maintaining oil and gross fluid production and water injection rates. Reservoir pressures in the ''T'' and ''D'' sands are at 88% and 91% hydrostatic levels, respectively. Well work during the first quarter and plans for 2002 are described in the Reservoir Management section. The steamflood operation in the Tar V pilot project is mature and profitable. Recent production performance has been below projections because of wellbore mechanical limitations that have been addressed during this quarter. As the fluid production temperatures were beginning to exceed 350 F, our self-imposed temperature limit, the pilot steamflood was converted to a hot waterflood project in June 2001 and will be converted to cold water injection next quarter.

  11. Integration of seismic methods with reservoir simulation, Pikes Peak heavy oil field, Saskatchewan

    NASA Astrophysics Data System (ADS)

    Zou, Ying

    The Pikes Peak heavy oil field has been operated by Husky Energy Ltd since 1981. Steam injection has been successfully employed to increase production. Efforts in geophysics and reservoir engineering have been made to improve interpretations in the mapping of reservoir conditions. This dissertation developed tools and a working flow for integrating the analysis of time-lapse seismic surveys with reservoir simulation, and applied them to the Pikes Peak field. Two time-lapse 2D seismic lines acquired in February 1991 and March 2000 in the eastern part of the field were carefully processed to produce wavelet and structure matched final sections. Reservoir simulation based on the field reservoir production history was carried out. It provided independent complementary information for the time-lapse seismic analysis. A rock physics procedure based on Gassmann's equation and Batzle and Wang's empirical relationship successfully linked the reservoir engineering to the seismic method. Based on the resultant seismic models, synthetic seismic sections were generated as the analogy of field seismic sections. The integrated interpretation for the Pikes Peak reservoir drew the following conclusions: The areas with a gas saturation difference, between two compared time steps, have seismic differences. Thicker gas zones correspond with large reflectivity changes on the top of the reservoir and larger traveltime delays in the seismic section. The thin gas zones only induce large reflectivity changes on the top of the reservoir, and do not have large time delays below the reservoir zone. High temperature regions also correlate with areas having large seismic energy differences. High temperature with thick gas (steam and methane) zones may be evidence for steam existence. The seismic differences at locations far from the production zone are due to the lower pressure that causes solution gas to evolve from the oil. Pressure changes propagate much faster (˜20 m in one month) than temperature changes (˜8 m in a year) based on the reservoir simulation results. The pressure dependence of the seismic data is due to its influences on gas saturation. The bypassed oil area and steam fronts (high temperature front) can be estimated from the temperature and oil saturation distributions from the reservoir simulation. AVO results show a steam and gas zone pattern similar to the one produced by reservoir simulation.

  12. Recognition of waterflood sweep and formation lithology in a giant Egyptian oil field by applied petrophysics

    SciTech Connect

    La Chance, D.P.; Winston, R.T.

    1987-06-01

    This paper presents a simplified formation-evaluation methodology that was successfully applied to the study of a giant Egyptian oil field. This method could resolve formation lithology and injected water saturations with a high degree of confidence. Observed core lithologies were matched with openhole log responses to generate lithology windows in a lithoporosity plot. Resolution of formation lithology by openhole logs required plotting the log responses on the lithoporisity plot and determining the lithology window in which the data fell. Formation intervals swept by injection water were found by analysis of two calculated water saturations (formation water and injection water) together with lithology and field-history information. This work relied heavily on the first successful full-zone core obtained in the field, which was cored and handled with fiberglass core barrels.

  13. Enhanced biodegradation of transformer oil in soils with cyclodextrin--from the laboratory to the field.

    PubMed

    Molnár, Mónika; Leitgib, Laura; Gruiz, Katalin; Fenyvesi, Eva; Szaniszló, Nikoletta; Szejtli, József; Fava, Fabio

    2005-03-01

    The use cyclodextrins for the intensification of bioremediation by improving the mobility and bioavailability of contaminants has recently been studied. In this work, the role of randomly methylated beta-cyclodextrin in the bioremediation of soils contaminated with transformer oil was studied both in bench scale bioreactors and through field experiments. The aims of this research were to (a) establish the scientific background of a cyclodextrin-based soil bioremediation technology, (b) demonstrate its feasibility and effectiveness in the field, and (c) develop an integrated methodology, consisting of a combination of physical, chemical, biological and ecotoxicological analytical methods, for efficiently monitoring the technology performances. The stepwise increasing scale of the experiments and the application of the integrated analytical methodology supported the development of a scientifically established new technology and the identification of the advantages and the limitations of its application in the field. At each phase of the study, randomly methylated beta-cyclodextrin was found to significantly enhance the bioremediation and detoxification of the transformer oil-contaminated soils employed by increasing the bioavailability of the pollutants and the activity of indigenous microorganisms. PMID:15730026

  14. Gas injection may have triggered earthquakes in the Cogdell oil field, Texas

    PubMed Central

    Gan, Wei; Frohlich, Cliff

    2013-01-01

    Between 1957 and 1982, water flooding was conducted to improve petroleum production in the Cogdell oil field north of Snyder, TX, and a contemporary analysis concluded this induced earthquakes that occurred between 1975 and 1982. The National Earthquake Information Center detected no further activity between 1983 and 2005, but between 2006 and 2011 reported 18 earthquakes having magnitudes 3 and greater. To investigate these earthquakes, we analyzed data recorded by six temporary seismograph stations deployed by the USArray program, and identified 93 well-recorded earthquakes occurring between March 2009 and December 2010. Relocation with a double-difference method shows that most earthquakes occurred within several northeast–southwest-trending linear clusters, with trends corresponding to nodal planes of regional focal mechanisms, possibly indicating the presence of previously unidentified faults. We have evaluated data concerning injection and extraction of oil, water, and gas in the Cogdell field. Water injection cannot explain the 2006–2011 earthquakes, especially as net volumes (injection minus extraction) are significantly less than in the 1957–1982 period. However, since 2004 significant volumes of gases including supercritical CO2 have been injected into the Cogdell field. The timing of gas injection suggests it may have contributed to triggering the recent seismic activity. If so, this represents an instance where gas injection has triggered earthquakes having magnitudes 3 and larger. Further modeling studies may help evaluate recent assertions suggesting significant risks accompany large-scale carbon capture and storage as a strategy for managing climate change. PMID:24191019

  15. Development programs call for two concrete platforms in oil, gas fields off Norway

    SciTech Connect

    Not Available

    1991-12-23

    This paper reports on development plans for two fields off Norway that have given a boost to use of concrete for the construction of floating production facilities. Conoco Norway Inc. let a $350 million contract for construction of the world's first concrete hull, tension leg platform (TLP) to Norwegian Contractors, Stavanger. As part of a $3.5 billion project, it will be installed in the Conoco group's Heidrun oil and gas field in the Haltenbanken area of the Norwegian Sea off mid-Norway. In addition, a group led by Norsk Hydro Produksjon AS, Oslo, chose a concrete floating production platform as the basis for a $2.42 billion development of the oil province in Troll gas field in the North SEa. Also in the Norwegian North Sea, companies involved in the Sleipner gas development project agreed to seek approval for the $1.77 billion, first phase development phase of West Sleipner reserves beginning in 1996. This will use conventional production technology, although the possibility of a concrete treatment platform has not been ruled out.

  16. Four-dimensional seismic analysis of the Hibernia oil field, Grand Banks, Canada

    NASA Astrophysics Data System (ADS)

    Wright, Richard James

    2004-12-01

    The seismic reflection method, traditionally a geologic structural imaging tool, is increasingly being utilized for petroleum reservoir monitoring purposes. Time-lapse, or four dimensional (4D) seismic reservoir monitoring is the process by which repeated 3D seismic surveys are acquired over a common area during the production of a petroleum reservoir in an effort to spatially image production related changes. While if successful, this seismic method can have a significant impact on an oil field's development plan, the sometimes subtle nature of the 4D seismic signals restricts the universal application of 4D seismic methods in all reservoirs and operating environments. To examine the potential use of 4D seismic on Canada's Grand Banks, this thesis conducts a 4D seismic analysis of the Hibernia oil field---the first example of 4D seismic technology on the Grand Banks. Due to a challenging environment (seismic and reservoir) at Hibernia for 4D seismic success, rock physics modeling predicts a subtle 4D seismic response for areas of both water and gas injection. To equalize the 4D seismic datasets, specialized poststack cross equalization including a volume event warping process is applied to two 3D post stack seismic datasets from the Hibernia oil field, a pre-production "legacy" survey acquired in 1991, and a 2001 survey. The cross equalization processing improves the repeatability of non-reservoir events fieldwide and enhances reservoir anomalies in some areas of the field. While the data contains a fair degree of noise, 4D seismic anomalies above the noise level can be imaged in areas of both water and gas injection. Through interpretation, some of these anomalies are shown to be consistent with modeled responses to water and gas injection. In addition, there is evidence that some of the seismic anomalies may be due to pore pressure changes in the reservoir. The results of the Hibernia 4D seismic analysis are then used as background for a feasibility analysis for the application of 4D seismic in other fields on the Grand Banks, which compared to Hibernia, prove to have similar 4D seismic potential. In accomplishing these objectives, this thesis makes new contributions in the areas of rock physics modeling, 4D seismic in marginal environments, methods for 4D seismic pressure/saturation inversion, and 4D seismic interpretation. As Hibernia is the first producing field in the region, this thesis provides an important benchmark for the evaluation of the potential role of 4D seismic analysis on development decisions for other Grand Banks fields currently in early production (Terra Nova), or under development (White Rose, Hebron).

  17. Microbial Oxidation of Natural Gas in a Plume Emanating from the Coal Oil Point Seep Field

    NASA Astrophysics Data System (ADS)

    Mendes, S. D.; Valentine, D. L.; Perez, C.; Scarlett, R.

    2012-12-01

    The hydrocarbon seep field at Coal Oil Point, off the coast of Santa Barbara, California, releases > 1010 g of thermogenic natural gas each year. Gases emitted from Coal Oil Point include methane, ethane, propane, and butane, which are atmospheric pollutants and greenhouse gases. Even though the seeps are at water depths of only 5-80 m, much of the gas dissolves and contributes to a plume that is transported by ocean currents. While hydrocarbons can support bacterial respiration, resulting in the removal of hydrocarbon gas from the plume, the time-scale for the bacterial respiratory response is unconstrained. To track hydrocarbon respiration 3H-ethane, propane, and butane were synthesized using Grignard reagents and tritiated water with yields of >70% and applied as tracers to samples up- and down-current from the seeps at Coal Oil Point. Validation experiments conducted in September 2011 aboard the R/V Atlantis show that 3H-labeled tracers are an order of magnitude more sensitive than previous methods using stable carbon isotopes (Valentine et. al 2010), making this technique preferable in natural systems. Application of the tracers concurrent with plume tracking in July-August 2012 show ethane, propane, and butane consumption are readily inducible on a timescale of days.

  18. Gas, Water, and Oil Production from the Wasatch Formation, Greater Natural Buttes Field, Uinta Basin, Utah

    USGS Publications Warehouse

    Nelson, Philip H.; Hoffman, Eric L.

    2009-01-01

    Gas, oil, and water production data were compiled from 38 wells with production commencing during the 1980s from the Wasatch Formation in the Greater Natural Buttes field, Uinta Basin, Utah. This study is one of a series of reports examining fluid production from tight gas reservoirs, which are characterized by low permeability, low porosity, and the presence of clay minerals in pore space. The general ranges of production rates after 2 years are 100-1,000 mscf/day for gas, 0.35-3.4 barrel per day for oil, and less than 1 barrel per day for water. The water:gas ratio ranges from 0.1 to10 barrel per million standard cubic feet, indicating that free water is produced along with water dissolved in gas in the reservoir. The oil:gas ratios are typical of a wet gas system. Neither gas nor water rates show dependence upon the number of perforations, although for low gas-flow rates there is some dependence upon the number of sandstone intervals that were perforated. Over a 5-year time span, gas and water may either increase or decrease in a given well, but the changes in production rate do not exhibit any dependence upon well proximity or well location.

  19. Exposures and cancer incidence near oil fields in the Amazon basin of Ecuador

    PubMed Central

    San, S; Armstrong, B; Cordoba, J; Stephens, C

    2001-01-01

    OBJECTIVES—To examine environmental exposure and incidence and mortality of cancer in the village of San Carlos surrounded by oil fields in the Amazon basin of Ecuador.?METHODS—Water samples of the local streams were analyzed for total petroleum hydrocarbons (TPHs). A preliminary list of potential cancer cases from 1989 to 1998 was prepared. Cases were compared with expected numbers of cancer morbidity and mortality registrations from a Quito reference population.?RESULTS—Water analysis showed severe exposure to TPHs by the residents. Ten patients with cancer were diagnosed while resident in the village of San Carlos. An overall excess for all types of cancer was found in the male population (8 observed v 3.5 expected) with a risk 2.26 times higher than expected (95% confidence interval (95% CI) 0.97 to 4.46). There was an overall excess of deaths for all types of cancer (6 v 1.6 expected) among the male population 3.6 times higher than the reference population (95% CI 1.31 to 7.81).?CONCLUSIONS—The observed excess of cancer might be associated with the pollution of the environment by toxic contaminants coming from the oil production.???Keywords: cancer; oil; Amazon; Ecuador PMID:11452046

  20. Integration of geological, geochemical, and geophysical spatial data of the Cement oil field, Oklahoma, test site

    USGS Publications Warehouse

    Termain, Patricia A.; Donovan, Terrence J.; Chavez, Pat S.

    1980-01-01

    Measurement pertaining to geology, geochemistry, and geophysics of the Cement oil field, Oklahoma, test site were collected employing both airborne sensors and ground-based data collection. The measurements include: (1) airborne gamma-ray spectrometry (supplying bismuth 214, thalium 208, and potassium 40 gamma-ray intensities); (2) aeromagnetic survey data; (3) multi-frequency airborne resistivity survey data (supplying apparent electrical resistivity of near surface materials); (4) gravity data; (5) geological and topographic maps; and (6) image data from Landsat MSS and U-2 photography.

  1. Standard practice for evaluating and qualifying oil field and refinery corrosion inhibitors using rotating cage

    E-print Network

    American Society for Testing and Materials. Philadelphia

    2006-01-01

    1.1 This practice covers a generally accepted procedure to use the rotating cage (RC) for evaluating corrosion inhibitors for oil field and refinery applications. 1.2 The values stated in SI units are to be regarded as the standard. The values given in parentheses are for information only. This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety and health practices and determine the applicability of regulatory limitations prior to use.

  2. Applying the Aramid Joined v-belt high torque, low speed oil field pumping units

    SciTech Connect

    Stork, D.; Watson, J.

    1982-11-01

    This paper discusses the successful application of Aramid fiber-reinforced Torque Team Plus Joined Vbelts to low speed; (8-20 rpm) high torque, up to (320,000 in-lb); 100% belt driven oil field pumping units. Also discussed is a comparison in operating efficiency over gear or chain units, reduced initial expense, and lower overall maintenance effort. The Aramid reinforced Joined V-belts were applied to a double reduction drive (68-142:1 ratio) eliminating gear or chain reducers. Pumping units range in size from 57,000 in-lb to 320,000 in-lb.

  3. Investigation of ginkgo biloba leave extracts as corrosion and Oil field microorganism inhibitors

    PubMed Central

    2013-01-01

    Ginkgo biloba (Ginkgoaceae), originating from China, now distributes all over the world. Wide application of Ginkgo biloba extracts is determined by the main active substances, flavonoids and terpenoids, which indicates its extracts suitable to be used as an effective corrosion inhibitor. The extracts of Ginkgo biloba leave have been investigated on the corrosion inhibition of Q235A steel with weight loss and potentiodynamic polarisation techniques. The inhibition efficiency of the extracts varies with extract concentration. The extracts inhibit corrosion mainly by adsorption mechanism. Potentiodynamic polarisation studies show that extracts are mixed type inhibitors. The antibacterial activity of the extracts against oil field microorganism (SRB, IB and TGB) was also investigated. PMID:23651921

  4. Geo-information approach to the study of Romashkino oil field geodynamics

    NASA Astrophysics Data System (ADS)

    Usmanov, S.; Sharipov, B.; Akhmetov, A.; Delev, A.

    2012-04-01

    Geodynamic processes have an immediate influence on a fluid dynamics, for that version they are of significant importance in the formation and reformation processes of oil and gas deposits. The object of our analysis was Romashkino oil field, which is confined to the anticlinal structure of the arch part of the South Tatar Arch. The initial data in our project include the series of a paper maps, which contain the location of the intersection of production and injection wells with the Kyn horizont at the Romashkino oil field and geologic engineering information, which contains the flow rates's inversions data of the well's production activity. Inversion occurs as a periodic increasing of the flow rates which is not caused by the external special influence on the well, against the long-term production activity's decreasing by the decreasing of oil's flow rates. During the analysis of the data we identified the anomalous wells in which the hydrocarbon feed process was observed with the highest probability based on several criteria. By the using of modern GIS technology we have compared the plots, in which an anomal wells are located, with a block structure of the basement and the sedimentary cover, and with the deconsolidated and fluid's penetrability zones of the crystalline basement. For analysis of tabular data array we used ArcGis software package. Romashkino's map was vectorized by using the EasyTrase and when we assigned a number to each object. When the project was exported to ArcGIS and data obtained the geographic coordinates. We obtained the following attributes for the testing wells: the year of exploitation's beginning, the period of the inversion, the ratio of flow rates before and after inversion, and others. We created a series of maps with location of wells, with a flow rate's inversion by the year (1957-1998) for Minnibayevo area and by the five-year intervals for Minnibayevo area separately and for the Romashkino oil field. The maps of the inversion's density were built by the interpolation from the values of the ratio of oil flow rates before and after the inversion in the wells. These data was selected as a characterizing of the inversion strength. Thereby we created the convenient and informative geodata base through using GIS technology. The comprehensive interpretation of a series of maps, created by ArcGIS software package, is in progress. Firstly an analysis of the location of arrangement of the production wells, in which was occurred inversion of oil production in the process of production activity was made. After this, we compared their location with the block structure scheme. We noticed that the wells are grouped in linear- elongated zone along the fault, there is an affinity of this well to the certain parts of the small-sized blocks. The development of scientific and practical research in this direction is of a high significant because it can lead to a change in the strategy and methodology of the geological prospecting on the one hand and of the exploration of hydrocarbon deposits on the other hand.

  5. Determination of electric field distribution in oil using the Kerr-effect technique after application of DC voltage

    Microsoft Academic Search

    T. Maeno; Y. Nonaka; T. Takada

    1990-01-01

    A technique based on the Kerr electrooptic effect is used for the measurement of electric field strength in dielectric liquids such as transformer oil. An elliptically polarized laser beam is used as incident light and the applied DC voltage is modulated with an AC voltage. Using this technique, low-level electric fields are measured in liquids with small Kerr constants using

  6. Changes in the size distribution of a water-in-oil emulsion due to electric field induced coalescence

    SciTech Connect

    Williams, T.J.; Bailey, A.G.

    1986-05-01

    A knowledge of the droplet size distribution of a water-in-oil emulsion subjected to an electric field provides useful information regarding electrostatic coalescence which can aid the formulation of coalescence models and the design of commercial electrostatic separators. Water droplet-size distribution measurements made using a laser light-scattering technique during the electrostatic resolution of a low-water-content water-in-oil emulsion are reported. A qualitative explanation of the results is presented.

  7. Changes in the Size Distribution of a Water-in-Oil Emulsion Due to Electric Field Induced Coalescence

    Microsoft Academic Search

    Trevor J. Williams; Adrian G. Bailey

    1986-01-01

    A knowledge of the droplet size distribution of a water-in-oil emulsion subjected to an electric field provides useful information regarding electrostatic coalescence which can aid the formulation of coalescence models and the design of commercial electrostatic separators. Water droplet size-distribution measurements made using a laser light-scattering technique during the electrostatic resolution of a low-water-content water-in-oil emulsion are reported. A qualitative

  8. Integrated reservoir characterization of mature oil reservoirs: An example from Oligocene Frio fluvial\\/deltaic sandstones, Rincon Field, south Texas

    Microsoft Academic Search

    L. E. McRae; M. H. Holtz

    1994-01-01

    The Frio fluvial\\/deltaic sandstone along the Vicksburg fault zone play of south Texas has produced nearly 1 billion bbl of oil from fluvial\\/deltaic sandstones since field development began in the 1940s. More than half of the reservoirs in this depositionally complex play have been abandoned, even though large volumes of oil remain. Current efforts integrating geological and engineering reservoir characterization

  9. Principal characteristics and forming conditions for medium-low abundance large scale oil\\/gas fields in China

    Microsoft Academic Search

    Wen-zhi ZHAO; Ze-cheng WANG; Hong-jun WANG; Zhao-yun WANG

    2008-01-01

    In recent years, some of large scale oil or gas fields with medium-low abundance have been discovered in onshore China. They have such characteristics in common as low porosity and permeability, small oil or gas column, low reserves abundance, and large scale. Studies conducted by the authors show that the formations of large-area reservoirs with medium-low abundance have the following

  10. Performance of a hybrid reverse osmosis-constructed wetland treatment system for brackish oil field produced water

    Microsoft Academic Search

    Cynthia Murray-Gulde; John E Heatley; Tanju Karanfil; John H Rodgers; James E Myers

    2003-01-01

    Using constructed wetlands, produced waters from oil fields (i.e., waters that have been in contact with oil in situ) can be treated to enhance water quality for irrigation purposes, or subsequent discharge to receiving aquatic systems. In produced water containing elevated levels of salt (i.e., brackish-produced waters), the ability to decrease the conductivity of the produced water may influence potential

  11. A surface vitrinite reflectance anomaly related to Bell Creek oil field, Montana, U.S.A.

    USGS Publications Warehouse

    Barker, C.E.; Dalziel, M.C.; Pawlewicz, M.J.

    1983-01-01

    Vitrinite reflectance measurements from surface samples of mudrock and coal show anomalously high values over the Bell Creek oil field. The average vitrinite reflectance (Rm) increases to a maximum of 0.9 percent over the field against background values of about 0.3 percent. The Rm anomaly coincides with a geochemical anomaly indicated by diagenetic magnetite in surface rocks and a geobiologic anomaly indicated by ethane-consuming bacteria. These samples were taken from the Upper Cretaceous Hell Creek and Paleocene Fort Union Formations which form an essentially conformable sequence. The depositional environment is similar in both formations, and we expect little variation in the source and composition of the organic matter. The surface R m should be approximately constant because of a uniform thermal history across the field. Temperature studies over local oil fields with similar geology suggest the expected thermal anomaly would be less than 10?C (50?F), which is too small to account for the significantly higher rank over the field. Coal clinkers are rare in the vicinity of Bell Creek and an Rm anomaly caused by burning of the thin, discontinuous coal seams is unlikely. The limited topographic relief, less than 305 m (1,000 ft), over the shallow-dipping homoclinal structure and the poor correlation between Rm and sample locality elevation (r = -0.2) indicate that the Rm anomaly is not due to burial, deformation and subsequent erosion. We conjecture that activity by petroleum-metabolizing bacteria is a possible explanation of the Rm anomaly. Microseepage from oil reservoirs supports large colonies of these organisms, some of which can produce enzymes that can cleave hydrocarbon side-chains on the kerogen molecule. The loss of these side chains causes condensation of the ring structures (Stach and others, 1982) and consequently increases its reflectance. These data indicate that vitrinite reflectance may be a useful tool to explore for stratigraphic traps in the Powder River Basin. Further, the large variation of R across the Bell Creek area suggests that vitrinite reflectance data from surface samples should be interpreted with caution.

  12. Degradation and remediation of soils polluted with oil-field wastewater

    NASA Astrophysics Data System (ADS)

    Gabbasova, I. M.; Suleymanov, R. R.; Garipov, T. T.

    2013-02-01

    The changes in the properties of gray forest soils and leached chernozems under the impact of contamination with highly saline oil-field wastewater were studied in a model experiment. It was shown that the soil contamination results in the development of technogenic salinization and alkalization leading to worsening of the major soil properties. The salinization of the soils with oil-field wastewater transformed the soil exchange complex: the cation exchange capacity decreased, and the exchangeable sodium percentage increased to up to 25% of the CEC upon the wastewater infiltration and up to 60% of the CEC upon the continuous soil saturation with the wastewater independently of the soil type. The content of exchangeable magnesium also increased due to the phenomenon of super-equivalent exchange. Despite the saturation of the soil adsorption complex with sodium, no development of the soil alkalization took place in the presence of the high concentration of soluble salts. However, the soil alkalization was observed upon the soil washing from soluble salts. The gypsum application to the washed soils lowered the exchangeable sodium concentration to acceptable values and normalized the soil reaction. The gypsum application without the preliminary washing of the soils from soluble salts was of low efficiency; even after six months, the content of exchangeable sodium remained very high. The subsequent soil washing resulted in the removal of the soluble salts but did not affect the degree of the soil alkalization.

  13. Oil reserves at Tengiz field reported as 2. 5 billion tons

    SciTech Connect

    Sagers, M.J.

    1987-11-01

    The unusual announcement (reserve figures are normally considered a state secret) occurred during a press conference in Moscow announcing the petrochemical joint venture with Occidental Petroleum and three other Western companies (Montedison and Enichem of Italy and Marubeni of Japan). If the estimates are accurate (it is unknown if the figure refers to total or recoverable reserves), this makes Tengiz not only one of the largest petroleum deposits in the USSR, but in the world. Whether this potential can be developed is still unclear. The Tengiz field was discovered in late 1979 and has been characterized by Soviet experts as one of the most complex and difficult to produce in the entire USSR. The reservoir rocks are of relatively poor quality, and being fissured limestones pose unusual drilling problems. The oil is also quite deep, at 4500-5500 meters. Other development problems arise in the anomalously great reservoir pressure and the high hydrogen sulfide and gas condensate content of the associated gas, which requires the construction of a gas processing facility, to be built nearby at Karaton. The harsh physical environment and the lack of infrastructure (the field is located in salt flats on the edge of the Caspian Sea) also hinder development. The Tengizneftegaz production association was officially established in 1985, but has yet to process any gas or produce any oil.

  14. Magnetic forward models of Cement oil field, Oklahoma, based on rock magnetic, geochemical, and petrologic constraints

    USGS Publications Warehouse

    Reynolds, R.L.; Webring, M.; Grauch, V.J.S.; Tuttle, M.

    1990-01-01

    Magnetic forward models of the Cement oil field, Oklahoma, were generated to assess the possibility that ferrimagnetic pyrrhotite related to hydrocarbon seepage in the upper 1 km of Permian strata contributes to aeromagnetic anomalies at Cement. Six bodies having different magnetizations were constructed for the magnetic models. Total magnetizations of the bodies of highest pyrrhotite content range from about 3 ?? 10-3 to 56 ?? 10-3 A/m in the present field direction and yield magnetic anomalies (at 120 m altitude) having amplitudes of less than 1 nT to ~6 to 7 nT, respectively. Numerous assumptions were made in the generation of the models, but nevertheless, the results suggest that pyrrhotite, formed via hydrocarbon reactions and within a range of concentrations estimated at Cement, is capable of causing magnetic anomalies. -from Authors

  15. Analysis of gravity anomaly over coral-reef oil field: Wilfred Pool, Sullivan County, Indiana

    SciTech Connect

    Dana, S.W.

    1980-03-01

    To compare the measured and theoretical gravity anomaly of a typical coral-reef oil field, data were collected from the wilfred Pool, Sullivan County, Indiana. Densities of available core samples from the field were determined and the anomaly was calculated, taking into account the lateral and vertical variation of density and the geologic structure known from core studies and drilling-log records of lithologic types penetrated by the wells. Comparison of the theoretical and actual anomalies indicated a rough correspondence except for several sharp negative anomalies on the flanks of the measured gravity anomaly. Further studies indicated that the negative anomalies are possibly due to fluvial erosion that produced, on the surface of the youngest Pennsylvanian sediments, channels which were later filled with glacial till of lower density than the sediments. 13 figures.

  16. 3-D reservoir characterization of the House Creek oil field, Powder River Basin, Wyoming

    USGS Publications Warehouse

    Higley, Debra K.; Pantea, Michael P.; Slatt, Roger M.

    1997-01-01

    This CD-ROM is intended to serve a broad audience. An important purpose is to explain geologic and geochemical factors that control petroleum production from the House Creek Field. This information may serve as an analog for other marine-ridge sandstone reservoirs. The 3-D slide and movie images are tied to explanations and 2-D geologic and geochemical images to visualize geologic structures in three dimensions, explain the geologic significance of porosity/permeability distribution across the sandstone bodies, and tie this to petroleum production characteristics in the oil field. Movies, text, images including scanning electron photomicrographs (SEM), thin-section photomicrographs, and data files can be copied from the CD-ROM for use in external mapping, statistical, and other applications.

  17. Additional Reserve Recovery Using New Polymer Treatment on High Water Oil Ratio Wells in Alameda Field, Kingman County, Kansas

    SciTech Connect

    James Spillane

    2005-10-01

    The Chemical Flooding process, like a polymer treatment, as a tertiary (enhanced) oil recovery process can be a very good solution based on the condition of this field and its low cost compared to the drilling of new wells. It is an improved water flooding method in which high molecular-weight (macro-size molecules) and water-soluble polymers are added to the injection water to improve the mobility ratio by enhancing the viscosity of the water and by reducing permeability in invaded zones during the process. In other words, it can improve the sweep efficiency by reducing the water mobility. This polymer treatment can be performed on the same active oil producer well rather than on an injector well in the existence of strong water drive in the formation. Some parameters must be considered before any polymer job is performed such as: formation temperature, permeability, oil gravity and viscosity, location and formation thickness of the well, amount of remaining recoverable oil, fluid levels, well productivity, water oil ratio (WOR) and existence of water drive. This improved oil recovery technique has been used widely and has significant potential to extend reservoir life by increasing the oil production and decreasing the water cut. This new technology has the greatest potential in reservoirs that are moderately heterogeneous, contain moderately viscous oils, and have adverse water-oil mobility ratios. For example, many wells in Kansas's Arbuckle formation had similar treatments and we have seen very effective results. In addition, there were previous polymer treatments conducted by Texaco in Alameda Field on a number of wells throughout the Viola-Simpson formation in the early 70's. Most of the treatments proved to be very successful.

  18. Did CO2 injection induce 2006-2011 earthquakes in the Cogdell oil field, Texas?

    NASA Astrophysics Data System (ADS)

    GAN, W.; Frohlich, C.

    2013-12-01

    Induced seismicity related to underground injection of liquids has been widely reported. However, earthquakes triggered by gas injection, particularly having magnitudes M3 and larger, haven't been observed. Davis and Pennington (1) concluded that earthquakes occurring 1974-1982 in the Cogdell oil field north of Snyder, TX were induced by water flooding for secondary recovery that took place between 1956 and 1982. Subsequently the National Earthquake Information Center (NEIC) reported no further seismicity between 1983 and 2005, but between 2006 and 2011 reported 18 earthquakes having magnitudes 3 and greater. In the present study we analyzed data recorded by six temporary seismograph stations deployed by the USArray program. We identified and carefully relocated 93 well-recorded earthquakes occurring between March 2009 and December 2010. Relocated epicenters occur within several NE-SW-trending linear clusters, with trends corresponding to nodal planes of regional focal mechanisms, possibly indicating the presence of previously unidentified subsurface faults. Moreover, both the rate and b value for the 2009-2011 activity differs from the values for earlier activity, possibly suggesting a different physical origin. We have evaluated data concerning injection and extraction of oil, water, and gas in the Cogdell field. Fluid injection doesn't explain the 2006-2011 earthquakes, especially as net volumes (injection minus extraction) are significantly less than in the 1957-1982 period, and don't appear to have undergone significant recent changes. However, since 2004 significant volumes of CO2 have been injected into the Cogdell fields. The timing of gas injection suggests it may have triggered the recent seismic activity. If so, this is the first reported instance where gas injection has triggered earthquakes having magnitudes M3 and larger. Further analysis may help to evaluate recent concerns about possible risks associated with large-scale carbon capture and storage as a strategy for managing climate change. 1. Davis SD, Pennington WD (1989) Induced seismic deformation in the Cogdell oil field of west Texas. Bull Seismol Soc Amer 79:1477-1495.

  19. Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 34, quarter ending March 31, 1983

    SciTech Connect

    Linville, B. (ed.) [ed.

    1983-07-01

    Progress achieved for the quarter ending March 1983 are presented for field projects and supporting research for the following: chemical flooding; carbon dioxide injection; and thermal/heavy oil. In addition, progress reports are presented for: resource assessment technology; extraction technology; environmental and safety; microbial enhanced oil recovery; oil recovered by gravity mining; improved drilling technology; and general supporting research. (ATT)

  20. Water alternating enriched gas injection to enhance oil production and recovery from San Francisco Field, Colombia

    E-print Network

    Rueda Silva, Carlos Fernando

    2003-01-01

    ) using Kulin oil (21 'API oil Irom Indonesia). ' The same effect of production acceleration was observed in these experiments and steam injectivity was improved with the addition of propane to the steam. Rivero and Mamora (2002) conducted several steam... studies of steam-propane and enriched gas injection for the Minas light crude oil. ' With steam-propane injection no improvement on production and oil recovery was obtained. Enriched gas injection increase the oil recovery in 13'/o, (74'/o OOIP with 5...

  1. CO2 Storage and Enhanced Oil Recovery: Bald Unit Test Site, Mumford Hills Oil Field, Posey County, Indiana

    SciTech Connect

    Frailey, Scott M.; Krapac, Ivan G.; Damico, James R.; Okwen, Roland T.; McKaskle, Ray W.

    2012-03-30

    The Midwest Geological Sequestration Consortium (MGSC) carried out a small-scale carbon dioxide (CO2) injection test in a sandstone within the Clore Formation (Mississippian System, Chesterian Series) in order to gauge the large-scale CO2 storage that might be realized from enhanced oil recovery (EOR) of mature Illinois Basin oil fields via miscible liquid CO2 flooding. As part of the MGSC�������¢����������������s Validation Phase (Phase II) studies, the small injection pilot test was conducted at the Bald Unit site within the Mumford Hills Field in Posey County, southwestern Indiana, which was chosen for the project on the basis of site infrastructure and reservoir conditions. Geologic data on the target formation were extensive. Core analyses, porosity and permeability data, and geophysical logs from 40 wells were used to construct cross sections and structure contour and isopach maps in order to characterize and define the reservoir architecture of the target formation. A geocellular model of the reservoir was constructed to improve understanding of CO2 behavior in the subsurface. At the time of site selection, the Field was under secondary recovery through edge-water injection, but the wells selected for the pilot in the Bald Unit had been temporarily shut-in for several years. The most recently shut-in production well, which was surrounded by four nearby shut-in production wells in a five-spot pattern, was converted to CO2 injection for this pilot. Two additional wells outside the immediate five-spot pattern, one of which was an active producer, were instrumented to measure surface temperature and pressure. The CO2 injection period lasted from September 3, 2009, through December 14, 2010, with one three-month interruption caused by cessation of CO2 deliveries due to winter weather. Water was injected into the CO2 injection well during this period. A total of 6,300 tonnes (6,950 tons) of CO2 were injected into the reservoir at rates that generally ranged from 18 to 32 tonnes (20 to 35 tons) per day. The CO2 injection bottomhole pressure generally remained at 8.3 to 9.0 MPag (1,200 to 1,300 psig). The CO2 injection was followed by continued monitoring for nine months during post-CO2 water injection. A monitoring, verification, and accounting (MVA) program was designed to determine the fate of injected CO2. Extensive periodic sampling and analysis of brine, groundwater, and produced gases began before CO2 injection and continued through the monitored waterflood periods. Samples were gathered from production wells and three newly installed groundwater monitoring wells. Samples underwent geochemical and isotopic analyses to reveal any CO2-related changes. Groundwater and kinetic modeling and mineralogical analysis were also employed to better understand the long-term dynamics of CO2 in the reservoir. No CO2 leakage into groundwater was detected, and analysis of brine and gas chemistry made it possible to track the path of plume migration and infer geochemical reactions and trapping of CO2. Cased-hole logging did not detect any CO2 in the near-wellbore region. An increase in CO2 concentration was first detected in February 2010 from the gas present in the carboy during brine sampling; however, there was no appreciable gas volume associated with the detection of CO2. The first indication of elevated gas rates from the commingled gas of the pilot�������¢����������������s production wells occurred in July 2010 and reached a maximum of 0.36 tonnes/day (0.41 tons/day) in September 2010. An estimated 27 tonnes (30 tons) of CO2 were produced at the surface from the gas separator at the tank battery from September 3, 2009, through September 11, 2011, representing 0.5% of the injected CO2. Consequently, 99.5%

  2. Geologic control of natural marine hydrocarbon seep emissions, Coal Oil Point seep field, California

    NASA Astrophysics Data System (ADS)

    Leifer, Ira; Kamerling, Marc J.; Luyendyk, Bruce P.; Wilson, Douglas S.

    2010-06-01

    High-resolution sonar surveys, and a detailed subsurface model constructed from 3D seismic and well data allowed investigation of the relationship between the subsurface geology and gas-phase (methane) seepage for the Coal Oil Point (COP) seep field, one of the world's largest and best-studied marine oil and gas seep fields, located over a producing hydrocarbon reservoir near Santa Barbara, California. In general, the relationship between terrestrial gas seepage, migration pathways, and hydrocarbon reservoirs has been difficult to assess, in part because the detection and mapping of gas seepage is problematic. For marine seepage, sonar surveys are an effective tool for mapping seep gas bubbles, and thus spatial distributions. Seepage in the COP seep field occurs in an east-west-trending zone about 3-4 km offshore, and in another zone about 1-2 km from shore. The farthest offshore seeps are mostly located near the crest of a major fold, and also along the trend of major faults. Significantly, because faults observed to cut the fold do not account for all the observed seepage, seepage must occur through fracture and joint systems that are difficult to detect, including intersecting faults and fault damage zones. Inshore seeps are concentrated within the hanging wall of a major reverse fault. The subsurface model lacks the resolution to identify specific structural sources in that area. Although to first order the spatial distribution of seeps generally is related to the major structures, other factors must also control their distribution. The region is known to be critically stressed, which would enhance hydraulic conductivity of favorably oriented faults, joints, and bedding planes. We propose that this process explains much of the remaining spatial distribution.

  3. Essential oil analysis and field evaluation of the citrosa plant "Pelargonium citrosum" as a repellent against populations of Aedes mosquitoes.

    PubMed

    Matsuda, B M; Surgeoner, G A; Heal, J D; Tucker, A O; Maciarello, M J

    1996-03-01

    A plant recently introduced into North America as the citrosa, Pelargonium citrosum ('Van Leenii'), has been marketed as a biological repellent against mosquitoes. Citrosa is claimed to repel mosquitoes within a 10 ft.2 (0.93 m2) area due to a continuous fragrant release of citronella oil. The total essential oil yield was 0.2 +/- 0.1% from fresh plant material. Chemical analysis by the authors revealed that combined essential oils of fresh greenhouse- and field-grown citrosa have 35.4 +/- 6.2% geraniol, 10.4 +/- 1.6% citronellol, 8.9 +/- 2.0% isomenthone, and 6.8 +/- 3.8% linalool. Both the morphology and essential oil of citrosa fall within the Pelargonium x asperum hybrid complex and are similar to 'Rosé', the commercial rose geranium. No character of morphology or essential oil of a Cymbopogon species yielding commercial citronella oil could be detected in the citrosa. The effectiveness of the citrosa as a repellent against field populations of spring Aedes spp. mosquitoes was evaluated and compared with a 75% deet (N,N-diethyl-3-methylbenzamide) formulation. Deet provided > 90% reduction in mosquitoes biting subjects for up to 8 h post-treatment. There was no significant difference between citrosa-treated and nontreated subjects. PMID:8723261

  4. Strontium isotope detection of brine contamination in the East Poplar oil field, Montana

    USGS Publications Warehouse

    Peterman, Zell E.; Thamke, Joanna N.; Futa, Kiyoto; Oliver, Thomas A.

    2010-01-01

    Brine contamination of groundwater in the East Poplar oil field was first documented in the mid-1980s by the U.S. Geological Survey by using hydrochemistry, with an emphasis on chloride (Cl) and total dissolved solids concentrations. Supply wells for the City of Poplar are located downgradient from the oil field, are completed in the same shallow aquifers that are documented as contaminated, and therefore are potentially at risk of being contaminated. In cooperation with the Office of Environmental Protection of the Fort Peck Tribes, groundwater samples were collected in 2009 and 2010 from supply wells, monitor wells, and the Poplar River for analyses of major and trace elements, including strontium (Sr) concentrations and isotopic compositions. The ratio of strontium-87 to strontium-86 (87Sr/86Sr) is used extensively as a natural tracer in groundwater to detect mixing among waters from different sources and to study the effects of water/rock interaction. On a plot of the reciprocal strontium concentration against the 87Sr/86Sr ratio, mixtures of two end members will produce a linear array. Using this plotting method, data for samples from most of the wells, including the City of Poplar wells, define an array with reciprocal strontium values ranging from 0.08 to 4.15 and 87Sr/86Sr ratios ranging from 0.70811 to 0.70828. This array is composed of a brine end member with an average 87Sr/86Sr of 0.70822, strontium concentrations in excess of 12.5 milligrams per liter (mg/L), and chloride concentrations exceeding 8,000 mg/L mixing with uncontaminated water similar to that in USGS06-08 with 18.0 mg/L chloride, 0.24 mg/L strontium, and a 87Sr/86Sr ratio of 0.70811. The position of samples from the City of Poplar public-water supply wells within this array indicates that brine contamination has reached all three wells. Outliers from this array are EPU-4G (groundwater from the Cretaceous Judith River Formation), brine samples from disposal wells (Huber 5-D and EPU 1-D), USGS92-11 (a well with water that was considerably contaminated in 1992 and becoming less saline with time), and PNR-27 (only slightly below the defined trend with an 87Sr/86Sr ratio of 0.70793). Water samples from the City of Poplar wells are also enriched in anions and cations that are abundant in oil-field brine.

  5. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2000-12-06

    Through December 1999, project work has been completed on the following activities: data preparation; basic reservoir engineering; developing a deterministic three dimensional (3-D) geologic model, a 3-D deterministic reservoir simulation model and a rock-log model; well drilling and completions; and surface facilities on the Fault Block II-A Tar (Tar II-A) Zone. Work is continuing on improving core analysis techniques, final reservoir tracer work, operational work and research studies to prevent thermal-related formation compaction in the Tar II-A steamflood area, and operational work on the Tar V steamflood pilot and Tar II-A post steamflood project. Work was discontinued on the stochastic geologic model and developing a 3-D stochastic thermal reservoir simulation model of the Tar II-A Zone in order to focus the remaining time on using the 3-D deterministic reservoir simulation model to provide alternatives for the Tar II-A post steamflood operations and shale compaction studies. Thermal-related formation compaction is a concern of the project team due to observed surface subsidence in the local area above the Tar II-A steamflood project. On January 12, 1999, the steamflood project lost its inexpensive steam source from the Harbor Cogeneration Plant as a result of the recent deregulation of electrical power rates in California. An operational plan was developed and implemented to mitigate the effects of the two situations by injecting cold water into the flanks of the steamflood. The purpose of flank injection has been to increase and subsequently maintain reservoir pressures at a level that would fill-up the steam chests in the ''T'' and ''D'' sands before they can collapse and cause formation compaction and to prevent the steam chests from reoccurring. A new 3-D deterministic thermal reservoir simulation model was used to provide operations with the necessary water injection rates and allowable production rates by well to minimize future surface subsidence and to accurately project reservoir steam chest fill-up by October 1999. A geomechanics study and a separate reservoir simulation study have been performed to determine the possible indicators of formation compaction, the temperatures at which specific indicators are affected and the projected temperature profiles in the over and underburden shales over a ten year period following steam injection. It was believed that once steam chest fill-up occurred, the reservoir would act more like a waterflood and production and cold water injection could be operated at lower Injection to production ratios (I/P) and net injection rates. In mid-September 1999, net water injection was reduced substantially in the ''D'' sands following steam chest fill-up. This caused reservoir pressures to plummet about 100 psi within six weeks. Starting in late-October 1999, net ''D'' sand injection was increased and reservoir pressures have slowly increased back to steam chest fill-up pressures as of the end of March 2000. When the ''T'' sands reached fill-up, net ''T'' sand injection was lowered only slightly and reservoir pressures stabilized. A more detailed discussion of the operational changes is in the Reservoir Management section of this report. A reservoir pressure monitoring program was developed as part of the poststeamflood reservoir management plan. This bi-monthly sonic fluid level program measures the static fluid levels in all idle wells an average of once a month. The fluid levels have been calibrated for liquid and gas density gradients by comparing a number of them with Amerada bomb pressures taken within a few days. This data allows engineering to respond quickly to rises or declines in reservoir pressure by either increasing injection or production or idling production. Expanding thermal recovery operations to other sections of the Wilmington Oil Field, including the Tar V horizontal well pilot steamflood project, is a critical part of the City of Long Beach and Tidelands Oil Production Company's development strategy for the field. The current thermal operations in the Wilm

  6. RESERVOIR CHARACTERIZATION OF UPPER DEVONIAN GORDON SANDSTONE, JACKSONBURG STRINGTOWN OIL FIELD, NORTHWESTERN WEST VIRGINIA

    SciTech Connect

    S. Ameri; K. Aminian; K.L. Avary; H.I. Bilgesu; M.E. Hohn; R.R. McDowell; D.L. Matchen

    2001-07-01

    The Jacksonburg-Stringtown oil field contained an estimated 88,500,000 barrels of oil in place, of which approximately 20,000,000 barrels were produced during primary recovery operations. A gas injection project, initiated in 1934, and a pilot waterflood, begun in 1981, yielded additional production from limited portions of the field. The pilot was successful enough to warrant development of a full-scale waterflood in 1990, involving approximately 8,900 acres in three units, with a target of 1,500 barrels of oil per acre recovery. Historical patterns of drilling and development within the field suggests that the Gordon reservoir is heterogeneous, and that detailed reservoir characterization is necessary for understanding well performance and addressing problems observed by the operators. The purpose of this work is to establish relationships among permeability, geophysical and other data by integrating geologic, geophysical and engineering data into an interdisciplinary quantification of reservoir heterogeneity as it relates to production. Conventional stratigraphic correlation and core description shows that the Gordon sandstone is composed of three parasequences, formed along the Late Devonian shoreline of the Appalachian Basin. The parasequences comprise five lithofacies, of which one includes reservoir sandstones. Pay sandstones were found to have permeabilities in core ranging from 10 to 200 mD, whereas non-pay sandstones have permeabilities ranging from below the level of instrumental detection to 5 mD; Conglomeratic zones could take on the permeability characteristics of enclosing materials, or could exhibit extremely low values in pay sandstone and high values in non-pay or low permeability pay sandstone. Four electrofacies based on a linear combination of density and scaled gamma ray best matched correlations made independently based on visual comparison of geophysical logs. Electrofacies 4 with relatively high permeability (mean value > 45 mD) was determined to be equivalent to the pay sandstone within the Gordon reservoir. Three-dimensional models of the electrofacies in the pilot waterflood showed that electrofacies 4 is present throughout this area, and the other electrofacies are more disconnected. A three-layer, back-propagation artificial neural network with three slabs in the middle layer can be used to predict permeability and porosity from gamma ray and bulk density logs, the first and the second derivatives of the log data with respect to depth, well location, and log baselines. Two flow units were defined based on the stratigraphic model and geophysical logs. A three-dimensional reservoir model including the flow units, values of permeability calculated through the artificial neural network and injection pressure-rate information were then used as inputs for a reservoir simulator to predict oil production performance for the center producers in the pilot area. This description of the reservoir provided significantly better simulation results than earlier results obtained using simple reservoir models. Bulk density and gamma ray logs were used to identify flow units throughout the field. As predicted by the stratigraphic analysis, one of the flow units crosses stratigraphic units in the reservoir. A neural network was used to predict permeability values for each flow unit in producer and injection wells. The reservoir simulator was utilized to predict the performance of two flood patterns located to the north of the pilot area. Considering the simple model utilized for simulation, the results are in very good agreement with the field history.

  7. Increased Oil Production and Reserves from Improved Completion Techniques in the Bluebell Field, Uinta Basin, Utah

    SciTech Connect

    Deo, M.D.; Morgan, C.D.

    1999-04-28

    The objective of the project is to increase oil production and reserves by the use of improved reservoir characterization and completion techniques in the Uinta Basin, Utah. To accomplish this objective, a two-year geologic and engineering characterization of the Bluebell field was conducted. The study evaluated surface and subsurface data, currently used completion techniques, and common production problems. It was determined that advanced case- and open-hole logs could be effective in determining productive beds and that stage-interval (about 500 ft [150 m] per stage) and bed-scale isolation completion techniques could result in improved well performance. In the first demonstration well (Michelle Ute well discussed in the previous technical report), dipole shear anisotropy (anisotropy) and dual-burst thermal decay time (TDT) logs were run before and isotope tracer log was run after the treatment. The logs were very helpful in characterizing the remaining hydrocarbon potential in the well. But, mechanical failure resulted in a poor recompletion and did not result in a significant improvement in the oil production from the well.

  8. Temporal Changes in Microbial Metabolic Characteristics in Field-Scale Biopiles Composed of Aged Oil Sludge.

    PubMed

    Wang, Xiang; Li, Fasheng; Guo, Guanlin; Wang, Shijie; Boronin, Alexander; Wang, Qunhui

    2014-09-01

    Disposal of oil sludge, a hazardous waste, is currently a prevalent environmental issue. In this study, two field-scale biopiles were constructed to explore the temporal changes of microbial metabolic characteristics during the biotreatment of aged oil sludge. Bulking agent was mixed thoroughly with oily sludge to form a treated pile. The BIOLOG™ system was used to analyze the community level physiological parameters, including microbial metabolic activity, diversity, and variance. In comparison with the control, the community level physiological parameters of the treated pile were dramatically improved. Microbial metabolic activity of the treated pile was improved by 25.06% calculated from the maximums during the treatment. Microbial diversity index (Shannon index) ranges were improved from 1.64-3.02 (control pile) to 2.34-3.14 (treated pile). The numbers of petroleum-degrading bacteria and the total heterotrophic bacteria were correlated with the environmental temperature, and microbial metabolic characteristics in the treated pile revealed the distinctive carbon resources selection with the addition of cotton stalk. Temporal microbial metabolic characteristics, which have important effect on bioremediation, were revealed in this study. PMID:25228785

  9. Polycrystalline-diamond drill bits for Venezuelan oil-field application

    SciTech Connect

    Heckes, A.A.; Meano, W.; Baker, L.E.

    1983-04-01

    A cooperative USA/Venezuelan R and D drilling program has been performed which was directed toward the development of a hard-rock-drilling capability for the oil industry using diffusion-bonded polycrystalline-diamond compact (PDC) bits. The drilling program was implemented according to Annex V-A Drilling, of the Joint Agreement between the Department of Energy (DOE) of the United States and the Ministry of Energy and Mines (MEM) of the Republic of Venezuela. This report was originally prepared in two sections, one on bit design and fabrication and the other on the field test, to be a portion of a larger Venezuela-MEM/USA-DOE Fossil-Energy Report on Supporting Technology for Enhanced Oil Recovery. As such, it fulfills one of the requirements of the joint agreement. Three diffusion-bonded PDC drill bits of PCI/Sandia design were successfully used by MARAVEN/INTEVEP to drill the deep (13,152 to 14,579 ft) cretaceous carbonate formations located under Lake Maracaibo, Venezuela. The bits gave penetration rates of 4.7, 13.2, and 13.5 feet per hour. This compares with penetration rates for conventional natural-diamond bits, drilling the same formation in nearby offset wells, of 2.0 to 6.77 feet per hour. If PDC bits are used to drill future wells, an average cost savings of about $90,000 per well is projected. 17 figures, 9 tables.

  10. Modeling surface deformation due to CO2 injection at an enhanced oil recovery field in Texas

    NASA Astrophysics Data System (ADS)

    Yang, Q.; Abdollahzadeh, M.; Dixon, T. H.; Malservisi, R.; Hosseini, S.

    2013-12-01

    The Geodesy Laboratory at the University of South Florida has operated 3 C-GPS stations at an enhanced oil recovery field in Texas since October 2011. Our GPS sites recorded vertical uplift during the injection phase when the reservoir was initially pressurized, and localized subsidence in phase with reservoir pressure after oil extraction started. In this study, we use analytical and numerical models to better understand the small-scale surface deformation observed by GPS due to CO2 injection. First, we use an analytical model of a pressurized horizontal circular crack in an elastic half-space to fit the surface deformation data. Then, constrained by the analytical modeling results, we develop a poroelastic Finite Element Model (FEM) to investigate the influence of reservoir geometry and overlying stratigraphy on surface displacement. A sensitivity study is carried out to understand the effects of realistic geometry and material properties on surface deformation. Our preliminary results show that a poroelastic FEM can explain the location-dependant time delay between the injection and surface response.

  11. An efficient thermotolerant and halophilic biosurfactant-producing bacterium isolated from Dagang oil field for MEOR application

    NASA Astrophysics Data System (ADS)

    Wu, Langping; Richnow, Hans; Yao, Jun; Jain, Anil

    2014-05-01

    Dagang Oil field (Petro China Company Limited) is one of the most productive oil fields in China. In this study, 34 biosurfactant-producing strains were isolated and cultured from petroleum reservoir of Dagang oil field, using haemolytic assay and the qualitative oil-displacement test. On the basis of 16S rDNA analysis, the isolates were closely related to the species in genus Pseudomonas, Staphylococcus and Bacillus. One of the isolates identified as Bacillus subtilis BS2 were selected for further study. This bacterium was able to produce a type of biosurfactant with excessive foam-forming properties at 37ºC as well as at higher temperature of 55ºC. The biosurfactant produced by the strain BS2 could reduce the surface tension of the culture broth from 70.87 mN/m to 28.97 mN/m after 8 days of incubation at 37ºC and to 36.15 mN/m after 20 days of incubation at 55ºC, respectively. The biosurfactant showed stability at high temperature (up to 120ºC), a wide range of pH (2 to 12) and salt concentrations (up to 12%) offering potential for biotechnology. Fourier transform infrared (FT-IR) spectrum of extracted biosurfactant tentatively characterized the produced biosurfactant as glycolipid derivative. Elemental analysis of the biosurfactant by energy dispersive X-ray spectroscopy (EDS) reveals that the biosurfactant was anionic in nature. 15 days of biodegradation of crude oil suggested a preferential usage of n-alkane upon microbial metabolism of BS2 as a carbon substrate and consequently also for the synthesis of biosurfactants. Core flood studies for oil release indicated 9.6% of additional oil recovery over water flooding at 37ºC and 7.2% of additional oil recovery at 55 ºC. Strain BS2 was characterized as an efficient biosurfactant-producing, thermotolerant and halophillic bacterium and has the potential for application for microbial enhanced oil recovery (MEOR) through water flooding in China's oil fields even in situ as adapted to reservoir chemistry and temperature.

  12. Quantitative reverse sample genome probing of microbial communities and its application to oil field production waters

    SciTech Connect

    Voordouw, G.; Shen, Y.; Harrington, C.S.; Teland, A.J. (Univ. of Calgary, Alberta (Canada)); Jack, T.R. (Novacor Research and Technology Corporation, Calgary, Alberta (Canada)); Westlake, W.S. (Univ. of Alberta (Canada))

    1993-12-01

    This paper presents a protocol for quantitative analysis of microbial communities by reverse sample genome probing is presented in which (i) whole community DNA is isolated and labeled in the presence of a known amount of an added internal standard and (ii) the resulting spiked reverse genome probe is hybridized with a master filter on which denatured genomic DNAs from bacterial standards isolated from the target environment were spotted in large amounts (up to 1,500 ng) in order to improve detection sensitivity. This protocol allowed reproducible fingerprinting of the microbial community in oil field production waters at 19 sites from which water and biofilm samples were collected. It appeared that selected sulfate-reducing bacteria were significantly enhanced in biofilms covering the metal surfaces in contact with the production waters.

  13. A new generation of electromagnetic and ultrasonic techniques for subsurface evaluation of oil field tubulars

    SciTech Connect

    Lewis, R.G.

    1988-01-01

    In the past few years, corrosion and mechanical fatigue have been becoming a more visible issue in the oil and gas industry. The issue of lost profits from lost production and the cost and liability resulting from failure has overcome the obvious concern of simple mechanical integrity. A new generation of tool designs have been developed for in-situ evaluation of well casings. These designs along with improvements to existing designs have just recently been introduced to address some of the limitations in subsurface well casing evaluation. These new hardware developments and interpretation techniques can now provide unpredecented accuracy for evaluating downhole tubular conditions. This paper reviews four recent designs while discussing the principals of measurement and offering actual field data in several comparisons. The four designs include: Electromagnetic: AC Types, DC Types, Casing Potential Profiling; Ultrasonic: Ultrasonic Thickness Types. An interpretation technique using sequential measurements to predict and manage for corrosion problems is also presented.

  14. Biogeochemical evidence for subsurface hydrocarbon occurrence, Recluse oil field, Wyoming; preliminary results

    USGS Publications Warehouse

    Dalziel, Mary C.; Donovan, Terrence J.

    1980-01-01

    Anomalously high manganese-to-iron ratios occurring in pine needles and sage leaves over the Recluse oil field, Wyoming, suggest effects of petroleum microseepage on the plants. This conclusion is supported by iron and manganese concentrations in soils and carbon and oxygen isotope ratios in rock samples. Seeping hydrocarbons provided reducing conditions sufficient to enable divalent iron and manganese to be organically complexed or adsorbed on solids in the soils. These bound or adsorped elements in the divalent state are essential to plants, and the plants readily assimilate them. The magnitude of the plant anomalies, combined with the supportive isotopic and chemical evidence confirming petroleum leakage, makes a strong case for the use of plants as a biogeochemical prospecting tool.

  15. Wavelet transform analysis for lithological characteristics identification in siliciclastic oil fields

    NASA Astrophysics Data System (ADS)

    Perez-Muñoz, Teresa; Velasco-Hernandez, Jorge; Hernandez-Martinez, Eliseo

    2013-11-01

    In this work, we propose the application of the wavelet transform analysis in well-logs (radioactivity, resistivity and sonic) to identify facies. The wavelet transform is applied to a set of well-log data for identifying correlations between wavelet coefficients and lithofacies sequences. Our results indicate that the scales, in a multiscale analysis, are related to the rock thickness and depending on the scale used it is possible to identify other particular or general sequences. The results obtained are compared and corroborated by standard geological procedures for lithological characterization, indicating that the wavelet analysis provides qualitative guides for the identification of lithological properties in wells. All our analyses are based on a siliciclastic oil field that belongs to Chicontepec Formation of the Tampico-Misantla basin in Mexico.

  16. Comparison of soft computing techniques for a three-phase oil field centrifuge.

    SciTech Connect

    Smith, R. E. (Ronald E.); Parkinson, w; Miller, N. (Neal)

    2002-01-01

    In this work we compare fuzzy techniques to neural network techniques for building a soft sensor for a three-phase oil field centrifuge. The soft sensor is used in a feed-forward control system that augments a feedback control system. Two approaches were used to develop the soft sensor. The first approach was to use a fuzzy rule based system based upon the experience of an expert operator. The expert operator's experience was supplemented using a computer model of the system. The second approach was to use a neural network to build the inverse of the computer model. The pros and cons of both techniques are discussed. KEYWORDS: fuzzy logic, neural networks, soft sensor, soft computing

  17. The role of active and ancient geothermal systems in evolution of Grant Canyon oil field, Railroad Valley, Nye County, Nevada

    SciTech Connect

    Hulen, J.B. (Univ. of Utah Research Inst., Salt Lake City (United States)); Bereskin, S.R. (Terra Tek, Inc., Salt Lake City, UT (United States)); Bortz, L.C.

    1991-06-01

    Since discovery in 1983, the Grant Canyon field has been among the most prolific oil producers (on a per-well basis) in the US. Production through June 1990 was 12,935,630 bbl of oil, principally from two wells which in tandem have consistently yielded more than 6,000 bbl of oil per day. The field is hosted by highly porous Devonian dolomite breccia loosely cemented with hydrothermal quartz. Results of fluid-inclusion and petrographic research in progress at Grant Canyon suggest that paleogeothermal and perhaps currently circulating geothermal systems may have played a major role in oil-reservoir evolution. For example, as previously reported, the breccia-cementing quartz hosts primary aqueous, aqueous/oil, and oil fluid inclusions which were trapped at about 120C (average homogenization temperature) and document initial oil migration and entrapment as droplets or globules dispersed in dilute (< 2.2 wt.% equivalent NaCl) aqueous solutions. Additional evidence of geothermal connection is that the horst-block trap at Grant Canyon is top and side sealed by valley-fill clastic and volcanic rocks which are locally hydrothermally altered and calcite flooded. These secondary seals are enhanced by disseminated, solid asphaltic residues locally accounting for 23% (volume) of the rock. Current reservoir temperatures at Grant Canyon (120C) and the adjacent Bacon Flat field (171C) attest to vigorous contemporary geothermal activity. Based on results of the authors' Grant Canyon work to date, they suggest that active and paleohydrothermal systems could be viable petroleum exploration targets in otherwise favorable terrain elsewhere in the Basin and Range.

  18. Investigating electrokinetics application for in-situ inorganic oil field scale control

    NASA Astrophysics Data System (ADS)

    Hashaykeh, Manal A. I. Albadawi

    Oil well scale formation and deposition is an expensive problem and could be a nightmare for any production engineer if the rate of deposition is rapid as in the case of North Sea oil fields. Inorganic scales accumulate in surface and subsurface equipment causing a reduction in oil production and severe damage for production equipment. The major components of most oil field scale deposits are BaSO4, CaSO4 and SrSO4, which are formed due to incompatible mixing of reservoir formation water and sea water flooded in secondary enhanced oil recovery (EOR) processes. This work focuses on BaSO4 scale as it is one of the toughest scale components to be removed either by chemical means or mechanical means. Scale control methods usually involve complicated treatment using chemical dissolution methods as primary attempt and mechanical scrapping or jetting methods in case of failure of the chemical means. In this work, we devised a novel in-situ scale control method benefiting from the application of direct current (DC) which involves some of the electrokinetic (EK) phenomena. The applications of EK has been proved in our laboratories yielding high efficiency in capturing barium and separating it from sulfate before reaching the production well, thus preventing deposition in the production wellbore or wellbore formation. This objective was evaluated in our lab designed EK apparatus in three parts. In part-1, an 18.5 cm unconsolidated sand core was used which produced inconsistent results. This problem was overcome in part-2, where the porous media involved 46 cm consolidated sandcore. This also partly fulfilled the purpose of upscaling. In part-3, the porous media was extended to a 100 cm spatial distance between the injection and production wells. For all the experiments the reservoir models were made of 125 µm uniform sand particles and followed a final consolidation pressure of 30 psi. The EK-reservoir model contains 2 basic junctions; one of them injecting a 500 ppm SO4 2- solution, representing sulfate rich sea water and the other injecting a 500 ppm Ba2+ solution representing divalent cations rich in formation water and an outlet for water production. In part-1, there were 4 locations for the electrodes, while in part-2 and part-3 there were 5 electrode locations distributed along the spatial distance. Salinity of injection and formation water was varied within a range of 0 to 40,000 ppm. The flow rates of injection and formation water were constant throughout each experiment. In part-1 experiments, the flow rate was 1 ml/min, in part-2 this was increased to 2 ml/min, finally in part-3 this was further increased to 4.3 ml/min. 2 V/cm voltage gradient was applied for all of the experiments. On a real time basis the current, pressure, temperature, and pH of production water were all monitored. Finally, solid samples with scale deposits within were collected from different locations of the flow tubes. To be analyzed using an ICP-MS. The results have demonstrated up to 90% scale mitigation by the application of EK. In addition, there was pressure reduction in the flow tube, which could be justified due to chlorine gas generation at the locations sides creating a stimulation effect due to increased acidity. The observations from this study concluded that the application of EK will attribute to the production efficiency due to less scaling and reducing corrosion of surface equipment. This will attempt to demonstrate the world's first promising technique that could be used to replace expensive solutions which require well closure and incur production interruption loss. However, it is recommended that further extensive studies need to be done to confirm the results and finally design a pilot scale project to validate the lab work.

  19. The development and field testing of a less hazardous and technically superior oil based drilling fluid

    SciTech Connect

    Kenny, P.; Norman, M.; Friestad, A.M.; Risvik, B.

    1996-12-31

    This paper describes the development and subsequent field results of a new invert emulsion, low toxicity, oil based drilling fluid (LTOBM). The new fluid was developed in response to the anticipated increased usage of LTOBM, and primary considerations in the development were those of working conditions, the environment, technical performance and economics. Developments in invert emulsion drilling fluids have, over recent years, been concentrated in the areas of reducing environmental impact, and improving technical performance. LTOBM have, as a result of this, been largely replaced by synthetic based drilling fluids (SBM), which exhibit similar, or improved technical performance, whilst claiming to have reduced environmental impact. This development focus has resulted in very few changes being made to LTOBM since the replacement of diesel by low toxicity mineral oil. The occupational health hazards involved in using SBM have, however, proven to be similar, or occasionally worse, than with LTOBM. Such health problems can be mainly attributed to two components; the base fluid and lime, the latter being a major contributor to skin irritation problems, and the former to both skin irritation, and inhalation problems. There has been a lack of occupational health studies carried out with respect to the use of SBM compared to LTOBM. This paper describes the laboratory testing conducted, and results obtained during the development, where several base fluids were screened, along with a multitude of fluid additives, prior to obtaining the optimal formulation. The final fluid was designed for use on high temperature high pressure wells and extended reach wells, as well as more {open_quotes}normal wells{close_quotes}. The laboratory data presented is supported by field data from the successful use of the system as a worker friendly, high performance, LTOBM drilling fluid.

  20. LOGAN WASH FIELD TREATABILITY STUDIES OF WASTEWATERS FROM OIL SHALE RETORTING PROCESSES

    EPA Science Inventory

    Treatability studies were conducted on retort water and gas condensate wastewater from modified in-situ oil shale retorts to evaluate the effectiveness of selected treatment technologies for removing organic and inorganic contaminants. At retorts operated by Occidental Oil Shale,...

  1. Saline-water contamination in Quaternary deposits and the Poplar River, East Poplar Oil Field, northeastern Montana

    USGS Publications Warehouse

    Thamke, J.N.; Craigg, S.D.

    1997-01-01

    The extent of saline-water contamination in Quaternary deposits in and near the East Poplar oil field may be as much as 12.4 square miles and appears to be present throughout the entire saturated zone. The saline-water contamination affects 9-60 billion gallons of ground water. Saline- contaminated water moves westward through Quaternary glacial deposits and merges with southward-flowing water in Quaternary alluvium in the Poplar River valley. Saline ground water discharges into the Poplar River, and increases the dissolved-solids and chloride concentrations of the river. The probable source of saline-water contamination in the Quaternary deposits is brine that is a byproduct of the production of crude oil in the East Poplar oil field study area.

  2. Molecular and cultivation-based analyses of microbial communities in oil field water and in microcosms amended with nitrate to control H 2 S production

    Microsoft Academic Search

    Raji Kumaraswamy; Sara Ebert; Murray R. Gray; Phillip M. Fedorak; Julia M. Foght

    2011-01-01

    Nitrate injection into oil fields is an alternative to biocide addition for controlling sulfide production (‘souring’) caused\\u000a by sulfate-reducing bacteria (SRB). This study examined the suitability of several cultivation-dependent and cultivation-independent\\u000a methods to assess potential microbial activities (sulfidogenesis and nitrate reduction) and the impact of nitrate amendment\\u000a on oil field microbiota. Microcosms containing produced waters from two Western Canadian oil

  3. Oil and gas: history of development and principal fields in Colorado

    Microsoft Academic Search

    J. C. Donaldson; L. MacMillan

    1980-01-01

    In 1862, Colorado became the second oil-producing area in the US following the initial discovery of oil. Exploration and development were slow and 60 years passed before Colorado became recognized as a potentially significant oil- and gas-producing state. Today there are 8 principal producing regions in Colorado: the Denver basin (including the Canon City embayment), the North Park basin, the

  4. Time lapse seismic observations and effects of reservoir compressibility at Teal South oil field

    NASA Astrophysics Data System (ADS)

    Islam, Nayyer

    One of the original ocean-bottom time-lapse seismic studies was performed at the Teal South oil field in the Gulf of Mexico during the late 1990's. This work reexamines some aspects of previous work using modern analysis techniques to provide improved quantitative interpretations. Using three-dimensional volume visualization of legacy data and the two phases of post-production time-lapse data, I provide additional insight into the fluid migration pathways and the pressure communication between different reservoirs, separated by faults. This work supports a conclusion from previous studies that production from one reservoir caused regional pressure decline that in turn resulted in liberation of gas from multiple surrounding unproduced reservoirs. I also provide an explanation for unusual time-lapse changes in amplitude-versus-offset (AVO) data related to the compaction of the producing reservoir which, in turn, changed an isotropic medium to an anisotropic medium. In the first part of this work, I examine regional changes in seismic response due to the production of oil and gas from one reservoir. The previous studies primarily used two post-production ocean-bottom surveys (Phase I and Phase II), and not the legacy streamer data, due to the unavailability of legacy prestack data and very different acquisition parameters. In order to incorporate the legacy data in the present study, all three post-stack data sets were cross-equalized and examined using instantaneous amplitude and energy volumes. This approach appears quite effective and helps to suppress changes unrelated to production while emphasizing those large-amplitude changes that are related to production in this noisy (by current standards) suite of data. I examine the multiple data sets first by using the instantaneous amplitude and energy attributes, and then also examine specific apparent time-lapse changes through direct comparisons of seismic traces. In so doing, I identify time-delays that, when corrected for, indicate water encroachment at the base of the producing reservoir. I also identify specific sites of leakage from various unproduced reservoirs, the result of regional pressure blowdown as explained in previous studies; those earlier studies, however, were unable to identify direct evidence of fluid movement. Of particular interest is the identification of one site where oil apparently leaked from one reservoir into a "new" reservoir that did not originally contain oil, but was ideally suited as a trap for fluids leaking from the neighboring spill-point. With continued pressure drop, oil in the new reservoir increased as more oil entered into the reservoir and expanded, liberating gas from solution. Because of the limited volume available for oil and gas in that temporary trap, oil and gas also escaped from it into the surrounding formation. I also note that some of the reservoirs demonstrate time-lapse changes only in the "gas cap" and not in the oil zone, even though gas must be coming out of solution everywhere in the reservoir. This is explained by interplay between pore-fluid modulus reduction by gas saturation decrease and dry-frame modulus increase by frame stiffening. In the second part of this work, I examine various rock-physics models in an attempt to quantitatively account for frame-stiffening that results from reduced pore-fluid pressure in the producing reservoir, searching for a model that would predict the unusual AVO features observed in the time-lapse prestack and stacked data at Teal South. While several rock-physics models are successful at predicting the time-lapse response for initial production, most fail to match the observations for continued production between Phase I and Phase II. Because the reservoir was initially overpressured and unconsolidated, reservoir compaction was likely significant, and is probably accomplished largely by uniaxial strain in the vertical direction; this implies that an anisotropic model may be required. Using Walton's model for anisotropic unconsolidated sand, I successfully mod

  5. Olive oil pilot-production assisted by pulsed electric field: impact on extraction yield, chemical parameters and sensory properties.

    PubMed

    Puértolas, Eduardo; Martínez de Marañón, Iñigo

    2015-01-15

    The impact of the use of pulsed electric field (PEF) technology on Arroniz olive oil production in terms of extraction yield and chemical and sensory quality has been studied at pilot scale in an industrial oil mill. The application of a PEF treatment (2 kV/cm; 11.25 kJ/kg) to the olive paste significantly increased the extraction yield by 13.3%, with respect to a control. Furthermore, olive oil obtained by PEF showed total phenolic content, total phytosterols and total tocopherols significantly higher than control (11.5%, 9.9% and 15.0%, respectively). The use of PEF had no negative effects on general chemical and sensory characteristics of the olive oil, maintaining the highest quality according to EU legal standards (EVOO; extra virgin olive oil). Therefore, PEF could be an appropriate technology to improve olive oil yield and produce EVOO enriched in human-health-related compounds, such as polyphenols, phytosterols and tocopherols. PMID:25149017

  6. Borehole geophysical data for the East Poplar oil field area, Fort Peck Indian Reservation, northeastern Montana, 1993, 2004, and 2005

    USGS Publications Warehouse

    Smith, Bruce D.; Thamke, Joanna N.; Tyrrell, Christa

    2014-01-01

    Areas of high electrical conductivity in shallow aquifers in the East Poplar oil field area were delineated by the U.S. Geological Survey (USGS), in cooperation with the Fort Peck Assiniboine and Sioux Tribes, in order to interpret areas of saline-water contamination. Ground, airborne, and borehole geophysical data were collected in the East Poplar oil field area from 1992 through 2005 as part of this delineation. This report presents borehole geophysical data for thirty-two wells that were collected during, 1993, 2004, and 2005 in the East Poplar oil field study area. Natural-gamma and induction instruments were used to provide information about the lithology and conductivity of the soil, rock, and water matrix adjacent to and within the wells. The well logs were also collected to provide subsurface controls for interpretation of a helicopter electromagnetic survey flown over most of the East Poplar oil field in 2004. The objective of the USGS studies was to improve understanding of aquifer hydrogeology particularly in regard to variations in water quality.

  7. Report on testing of engine and transmission ECU's (electronic control units) integrated into oil field services pumping equipment

    Microsoft Academic Search

    E. Daunis; A. Burmeister

    1986-01-01

    A microprocessor-based control unit has been developed to interface with an engine\\/transmission\\/pump power train system. The purpose is to establish remote control and test component reliability in the oil field environment. The unit controls pump rate, pressure, engine throttle and transmission range in addition to storing vital statistics and performing diagnostics.

  8. Isotopic and chemical data from carbonate cements in surface rocks over and near four Oklahoma oil fields

    USGS Publications Warehouse

    Henry, Mitchell E.; Donovan, Terrence J.

    1978-01-01

    Carbonate cements in outcropping sandstones overlying the Doyle, Fox-Graham, Velma, and part of Wheeler oil fields, Oklahoma, were analyzed for their C13/ 12, 018/016, iron, and manganese compositions. The peculiar areal distribution of the values obtained is interpreted to be the direct result of hydrocarbon microseepage.

  9. Model building for Chang8 low permeability sandstone reservoir in the Yanchang formation of the Xifeng oil field

    Microsoft Academic Search

    Fan SONG; Jia-gen HOU; Ni-na SU

    2009-01-01

    In order to build a model for the Chang-8 low permeability sandstone reservoir in the Yanchang formation of the Xifeng oil field, we studied sedimentation and diagenesis of sandstone and analyzed major factors controlling this low permeability reservoir. By doing so, we have made clear that the spatial distribution of reservoir attribute parameters is controlled by the spatial distribution of

  10. Thermal field and the presence of oil and gas in the Far East. [Thermal flux variations in the earth

    Microsoft Academic Search

    K. M. Sevostyanov; M. A. Vilenskii

    1976-01-01

    Correlations are drawn between the thermal fields of different places at various depths and the presence of gas and oil in these locations in the Far East. Various arguments are cited as to whether the variations of deposits are due to temperature or pressure factors. To take account of both interrelated factors, a futher concept, the geochronothermobar (time in million

  11. Field manual for plunging water jet use in oil spill cleanup. Final report Sep 82Jul 83

    Microsoft Academic Search

    1984-01-01

    The use of plunging water jets can often make possible the control (and, as a consequence, the cleanup) of spilled oil and other floating pollutants in currents too swift for conventional equipment. This short, illustrated manual provides practical information for field and planning personnel on the principles of plunging water jet operation, rapid fabrication of the equipment (from readily available

  12. Occurrence of oil and gas fields and source rock transformation in the west Siberian basin and Barents Sea platform

    Microsoft Academic Search

    1993-01-01

    The West Siberian and Barents Sea basins contain the largest demonstrated reserves of gas in the world (more than 33 trilion m[sup 3]) and very large recoverable reserves of oil (about 19 billion tons). The main productive reservoirs are of the Jurassic and Cretaceous and are composed of marine and alluvial sandstones. Major gas fields of the West Siberian basin

  13. Simulation studies of a horizontal well producing from a thin oil-rim reservoir in the SSB1 field, Malaysia

    E-print Network

    Abdul Hakim, Hazlan

    1995-01-01

    Three-dimensional simulation studies have been carried out to investigate the performance of a horizontal well producing from a thin oil-rim reservoir, X3/X4 in the SSBI field, Malaysia. A heterogeneous model was used which honored the reservoir...

  14. A Novel Process for Natural Gas Liquids Recovery from Oil Field Associated Gas with Liquefied Natural Gas Cryogenic Energy Utilization

    Microsoft Academic Search

    Haijun BIAN; Wendong XU; Xiuxi LI; Yu QIAN

    2011-01-01

    A novel process to recovery natural gas liquids from oil field associated gas with liquefied natural gas (LNG) cryogenic energy utilization is proposed. Compared to the current electric refrigeration process, the proposed process uses the cryogenic energy of LNG and saves 62.6% of electricity. The proposed process recovers ethane, liquid petroleum gas (propane and butane) and heavier hydrocarbons, with total

  15. FIELD STUDIES ON USBM AND TOSCO II RETORTED OIL SHALES: VEGETATION, MOISTURE, SALINITY, AND RUNOFF, 1977-1980

    EPA Science Inventory

    Field studies were initiated in 1973 to investigate the vegetative stabilization of processed oil shales and to follow moisture and soluble salt movement within the soil/shale profile. Research plots with two types of retorted shales (TOSCO II and USBM) with leaching and soil cov...

  16. Draft Genome Sequences of Three Smithella spp. Obtained from a Methanogenic Alkane-Degrading Culture and Oil Field Produced Water

    PubMed Central

    Tan, BoonFei; de Araújo e Silva, Renata; Rozycki, Trent; Nesbø, Camilla

    2014-01-01

    Two draft genomes affiliated with Smithella spp. were obtained from a methanogenic alkane-degrading enrichment culture by single-cell sorting and metagenome contig binning, and a third was obtained by single-cell sorting of oil field produced water. Two genomes contained putative assABC genes encoding alkylsuccinate synthase, indicating genetic potential for fumarate activation of alkanes. PMID:25342693

  17. Class III Mid-Term Project, "Increasing Heavy Oil Reserves in the Wilmington Oil Field Through Advanced Reservoir Characterization and Thermal Production Technologies"

    SciTech Connect

    Scott Hara

    2007-03-31

    The overall objective of this project was to increase heavy oil reserves in slope and basin clastic (SBC) reservoirs through the application of advanced reservoir characterization and thermal production technologies. The project involved improving thermal recovery techniques in the Tar Zone of Fault Blocks II-A and V (Tar II-A and Tar V) of the Wilmington Field in Los Angeles County, near Long Beach, California. A primary objective has been to transfer technology that can be applied in other heavy oil formations of the Wilmington Field and other SBC reservoirs, including those under waterflood. The first budget period addressed several producibility problems in the Tar II-A and Tar V thermal recovery operations that are common in SBC reservoirs. A few of the advanced technologies developed include a three-dimensional (3-D) deterministic geologic model, a 3-D deterministic thermal reservoir simulation model to aid in reservoir management and subsequent post-steamflood development work, and a detailed study on the geochemical interactions between the steam and the formation rocks and fluids. State of the art operational work included drilling and performing a pilot steam injection and production project via four new horizontal wells (2 producers and 2 injectors), implementing a hot water alternating steam (WAS) drive pilot in the existing steamflood area to improve thermal efficiency, installing a 2400-foot insulated, subsurface harbor channel crossing to supply steam to an island location, testing a novel alkaline steam completion technique to control well sanding problems, and starting on an advanced reservoir management system through computer-aided access to production and geologic data to integrate reservoir characterization, engineering, monitoring, and evaluation. The second budget period phase (BP2) continued to implement state-of-the-art operational work to optimize thermal recovery processes, improve well drilling and completion practices, and evaluate the geomechanical characteristics of the producing formations. The objectives were to further improve reservoir characterization of the heterogeneous turbidite sands, test the proficiency of the three-dimensional geologic and thermal reservoir simulation models, identify the high permeability thief zones to reduce water breakthrough and cycling, and analyze the nonuniform distribution of the remaining oil in place. This work resulted in the redevelopment of the Tar II-A and Tar V post-steamflood projects by drilling several new wells and converting idle wells to improve injection sweep efficiency and more effectively drain the remaining oil reserves. Reservoir management work included reducing water cuts, maintaining or increasing oil production, and evaluating and minimizing further thermal-related formation compaction. The BP2 project utilized all the tools and knowledge gained throughout the DOE project to maximize recovery of the oil in place.

  18. Competitive Oxidation of Volatile Fatty Acids by Sulfate and Nitrate-Reducing Bacteria from an Oil Field in Argentina

    Microsoft Academic Search

    Aleksandr A. Grigoryan; Sabrina L. Cornish; Brenton Buziak; Shiping Lin; Adriana Cavallaro; Joseph J. Arensdorf; Gerrit Voordouw

    2008-01-01

    Acetate, propionate, and butyrate, collectively referred to as volatile fatty acids (VFA), are considered among the most important electron donors for sulfate-reducing bacteria (SRB) and heterotrophic nitrate-reducing bacteria (hNRB) in oil fields. Samples obtained from a field in the Neuquen Basin, western Argentina, had significant activity of mesophilic SRB, hNRB, and nitrate-reducing, sulfide-oxidizing bacteria (NR-SOB). In microcosms, containing VFA (3

  19. A He-Ne Laser-Based Field-Device For Oil And Gas Prospecting

    NASA Astrophysics Data System (ADS)

    Jordan, K. J.; Menzel, E. R.

    1987-04-01

    Atmospheric methane surveys may outline prospective oil and natural gas reservoirs. Methane sensing can also be applied to detect gas leakage of pipelines or landfills. We describe a field-device capable of measuring small changes in methane concentration in the near-surface atmosphere for such surveys. The detection of methane uses the attenuation of the 3.3922 ?m He-Ne laser line in a pressurized flow cell through which air circulates at a regulated pressure of about 3 atmospheres. A second He-Ne laser line at 3.3912 ?m, which is only weakly absorbed by methane, is used as a reference for ratio recording to compensate for laser intensity fluctuations and scattering by water or dust. The device is operated from a moving vehicle. Thus, sampling is continuous, i.e., large areas can rapidly be surveyed. Field tests showed the device to be rugged enough to withstand the rigors of off-road travel as well as summer heat.

  20. Analysis of AIS Data of the Recluse Oil Field, Recluse, Wyoming

    NASA Technical Reports Server (NTRS)

    Dykstra, J. D.; Segal, D. B.

    1985-01-01

    Airborne Imaging Spectrometer (AIS) data were flown over the Recluse, Wyoming oil field on September 9, 1984. Processing software was developed at Earth Satellite Corporation (EarthSat) for interactive analysis of the AIS data. EarthSat's AIS processing capabilities include destriping, solar irradiance corrections, residual calculations, geometric resampling, equal energy normalization, interactive spectral classifications and a variety of compressive algorithms to reduce the data to 8-bit format with a minimum of information loss. The in-house photolab facilities of EarthSat can routinely produce high-quality color renditions of the enhanced AIS data. A total of 80 lithologic samples were collected under the AIS flight lines. Correlation (within the atmospheric windows) between the laboratory and the AIS spectra of sample sites was generally poor. Reasonable correlation was only possible in large, freshly plowed fields. Mixed pixels and contrast between the natural and sample's surfaces were believed responsible for the poor correlation. Finally, a drift of approximately three channels was observed in the diffraction grating position within the 1.8 to 2.1 micron quadrant.

  1. Hackberry oil and gas fields in southeast Texas: channel/fan depositional systems and structural controls

    SciTech Connect

    Ewing, T.E.; Reed, R.S.

    1983-03-01

    Deep-water sandstones of the Hackberry Formation (Oligocene) host significant quantities of oil and gas. They remain one of the most important deep exploration targets in southeastern-most Texas; new fields producing from the Hackberry have been discovered at a steady rate from 1946 to the present. The Hackberry contains two hydrocarbon plays. The updip play is relatively shallow, oil-rich, and lies near the updip limit of deep-water deposition. The downdip play is gas rich and generally geopressured. The reservoirs lie either within or on the flanks of major channel systems and are often bounded updip by small growth faults. The Hackberry Formation is a wedge of sand and shale with bathyal fauna that separates upper Frio sandstone and shale from middle and lower Frio shale and sand. The main sandstone lies atop a channeled unconformity at the base of the formation. Topmost are proximal to medial fan deposits with slightly meandering channels and overbank turbidites. This sequence suggests that the Hackberry sands were laid down by an aggrading, onlapping submarine canyon-fan complex that eroded headward into the contemporaneous Frio barrier bar-strand plain. The early structural history of the area is obscure, but Vicksburg-age faulting associated with continental slope sedimentation is possible. Small growth faults displace the Hackberry section less than 500 ft (150 m) and extend upward into the Miocene strata. Isopach and isolith maps indicate that the Orange, Port Neches, and Fannett salt domes were active uplifts during Frio and Anahuac deposition. Near Spindletop dome, however, only a north-south trending salt-cored ridge was present.

  2. Improved Oil Recovery from Upper Jurassic Smackover Carbonates through the Application of Advanced Technologies at Womack Hill Oil Field, Choctaw and Clarke Counties, Eastern Gulf Coastal Plain

    SciTech Connect

    Ernest A. Mancini

    2003-12-31

    Pruet Production Co. and the Center for Sedimentary Basin Studies at the University of Alabama, in cooperation with Texas A&M University, Mississippi State University, University of Mississippi, and Wayne Stafford and Associates proposed a three-phase, focused, comprehensive, integrated and multidisciplinary study of Upper Jurassic Smackover carbonates (Class II Reservoir), involving reservoir characterization and 3-D modeling (Phase I) and a field demonstration project (Phases II and III) at Womack Hill Field Unit, Choctaw and Clarke Counties, Alabama, eastern Gulf Coastal Plain. Phase I of the project has been completed. The principal objectives of the project are: increasing the productivity and profitability of the Womack Hill Field Unit, thereby extending the economic life of this Class II Reservoir and transferring effectively and in a timely manner the knowledge gained and technology developed from this project to producers who are operating other domestic fields with Class II Reservoirs. The major tasks of the project included reservoir characterization, recovery technology analysis, recovery technology evaluation, and the decision to implement a demonstration project. Reservoir characterization consisted of geoscientific reservoir characterization, petrophysical and engineering property characterization, microbial characterization, and integration of the characterization data. Recovery technology analysis included 3-D geologic modeling, reservoir simulation, and microbial core experiments. Recovery technology evaluation consisted of acquiring and evaluating new high quality 2-D seismic data, evaluating the existing pressure maintenance project in the Womack Hill Field Unit, and evaluating the concept of an immobilized enzyme technology project for the Womack Hill Field Unit. The decision to implement a demonstration project essentially resulted in the decision on whether to conduct an infill drilling project in Womack Hill Field. Reservoir performance, multiwell productivity analysis, and reservoir simulation studies indicate that water injection continues to provide stable support to maintain production from wells in the western unitized area of the field and that the strong water drive present in the eastern area of the field is adequate to sustain production from this part of the field. Although the results from the microbial characterization and microbial core experiments are very promising, it is recommended that an immobilized enzyme technology project not be implemented in the Womack Hill Field Unit until live (freshly taken and properly preserved) cores from the Smackover reservoir in the field are acquired to confirm the microbial core experiments to date. From 3-D geologic modeling, reservoir performance analysis, and reservoir simulation, four areas in the Womack Hill Field were identified as prospective infill drilling sites to recover undrained oil from the field. It was determined that the two areas in the unit area probably can be effectively drained by perforating higher zones in the Smackover reservoir in currently producing wells. The two areas in the eastern (non-unitized) part of the field require the drilling of new wells. The successful drilling and testing of a well in 2003 by J. R. Pounds, Inc. has proven the oil potential of the easternmost site in the non-unitized part of the field. Pruet Production Co. acquired new 2-D seismic data to evaluate the oil potential of the westernmost site. Because of the effects of a fault shadow from the major fault bounding the southern border of the Womack Hill Field, it is difficult to evaluate conclusively this potential drill site. Pruet Production Co. has decided not to drill this new well at this time and to further evaluate the new 2-D seismic profiles after these data have been processed using a pre-stack migration technique. Pruet Production Co. has elected not to continue into Phase II of this project because they are not prepared to make a proposal to the other mineral interest owners regarding the drilling of new wells as part of an infil

  3. Improved Oil Recovery from Upper Jurassic Smackover Carbonates through the Application of Advanced Technologies at Womack Hill Oil Field, Choctaw and Clarke Counties, Eastern Gulf Costal Plain

    SciTech Connect

    Ernest A. Mancini

    2006-05-31

    Pruet Production Co. and the Center for Sedimentary Basin Studies at the University of Alabama, in cooperation with Texas A&M University, Mississippi State University, University of Mississippi, and Wayne Stafford and Associates proposed a three-phase, focused, comprehensive, integrated and multidisciplinary study of Upper Jurassic Smackover carbonates (Class II Reservoir), involving reservoir characterization and 3-D modeling (Phase I) and a field demonstration project (Phases II and III) at Womack Hill Field Unit, Choctaw and Clarke Counties, Alabama, eastern Gulf Coastal Plain. Phase I of the project has been completed. The principal objectives of the project are: increasing the productivity and profitability of the Womack Hill Field Unit, thereby extending the economic life of this Class II Reservoir and transferring effectively and in a timely manner the knowledge gained and technology developed from this project to producers who are operating other domestic fields with Class II Reservoirs. The major tasks of the project included reservoir characterization, recovery technology analysis, recovery technology evaluation, and the decision to implement a demonstration project. Reservoir characterization consisted of geoscientific reservoir characterization, petrophysical and engineering property characterization, microbial characterization, and integration of the characterization data. Recovery technology analysis included 3-D geologic modeling, reservoir simulation, and microbial core experiments. Recovery technology evaluation consisted of acquiring and evaluating new high quality 2-D seismic data, evaluating the existing pressure maintenance project in the Womack Hill Field Unit, and evaluating the concept of an immobilized enzyme technology project for the Womack Hill Field Unit. The decision to implement a demonstration project essentially resulted in the decision on whether to conduct an infill drilling project in Womack Hill Field. Reservoir performance, multiwell productivity analysis, and reservoir simulation studies indicate that water injection continues to provide stable support to maintain production from wells in the western unitized area of the field and that the strong water drive present in the eastern area of the field is adequate to sustain production from this part of the field. Although the results from the microbial characterization and microbial core experiments are very promising, it is recommended that an immobilized enzyme technology project not be implemented in the Womack Hill Field Unit until live (freshly taken and properly preserved) cores from the Smackover reservoir in the field are acquired to confirm the microbial core experiments to date. From 3-D geologic modeling, reservoir performance analysis, and reservoir simulation, four areas in the Womack Hill Field were identified as prospective infill drilling sites to recover undrained oil from the field. It was determined that the two areas in the unit area probably can be effectively drained by perforating higher zones in the Smackover reservoir in currently producing wells. The two areas in the eastern (non-unitized) part of the field require the drilling of new wells. The successful drilling and testing of a well in 2003 by J. R. Pounds, Inc. has proven the oil potential of the easternmost site in the non-unitized part of the field. Pruet Production Co. acquired new 2-D seismic data to evaluate the oil potential of the westernmost site. Because of the effects of a fault shadow from the major fault bounding the southern border of the Womack Hill Field, it is difficult to evaluate conclusively this potential drill site. Pruet Production Co. has decided not to drill this new well at this time and to further evaluate the new 2-D seismic profiles after these data have been processed using a pre-stack migration technique. Pruet Production Co. has elected not to continue into Phase II of this project because they are not prepared to make a proposal to the other mineral interest owners regarding the drilling of new wells as part of an infil

  4. Activities of the Oil Implementation Task Force, reporting period March--August 1991; Contracts for field projects and supporting research on enhanced oil recovery, reporting period October--December 1990

    SciTech Connect

    Not Available

    1991-10-01

    Activities of DOE's Oil Implementation Task Force for the period March--August 1991 are reviewed. Contracts for fields projects and supporting research on enhanced oil recovery are discussed, with a list of related publications given. Enhanced recovery processes covered include chemical flooding, gas displacement, thermal recovery, and microbial recovery.

  5. Brine Contamination of Ground Water and Streams in the Baxterville Oil Field Area, Lamar and Marion Counties, Mississippi

    USGS Publications Warehouse

    Kalkhoff, Stephen J.

    1993-01-01

    A hydrologic investigation to define the extent of brine contamination in ground water and streams in the Baxterville oil field area was conducted from October 1984 through November 1985. The 260-square-mile study area includes the Baxterville oil field (approximately 12.5 square miles) in southwestern Lamar and southeastern Marion Counties, Mississippi. Since 1944, disposal of more than 1 billion barrels of brine pumped from the oil- producing zones has contaminated (increased chloride to greater than background concentrations) parts of the Citronelle and shallow Miocene aquifers and some streams that drain the oil field. Many domestic wells have been abandoned because of the presence of substantial quantities of brine in the ground water. Brine has moved laterally through the shallowest aquifers and discharged into Clear Creek and its tributaries. Although the presence of brine in surface water was greatest during periods of low flow when streamflow originated primarily from ground-water inflow, brine was also detected during high-flow periods when streamflow consisted largely of precipitation runoff.

  6. Use of Ambersorb{reg_sign} carbonaceous adsorbent for removal of BTEX compounds from oil-field produced water

    SciTech Connect

    Gallup, D.L. [Unocal Corp., Santa Rosa, CA (United States); Isacoff, E.G.; Smith, D.N. III [Rohm and Haas Company, Spring House, PA (United States)

    1996-12-31

    The removal of high concentrations of BTEX compounds (benzene, toluene, ethylbenzene and xylenes) from oil-field produced waters using a carbonaceous adsorbent was successfully demonstrated in the field. The carbonaceous adsorbent was much more effective in removing BTEX compounds from produced water than activated carbon or modified clays. The primary objectives of the field studies were to evaluate the efficiency of oil removal processes to protect the adsorbent from fouling, to determine the BTEX removal efficiency of a carbonaceous adsorbent at a high flow rate loading, and to demonstrate regeneration of the adsorbent. Adsorbent fouling with oil was mitigated by mechanical coalescing for heavier crude and emulsion-breaking for lighter crude. Adsorbent extenders and filters did not control fouling in the presence of exceedingly emulsified crude oil. Carbonaceous adsorbent reduced BTEX compounds levels from the 25-130 mg/l range to less than 1 mg/l treating approximately 500 bed volumes of produced water per cycle. Regeneration of the adsorbent using low pressure steam or solvents was successfully achieved with regeneration efficiencies exceeding 95 percent. 13 refs., 7 figs., 4 tabs.

  7. Monitoring population abundance of the sand lizard Acanthodactylus scutellatus and their ant prey in oil polluted soils at Kuwait's greater Al-Burgan oil field.

    PubMed

    Al-Hashem, M

    2009-11-01

    Desert ecosystems in Al-Burgan oil fields of Kuwait were contaminated by heavy metals and petroleum hydrocarbons due to oil spill generated by the Gulf War in 1990. Studying sand lizard (Acanthodactylus scutellatus) population and their ant prey in the years 2002 and 2003 to detect the effects of oil pollution is now a focus of study. Polluted sites with apparently different degrees of pollution (namely tar mat, soot and clear sites) were compared with control sites outside this region. Total lizard numbers were recorded by using transect method. Number of ants was recorded by walking the transects and counting ants present. The results showed no difference in lizard population between the different study sites in 2002 and 2003 by applying the transect method. No difference in ant populations between the different study sites in 2002 and 2003. Although, the mean estimated lizard numbers were lower at the tar mat sites, the ant number in this location was greatest, meaning that food availability was highest at these sites. This suggests any reduction in the numbers of lizards is unrelated to low resource availability. The lizard numbers at the tar mat sites could be depressed by some property of the pollutants. PMID:20128514

  8. Correlations among hydrocarbon microseepage, soil chemistry, and uptake of micronutrients by plants, Bell Creek oil field, Montana

    USGS Publications Warehouse

    Roeming, S.S.; Donovan, T.J.

    1985-01-01

    Chelate-extractable iron and manganese concentrations in soils over and around the Bell Creek oil field suggest that compared to low average background values, there are moderate amounts of these elements directly over the production area and higher concentrations distributed in an aureole pattern around the periphery of the field. Adsorbed and organically bound iron and manganese appear to be readily taken up by plants resulting in anomalously high levels of these elements in leaves and needles over the oil field and suggesting correlation with corresponding low concentrations in soils. Iron and manganese appear to have bypassed the soil formation process where, under normal oxidizing conditions, they would have ultimately precipitated as insoluble oxides and hydroxides. ?? 1985.

  9. Analysis of Data from a Downhole Oil/Water Separator Field Trial in East Texas

    SciTech Connect

    Veil, John A.; Layne, Arthur Langhus

    2001-04-19

    Downhole oil/water separator (DOWS) technology is available to separate oil from produced water at the bottom of an oil well. Produced water can be injected directly to a disposal formation rather than lifting it to the surface, treating it there, and reinjecting it. Because of a lack of detailed performance data on DOWS systems, the U.S. Department of Energy (DOE) provided funding to secure DOWS performance data. A large U.S. oil and gas operator offered to share its data with Argonne National Laboratory. This report summarizes data from the DOWS installation in eastern Texas.

  10. A procedure to estimate the parent population of the size of oil and gas fields as revealed by a study of economic truncation

    USGS Publications Warehouse

    Schuenemeyer, J.H.; Drew, L.J.

    1983-01-01

    An estimation technique has been derived to predict the number of small fields in a geologic play or basin. Historically, many small oil and gas fields went unreported because they were not economical. This led to an underestimation of the number of undiscovered small fields. A study of the distributions of reported oil and gas fields in well-explored areas suggests that the large fields when grouped into log base 2 size classes are geometrically distributed. Further, the number of small fields reported is a function of the cost of exploration and development. Thus, the population field-size distribution is conjectured to be log geometric in form. ?? 1983 Plenum Publishing Corporation.

  11. IMPROVED OIL RECOVERY FROM UPPER JURASSIC SMACKOVER CARBONATES THROUGH THE APPLICATION OF ADVANCED TECHNOLOGIES AT WOMACK HILL OIL FIELD, CHOCTAW AND CLARKE COUNTIES, EASTERN GULF COASTAL PLAIN

    SciTech Connect

    Ernest A. Mancini

    2003-05-20

    Pruet Production Co. and the Center for Sedimentary Basin Studies at the University of Alabama, in cooperation with Texas A&M University, Mississippi State University, University of Mississippi, and Wayne Stafford and Associates are undertaking a focused, comprehensive, integrated and multidisciplinary study of Upper Jurassic Smackover carbonates (Class II Reservoir), involving reservoir characterization and 3-D modeling and an integrated field demonstration project at Womack Hill Oil Field Unit, Choctaw and Clarke Counties, Alabama, Eastern Gulf Coastal Plain. The principal objectives of the project are: increasing the productivity and profitability of the Womack Hill Field Unit, thereby extending the economic life of this Class II Reservoir and transferring effectively and in a timely manner the knowledge gained and technology developed from this project to producers who are operating other domestic fields with Class II Reservoirs. The principal research efforts for Year 3 of the project have been recovery technology analysis and recovery technology evaluation. The research focus has primarily been on well test analysis, 3-D reservoir simulation, microbial core experiments, and the decision to acquire new seismic data for the Womack Hill Field area. Although Geoscientific Reservoir Characterization and 3-D Geologic Modeling have been completed and Petrophysical and Engineering Characterization and Microbial Characterization are essentially on schedule, a no-cost extension until September 30, 2003, has been granted by DOE so that new seismic data for the Womack Hill Field can be acquired and interpreted to assist in the determination as to whether Phase II of the project should be implemented.

  12. Super-giant oil fields and future prospects in the Middle East

    SciTech Connect

    Christian, L. [Consultant, Dallas, TX (United States); Johnston, D. [Daniel Johnston & Co., Inc., Dallas, TX (United States)

    1995-06-01

    Upper Jurassic carbonates, Lower Cretaceous sands, Lower Cretaceous carbonates and Tertiary carbonates of the Middle East contain more than 50% of the worlds oil. Our area of interest covers SE Turkey and Syria in the north to the borders of Yemen and Oman in the south, and from the Red Sea across Saudi Arabia, the Emirates and the Arabian/Persian Gulf to Iran in the East. There are over 80 fields in this region with over 1 billion barrels of recoverable reserves. Yet only around 30,000 wells have been drilled in this territory. Regional structure and stratigraphy are discussed within the context of three major plays in the region as well as a new play in the Permo-Carboniferous. Numerous opportunities are available and countries such as Iraq and Iran may one day open their doors more to the industry than is presently the case. The dramatic petroleum geology of the region will stamp its influence on the nature of business and opportunities for years to come. While fiscal systems here already offer some of the toughest terms in the world, future deals in the more prolific areas will be even tougher. But, the economies of Middle Eastern scale will provide some of the great mega-opportunities of future international exploration.

  13. Field development of oil palms (Elaeis guineensis jacq) originating from cryopreserved stabilized polyembryonic cultures.

    PubMed

    Konan, E K; Durand-Gasselin, T; Kouadio, Y J; Niamké, A C; Dumet, D; Duval, Y; Rival, A; Engelmann, F

    2007-01-01

    In this paper, the long term observation of plants originating from control and cryopreserved stabilized polyembryonic cultures (SPCs) of six elite oil palm clones was carried out. Survival of plantlets in the nursery was monitored, then a series of vegetative and floral characteristics of over 440 palms were studied for up to 12 years after field transfer in Côte D'Ivoire. The six clones tested showed an average recovery of 34% after freezing in liquid nitrogen. The average survival in the nursery of plantlets originating from pretreated and dehydrated and from cryopreserved SPCs was higher than that of control SPCs. Palm trees originating from control SPCs were found to flower earlier than those originating from pretreated and dehydrated and from cryopreserved SPCs. This delay in flowering disappeared progressively and all palms had flowered 3 years after planting regardless of the SPC treatment. Abnormal palms were observed in one clone only. With this clone, the percentage of abnormal palms originating from cryopreserved SPCs was significantly lower (5%) than that measured on palms originating from control SPCs (29%). PMID:18075706

  14. Probing asphaltene aggregation in native crude oils with low-field NMR.

    PubMed

    Zielinski, Lukasz; Saha, Indrajit; Freed, Denise E; Hürlimann, Martin D; Liu, Yongsheng

    2010-04-01

    We show that low-field proton nuclear magnetic resonance (NMR) relaxation and diffusion experiments can be used to study asphaltene aggregation directly in crude oils. Relaxation was found to be multiexponential, reflecting the composition of a complex fluid. Remarkably, the relaxation data for samples with different asphaltene concentrations can be collapsed onto each other by a simple rescaling of the time dimension with a concentration-dependent factor xi, whereas the observed diffusion behavior is unaffected by asphaltene concentration. We interpret this finding in terms of a theoretical model that explains the enhanced relaxation by the transitory entanglement of solvent hydrocarbons within asphaltene clusters and their subsequent slowed motion and diffusion within the cluster. We relate the measured scaling parameters xi to cluster sizes, which we find to be on the order of 2.2-4.4 nm for an effective sphere diameter. These sizes are in agreement with the typical values reported in the literature as well as with the small-angle X-ray scattering (SAXS) experiments performed on our samples. PMID:20131761

  15. Modified vegetation indices for Ganoderma disease detection in oil palm from field spectroradiometer data

    NASA Astrophysics Data System (ADS)

    Shafri, Helmi Z. M.; Anuar, M. Izzuddin; Saripan, M. Iqbal

    2009-10-01

    High resolution field spectroradiometers are important for spectral analysis and mobile inspection of vegetation disease. The biggest challenges in using this technology for automated vegetation disease detection are in spectral signatures pre-processing, band selection and generating reflectance indices to improve the ability of hyperspectral data for early detection of disease. In this paper, new indices for oil palm Ganoderma disease detection were generated using band ratio and different band combination techniques. Unsupervised clustering method was used to cluster the values of each class resultant from each index. The wellness of band combinations was assessed by using Optimum Index Factor (OIF) while cluster validation was executed using Average Silhouette Width (ASW). 11 modified reflectance indices were generated in this study and the indices were ranked according to the values of their ASW. These modified indices were also compared to several existing and new indices. The results showed that the combination of spectral values at 610.5nm and 738nm was the best for clustering the three classes of infection levels in the determination of the best spectral index for early detection of Ganoderma disease.

  16. Costs for off-site disposal of nonhazardous oil field wastes: Salt caverns versus other disposal methods

    SciTech Connect

    Veil, J.A.

    1997-09-01

    According to an American Petroleum Institute production waste survey reported on by P.G. Wakim in 1987 and 1988, the exploration and production segment of the US oil and gas industry generated more than 360 million barrels (bbl) of drilling wastes, more than 20 billion bbl of produced water, and nearly 12 million bbl of associated wastes in 1985. Current exploration and production activities are believed to be generating comparable quantities of these oil field wastes. Wakim estimates that 28% of drilling wastes, less than 2% of produced water, and 52% of associated wastes are disposed of in off-site commercial facilities. In recent years, interest in disposing of oil field wastes in solution-mined salt caverns has been growing. This report provides information on the availability of commercial disposal companies in oil-and gas-producing states, the treatment and disposal methods they employ, and the amounts they charge. It also compares cavern disposal costs with the costs of other forms of waste disposal.

  17. Near-tip-screenout hydraulic fracturing of oil wells in the Bach Ho field, offshore Vietnam

    SciTech Connect

    Hung, L.V.; San, N.T.; Shelomentsev, A.G.; Tronov, J.A.; Lam, D.D.; Thomas, R.L.; Fox, T.; Bisdikian, C.

    1995-10-01

    The first hydraulic fracturing of wells in Vietnam were successfully performed Offshore in the Bach Ho (White Tiger) Oil Field. Near-tip-screenouts rather than tip-screenout treatments were performed. The goal of the project was to improve production from existing wells rather than drill new wells and reduce the cost per barrel produced. This case study involves wells with multiple perforated zones completed in the Oligocene sandstone. Zones were selectively fractured in order to optimize production. A detailed description candidate selection, design, execution and evaluation processes are presented. The Bach Ho field has been producing for 8 years but not at its potential due to various reasons including drilling and completion fluid damage. Although acidizing was an option for damage removal, hydraulic fracturing was selected as a way to bypass near-wellbore damage and generate a negative skin. Production simulators were used to quantify post-frac production. Due to suspected high closure stress, high strength proppant was selected and ramped in a high temperature fracturing fluid. Calibration treatments were conducted on several wells to quantify fluid leak-off, fracture height and Young`s modulus. Based on the results of the calibration treatment, fracture designs were modified. As predicted by computer simulation, near-tip-screenouts occurred as planned. The treatments were performed using a work boat with skid pumping/blending equipment, a computer monitoring/operation center and a laboratory. Strict QC procedures were followed to ensure the quality of all products. Post-frac well tests results and production data are presented. Overall, the fracturing campaign was very successful with wells showing negative skins and up to a five fold increase of production in agreement with systems analysis predictions.

  18. DSA Analysis of IRM Curves for Hydrocarbon Microseepage Characterization in Oil Fields From Eastern and Western Venezuela

    NASA Astrophysics Data System (ADS)

    Aldana, M.; Costanzo-Alvarez, V.; Gonzalez, C.; Gomez, L.

    2009-05-01

    During the last few years we have performed surface reservoir characterization at some Venezuelan oil fields using rock magnetic properties. We have tried to identify, at shallow levels, the "oil magnetic signature" of subjacent reservoirs. Recent data obtained from eastern Venezuela (San Juan field) emphasizes the differences between rock magnetic data from eastern and western oil fields. These results support the hypothesis of different authigenic processes. To better characterize hydrocarbon microseepage in both cases, we apply a new method to analyze IRM curves in order to find out the main magnetic phases responsible for the observed magnetic susceptibility (MS) anomalies. This alternative method is based on a Direct Signal Analysis (DSA) of the IRM in order to identify the number and type of magnetic components. According to this method, the IRM curve is decomposed as the sum of N elementary curves (modeled using the expression proposed by Robertson and France, 1994) whose mean coercivities vary in the interval of the measured magnetic field. The result is an adjusted spectral histogram from which the number of main contributions, their widths and mean coercivities, associated with the number and type of magnetic minerals, can be obtained. This analysis indicates that in western fields the main magnetic mineralogy is magnetite. Conversely in eastern fields, the MS anomalies are mainly caused by the presence of Fe sulphides (i.e. greigite). These results support the hypothesis of two different processes. In western fields a net electron transfer from the organic matter, degraded by hydrocarbon gas leakage, should occur precipitating Fe(II) magnetic minerals (e.g. magnetite). On the other hand, high concentrations of H2S at shallow depth levels, might allow the formation of secondary Fe-sulphides in eastern fields.

  19. Prebreakdown phenomena in mineral oil under step and ac voltage in large-gap divergent fields

    Microsoft Academic Search

    P. Rain; O. Lesaint

    1994-01-01

    This paper presents an experimental study of the propagation of prebreakdown phenomena in transformer oil, in large point-plane gaps (5 to 20 cm), in positive polarity under step and ac voltages. The prebreakdown phenomena are characterized via the simultaneous recordings of transient currents, charges, photocurrents, and high-speed photographs of the emitted light. In these experimental conditions, prebreakdown phenomena in oil

  20. Simulation studies of steam-propane injection for the Hamaca heavy oil field

    E-print Network

    Venturini, Gilberto Jose

    2002-01-01

    Simulation studies were performed to evaluate a novel technology, steam-propane injection, for the heavy Hamaca crude oil. The oil has a gravity of 9.3?API and a viscosity of 25,000 cp at 50?C. Two types of simulation studies were performed: a...

  1. ENVIRONMENTAL CHARACTERIZATION OF GEOKINETICS' IN-SITU OIL SHALE RETORTING TECHNOLOGY: FIELD AND ANALYTICAL DATA APPENDICES

    EPA Science Inventory

    Air emissions and water effluents from true in-situ oil shale retorting were physically, chemically and biologically characterized by sampling of Geokinetics Retort No. 17, a pilot-scale unit which produced 30 barrels of crude shale oil per day during testing from July 16 to July...

  2. Field Evaluation of Essential Oils for Reducing Attraction by the Japanese Beetle (Coleoptera: Scarabaeidae)

    Technology Transfer Automated Retrieval System (TEKTRAN)

    This study evaluated 47 commercial plant-derived essential oils individually or as blends for their potential as adult Japanese beetle (Popillia japonica Newman) repellents during 2003 to 2007. A bioassay procedure used traps to evaluate whether essential oils could repel beetles from Japanese beet...

  3. Unitization of oil and gas fields in Texas. A study of legislative, administrative, and judicial policies

    Microsoft Academic Search

    1986-01-01

    In the 1970s, the long lines of cars at gasoline stations, the blackouts, and the school and factory closings announced to the public that the United States had an ''energy crisis.'' In response, an outpouring of state and federal legislation sought to lessen the effects of the oil and gas shortages and to prevent their recurrence. By 1985, every oil-

  4. Late diagenetic indicators of buried oil and gas: II, Direct detection experiment at Cement and Garza oil fields, Oklahoma and Texas, using enhanced LANDSAT I and II images

    USGS Publications Warehouse

    Donovan, Terrence J.; Termain, Patricia A.; Henry, Mitchell E.

    1979-01-01

    The Cement oil field, Oklahoma, was a test site for an experiment designed to evaluate LANDSAT's capability to detect an alteration zone in surface rocks caused by hydrocarbon microseepage. Loss of iron and impregnation of sandstone by carbonate cements and replacement of gypsum by calcite are the major alteration phenomena at Cement. The bedrock alterations are partially masked by unaltered overlying beds, thick soils, and dense natural and cultivated vegetation. Interpreters biased by detailed ground truth were able to map the alteration zone subjectively using a magnified, filtered, and sinusoidally stretched LANDSAT composite image; other interpreters, unbiased by ground truth data, could not duplicate that interpretation. Similar techniques were applied at a secondary test site (Garza oil field, Texas), where similar alterations in surface rocks occur. Enhanced LANDSAT images resolved the alteration zone to a biased interpreter and some individual altered outcrops could be mapped using higher resolution SKYLAB color and conventional black and white aerial photographs suggesting repeat experiments with LANDSAT C and D.

  5. How clean is clean enough? Maintaining thermal protective clothing under field conditions in the oil and gas sector.

    PubMed

    Crown, Elizabeth M; Feng, Aifen; Xu, Xia

    2004-01-01

    The purpose of this research was to develop practical care procedures to help maintain the protective quality of flame resistant workwear laundered by workers in the field. Based on observed field conditions, experiments were conducted that simulated domestic laundry procedures. The first experiment involved two flame resistant (FR) fabrics, contaminated or not contaminated with oil. Independent variables also included detergent type and laundry pre-treatment. Other laundry parameters were controlled. Results indicated that it is easier to maintain the FR performance of the FR-treated blend than it is for the aramid fabric. It is hypothesized that energy generated by initial ignition of oil on the specimens triggers the FR mechanism of the treatment, which in turn inhibits further combustion. A second experiment using larger specimens and a domestic washing machine also supported the hypothesized mechanism. PMID:15377409

  6. The influence of bioaugmentation and biosurfactant addition on bioremediation efficiency of diesel-oil contaminated soil: feasibility during field studies.

    PubMed

    Szulc, Alicja; Ambro?ewicz, Damian; Sydow, Mateusz; ?awniczak, ?ukasz; Piotrowska-Cyplik, Agnieszka; Marecik, Roman; Chrzanowski, ?ukasz

    2014-01-01

    The study focused on assessing the influence of bioaugmentation and addition of rhamnolipids on diesel oil biodegradation efficiency during field studies. Initial laboratory studies (measurement of emitted CO2 and dehydrogenase activity) were carried out in order to select the consortium for bioaugmentation as well as to evaluate the most appropriate concentration of rhamnolipids. The selected consortium consisted of following bacterial taxa: Aeromonas hydrophila, Alcaligenes xylosoxidans, Gordonia sp., Pseudomonas fluorescens, Pseudomonas putida, Rhodococcus equi, Stenotrophomonas maltophilia, Xanthomonas sp. It was established that the application of rhamnolipids at 150 mg/kg of soil was most appropriate in terms of dehydrogenase activity. Based on the obtained results, four treatment methods were designed and tested during 365 days of field studies: I) natural attenuation; II) addition of rhamnolipids; III) bioaugmentation; IV) bioaugmentation and addition of rhamnolipids. It was observed that bioaugmentation contributed to the highest diesel oil biodegradation efficiency, whereas the addition of rhamnolipids did not notably influence the treatment process. PMID:24291585

  7. Enigmatic organosiliceous rocks in the 2000 Ma petrified oil field in Russian Fennoscandia

    NASA Astrophysics Data System (ADS)

    Deines, Yu.; Melezhik, V.; Lepland, A.; Filippov, M.; Romashkin, A.; Rychanchik, D.

    2009-04-01

    The c. 2000 Ma, 900 m-thick, Zaonezhskaja Formation in the Onega basin, Russian Fennoscandia, contains one of the greatest accumulations of organic matter (OM) in the Early Precambrian. It also represents a unique preservation of a supergiant petrified oil field. Zaonezhskaja Formation rocks are greenschist-facies volcaniclastic greywackes (distal turbidites), dolostone and limestones, mafic tuffs and lavas intruded by numerous mafic sills. Several sedimentary beds are enriched in OM with the overall content of total organic carbon (TOC) ranging from 0.1 to 16 wt.% whereas d13C varies between -44 and -17 per mil(V-PDB). The formation contains plentiful evidence of generation and migration of oil (now petrified) as well as oil traps. Results of geophysical surveys combined with drillcore data, including results recently obtained within the framework of the Fennoscandian Arctic Russia - Drilling Early Earth Project (FAR-DEEP), revealed numerous bodies of organosiliceous rocks (OSR) containing mainly silica (c. 57 wt.% SiO2), organic carbon (up to 40 wt.%), Al2O3 (c. 5 wt.%), S (c. 2 wt.%), and minor K, Mg, Fe, Ca and Ti. d13C of the OSR ranges between -40 and -20 per mil. The OSR form crudely stratified beds, cupola-like bodies or veins. The cupola-like bodies show cross-cutting (intrusive) contacts with the host turbiditic greywackes, reach thicknesses of 120 m with a lateral extent of several hundreds of metres. Veins are a few tens of centimetres thick. The OSR show close spatial association with gabbro sills. Although different fabrics have been recognised in the OSR, syngenetic macro- and microbreccias per se are the most common rock types. Fragments of different sedimentary rocks, as well as those with alternating C-rich and C-poor concentric lamina are present. The latter suggests precipitation from hydrothermal fluids. The nature of the OSR remains enigmatic. Several models have been advanced for explanation of origin of the OSR. However, neither of them could explain the source, and joint transport of two major components, namely silica and OM. We propose a model involving a hydrothermal system initiated by heat produced during the emplacement of numerous mafic intrusive bodies. Such heat may have created the necessary temperature gradient for earlier oil generation, thermal oil to gas cracking, and initiation of shallow-seated, sub-surface, hydrothermal circulation. The proposed result would have been the mingling of silica leached from mafic rocks with hydrocarbon, and gas (primarily CO2, CH4) extracted from the host sedimentary rocks. Such a gas-rich C-Si-H2O substance would have migrated into permeable beds. A high sedimentation rate, as expected in many turbiditic depositional environments, would have produced a high lithostatic pressure on to unlithified beds during the course of the basin subsidence. This would have forced gas-rich C-Si-H2O fluids that moved either laterally along permeable beds or vertically along zones of weakness. In the first case, sediments 'impregnated' with gas-rich C-Si-H2O fluids would have formed stratigraphic beds of OSR, whereas in the second case the result would been crosscutting veins. Beds may retain some primary layering, whereas veins do not. If veins reached the seafloor, the sediment - C-Si-H2O mush would have extruded in the form of a mud volcano / hydrothermal mound, and thus formed a cupola-like morphology. During the course of compression, the sediment - C-Si-H2O mush might have experienced several stages of partial lithification, as well as fluidisation processes leading to the formation of several generations of micro- and macro-brecciated rocks. The large d13C range of reduced carbon in the OSR suggests a complex maturation process of the biogenic OM. Further detailed microstructural, geochemical, isotopic and biomarker studies are planned for distinguishing between biological and abiological processes involved in the formation of the enigmatic OSR.

  8. LANDSAT Study of Alteration Aureoles in Surface Rocks Overlying Petroleum Deposits. [Cement and Davenport oil fields, Oklahoma

    NASA Technical Reports Server (NTRS)

    Donovan, T. J. (principal investigator)

    1975-01-01

    The author has identified the following significant results. A series of low altitude underflight remote sensing experiments were flown at Cement and Davenport oil fields, Oklahoma. An experimental algorithm which employs a sinusoidal stretch of brightness values was developed and applied to a January 1973 scene (bands 4, 5, and 6) of Cement. The results, although not spectacular, are extremely encouraging and for the first time demonstrate that the alteration anomaly at Cement may be defined through enhanced LANDSAT images.

  9. Chemical and microbiological changes in laboratory incubations of nitrate amendment “sour” produced waters from three western Canadian oil fields

    Microsoft Academic Search

    R E Eckford; P M Fedorak

    2002-01-01

      Nitrate addition to oil field waters stops the biogenic formation of sulfide because the activities of nitrate-reducing bacteria\\u000a (NRB) suppress the activities of sulfate-reducing bacteria (SRB). In general, there are two types of NRB — the heterotrophic\\u000a NRB and the chemolithotrophic NRB. Within the latter group are the nitrate-reducing, sulfide-oxidizing bacteria (NR-SOB).\\u000a To date, no study has specifically addressed the

  10. Detection of biomarkers in the organic matter of rocks from the Romashkinskoe oil field using gas chromatography-mass spectrometry

    Microsoft Academic Search

    N. S. Sharipova; G. K. Budnikov; B. V. Uspenskii; G. P. Kayukova

    2010-01-01

    Polycyclic hydrocarbons (biomarkers) were detected in the organic matter of Paleozoic and pre-Paleozoic rocks from the Romashkinskoe\\u000a oil field in the Volga-Ural region using gas chromatography-mass spectrometry. Coefficients were calculated from the ratio\\u000a between tetra- and pentacyclic hydrocarbons, and the facial genetic types, possible generation sources, and evolution transformation\\u000a conditions of the initial organic matter were determined from the array

  11. Thermodynamics of diagenetic fluid and fluid\\/mineral reactions in the Eogene Xingouzui Formation, oil Field T, Jianghan Basin

    Microsoft Academic Search

    Ni Shijun; Luo Yutian; Liu Lihua; Wang Xuben; Li Sue; Luo Yangdi; Han Dingrong

    1994-01-01

    This study focuses on the thermodynamics of diagenetic fluid from the Eogene Xingouzui Formation which represents the most\\u000a important reservoir in Field Oil T in the Jianghan Basin. The measured homogenization temperatures (110–139 °C) of fluid inclusions\\u000a in diagenetic minerals fell within the range of 67 –155 °C at the middle diagenetic stage. The pressure of diagenetic fluid\\u000a is estimated

  12. Contracts for field projects and supporting research on enhanced oil recovery. Progress review number 86, quarter ending March 31, 1996

    SciTech Connect

    NONE

    1997-05-01

    Summaries are presented for 37 enhanced oil recovery contracts being supported by the Department of Energy. The projects are grouped into gas displacement methods, thermal recovery methods, geoscience technology, reservoir characterization, and field demonstrations in high-priority reservoir classes. Each summary includes the objectives of the project and a summary of the technical progress, as well as information on contract dates, size of award, principal investigator, and company or facility doing the research.

  13. Experimental Fireflood in a Very Viscous Oil-Unconsolidated Sand Reservoir, S.E. Pauls Valley Field, Oklahoma

    Microsoft Academic Search

    Lincoln Elkins; Dick Morton; William Blackwell

    1972-01-01

    The subject field produces 8,000 cp 10$ API oil by natural water drive from an unconsolidated sand reservoir about 100 ft thick. Nearly all wells produced 10 to 50% sand initially, declining later to 0.1 to 2%, regardless of completion method. Apparently this production of sand created interconnecting worm hole porosity extending at least between wells on 10-acre spacing. Some

  14. Comparative laboratory and field evaluation of repellent formulations containing deet and lemon eucalyptus oil against mosquitoes in Queensland, Australia.

    PubMed

    Frances, S P; Rigby, L M; Chow, W K

    2014-03-01

    A field trial comparing a formulation containing 40% deet (N,N-diethyl-3-methyl benzamide) in ethanol (Bushman) and 32% lemon eucalyptus oil (LEO; Mosi-guard) as protection against mosquitoes at Redcliffe, Queensland, Australia, was conducted in February 2012 and February 2013. The 40% deet formulation provided 100% protection against mosquitoes for 7 h, while the 32% LEO provided >95% protection for 3 h. PMID:24772681

  15. An extractive distillation technique for producing CO 2 enriched injection gas in enhanced oil recovery (EOR) fields

    Microsoft Academic Search

    B. ZareNezhad; N. Hosseinpour

    2009-01-01

    Sharp Separation of CO2 (carbon dioxide) from CO2-rich gases issuing from enhanced oil recovery (EOR) fields is investigated by different processing alternatives. A new extractive distillation technique without using an external solvent is introduced for debottlenecking of CO2 separation problem encountered in cryogenic distillation units. The technique involves the addition of a portion of produced C4+ (NGL) stream (natural gas

  16. Remains of Homo erectus from Bouri, Middle Awash, Ethiopia

    Microsoft Academic Search

    Berhane Asfaw; W. Henry Gilbert; Yonas Beyene; William K. Hart; Paul R. Renne; Giday WoldeGabriel; Elisabeth S. Vrba; Tim D. White

    2002-01-01

    The genesis, evolution and fate of Homo erectus have been explored palaeontologically since the taxon's recognition in the late nineteenth century. Current debate is focused on whether early representatives from Kenya and Georgia should be classified as a separate ancestral species (`H. ergaster'), and whether H. erectus was an exclusively Asian species lineage that went extinct. Lack of resolution of

  17. Investigation of Diospyros Kaki L.f husk extracts as corrosion inhibitors and bactericide in oil field

    PubMed Central

    2013-01-01

    Background Hydrochloric acid is used in oil-well acidizing commonly for improving the crude oil production of the low-permeable reservoirs, while it is a great challenge for the metal instruments involved in the acidification. Developing natural products as oilfield chemicals is a straight way to find less expensive, green and eco-friendly materials. The great plant resources in Qin-ling and Ba-shan Mountain Area of Shannxi Province enable the investigating of new green oil field chemicals. Diospyros Kaki L.f (persimmon), a famous fruit tree is widely planted in Qin-ling and Ba-shan Mountain Area of Shaanxi Province. It has been found that the crude persimmon extracts are complex mixtures containing vitamins, p-coumaric acid, gallic acid, catechin, flavonoids, carotenoids and condensed tannin and so on, which indicates the extracts of persimmon husk suitable to be used as green and eco-friendly corrosion inhibitors. Findings Extracts of persimmon husk were investigated, by using weight loss and potentiodynamic polarisation techniques, as green and eco-friendly corrosion inhibitors of Q235A steel in 1M HCl. The inhibition efficiency of the extracts varied with extract concentration from 10 to 1,000 mg/L. There are some synergistic effects between the extracts and KI, KSCN and HMTA. Potentiodynamic polarization studies indicate that extracts are mixed-type inhibitors. Besides, the extracts were screened for antibacterial activity against oil field microorganisms, and they showed good to moderate activity against SRB, IB and TGB. Conclusions The inhibition efficiency of the extracts varied with extract concentration from 10 to 1,000 mg/L, and the highest reaches to 65.1% with the con concentration of 1,000 mg/L WE. KI, KSCN and HMTA they can enhance the IE of WE effectively to 97.3% at most, but not effective for KI and KSCN to AE. Tafel polarisation measurements indicate the extracts behave as mixed type inhibitor. Investigation of the antibacterial activity against oil field microorganism showed the extracts can inhibit SRB, IB and TGB with moderate to highly efficiency under 1,000 mg/L, which makes extracts potential to be used as bifunctional oil field chemicals. PMID:23816431

  18. Effect of Nitrate Injection on the Microbial Community in an Oil Field as Monitored by Reverse Sample Genome Probing

    PubMed Central

    Telang, A. J.; Ebert, S.; Foght, J. M.; Westlake, D.; Jenneman, G. E.; Gevertz, D.; Voordouw, G.

    1997-01-01

    The reverse sample genome probe (RSGP) method, developed for monitoring the microbial community in oil fields with a moderate subsurface temperature, has been improved by (i) isolation of a variety of heterotrophic bacteria and inclusion of their genomes on the oil field master filter and (ii) use of phosphorimaging technology for the rapid quantitation of hybridization signals. The new master filter contains the genomes of 30 sulfate-reducing, 1 sulfide-oxidizing, and 16 heterotrophic bacteria. Most have been identified by partial 16S rRNA sequencing. Use of improved RSGP in monitoring the effect of nitrate injection in an oil field indicated that the sulfide-oxidizing, nitrate-reducing isolate CVO (a Campylobacter sp.) becomes the dominant community component immediately after injection. No significant enhancement of other community members, including the sulfate-reducing bacteria, was observed. The elevated level of CVO decayed at most sampling sites within 30 days after nitrate injection was terminated. Chemical analyses indicated a corresponding decrease and subsequent increase in sulfide concentrations. Thus, transient injection of a higher potential electron acceptor into an anaerobic subsurface system can have desirable effects (i.e., reduction of sulfide levels) without a permanent adverse influence on the resident microbial community. PMID:16535595

  19. Increasing heavy oil reserves in the Wilmington Oil field through advanced reservoir characterization and thermal production technologies. Quarterly report, April 1, 1996--June 30, 1996

    SciTech Connect

    Hara, S.

    1996-08-05

    The project involves improving thermal recovery techniques in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., California using advanced reservoir characterization and thermal production technologies. Inadequate characterization of the heterogeneous turbidite sands, high permeability thief zones, low gravity oil, and nonuniform distribution of remaining oil have all contributed to poor sweep efficiency, high steam-oil ratios, and early steam breakthrough. Operational problems related to steam breakthrough, high reservoir pressure, and unconsolidated formation sands have caused premature well and downhole equipment failures. In aggregate, these reservoir and operational constraints have resulted in increased operating costs and decreased recoverable reserves. The technologies include: (1) Develop three-dimensional (3-D) deterministic and stochastic geologic models. (2) Develop 3-D deterministic and stochastic thermal reservoir simulation models to aid in reservoir management and subsequent development work. (3) Develop computerized 3-D visualizations of the geologic and reservoir simulation models to aid in analysis. (4) Perform detailed study on the geochemical interactions between the steam and the formation rock and fluids. (5) Pilot steam injection and production via four new horizontal wells (2 producers and 2 injectors). (6) Hot water alternating steam (WAS) drive pilot in the existing steam drive area to improve thermal efficiency. (7) Installing an 2400 foot insulated, subsurface harbor channel crossing to supply steam to an island location. (8) Test a novel alkaline steam completion technique to control well sanding problems and fluid entry profiles. (9) Advanced reservoir management through computer-aided access to production and geologic data to integrate reservoir characterization, engineering, monitoring, and evaluation.

  20. Increasing heavy oil reservers in the Wilmington oil Field through advanced reservoir characterization and thermal production technologies, technical progress report, October 1, 1996--December 31, 1996

    SciTech Connect

    Hara, S. [Tidelands Oil Production Co., Long Beach, CA (United States)], Casteel, J. [USDOE Bartlesville Project Office, OK (United States)

    1997-05-11

    The project involves improving thermal recovery techniques in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., Calif. using advanced reservoir characterization and thermal production technologies. The existing steamflood in the Tar zone of Fault Block (FB) 11-A has been relatively inefficient because of several producibility problems which are common in SBC reservoirs. Inadequate characterization of the heterogeneous turbidite sands, high permeability thief zones, low gravity oil, and nonuniform distribution of remaining oil have all contributed to poor sweep efficiency, high steam-oil ratios, and early steam breakthrough. Operational problems related to steam breakthrough, high reservoir pressure, and unconsolidated formation sands have caused premature well and downhole equipment failures. In aggregate, these reservoir and operational constraints have resulted in increased operating costs and decreased recoverable reserves. The advanced technologies to be applied include: (1) Develop three-dimensional (3-D) deterministic and stochastic geologic models. (2) Develop 3-D deterministic and stochastic thermal reservoir simulation models to aid in reservoir management and subsequent development work. (3) Develop computerized 3-D visualizations of the geologic and reservoir simulation models to aid in analysis. (4) Perform detailed study on the geochemical interactions between the steam and the formation rock and fluids. (5) Pilot steam injection and production via four new horizontal wells (2 producers and 2 injectors). (6) Hot water alternating steam (WAS) drive pilot in the existing steam drive area to improve thermal efficiency. (7) Installing a 2100 foot insulated, subsurface harbor channel crossing to supply steam to an island location. (8) Test a novel alkaline steam completion technique to control well sanding problems and fluid entry profiles. (9) Advanced reservoir management through computer-aided access to production and geologic data to integrate reservoir characterization, engineering, monitoring, and evaluation.

  1. Formation of seep bubble plumes in the Coal Oil Point seep field

    NASA Astrophysics Data System (ADS)

    Leifer, Ira; Culling, Daniel

    2010-06-01

    The fate of marine seep gases (transport to the atmosphere or dissolution, and either bacterial oxidation or diffusion to the atmosphere) is intimately connected with bubble and bubble-plume processes, which are strongly size-dependent. Based on measurements with a video bubble measurement system in the Coal Oil Point seep field in the Santa Barbara Channel, California, which recorded the bubble-emission size distribution (?) for a range of seep vents, three distinct plume types were identified, termed minor, major, and mixed. Minor plumes generally emitted bubbles with a lower emission flux, Q, and had narrow, peaked ? that were well described by a Gaussian function. Major plumes showed broad ? spanning very small to very large bubbles, and were well described by a power law function. Mixed plumes showed characteristics of both major and minor plume classes, i.e., they were described by a combination of Gaussian and power law functions, albeit poorly. To understand the underlying formation mechanism, laboratory bubble plumes were created from fixed capillary tubes, and by percolating air through sediment beds of four different grain sizes for a range of Q. Capillary tubes produced a ? that was Gaussian for low Q. The peak radius of the Gaussian function describing ? increased with capillary diameter. At high Q, they produced a broad distribution, which was primarily described by a power law. Sediment-bed bubble plumes were mixed plumes for low Q, and major plumes for high Q. For low- Q sediment-bed ?, the peak radius decreased with increasing grain size. For high Q, sediment-bed ? exhibited a decreased sensitivity to grain size, and ? tended toward a power law, similar to that for major seep plumes.

  2. Salvaging dipmeters using an oil field {open_quotes}Dinosaur{close_quotes}

    SciTech Connect

    Breimayer, A.R.P.; Puzio, L.B. [Terradip, Houston, TX (United States)

    1996-09-01

    Although state-of-the-art methods such as 3-D seismic and formation imaging tools are widely used, the advantages of the old standard dipmeter should not be dismissed. Seismic dip is subject to velocity errors, and formation imagers cannot be run in all borehole conditions. The dipmeter offers a relatively low cost, highly effective alternative for defining geologic features. The 60{double_prime}= 100{prime} scale playback of the raw dipmeter data may be an oil field {open_quotes}dinosaur,{close_quotes} but it is also the key to assessing the reliability of a dipmeter. This playback should be used to determine CORRELATION QUALITY, critical to the accuracy of any dipmeter. Computer computation of the raw dipmeter data does not always yield reliable dip information, particularly when dipmeters are run under adverse hole conditions or in complex geology. This data can be often salvaged by optical correlation of the 60{close_quote} playback - the process of manually correlating raw dipmeter resistivity curves to determine the attitude of bedding planes in the subsurface. Problems such as tool noise, tool pulls, and poor pad contact compromise data quality. These problems can be recognized and compensated for using optical correlation. Finally, at the 60{double_prime} scale many formation textures and structural characteristics visible on the formation imaging logs are also discernible on the standard dipmeter traces. We will offer many Gulf Coast examples and some hands-on demonstrations using the 60{double_prime} data, and show improved tadpole plots which result from optical correlation.

  3. Increasing Waterflooding Reservoirs in the Wilmington Oil Field through Improved Reservoir Characterization and Reservoir Management, Class III

    SciTech Connect

    Koerner, Roy; Clarke, Don; Walker, Scott; Phillips, Chris; Nguyen, John; Moos, Dan; Tagbor, Kwasi

    2001-08-07

    This project was intended to increase recoverable waterflood reserves in slope and basin reservoirs through improved reservoir characterization and reservoir management. The particular application of this project is in portions of Fault Blocks IV and V of the Wilmington Oil Field, in Long Beach, California, but the approach is widely applicable in slope and basin reservoirs, transferring technology so that it can be applied in other sections of the Wilmington field and by operators in other slope and basin reservoirs is a primary component of the project.

  4. Ground level concentration of sulfur dioxide at Kuwait`s major population centers during the oil-field fires

    SciTech Connect

    Al-Ajmi, D.N.; Marmoush, Y.R. [Kuwait Institute for Scientific Research (Kuwait)] [Kuwait Institute for Scientific Research (Kuwait)

    1996-08-01

    During the Iraqi occupation, Kuwait`s oil wells were ignited. the fires were damaging to the country`s oil resources and air quality. The impact of the oil-field fires on the air quality was studied to determine the level of exposure to pollutants in major population centers. The period of July-September 1991 was selected for examination. A mathematical model was used to compute the ground-level concentration isopleths. The results of these computations are supported by significant concentrations measured and reported by the Environmental Protection Council, Kuwait. The ground-level concentrations of sulfur dioxide in the major population centers, whether measure or estimated, were less than the ambient standards of the U.S. Environmental Protection Agency`s air pollution index. The dispersive characteristics were classified according to wind conditions. The results of this assessment provide historical data on Kuwait`s oil fires and may be useful in assessing risks resulting from this catastrophe. 6 refs., 10 fig., 2 tab.

  5. Open-source LCA tool for estimating greenhouse gas emissions from crude oil production using field characteristics.

    PubMed

    El-Houjeiri, Hassan M; Brandt, Adam R; Duffy, James E

    2013-06-01

    Existing transportation fuel cycle emissions models are either general and calculate nonspecific values of greenhouse gas (GHG) emissions from crude oil production, or are not available for public review and auditing. We have developed the Oil Production Greenhouse Gas Emissions Estimator (OPGEE) to provide open-source, transparent, rigorous GHG assessments for use in scientific assessment, regulatory processes, and analysis of GHG mitigation options by producers. OPGEE uses petroleum engineering fundamentals to model emissions from oil and gas production operations. We introduce OPGEE and explain the methods and assumptions used in its construction. We run OPGEE on a small set of fictional oil fields and explore model sensitivity to selected input parameters. Results show that upstream emissions from petroleum production operations can vary from 3 gCO2/MJ to over 30 gCO2/MJ using realistic ranges of input parameters. Significant drivers of emissions variation are steam injection rates, water handling requirements, and rates of flaring of associated gas. PMID:23634761

  6. Fuzzy SPC filter for a feed-forward control system for a three-phase oil field centrifuge.

    SciTech Connect

    Parkinson, W. J. (William Jerry),; Smith, R. E. (Ronald E.); Mortensen, F. N. (Fred N.); Wantuck, P. J. (Paul J.); Jamshidi, Mohammad; Ross, Timothy J.

    2002-01-01

    In this work we describe a signal filter for a feed-forward controller based on the application of fuzzy logic combined with statistical process control (SPC), The feed-forward controller is for a three-phase oil field centrifuge. The centrifuge system is used to separate meta-stable three-phase emulsions consisting of oil and water stabilized by solids. These emulsions are considered to be unusable wastes and must be disposed of in an environmentally acceptable manner. The centrifuge is capable of turning these wastes into clean saleable oil, water that can be reused in an operating process or re-injected into oil wells and, solids that can be disposed of in landfills. The feed-forward controller is used for feed disturbance rejection. It works in conjunction with and, is capable of over-riding the actions of, a feedback controller. The measured feed variables for the feed-forward controller each exhibit reasonably large random fluctuations. It is therefore quite important to use a signal filter that truly recognizes the difference between random noise and a 'caused' event, in order to prevent overriding a perfectly good correction from the feedback controller.

  7. Increasing Waterflood Reserves in the Wilmington Oil Field through Improved Reservoir Characterization and Reservoir Management

    SciTech Connect

    Clarke, D.; Koerner, R.; Moos D.; Nguyen, J.; Phillips, C.; Tagbor, K.; Walker, S.

    1999-04-05

    This project used advanced reservoir characterization tools, including the pulsed acoustic cased-hole logging tool, geologic three-dimensional (3-D) modeling software, and commercially available reservoir management software to identify sands with remaining high oil saturation following waterflood. Production from the identified high oil saturated sands was stimulated by recompleting existing production and injection wells in these sands using conventional means as well as a short radius redrill candidate.

  8. External magnetic field dependent light transmission and scattered speckle pattern in a magnetically polarizable oil-in-water nanoemulsion

    NASA Astrophysics Data System (ADS)

    Brojabasi, Surajit; Lahiri, B. B.; Philip, John

    2014-12-01

    We study the magnetic field dependent light transmission and scattered speckle pattern in a magnetically polarizable oil-in-water emulsion of droplet diameter ~220 nm, where the direction of propagation of light is parallel to the direction of the external magnetic field. Up to a magnetic field of 50 Gauss, the nanoemulsion remains opaque due to intense Mie scattering. Above 50 Gauss, the transmitted light intensity increases with external magnetic field up to a critical field (BC). Further increase in the magnetic field leads to a reduction in the transmitted intensity. The BC shifts to a lower magnetic field with increasing volume fraction (?) and follows a power law dependence with ?, indicating a disorder-order transition. The scattered light intensity at the lobe part is found to increase with external magnetic field. The analysis of the lobe part reveals that the speckle contrast increases with external magnetic field due to the coarsening of the linear chain-like aggregates formed along the direction of the external magnetic field. The angular speckle correlation coefficient is found to be symmetrical on either side of the transmitted bright spot and decays exponentially with measurement angles.

  9. Sources of aeromagnetic anomalies over Cement oil field (Oklahoma), Simpson oil field (Alaska), and the Wyoming-Idaho-Utah thrust belt

    USGS Publications Warehouse

    Reynolds, R.L.; Fishman, N.S.; Hudson, M.R.

    1991-01-01

    Geochemical and rock magnetic studies, undertaken to determine the causes of magnetic anomalies have revealed different magnetic sources developed under different sedimentologic, geochemical, and structural settings. Results show that abiologic and biologic mechanisms can generate different magnetic sulfide minerals in zones of sulfide hydrocarbon seepage. More commonly, sulfidic seepage could either diminish magnetization by replacement of detrital magnetic minerals with nonmagnetic sulfide minerals, or it would have no effect on magnetization if such detrital minerals were originally absent. An important negative result is the absence of abundant secondary (diagenetic) magnetite in the seepage environments. Although secondary magnetite occurs in some biodegraded crude oils, concentrations of such magnetite capable of producing aeromagnetic anomalies have not been documented. -from Authors

  10. Geological and Geochemical Aspects of the Deep Origin of the Oil Fields of Volga-Ural Region in East-European Platform

    NASA Astrophysics Data System (ADS)

    Plotnikova, Irina

    2010-05-01

    The study area for research is territory of Tatarstan and the South Tatarstan Arch located in the Volgo-Ural Region, which is an enigmatic crustal segment that occupies the eastern third of the East European Craton. The tectonic structure and history of geological development of this region are mainly defined by the fact that Tatarstan is a junction between several first-order tectonic elements. The present-day structure of the crystalline basement is a result of the evolution of the faults and blocks originally formed in Late Proterozoic times and those that partly originated from the older dislocations. The South Tatarstan arch contains Tatarstani largest oil fields - Romashkino, Novo-Elkhovo and Bavli. The analysis of areal and sectional distribution of the oil fields has allowed the tracing of the close link between the oil bearing capacity of the sedimentary cover and the block structure of the basement. All the oil fields above the South Tatarstan arch are controlled by the faults crosscutting the crystalline basement and the sedimentary cover. Oil accumulations in the lower productive strata of the sedimentary cover are confined to the basement zones with the maximum degree of tectonic fracturing and to the fault-intersection nodes. Genetic identity of oils and bitumens of the sedimentary cover, and the confinement of oil pools to tectonic faults confirm the role of the vertical migration it plays in the formation of commercial oil and bitumen accumulations in the Palaeozoic sedimentary sequences. The report contains data of analyse the distribution of oil in the sedimentary cover of Tatarstan in general and the location of the Romashkino oil field in particular from a new viewpoint, in their relation to the following factors: the composition and tectonomagmatic evolution of the crystalline basement in the pre-platform stage of its development; the fluid dynamic evolution in Phanerozoic times; and neotectonic processes. Cumulative oil production in Tatarstan has already reached 3.1 B tons, thus substantially exceeding hydrocarbons quantity, calculated geochemically on the basis of the Paleozoic source rock potentials of all sedimentary strata. The insufficient maturity of organic matter in Domanic clay-cilicon-carbonate formations obviously shows the impossibility for the commercial amounts of hydrocarbons of being generated from the available material of the sedimentary cover. Integrated analysis of deep drilling, geological data, geochemical characteristics of oil composition and trace elements of oil, geochemistry of dispersed organic matter of Devonian and Carboniferous deposits except the remote migration of oil from the sedimentary strata of the Urals Foredeep and Prikaspian depression toward the South Tatarstan Arch. Dominated role of the deep factors in generation of oil is grounded by results of deep drilling and geological, geochemical, geophysical investigations.

  11. The effect of an oil drilling operation on the trace metal concentrations in offshore bottom sediments of the Campos Basin oil field, SE Brazil.

    PubMed

    Rezende, C E; Lacerda, L D; Ovalle, A R C; Souza, C M M; Gobo, A A R; Santos, D O

    2002-07-01

    The concentrations of Al, Fe, Mn, Zn, Cu, Pb, Ni, Cr, Ba, V, Sn and As in offshore bottom sediments from the Bacia de Campos oil field, SE Brazil, were measured at the beginning and at 7 months after completion of the drilling operation. Concentrations of Al, Fe, Ba, Cr, Ni and Zn were significantly higher closer to the drilling site compared to stations far from the site. Average concentrations of Al, Cu, and in particular of Ni, were significantly higher at the end of the drilling operation than at the beginning. Comparison between drilling area sediments with control sediments of the continental platform, however, showed no significant difference in trace metal concentrations. Under the operation conditions of this drilling event, the results show that while changes in some trace metal concentrations do occur during drilling operations, they are not significantly large to be distinguished from natural variability of the local background concentrations. PMID:12222892

  12. Increasing heavy oil reserves in the Wilmington oil field through advanced reservoir characterization and thermal production technologies. Quarterly report, July 1 - September 30, 1996

    SciTech Connect

    Hara, S. [Tidelands Oil Production Co., Long Beach, CA (United States)

    1996-12-01

    The project involves improving thermal recovery techniques in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., Calif. using advanced reservoir characterization and thermal production technologies. This is the sixth quarterly technical progress report for the project. Through September 1996, the project continues to make good progress but is slightly behind schedule. Estimated costs are on budget for the work performed to date. Technical achievements accomplished during the quarter include placing the first two horizontal wells on production following cyclic steam stimulation, completing several draft technical reports and preparing presentations on the deterministic geologic model, steam channel crossing and horizontal well drilling for technical transfer. Cyclic steam injection into the first two horizontal wells was completed in June 1996 and initial oil production from the project began the same month. Work has commenced on the stochastic geologic and reservoir simulation models. High temperature core work and reservoir tracer work will commence in the First Quarter 1997.

  13. Excito-repellency of essential oils against an Aedes aegypti (L.) field population in Thailand.

    PubMed

    Boonyuan, Wasana; Grieco, John P; Bangs, Michael J; Prabaripai, Atchariya; Tantakom, Siripun; Chareonviriyaphap, Theeraphap

    2014-06-01

    An investigation of the behavioral responses of Aedes aegypti (= Stegomyia aegypti) to various concentrations of essential oils (2.5, 5, and 10%) extracted from hairy basil (Ocimum americanum Linn), ginger (Zingiber officinale Roscoe), lemongrass (Cymbopogon citratus Stapf), citronella grass (Cymbopogon nardus Rendle), and plai (Zingiber cassumunar Roxb) were performed using an excito-repellency test chamber. Results showed that Ae. aegypti exhibited varying levels of escape response in both the contact and noncontact chambers in response to different essential oils. The magnitude of the behaviors changed in a dose-response fashion depending on the percent volume to volume concentration of oil used. A 2.5% concentration of hairy basil oil produced a significantly greater escape response compared to the other extracts at the same concentration (P< 0.05). Oils of ginger, lemongrass, and citronella produced stronger irritant and repellent responses at the median 5% concentration compared to the lowest and highest concentrations. There was marked suppression of escape for both contact and noncontact tests using 10% concentrations of hairy basil, lemongrass, and citronella, with high knockdown for all three oils after 30 min. Hairy basil and lemongrass had the highest insecticidal activity to Ae. aegypti, with LC50 values of 6.3 and 6.7 percent, respectively. We conclude that the essential oils from native plants tested, and likely many other extracts found in plants, have inherent repellent and irritant qualities that should to be screened and optimized for their behavior-modifying properties against Ae. aegypti and other biting arthropods of public health and pest importance. PMID:24820563

  14. Litho-geophysical structure of Paleozoic-Mesozoic contact zones in North-Ostaninsk oil field (Tomsk Oblast)

    NASA Astrophysics Data System (ADS)

    Ezhova, A.; Merkulov, V.; Chekanstev, V.; Abramova, R.

    2015-02-01

    A multidiscipline seismic and gravimagnetic survey, as well as paleomagnetic and lithologic-stratigraphic analysis of pre-Jurassic formations were conducted in North- Ostaninsk oil field within south-east Western Siberian petroleum province. A multidirectional tectonic deformation network merging into the destruction zones of Paleozoic basement was identified. The material composition and age of pre-Jurassic formations within each tectonic block were determined. Fundamentally new geological structure model of the Paleozoic suite was proposed : North-Ostaninsk erosion-tectonic protrusion - a reversed and structurally-complex fracture - deformed tectonic syncline fold where the oil reservoir is confined to the dipping limb. Reversed morphostructures in the erosion-tectonic protrusions could be a prospecting indicator in evaluating the hydrocarbon potential of Paleozoic sediments.

  15. ADAPTIVE MANAGEMENT AND PLANNING MODELS FOR CULTURAL RESOURCES IN OIL & GAS FIELDS IN NEW MEXICO AND WYOMING

    SciTech Connect

    Peggy Robinson

    2005-01-01

    This report summarizes activities that have taken place in the last 6 months (July 2004-December 2004) under the DOE-NETL cooperative agreement ''Adaptive Management and Planning Models for Cultural Resources in Oil and Gas Fields, New Mexico and Wyoming'' DE-FC26-02NT15445. This project examines the practices and results of cultural resource investigation and management in two different oil and gas producing areas of the US: southeastern New Mexico and the Powder River Basin of Wyoming. The project evaluates how cultural resource investigations have been conducted in the past and considers how investigation and management could be pursued differently in the future. The study relies upon full database population for cultural resource inventories and resources and geomorphological studies. These are the basis for analysis of cultural resource occurrence, strategies for finding and evaluating cultural resources, and recommendations for future management practices. Activities can be summarized as occurring in either Wyoming or New Mexico.

  16. Field establishment of fourwing saltbush in processed oil shale and disturbed native soil as influenced by vesicular-arbuscular mycorrhizae

    SciTech Connect

    Call, C.A.; McKell, C.M.

    1984-04-30

    Seedlings of fourwing saltbush (Atriplex canescens (Pursh) Nutt.) were inoculated with indigenous vesicular-arbuscular mycorrhizal (VAM) fungi in a containerized system and transplanted into processed oil shale and disturbed native soil in a semiarid rangeland environment in northwestern Colorado. After two growing seasons in the field, plants inoculated with VAM had greater aboveground biomass, cover, and height than noninoculated plants. Mycorrhizal plants were more effective in the uptake of water and phosphorus. Infection levels of inoculated plants were greatly reduced in processed shale (from 13.0 at outplanting to 3.8 at harvest), but functional VAM associations could be found after two growing seasons. Results indicate that VAM help make processed oil shale a more tractable medium for the establishment of plants representative of later successional stages by allowing these plants to make effective use of the natural resources that are limiting under conditions of high stress. 39 references, 1 figure.

  17. Variation of i-butane \\/ n-butane ratio in oils of the Romashkino oil field for the period of 1982–2000: Probable influence of the global seismicity on the fluid migration

    Microsoft Academic Search

    R. Kh. Muslimov; N. N. Sidorova; I. N. Plotnikova

    2006-01-01

    Changes in oil composition in the course of the development depend on numerous factors including both technogenic and natural ones. Physicochemical compositional analysis of 2456 oil samples collected in the Romashkino field in 1982–2000 from two productive strata (Devonian and Carboniferous reservoirs) has indicated statistically significant variations in the i-butane to n-butane content ratio (i-b\\/n-b). This ratio is characterized not only

  18. Control of hydrogen sulfide production in oil fields by managing microbial communities through nitrate or nitrite addition

    NASA Astrophysics Data System (ADS)

    Hubert, Casey R. J.

    Nitrate or nitrite injection into oil reservoirs during water flooding has the potential to control biological souring, the production of hydrogen sulfide (H2S) by sulfate-reducing bacteria (SRB). Souring control is essential because sulfide is toxic, sulfide precipitates can plug reservoir formations, souring lowers crude oil value, and SRB induce corrosion. Nitrate and nitrite can stimulate heterotrophic nitrate- or nitrite-reducing bacteria (hNRB) and nitrate- or nitrite-reducing, sulfide oxidizing bacteria (NRSOB). Nitrite also inhibits SRB activity by blocking the sulfate reduction pathway. Continuous up-flow packed-bed bioreactors were inoculated with produced water from the Coleville oil field to establish sulfide-producing biofilms similar to those found in sour reservoirs. Nitrate or nitrite addition to bioreactors indicated that the dose required for hNRB or NR-SOB to control souring depended on the concentration of oil organics. Either mechanism mediates the net removal of oil organics (lactate) with nitrate or nitrite, with lower doses of nitrate required due to its greater oxidative power. Microbial community analysis by reverse sample genome probing (RSGP) revealed that NR-SOB mediated sulfide removal at low nitrate or nitrite concentrations when lactate was still available to SRB and the redox potential was low. At high nitrate doses hNRB oxidized lactate directly, produced nitrite and maintained a high redox potential, thus excluding SRB activity. Facultatively chemolithotrophic Campylobacter sp. strains were isolated from the bioreactors and incorporated into RSGP analyses, revealing their dominance in both NR-SOB- and hNRB-containing communities. The metabolic flexibility of these strains may confer a competitive advantage over obligate chemolithotrophs like Thiomicrospira sp. strain CVO or hNRB that do not have NR-SOB activity like newly isolated Thauera sp. and Rhodobacter sp. strains. A single high dose of nitrite resulted in immediate inhibition of SRB that was independent of hNRB or NR-SOB. Examination of corrosion coupons following bioreactor experiments revealed that nitrite inhibition was the only mechanism that prevented both souring and corrosion. Sulfide elimination by hNRB or NR-SOB resulted in increased pitting corrosion in the region of greatest microbial activity. These findings are instructive for designing souring control treatments and improve understanding of oil field microbial communities.

  19. Occurrence of oil in the Austin Chalk at Van field, Van Zandt County, Texas: A unique geologic setting

    SciTech Connect

    Lowe, J.T.; Carrington, D.B. (Unocal Corp., Houston, TX (USA))

    1990-09-01

    The Austin Chalk is buried to a depth of only 2,100-2,500 ft and has retained primary microporosity unlike the typical deep fractured chalk reservoirs. The Van structure is a complexly faulted domal anticline created by salt intrusion and is approximately 2,000 ft higher than surrounding structures in the area. A major northwest-dipping fault acts as the primary trapping mechanism. The field has produced 0.5 billion BO from thick Woodbine sands since its discovery in 1929. Occurrence of oil in the Austin Chalk has been known since the field discovery, but prior completions were low rate oil producers. Recent development of a large fracture stimulation technique has resulted in increased production rates of up to 300 BOPD. The Austin Chalk reservoir limits were determined by isopaching feet of minimum productive resistivity having porosity above a cutoff value. The resistivity/porosity isopach showed a direct correlation between Austin Chalk productivity and the Austin Chalk structure and faulting pattern. Structural evidence along with oil typing indicate that the oil in the Austin Chalk has migrated upward along fault planes and through fault juxtaposition from the Woodbine sands 200 ft below the Austin Chalk. Thin-section and scanning electron microscopy work performed on conventional cores showed that the Van Austin Chalk formation is a very fine grained limestone composed primarily of coccoliths. Various amounts of detrital illite clay are present in the coccolith matrix. All effective porosity is micro-intergranular and ranges from 15 to 35%. Based on the core analyses, the main porosity reducing agent and therefore control on reservoir quality is the amount of detrital clay present filling the micropores. Permeability is very low with values ranging from 0.01 to 1.5 md. There is no evidence of significant natural fractures in the core. Artificial fractures are therefore required to create the permeability needed to sustain commercial production rates.

  20. Oil Field Souring Control by Nitrate-Reducing Sulfurospirillum spp. That Outcompete Sulfate-Reducing Bacteria for Organic Electron Donors? †

    PubMed Central

    Hubert, Casey; Voordouw, Gerrit

    2007-01-01

    Nitrate injection into oil reservoirs can prevent and remediate souring, the production of hydrogen sulfide by sulfate-reducing bacteria (SRB). Nitrate stimulates nitrate-reducing, sulfide-oxidizing bacteria (NR-SOB) and heterotrophic nitrate-reducing bacteria (hNRB) that compete with SRB for degradable oil organics. Up-flow, packed-bed bioreactors inoculated with water produced from an oil field and injected with lactate, sulfate, and nitrate served as sources for isolating several NRB, including Sulfurospirillum and Thauera spp. The former coupled reduction of nitrate to nitrite and ammonia with oxidation of either lactate (hNRB activity) or sulfide (NR-SOB activity). Souring control in a bioreactor receiving 12.5 mM lactate and 6, 2, 0.75, or 0.013 mM sulfate always required injection of 10 mM nitrate, irrespective of the sulfate concentration. Community analysis revealed that at all but the lowest sulfate concentration (0.013 mM), significant SRB were present. At 0.013 mM sulfate, direct hNRB-mediated oxidation of lactate by nitrate appeared to be the dominant mechanism. The absence of significant SRB indicated that sulfur cycling does not occur at such low sulfate concentrations. The metabolically versatile Sulfurospirillum spp. were dominant when nitrate was present in the bioreactor. Analysis of cocultures of Desulfovibrio sp. strain Lac3, Lac6, or Lac15 and Sulfurospirillum sp. strain KW indicated its hNRB activity and ability to produce inhibitory concentrations of nitrite to be key factors for it to successfully outcompete oil field SRB. PMID:17308184

  1. Oil field souring control by nitrate-reducing Sulfurospirillum spp. that outcompete sulfate-reducing bacteria for organic electron donors.

    PubMed

    Hubert, Casey; Voordouw, Gerrit

    2007-04-01

    Nitrate injection into oil reservoirs can prevent and remediate souring, the production of hydrogen sulfide by sulfate-reducing bacteria (SRB). Nitrate stimulates nitrate-reducing, sulfide-oxidizing bacteria (NR-SOB) and heterotrophic nitrate-reducing bacteria (hNRB) that compete with SRB for degradable oil organics. Up-flow, packed-bed bioreactors inoculated with water produced from an oil field and injected with lactate, sulfate, and nitrate served as sources for isolating several NRB, including Sulfurospirillum and Thauera spp. The former coupled reduction of nitrate to nitrite and ammonia with oxidation of either lactate (hNRB activity) or sulfide (NR-SOB activity). Souring control in a bioreactor receiving 12.5 mM lactate and 6, 2, 0.75, or 0.013 mM sulfate always required injection of 10 mM nitrate, irrespective of the sulfate concentration. Community analysis revealed that at all but the lowest sulfate concentration (0.013 mM), significant SRB were present. At 0.013 mM sulfate, direct hNRB-mediated oxidation of lactate by nitrate appeared to be the dominant mechanism. The absence of significant SRB indicated that sulfur cycling does not occur at such low sulfate concentrations. The metabolically versatile Sulfurospirillum spp. were dominant when nitrate was present in the bioreactor. Analysis of cocultures of Desulfovibrio sp. strain Lac3, Lac6, or Lac15 and Sulfurospirillum sp. strain KW indicated its hNRB activity and ability to produce inhibitory concentrations of nitrite to be key factors for it to successfully outcompete oil field SRB. PMID:17308184

  2. Floating production platforms and their applications in the development of oil and gas fields in the South China Sea

    NASA Astrophysics Data System (ADS)

    Zhang, Dagang; Chen, Yongjun; Zhang, Tianyu

    2014-03-01

    This paper studies the current available options for floating production platforms in developing deepwater oil fields and the potential development models of future oil and gas exploration in the South China Sea. A detailed review of current deepwater platforms worldwide was performed through the examples of industry projects, and the pros and cons of each platform are discussed. Four types of platforms are currently used for the deepwater development: tension leg platform, Spar, semi-submersible platform, and the floating production system offloading. Among these, the TLP and Spar can be used for dry tree applications, and have gained popularity in recent years. The dry tree application enables the extension of the drilling application for fixed platforms into floating systems, and greatly reduces the cost and complexity of the subsea operation. Newly built wet tree semi-submersible production platforms for ultra deepwater are also getting their application, mainly due to the much needed payload for deepwater making the conversion of the old drilling semi-submersible platforms impossible. These platforms have been used in different fields around the world for different environments; each has its own advantages and disadvantages. There are many challenges with the successful use of these floating platforms. A lot of lessons have been learned and extensive experience accumulated through the many project applications. Key technologies are being reviewed for the successful use of floating platforms for field development, and potential future development needs are being discussed. Some of the technologies and experience of platform applications can be well used for the development of the South China Sea oil and gas field.

  3. Development and field testing of a Light Aircraft Oil Surveillance System (LAOSS)

    NASA Technical Reports Server (NTRS)

    Burns, W.; Herz, M. J.

    1976-01-01

    An experimental device consisting of a conventional TV camera with a low light level photo image tube and motor driven polarized filter arrangement was constructed to provide a remote means of discriminating the presence of oil on water surfaces. This polarized light filtering system permitted a series of successive, rapid changes between the vertical and horizontal components of reflected polarized skylight and caused the oil based substances to be more easily observed and identified as a flashing image against a relatively static water surface background. This instrument was flight tested, and the results, with targets of opportunity and more systematic test site data, indicate the potential usefulness of this airborne remote sensing instrument.

  4. Environmental assessment of Buccaneer gas and oil field in the northwestern Gulf of Mexico, 1978-1979. Volume V. Effects of gas and oil field structures and effluents on fouling community production and function. Annual report

    SciTech Connect

    Howard, R.L.; Boland, G.S.; Gallaway, B.J.; Dennis, G.D.

    1980-12-01

    Research performed during 1978-79 was designed to obtain additional information about the effects of offshore platforms and effluents on biofouling communities and to obtain information about the functioning of the system. Produced water was confirmed to be characterized by a high oxygen demand and to increase the respiratory rates of the biofouling community. Stations near the produced water discharge were observed to have significantly lower biofouling biomass than other platform supports and platforms with produced water discharges had lower microalgae biomass than control structures. Sets of the small barnacle species are typically overgrown by B. tintinnabulum in the Buccaneer Oil Field.

  5. Activities of the Oil Implementation Task Force, December 1990--February 1991; Contracts for field projects and supporting research on enhanced oil recovery, April--June 1990

    SciTech Connect

    Tiedemann, H.A. (ed.) (USDOE Bartlesville Project Office, OK (USA))

    1991-03-01

    The Oil Implementation Task Force was appointed to implement the US DOE's new oil research program directed toward increasing domestic oil production by expanded research on near- or mid-term enhanced oil recovery methods. An added priority is to preserve access to reservoirs that have the largest potential for oil recovery, but that are threatened by the large number of wells abandoned each year. This report describes the progress of research activities in the following areas: chemical flooding; gas displacement; thermal recovery; resource assessment; microbial technology; geoscience technology; and environmental technology. (CK)

  6. The movement of a conducting particle in transformer oil in AC fields

    Microsoft Academic Search

    S. Birlasekaran

    1993-01-01

    A theoretical model is proposed and used to analyze the movement of a small conducting sphere stressed with alternating voltage in transformer oil. The model is verified by comparing it with the experimental observations of a metal particle of radius 0.5 mm in an electrode gap of 8 mm stressed with AC voltage. The model suggests that for practically existing

  7. Electrical heating of oil reservoirs; Numerical simulation and field test results

    SciTech Connect

    Pizzarro, J.O.S. (Petrobras, Bahia (BR)); Trevisan, O.V. (Universidade Estadual de Campinas, SP (Brazil))

    1990-10-01

    This paper presents the development of a numerical model designed to simulate EOR by in-situ electric heating. The paper includes the results of validation tests vs. analytical solutions, comparisons of oil production and energy consumption for different electrode schemes, and the results of simulations of the Rio Panon, Brazil, pilot test.

  8. Electromagnetic oil field mapping for improved process monitoring and reservoir characterization: A poster presentation

    SciTech Connect

    Waggoner, J.R.; Mansure, A.J.

    1992-02-01

    This report is a permanent record of a poster paper presented by the authors at the Third International Reservoir Characterization Technical Conference in Tulsa, Oklahoma on November 3--5, 1991. The subject is electromagnetic (EM) techniques that are being developed to monitor oil recovery processes to improve overall process performance. The potential impact of EM surveys is very significant, primarily in the areas of locating oil, identifying oil inside and outside the pattern, characterizing flow units, and pseudo-real time process control to optimize process performance and efficiency. Since a map of resistivity alone has little direct application to these areas, an essential part of the EM technique is understanding the relationship between the process and the formation resistivity at all scales, and integrating this understanding into reservoir characterization and simulation. First is a discussion of work completed on the core scale petrophysics of resistivity changes in an oil recovery process; a steamflood is used as an example. A system has been developed for coupling the petrophysics of resistivity with reservoir simulation to simulate the formation resistivity structure arising from a recovery process. Preliminary results are given for an investigation into the effect of heterogeneity and anisotropy on the EM technique, as well as the use of the resistivity simulator to interpret EM data in terms of reservoir and process parameters. Examples illustrate the application of the EM technique to improve process monitoring and reservoir characterization.

  9. A new generation of electromagnetic and ultrasonic techniques for subsurface evaluation of oil field tubulars

    Microsoft Academic Search

    1988-01-01

    In the past few years, corrosion and mechanical fatigue have been becoming a more visible issue in the oil and gas industry. The issue of lost profits from lost production and the cost and liability resulting from failure has overcome the obvious concern of simple mechanical integrity. A new generation of tool designs have been developed for in-situ evaluation of

  10. A Multifrequency Polarimetric SAR Processing Chain to Observe Oil Fields in the Gulf of Mexico

    Microsoft Academic Search

    Maurizio Migliaccio; Ferdinando Nunziata; Antonio Montuori; Xiaofeng Li; William G. Pichel

    2011-01-01

    Within the National Environmental Satellite, Data, and Information Service, National Oceanic and Atmospheric Ad- ministration, multiplatform synthetic aperture radar (SAR) im- agery is being used to aid posthurricane and postaccident response efforts in the Gulf of Mexico, such as in the case of the recent Deepwater Horizon oil spill. The main areas of interest related to such disasters are the

  11. Sedimentation, zoning of reservoir rocks in W. Siberian basin oil fields

    Microsoft Academic Search

    Kliger

    1994-01-01

    A line pattern of well cluster spacing was chosen in western Siberia because of taiga, marshes, etc., on the surface. The zoning of the oil pools within productive Upper Jurassic J[sub 3] intervals is complicated. This is why until the early 1990s almost each third well drilled in the Shaimsky region on the western edge of the West Siberian basin

  12. Field applications of the piscine anaphase aberration test: lessons from the Exxon Valdez oil spill.

    PubMed

    Hose, J E; Brown, E D

    1998-03-20

    Several large-scale genotoxicity assessments have been performed in coastal marine areas that have demonstrated either localized or widespread genetic effects resulting from human activity. One common assessment method is the anaphase aberration test, a measurement of abnormal chromosome division, using embryolarval fishes. It can be used to detect the presence of mutagens within a poorly characterized complex mixture or monitor specific genotoxins and is easily adapted for laboratory screening. One comprehensive marine genotoxicity assessment was conducted using Pacific herring (Clupea pallasi) following the Exxon Valdez oil spill (EVOS) in Prince William Sound (PWS), AK in late March 1989. In early May, genetic damage was detected at many sites within the oil trajectory and was correlated with concentrations of polycyclic aromatic hydrocarbons characteristic of Exxon Valdez oil (EVO) in intertidal mussels. Effects were related spatially and temporally to oil exposure. Anaphase aberration rates decreased throughout May and June 1989, and by 1991, genotoxicity was undetectable. The abundance of the 1989 herring year class in PWS is significantly reduced; this is the first reported example linking genotoxicity to subsequent population level effects. This review describes the methodology for the anaphase aberration test using fish eggs, its applications for large-scale assessments and supportive laboratory studies, and its limitations for prediction of higher level effects on populations. PMID:9672658

  13. Contracts for field projects and supporting research on enhanced oil recovery. Progress review number 87

    SciTech Connect

    NONE

    1997-10-01

    Approximately 30 research projects are summarized in this report. Title of the project, contract number, company or university, award amount, principal investigators, objectives, and summary of technical progress are given for each project. Enhanced oil recovery projects include chemical flooding, gas displacement, and thermal recovery. Most of the research projects though are related to geoscience technology and reservoir characterization.

  14. Chromosomal aberrations in lymphocytes of employees in transformer and generator production exposed to electromagnetic fields and mineral oil.

    PubMed

    Skyberg, K; Hansteen, I L; Vistnes, A I

    2001-04-01

    The objective was to study the risk of cytogenetic damage among high voltage laboratory workers exposed to electromagnetic fields and mineral oil. This is a cross sectional study of 24 exposed and 24 matched controls in a Norwegian transformer factory. The exposure group included employees in the high voltage laboratory and in the generator soldering department. Electric and magnetic fields and oil mist and vapor were measured. Blood samples were analyzed for chromosomal aberrations in cultured lymphocytes. In addition to conventional cultures, the lymphocytes were also treated with hydroxyurea and caffeine. This procedure inhibits DNA synthesis and repair in vitro, revealing in vivo genotoxic lesions that are repaired during conventional culturing. In conventional cultures, the exposure group and the controls showed similar values for all cytogenetic parameters. In the DNA synthesis- and repair-inhibited cultures, generator welders showed no differences compared to controls. Among high voltage laboratory testers, compared to the controls, the median number of chromatid breaks was doubled (5 vs. 2.5 per 50 cells; P<0.05) the median number of chromosome breaks was 2 vs. 0.5 (P>0.05) and the median number of aberrant cells was 5 vs. 3.5 (P<0.05). Further analysis of the inhibited culture data from this and a previous study indicated that years of exposure and smoking increase the risk of aberrations. We conclude that there was no increase in cytogenetic damage among exposed workers compared to controls in the conventional lymphocyte assay. In inhibited cultures, however, there were indications that electromagnetic fields in combination with mineral oil exposure may produce chromosomal aberrations. PMID:11255210

  15. Application of denaturing high-performance liquid chromatography for monitoring sulfate-reducing bacteria in oil fields.

    PubMed

    Priha, Outi; Nyyssönen, Mari; Bomberg, Malin; Laitila, Arja; Simell, Jaakko; Kapanen, Anu; Juvonen, Riikka

    2013-09-01

    Sulfate-reducing bacteria (SRB) participate in microbially induced corrosion (MIC) of equipment and H2S-driven reservoir souring in oil field sites. Successful management of industrial processes requires methods that allow robust monitoring of microbial communities. This study investigated the applicability of denaturing high-performance liquid chromatography (DHPLC) targeting the dissimilatory sulfite reductase ß-subunit (dsrB) gene for monitoring SRB communities in oil field samples from the North Sea, the United States, and Brazil. Fifteen of the 28 screened samples gave a positive result in real-time PCR assays, containing 9 × 10(1) to 6 × 10(5) dsrB gene copies ml(-1). DHPLC and denaturing gradient gel electrophoresis (DGGE) community profiles of the PCR-positive samples shared an overall similarity; both methods revealed the same samples to have the lowest and highest diversity. The SRB communities were diverse, and different dsrB compositions were detected at different geographical locations. The identified dsrB gene sequences belonged to several phylogenetic groups, such as Desulfovibrio, Desulfococcus, Desulfomicrobium, Desulfobulbus, Desulfotignum, Desulfonatronovibrio, and Desulfonauticus. DHPLC showed an advantage over DGGE in that the community profiles were very reproducible from run to run, and the resolved gene fragments could be collected using an automated fraction collector and sequenced without a further purification step. DGGE, on the other hand, included casting of gradient gels, and several rounds of rerunning, excising, and reamplification of bands were needed for successful sequencing. In summary, DHPLC proved to be a suitable tool for routine monitoring of the diversity of SRB communities in oil field samples. PMID:23793633

  16. Application of Denaturing High-Performance Liquid Chromatography for Monitoring Sulfate-Reducing Bacteria in Oil Fields

    PubMed Central

    Nyyssönen, Mari; Bomberg, Malin; Laitila, Arja; Simell, Jaakko; Kapanen, Anu; Juvonen, Riikka

    2013-01-01

    Sulfate-reducing bacteria (SRB) participate in microbially induced corrosion (MIC) of equipment and H2S-driven reservoir souring in oil field sites. Successful management of industrial processes requires methods that allow robust monitoring of microbial communities. This study investigated the applicability of denaturing high-performance liquid chromatography (DHPLC) targeting the dissimilatory sulfite reductase ß-subunit (dsrB) gene for monitoring SRB communities in oil field samples from the North Sea, the United States, and Brazil. Fifteen of the 28 screened samples gave a positive result in real-time PCR assays, containing 9 × 101 to 6 × 105 dsrB gene copies ml?1. DHPLC and denaturing gradient gel electrophoresis (DGGE) community profiles of the PCR-positive samples shared an overall similarity; both methods revealed the same samples to have the lowest and highest diversity. The SRB communities were diverse, and different dsrB compositions were detected at different geographical locations. The identified dsrB gene sequences belonged to several phylogenetic groups, such as Desulfovibrio, Desulfococcus, Desulfomicrobium, Desulfobulbus, Desulfotignum, Desulfonatronovibrio, and Desulfonauticus. DHPLC showed an advantage over DGGE in that the community profiles were very reproducible from run to run, and the resolved gene fragments could be collected using an automated fraction collector and sequenced without a further purification step. DGGE, on the other hand, included casting of gradient gels, and several rounds of rerunning, excising, and reamplification of bands were needed for successful sequencing. In summary, DHPLC proved to be a suitable tool for routine monitoring of the diversity of SRB communities in oil field samples. PMID:23793633

  17. Adaptive Management and Planning Models for Cultural Resources in Oil and Gas Fields in New Mexico and Wyoming

    SciTech Connect

    Eckerle, William; Hall, Stephen

    2005-12-30

    In 2002, Gnomon, Inc., entered into a cooperative agreement with the U.S. Department of Energy (DOE) National Energy Technology Laboratory (NETL) for a project entitled, Adaptive Management and Planning Models for Cultural Resources in Oil and Gas Fields in New Mexico and Wyoming (DE-FC26-02NT15445). This project, funded through DOE’s Preferred Upstream Management Practices grant program, examined cultural resource management practices in two major oil- and gas-producing areas, southeastern New Mexico and the Powder River Basin of Wyoming (Figure 1). The purpose of this project was to examine how cultural resources have been investigated and managed and to identify more effective management practices. The project also was designed to build information technology and modeling tools to meet both current and future management needs. The goals of the project were described in the original proposal as follows: Goal 1. Create seamless information systems for the project areas. Goal 2. Examine what we have learned from archaeological work in the southeastern New Mexico oil fields and whether there are better ways to gain additional knowledge more rapidly or at a lower cost. Goal 3. Provide useful sensitivity models for planning, management, and as guidelines for field investigations. Goal 4. Integrate management, investigation, and decision- making in a real-time electronic system. Gnomon, Inc., in partnership with the Wyoming State Historic Preservation Office (WYSHPO) and Western GeoArch Research, carried out the Wyoming portion of the project. SRI Foundation, in partnership with the New Mexico Historic Preservation Division (NMHPD), Statistical Research, Inc., and Red Rock Geological Enterprises, completed the New Mexico component of the project. Both the New Mexico and Wyoming summaries concluded with recommendations how cultural resource management (CRM) processes might be modified based on the findings of this research.

  18. Reservoir characterization, three-dimensional geological modeling, and reservoir simulation of North Blowhorn Creek Oil Field, Lamar County, Alabama

    NASA Astrophysics Data System (ADS)

    Panetta, Brian

    North Blowhorn Creek Oil Field is located in northeastern Lamar County, Alabama. The field was unitized and a water flood project started in 1983. In 1992, a microbial permeability profile modification project began as a result of continued declining production. The original oil in place was estimated to be 16 million barrels. The Carter sandstone lies within the Carter interval which is underlain by the Bangor Limestone and is overlain by the Millerella limestone. The depositional model proposed interprets the Carter sandstone, at North Blowhorn Creek Field, as a delta-destructive barrier island spit complex characterized by spit accretion and later drowned and covered by open shelf deposits. Eight facies were identified within the Carter interval from describing 20 well cores. The Carter is an elongate sand body that trends northwest to southeast. The primary reservoir facies is the foreshore/upper shoreface facies. The trapping mechanism is stratigraphic. Reservoir characterization and modeling of the Carter sandstone has the potential to improve field-scale reservoir management. Resistivity logs were used to identify reservoir rocks in wells without core. 3-D modeling shows the heterogeneous nature of the reservoir facies. Heterogeneities within the reservoir reduce waterflood sweep efficiency across the main axis of the reservoir in the field. Flow is also restricted along the axis of the sand body due in part to spit accretion. The purpose of this study was to integrate 3-D geologic modeling, decline curve and type curve analysis and reservoir simulation to characterize the geology, geometry and flow characteristics of North Blowhorn Creek Oil Field in an effort to provide a reservoir management strategy to increase the ultimate recovery from the field. Decline curve analysis was performed for all production wells to calculate an estimated ultimate recovery (EUR) and amount of remaining reserves for each well. Type curve analysis was performed in an effort to characterize the effectiveness of the water flood and MPPM projects. A reservoir simulation was performed based on the 3-D geologic model that was constructed in a previous study. The simulation work was an effort to find areas of remaining reserves and validate the geologic model.

  19. Electric-fields-enhanced destabilization of oil-in-water emulsions flowing through a confined wedgelike gap

    NASA Astrophysics Data System (ADS)

    Xie, Guoxin; Luo, Jianbin; Liu, Shuhai; Guo, Dan; Zhang, Chenhui

    2010-09-01

    External electric fields (EEFs) have been applied on a wedgelike gap in a ball-disk configuration, through which oil-in-water (O/W) emulsions flowed. The film formation properties of O/W emulsions in the contact region between the ball and the disk, which is closely related to the stability of oil droplets in the wedgelike gap, have been investigated experimentally. It is found that the film formation property of emulsions in the contact region increases with the EEF strength, but tends to saturate after a critical EEF strength was reached. For the emulsion with a larger oil concentration, it can be enhanced by EEFs more dramatically. The change in the film formation property is more significant when EEFs were applied in emulsions with relatively high emulsifier concentrations, however, the droplet stability is higher in the emulsions with low emulsifier concentrations even when EEFs were applied. The ability of the deformation and breakup of droplets under EEFs in the wedge was also analyzed theoretically to correlate with the experimental results.

  20. Assessment of the potential environmental fate and effects of oil-field discharge waters containing {sup 226}radium

    SciTech Connect

    Herrera, A.W.; Hill, S.L.; Bergman, H.L. [Univ. of Wyoming, Laramie, WY (United States). Dept. of Zoology and Physiology

    1994-12-31

    The naturally occurring radionuclide, radium-226, has been detected in oil production waters in all regions of the country. A produced water discharge into the Loch Katrina wetland in Park County, WY was investigated with respect to the transport and fate of radium in surface waters. The 866-acre Loch Katrina wetland complex is sustained primarily by oil-field produced waters and provides habitat for many species of aquatic birds. While the short-term benefits of this discharge are indisputable, the long-term hazards posed by the transport of radium from deep aquifers to surface waters are not well understood. Guidelines regulating the management of radium-contaminated sediments in receiving waters or settling ponds in Wyoming have yet to be established. The purpose of this study was to provide information to regional regulatory agencies and the oil and gas industry in the development of guidelines and procedures for managing radium and other naturally occurring radioactive materials. The authors will report the results of the sampling survey of produced waters, sediment and biota performed in the Loch Katrina wetland complex in Wyoming.

  1. Applications of EOR (enhanced oil recovery) technology in field projects--1990 update

    SciTech Connect

    Pautz, J.F.; Thomas, R.D.

    1991-01-01

    Trends in the type and number of US enhanced oil recovery (EOR) projects are analyzed for the period from 1980 through 1989. The analysis is based on current literature and news media and the Department of Energy (DOE) EOR Project Data Base, which contains information on over 1,348 projects. The characteristics of the EOR projects are grouped by starting date and process type to identify trends in reservoir statistics and applications of process technologies. Twenty-two EOR projects starts were identified for 1989 and ten project starts for 1988. An obvious trend over recent years has been the decline in the number of project starts since 1981 until 1988 which corresponds to the oil price decline during that period. There was a modest recovery in 1989 of project starts, which lags the modest recovery of oil prices in 1987 that was reconfirmed in 1989. During the time frame of 1980 to 1989, there has been a gradual improvement in costs of operation for EOR technology. The perceived average cost of EOR has gone down from a $30/bbl range to low $20/bbl. These costs of operation seems to stay just at the price of oil or slightly above to result in marginal profitability. The use of polymer flooding has drastically decreased both in actual and relative numbers of project starts since the oil price drop in 1986. Production from polymer flooding is down more than 50%. Long-term plans for large, high-cost projects such as CO{sub 2} flooding in West Texas, steamflooding in California, and hydrocarbon flooding on the North Slope have continued to be implemented. EOR process technologies have been refined to be more cost effective as shown by the continued application and rising production attributable to EOR. 8 refs., 6 figs., 13 tabs.

  2. Effect of the Exxon Valdez oil spill on intertidal fish: A field study

    SciTech Connect

    Barber, W.E. [Univ. of Alaska, Fairbanks, AK (United States)] [Univ. of Alaska, Fairbanks, AK (United States); McDonald, L.L.; Erickson, W.P. [Western Ecosystems Technology, Cheyenne, WY (United States)] [and others] [Western Ecosystems Technology, Cheyenne, WY (United States); and others

    1995-07-01

    The purpose of this study was to evaluate the impact of the March 1989 Exxon Valdez oil spill and subsequent cleanup activities on density, biomass, and species diversity of intertidal fishes in Prince William Sound, Alaska. Intertidal fish were sampled in a quasi-experimental, matched-pairs (oiled-cleaned versus reference sites) design stratified by three habitat types with random selection of oiled-cleaned (O-C) sites. Site pairs were sampled twice in 1990 and in 1991. Of 21 fish taxa, 5 made up 98% and 1 made up 74% of total abundance. There were no significant differences in species diversity between reference and O-C sites. Density, however, was significantly greater at reference sites for all habitats combined for both visits in 1990. In contrast, density in 1991 was about equal at reference and O-C sites. Total biomass for all habitats combined was greater at reference than O-C sites during both visits in 1990, but differences were not statistically significant. In 1991, however, the total biomass at reference and O-C sites was about equal. Forward stepwise multiple logistic regression models indicated that presence of oil was a significant predictor of reduced density at mid-intertidal levels in 1990 but not in 1991. From the general pattern of lower density and biomass on O-C sites in 1990 followed by no significant differences in 1991 and corroborating evidence of multiple-regression modeling, we conclude that the presence of oil and subsequent cleanup activities had a negative impact on intertidal fishes in 1990 and that there was evidence that recovery was underway in 1991. 50 refs., 6 figs., 6 tabs.

  3. Increased Oil Production and Reserves from Improved Completion Techniques in the Bluebell Field, Uinta Basin, Utah, Class I

    SciTech Connect

    Morgan, Craig D.; Gwynn, Wallace; Deo, Milind D.; Jarrard, Richard; Curtice, Richard; Morris, Thomas H.; Smouse, DeForrest; Tripp, Carol N.

    2000-01-20

    The objective of this project was to increase oil production and reserves by the use of improved reservoir characterization and completion techniques in the Unita Basin Utah. To accomplish this objective, a two-year geologic and engineering characterization of the Bluebell field was conducted. The study evaluated surface and subsurface data, currently used completion techniques, and common production problems. It was determined that advanced case- and open-hole logs could be effective in determining productive beds and that staged-interval (about 500 ft [150 m] per stage) and bed-scale isolation completion techniques could result in improved well performance.

  4. Standard practice for evaluating and qualifying oil field and refinery corrosion inhibitors using the rotating cylinder electrode

    E-print Network

    American Society for Testing and Materials. Philadelphia

    2006-01-01

    1.1 This practice covers a generally accepted procedure to use the rotating cylinder electrode (RCE) for evaluating corrosion inhibitors for oil field and refinery applications in defined flow conditions. 1.2 The values stated in SI units are to be regarded as the standard. The values given in parentheses are for information only. This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety and health practices and determine the applicability of regulatory limitations prior to use.

  5. Caribou distribution during the post-calving period in relation to infrastructure in the Prudhoe Bay oil field, Alaska

    USGS Publications Warehouse

    Cronin, M.A.; Amstrup, Steven C.; Durner, G.M.; Noel, L.E.; McDonald, T.L.; Ballard, W.B.

    1998-01-01

    There is concern that caribou (Rangifer tarandus) may avoid roads and facilities (i.e., infrastructure) in the Prudhoe Bay oil field (PBOF) in northern Alaska, and that this avoidance can have negative effects on the animals. We quantified the relationship between caribou distribution and PBOF infrastructure during the post-calving period (mid-June to mid-August) with aerial surveys from 1990 to 1995. We conducted four to eight surveys per year with complete coverage of the PBOF. We identified active oil field infrastructure and used a geographic information system (GIS) to construct ten 1 km wide concentric intervals surrounding the infrastructure. We tested whether caribou distribution is related to distance from infrastructure with a chi-squared habitat utilization-availability analysis and log-linear regression. We considered bulls, calves, and total caribou of all sex/age classes separately. The habitat utilization-availability analysis indicated there was no consistent trend of attraction to or avoidance of infrastructure. Caribou frequently were more abundant than expected in the intervals close to infrastructure, and this trend was more pronounced for bulls and for total caribou of all sex/age classes than for calves. Log-linear regression (with Poisson error structure) of numbers of caribou and distance from infrastructure were also done, with and without combining data into the 1 km distance intervals. The analysis without intervals revealed no relationship between caribou distribution and distance from oil field infrastructure, or between caribou distribution and Julian date, year, or distance from the Beaufort Sea coast. The log-linear regression with caribou combined into distance intervals showed the density of bulls and total caribou of all sex/age classes declined with distance from infrastructure. Our results indicate that during the post-calving period: 1) caribou distribution is largely unrelated to distance from infrastructure; 2) caribou regularly use habitats in the PBOF; 3) caribou often occur close to infrastructure; and 4) caribou do not appear to avoid oil field infrastructure.

  6. Composition and physical properties of siliceous and clay-siliceous reservoir rock in the Okruzhnoye oil field (Sakhalin Island)

    SciTech Connect

    Yurochko, A.I.

    1982-11-01

    Siliceous rocks occur extensively in sedimentary basins in the northern part of the Pacific Mobile Belt. The Okruzhnoye field consists of such rocks. Its main productive horizon is the Pilengskaya Formation, of Miocene age, ranging from 100 to 500 meters in thickness or more and consisting of thin interbedded pelitomorphic siliceous and clay-siliceous rock with a few thin intercalcations of tuff, sandstone, and aleurolite. The productive beds are covered by argillaceous rock and form a stratigraphic trap about 600 meters thick which is filled with oil almost to the spill point. In this paper, the geochemical composition and physical properties of this reservoir are detailed. (JMT)

  7. Revitalizing mature miocene reservoirs in NE Anzoategui: A sequence stratigraphic perspective in the Quiamare and La Celba oil fields

    SciTech Connect

    Galeazzi, S.; Paredes, S.; Dellape, D.; Moroder, G. [Astra, Anzoategui (Venezuela)

    1996-08-01

    A large proportion of the oil reserves discovered in NE Anzoategui are contained in the 3000-m-thick Lower to Middle Miocene strata of the Oficina Formation. Light oil and gas are contained in multiple sandstone reservoirs. Most producing zones are isolated by shale separators, and feature independent fluid contacts. Individual producing zones are laterally extensive, but locally they show interruptions and considerable internal heterogeneity. Reservoir compartmentalization is due to second or third order accommodation faulting and stratigraphic terminations. Sandstones yielding commercial production range in thicknesses from 10 to 50 ft, and contain intergranular porosities that vary from 6 to 24%. Conjugate-type subvertical fractures locally provide the difference between commercial and non-commercial flow rates in low porosity sandstones. Typically, drive style varies from dissolved gas drive and gas cap expansion to natural water drive where unaltered oil coexists with meteoric water. The Miocene series are widespread deposits represented by two major transgressive-regressive genetic packages. Observation of facies, parasequence stacking and stratal termination patterns suggests the presence of at least ten depositional sequences. Strata patterns, lithologic and paleontologic criteria indicate that sedimentation took place within a low relief (ramp-type) depositional setting, in depositional environments ranging from coastal plain through estuarine and shallow marine. Individual producing zones represent a variety of systems tracts, which include transgressive systems tracts, lowstand prograding complexes, and less commonly incised valley fill and highstand deposits. A sequence stratigraphic analysis of the reservoirs in the mature Quiamare oil field has led to the delineation and development of important additional shallow reserves.

  8. Toxicology of oil field wastes. Hazards to livestock associated with the petroleum industry.

    PubMed

    Edwards, W C

    1989-07-01

    In oil-producing states, the proximity of livestock to drilling operations and production sites often results in poisoning of animals from ingestion of crude oil, condensate, salt water, heavy metals, and caustic chemicals. The heavy metals encountered most frequently are lead from pipe joint compound and arsenicals and chromates used as corrosion inhibitors. Numerous toxic and caustic chemicals are used in drilling muds and fluids. Crude oil and salt water spills are common occurrences around production sites. Pipeline breaks may result in exposure of livestock to crude oil or refined petroleum hydrocarbons. Ingestion of petroleum hydrocarbons may result in sudden death from peracute bloat. The most common cause of illness or death following exposure to petroleum hydrocarbons is aspiration pneumonia, which may cause a chronic progressive deterioration of health, with death after several days or weeks. Cases in which livestock are exposed to oil, salt water, or caustic chemicals, but do not die acutely or from aspiration pneumonia are more frustrating to diagnose. In these cases, parasitism, poor nutrition, and other debilitating diseases must be considered. Anorexia, weight loss, and decreased rumen motility may be caused by a disruption of normal rumen function. Petroleum hydrocarbons, salt water, and caustic chemicals have the potential of altering rumen flora and enzymatic processes as well as damaging the ruminal and gastrointestinal epithelium. The toxicity of petroleum hydrocarbons appears to be related more closely to the volatility and viscosity of the product than to other factors. The more volatile straight chain and aromatic petroleum hydrocarbons have a greater potential for aspiration pneumonia and may produce an anesthetic-like action if absorbed systemically. The more volatile petroleum hydrocarbons also are more irritating to skin and mucous membranes and appear to be more damaging to rumen flora. Treatment of petroleum hydrocarbon ingestion is aimed at preventing aspiration pneumonia and the animal's absorption of highly volatile components. Activated charcoal slurries and, in some instances, vegetable oil may be used to absorb the ingested petroleum or alter its viscosity to minimize absorption and aspiration. These procedures should be followed by the administration of rumenatories or saline cathartics to hasten the evacuation of the gastrointestinal tract. Chronic poor performance animals with anorexia and rumen dysfunction may respond to fresh rumen inoculant, intravenous glucose, and B-complex vitamins. Prognosis primarily hinges on whether or not aspiration pneumonia has occurred. Treatment of aspiration pneumonia rarely is effe PMID:2667711

  9. Investigation of high-temperature, igneous-related hydraulic fracturing as a reservoir control in the Blackburn and Grant Canyon/Bacon Flat oil fields, Nevada

    SciTech Connect

    Hulen, J.B.

    1991-01-01

    Research in progress to evaluate natural, igenous-related hydrothermal fracturing as a reservoir control in two eastern Nevada oil fields has revealed evidence of a far more comprehensive role for moderate- to high-temperature hydrothermal systems in Basin-and-Range oil-reservoir evolution. Fluid-inclusion and petrographic studies have shown that (now) oil-bearing dolomite breccias of the Blackburn field (Pine Valley, Eureka County) were formed when overpressured, magmatically-heated, high-temperature (>350{degrees}C) hydrothermal brines explosively ruptured their host rocks; similar studies of texturally identical breccias of the Grant Canyon/Bacon Flat field (Railroad Valley, Nye County) so far do not support such an explosive origin. At Grant Canyon, however, hydrothermal, breccia-cementing quartz hosts primary oil, aqueous/oil, and aqueous fluid inclusions (homogenization temperature = 120{degrees}C) which document a direct geothermal connection for oil migration and entrapment. Moreover, at both Blackburn and Grant Canyon/Bacon Flat, the oil reservoirs are top- and side-sealed by hydrothermally altered Tertiary ignimbrites and epiclastic rocks. Contemporary geothermal activity is also apparent at grant Canyon/Bacon Flat, where subsurface water temperatures reach 171{degrees}C, and at Blackburn, above which a petroleum-providing hot spring issues at a temperature of 90{degrees}C. We suggest that in the Basin and Range province, hydrothermal systems may have: (1) matured oil from otherwise submature source rocks; (2) transported oil to ultimate entrapment sites by convection in moderate-to high-temperature fluids; and (3) sealed reservoir traps through hydrothermal alteration of overlying Tertiary caprocks. 69 refs., 11 figs., 1 tab.

  10. Orgin and significance of geochemical variability among oils and gas-condensates in the Tiger Shoal Field, northern Gulf of Mexico

    SciTech Connect

    Kelley, P.A.; Imbus, S.W. [Texaco E& P Technology, Houston, TX (United States); McKeever, S.R. [Texaco E& P Inc., New Orleans, LA (United States)

    1995-12-31

    Geochemical data placed in geological context is key to understanding the processes controlling the variability of oils and gas-condensates in the Tiger Shoal Field, northern Gulf of Mexico. Thermal maturity at generation and phase partitioning are the principal processes accounting for variability in the bulk and molecular properties of the oils and gas-condensates. Quantification of the extent that these processes altered the oils and gas-condensates between fault blocks and among individual sands permits: (1) documentation of the most effective migration conduits, (2) inference of deeper or shallower pay zones, (3) and assessment of vertical and lateral fluid connectivity. Calibration of bulk to molecular properties will permit rapid assessment of the type and extent of alteration using basic parameters such as API gravity and gas oil ratio (GOR). Upon mass balancing with initial reserves data, a detailed risking scheme for remaining prospects within the field can be formulated.

  11. Study of high-resolution thermal inertia over western India oil fields using ASTER data

    NASA Astrophysics Data System (ADS)

    Nasipuri, P.; Majumdar, T. J.; Mitra, D. S.

    2006-03-01

    Day and consecutive nighttime Advanced Spaceborne Thermal Emission and reflection Radiometer (ASTER) data have been utilized over a part of the Cambay basin, Gujarat, India to generate thermal inertia imagery and has been utilized for exploration of petroliferous basins. Oilfield map, when draped over the high-resolution thermal inertia image, appears to contain low thermal inertia values, after proper masking. This anomaly might have resulted from the nighttime temperature anomaly, which again indicates formation of a complex oil-water immiscible layer, which retards the transfer of heat from the oil deposit to the surroundings. The work has been carried out as a part of joint study for utilization of ASTER data between SAC (ISRO), KDMIPE (ONGC) and ERSDAC, Japan. Color images (Figs. 4-8) are available on web.

  12. The Jinadriyah anticlines: a surface model for oil fields in eastern Saudi Arabia

    Microsoft Academic Search

    Mohammed J. Al-Mahmoud; Mesbah H. Khalil; Adel R. Moustafa

    2009-01-01

    Mesozoic oil in Saudi Arabia exists in north\\/south-oriented anticlines. Such anticlines are usually studied using subsurface\\u000a data. The present study introduces, for the first time in Saudi Arabia, a surface analog for these anticlines. The study covers\\u000a two northerly oriented anticlines located in the Jinadriyah area at 15 km to the northeast of the Riyadh city. They are named\\u000a herein the

  13. Carbon Dioxide Sequestration in Depleted Oil\\/Gas Fields: Evaluation of Gas Microseepage and Carbon Dioxide Fate at Rangely, Colorado USA

    Microsoft Academic Search

    R. W. Klusman

    2002-01-01

    Large-scale CO2 dioxide injection for purposes of enhanced oil recovery (EOR) has been operational at Rangely, Colorado since 1986. The Rangely field serves as an onshore prototype for CO2 sequestration in depleted fields by production of a valuable commodity which partially offsets infrastructure costs. The injection is at pressures considerably above hydrostatic pressure, enhancing the possibility for migration of buoyant

  14. Repellency of hydrogenated catmint oil formulations to black flies and mosquitoes in the field.

    PubMed

    Spero, Niketas C; Gonzalez, Yamaira I; Scialdone, Mark A; Hallahan, David L

    2008-11-01

    The essential oil of catmint, Nepeta cataria L., was hydrogenated to yield an oil enriched in dihydronepetalactone (DHN) diastereomers, termed. This material was used for the preparation of liquid alcohol-based and lotion formulations. The efficacy of these formulations as repellents was tested after application to human test subjects at two locations in the United States: Maine and Florida. In Maine, data on repellency of the hydrogenated catmint oil formulations toward black flies (Simulium decorum Walker) and mosquitoes (primarily Aedes intrudens Dyar) were obtained. In these tests, protection from black flies was conferred for 6 h or more with all formulations, and both liquid and lotion formulations at 15 wt% active ingredient gave complete protection for 7.5 h. All formulations conferred protection from mosquitoes for >4 h, with the best (15 wt% lotion) giving >8 h of complete protection. In Florida, data on repellency toward a mixed population of mosquitoes indicated that all formulations conferred protection for >4 h, with the 15 wt% lotion giving >6 h complete protection from bites. PMID:19058632

  15. Integrated study of the Judy Field (Block 30\\/7a) — an overpressured Central North Sea oil\\/gas field

    Microsoft Academic Search

    R. E Swarbrick; M. J Osborne; D Grunberger; G. S Yardley; G Macleod; A. C Aplin; S. R Larter; I Knight; H. A Auld

    2000-01-01

    The Triassic reservoirs of the Judy Field, an overpressured petroleum accumulation in the Central North Sea, have been studied to determine their pressure and petroleum filling history. The magnitude of overpressure in the Pre-Cretaceous aquifer is similar across the field at about 24MPa (3500psi), but with some higher pressure laterally in areas closest to the major depocentres. Pressure modelling shows

  16. Thermal and mass history of Fairway Field in east Texas: Implication for geothermal energy development in an oil and gas setting

    NASA Astrophysics Data System (ADS)

    Kweik, Ramsey Sharif

    Fairway Field is an oil field operated by Hunt Oil Company located in East Texas near the town of Poynor, Texas in Henderson County. The field was discovered in 1960 and is still producing today with the field life projected beyond 2015 (Webster et al., 2008). Hunt Oil Company granted access to over 2,900 open-hole well logs and pressure surveys for this research project. This thermal and mass history of production from a major hydrocarbon field is an especially rare opportunity, as oil and gas companies in Texas are generally not required to share pressure survey data with regulatory agencies, and thus these types of data are not typically available to the research community. This data set, coupled with fluid production and injection data, provides an opportunity to analyze temperature variations associated with fluid migration and field development as a function of time. Fairway Field was determined to have an average conductive heat flow value of 69 +/- 6 mW/m2. Using fluid production volumes, heat loss was determined to be -1.7 x 1017 Joules which represents a thermal recovery factor of -6.2% for the James Limestone Formation in Fairway Field. Given the fact that the field has been in development for over 50 years and has not exhibited a decrease but an increase in reservoir temperatures (+20 °F over 54 years), Fairway Field illustrates that sedimentary basins have considerable potential for geothermal development. An increased availability of pressure survey temperature data and fluid data from oil and gas companies provides a better understanding of such dynamic geothermal systems, helps evaluate the working life of a field, and is a tool for assessing development risk associated with future geothermal energy development in such settings.

  17. Strontium isotope systematics of mixing groundwater and oil-field brine at Goose Lake in northeastern Montana, USA

    USGS Publications Warehouse

    Peterman, Zell E.; Thamke, Joanna N.; Futa, Kiyoto; Preston, Todd

    2012-01-01

    Groundwater, surface water, and soil in the Goose Lake oil field in northeastern Montana have been affected by Cl?-rich oil-field brines during long-term petroleum production. Ongoing multidisciplinary geochemical and geophysical studies have identified the degree and local extent of interaction between brine and groundwater. Fourteen samples representing groundwater, surface water, and brine were collected for Sr isotope analyses to evaluate the usefulness of 87Sr/86Sr in detecting small amounts of brine. Differences in Sr concentrations and 87Sr/86Sr are optimal at this site for the experiment. Strontium concentrations range from 0.13 to 36.9 mg/L, and corresponding 87Sr/86Sr values range from 0.71097 to 0.70828. The local brine has 168 mg/L Sr and a 87Sr/86Sr value of 0.70802. Mixing relationships are evident in the data set and illustrate the sensitivity of Sr in detecting small amounts of brine in groundwater. The location of data points on a Sr isotope-concentration plot is readily explained by an evaporation-mixing model. The model is supported by the variation in concentrations of most of the other solutes.

  18. Silurian "Clinton" Sandstone Reservoir Characterization for Evaluation of CO2-EOR Potential in the East Canton Oil Field, Ohio

    SciTech Connect

    Riley, Ronald; Wicks, John; Perry, Christopher

    2009-12-30

    The purpose of this study was to evaluate the efficacy of using CO2-enhanced oil recovery (EOR) in the East Canton oil field (ECOF). Discovered in 1947, the ECOF in northeastern Ohio has produced approximately 95 million barrels (MMbbl) of oil from the Silurian “Clinton” sandstone. The original oil-in-place (OOIP) for this field was approximately 1.5 billion bbl and this study estimates by modeling known reservoir parameters, that between 76 and 279 MMbbl of additional oil could be produced through secondary recovery in this field, depending on the fluid and formation response to CO2 injection. A CO2 cyclic test (“Huff-n-Puff”) was conducted on a well in Stark County to test the injectivity in a “Clinton”-producing oil well in the ECOF and estimate the dispersion or potential breakthrough of the CO2 to surrounding wells. Eighty-one tons of CO2 (1.39 MMCF) were injected over a 20-hour period, after which the well was shut in for a 32-day “soak” period before production was resumed. Results demonstrated injection rates of 1.67 MMCF of gas per day, which was much higher than anticipated and no CO2 was detected in gas samples taken from eight immediately offsetting observation wells. All data collected during this test was analyzed, interpreted, and incorporated into the reservoir characterization study and used to develop the geologic model. The geologic model was used as input into a reservoir simulation performed by Fekete Associates, Inc., to estimate the behavior of reservoir fluids when large quantities of CO2 are injected into the “Clinton” sandstone. Results strongly suggest that the majority of the injected CO2 entered the matrix porosity of the reservoir pay zones, where it diffused into the oil. Evidence includes: (A) the volume of injected CO2 greatly exceeded the estimated capacity of the hydraulic fracture and natural fractures; (B) there was a gradual injection and pressure rate build-up during the test; (C) there was a subsequent, gradual flashout of the CO2 within the reservoir during the ensuing monitored production period; and (D) a large amount of CO2 continually off-gassed from wellhead oil samples collected as late as 3½ months after injection. After the test well was returned to production, it produced 174 bbl of oil during a 60-day period (September 22 to November 21, 2008), which represents an estimated 58 percent increase in incremental oil production over preinjection estimates of production under normal, conditions. The geologic model was used in a reservoir simulation model for a 700-acre model area and to design a pilot to test the model. The model was designed to achieve a 1-year response time and a five-year simulation period. The reservoir simulation modeling indicated that the injection wells could enhance oil production and lead to an additional 20 percent recovery in the pilot area over a five-year period. The base case estimated that by injecting 500 MCF per day of CO2 into each of the four corner wells, 26,000 STBO would be produced by the central producer over the five-year period. This would compare to 3,000 STBO if a new well were drilled without the benefit of CO2 injection. This study has added significant knowledge to the reservoir characterization of the “Clinton” in the ECOF and succeeded in identifying a range on CO2-EOR potential. However, additional data on fluid properties (PVT and swelling test), fractures (oriented core and microseis), and reservoir characteristics (relative permeability, capillary pressure, and wet ability) are needed to further narrow the uncertainties and refine the reservoir model and simulation. After collection of this data and refinement of the model and simulation, it is recommended that a larger scale cyclic- CO2 injection test be conducted to better determine the efficacy of CO2-EOR in the “Clinton” reservoir in the ECOF.

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

    SciTech Connect

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

    1992-06-01

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

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

    SciTech Connect

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

    1992-06-01

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

  1. Breakdown of Transformer Oil

    Microsoft Academic Search

    Y. Kawaguchi; H. Murata; M. Ikeda

    1972-01-01

    Breakdown of transformer oil is affected not only by electrostatic field configurations, but also by many other factors. The latters make it difficult to predict break- down voltage from electrostatic field, as made for air and S F6 gaps. Alternatively, many experimenters tried to express the breakdown stress of oil as a function of stressed oil volume. But, results are

  2. Reservoir simulation of co2 sequestration and enhanced oil recovery in Tensleep Formation, Teapot Dome field

    E-print Network

    Gaviria Garcia, Ricardo

    2006-04-12

    Teapot Dome field is located 35 miles north of Casper, Wyoming in Natrona County. This field has been selected by the U.S. Department of Energy to implement a field-size CO2 storage project. With a projected storage of 2.6 million tons of carbon...

  3. Effect of the vesicular–arbuscular mycorrhizal (VAM) fungus Glomus fasciculatum on the essential oil yield related characters and nutrient acquisition in the crops of different cultivars of menthol mint ( Mentha arvensis) under field conditions

    Microsoft Academic Search

    M. L Gupta; Arun Prasad; Muni Ram; Sushil Kumar

    2002-01-01

    The effects of inoculation with vesicular–arbuscular mycorrhizal (VAM) fungus Glomus fasciculatum on the root colonization, growth, essential oil yield and nutrient acquisition of three cultivars of menthol mint (Mentha arvensis); Kalka, Shivalik and Gomti, were studied under field conditions. The VAM inoculation significantly increased the root colonization, plant height, fresh herbage and dry matter yield, oil content and oil yield

  4. Producing Light Oil from a Frozen Reservoir: Reservoir and Fluid Characterization of Umiat Field, National Petroleum Reserve, Alaska

    SciTech Connect

    Hanks, Catherine

    2012-12-31

    Umiat oil field is a light oil in a shallow, frozen reservoir in the Brooks Range foothills of northern Alaska with estimated oil-in-place of over 1 billion barrels. Umiat field was discovered in the 1940’s but was never considered viable because it is shallow, in the permafrost, and far from any transportation infrastructure. The advent of modern drilling and production techniques has made Umiat and similar fields in northern Alaska attractive exploration and production targets. Since 2008 UAF has been working with Renaissance Alaska Inc. and, more recently, Linc Energy, to develop a more robust reservoir model that can be combined with rock and fluid property data to simulate potential production techniques. This work will be used to by Linc Energy as they prepare to drill up to 5 horizontal wells during the 2012-2013 drilling season. This new work identified three potential reservoir horizons within the Cretaceous Nanushuk Formation: the Upper and Lower Grandstand sands, and the overlying Ninuluk sand, with the Lower Grandstand considered the primary target. Seals are provided by thick interlayered shales. Reserve estimates for the Lower Grandstand alone range from 739 million barrels to 2437 million barrels, with an average of 1527 million bbls. Reservoir simulations predict that cold gas injection from a wagon-wheel pattern of multilateral injectors and producers located on 5 drill sites on the crest of the structure will yield 12-15% recovery, with actual recovery depending upon the injection pressure used, the actual Kv/Kh encountered, and other geologic factors. Key to understanding the flow behavior of the Umiat reservoir is determining the permeability structure of the sands. Sandstones of the Cretaceous Nanushuk Formation consist of mixed shoreface and deltaic sandstones and mudstones. A core-based study of the sedimentary facies of these sands combined with outcrop observations identified six distinct facies associations with distinctive permeability trends. The Lower Grandstand sand consists of two coarsening-upward shoreface sands sequences while the Upper Grandstand consists of a single coarsening-upward shoreface sand. Each of the shoreface sands shows a distinctive permeability profile with high horizontal permeability at the top getting progressively poorer towards the base of the sand. In contrast, deltaic sandstones in the overlying Ninuluk are more permeable at the base of the sands, with decreasing permeability towards the sand top. These trends impart a strong permeability anisotropy to the reservoir and are being incorporated into the reservoir model. These observations also suggest that horizontal wells should target the upper part of the major sands. Natural fractures may superimpose another permeability pattern on the Umiat reservoir that need to be accounted for in both the simulation and in drilling. Examination of legacy core from Umiat field indicate that fractures are present in the subsurface, but don't provide information on their orientation and density. Nearby surface exposures of folds in similar stratigraphy indicate there are at least three possible fracture sets: an early, N/S striking set that may predate folding and two sets possibly related to folding: an EW striking set of extension fractures that are parallel to the fold axes and a set of conjugate shear fractures oriented NE and NW. Analysis of fracture spacing suggests that these natural fractures are fairly widely spaced (25-59 cm depending upon the fracture set), but could provide improved reservoir permeability in horizontal legs drilled perpendicular to the open fracture set. The phase behavior of the Umiat fluid needed to be well understood in order for the reservoir simulation to be accurate. However, only a small amount of Umiat oil was available; this oil was collected in the 1940’s and was severely weathered. The composition of this ‘dead’ Umiat fluid was characterized by gas chromatography. This analysis was then compared to theoretical Umiat composition derived using the Pedersen method with original Umiat

  5. Increasing Waterflooding Reservoirs in the Wilmington Oil Field through Improved Reservoir Characterization and Reservoir Management

    SciTech Connect

    Clarke, Don; Koerner, Roy; Moos, Dan; Nguyen, John; Phillips, Chris; Tagbor, Kwasi; Walker, Scott

    1999-11-09

    The objectives of this quarterly report are to summarize the work conducted under each task during the reporting period July - September 1998 and to report all technical data and findings as specified in the ''Federal Assistance Reporting Checklist''. The main objective of this project is the transfer of technologies, methodologies, and findings developed and applied in this project to other operators of Slope and Basin Clastic Reservoirs. This project will study methods to identify sands with high remaining oil saturation and to recomplete existing wells using advanced completion technology.

  6. Increasing Waterflood Reserves in the Wilmington Oil Field Through Improved Reservoir Characterization and Reservoir Management

    SciTech Connect

    Chris Phillips; Dan Moos; Don Clarke; Dwasi Tagbor; John Nguygen; Roy Koerner; Scott Walker

    1997-04-10

    The objectives of this quarterly report are to summarize the work conducted under each task during the reporting period January - March 1997 and to report all technical data and findings as specified in the "Federal Assistance Reporting Checklist". The main objective of this project is the transfer of technologies, methodologies, and findings developed and applied in this project to other operators of Slope and Basin Clastic Reservoirs. This project will study methods to identify sands with high remaining oil saturation and to recomplete existing wells using advanced completion technology.

  7. Gas, Oil, and Water Production from Grand Valley, Parachute, Rulison, and Mamm Creek Fields in the Piceance Basin, Colorado

    USGS Publications Warehouse

    Nelson, Philip H.; Santus, Stephen L.

    2010-01-01

    Gas, oil, and water production data for tight gas reservoirs were compiled from selected wells in western Colorado. These reservoir rocks-the relatively shallow Paleogene Wasatch G sandstone interval in the Parachute and Rulison fields and fluvial sandstones in the deeper Upper Cretaceous Mesaverde Group in the Grand Valley, Parachute, Rulison, and Mamm Creek fields-are characterized by low permeability, low porosity, and the presence of clay minerals in pore space. Production from each well is represented by two samples spaced five years apart, the first sample typically taken two years after production commenced, which was generally in the 1990s. For each producing interval, summary diagrams of oil-versus-gas and water-versus-gas production show fluid production rates, the change in rates during five years, the water-gas and oil-gas ratios, and the fluid type. These diagrams permit well-to-well and field-to-field comparisons. Fields producing water at low rates (water dissolved in gas in the reservoir) can be distinguished from fields producing water at moderate or high rates, and the water-gas ratios are quantified. Dry gas is produced from the Wasatch G interval and wet gas is produced from the Mesaverde Group. Production from the Wasatch G interval is also almost completely free of water, but water production commences with gas production in wells producing from the Mesaverde Group-all of these wells have water-gas ratios exceeding the amount that could exist dissolved in gas at reservoir temperature and pressure. The lack of produced water from the Wasatch G interval is attributed to expansion of the gas accumulation with uplift and erosion. The reported underpressure of the Wasatch G interval is here attributed to hydraulic connection to the atmosphere by outcrops in the Colorado River valley at an elevation lower than that of the gas fields. The amount of reduction of gas production over the five-year time span between the first and second samples is roughly one-half, with median values of second-sample to first-sample gas-production ratios ranging from 0.40 for Rulison-Mesaverde to 0.63 for Rulison-Wasatch G. Commencing with the first sample, the logarithm-of-production rate appears to decline linearly with time in many wells. However, water production is much more erratic as a function of time from an individual well and also from one well to the next within a field. Water production can either decrease or increase with time (from the first to the second sample). In this study, slightly more than half the wells producing from the Mesaverde Group show decreases in water production with time. Plots of water decline versus gas decline show little relation between the two, with only the wells in Rulison field displaying some tendency for water and gas to decline proportionately

  8. Fracture density determination using a novel hybrid computational scheme: a case study on an Iranian Marun oil field reservoir

    NASA Astrophysics Data System (ADS)

    Nouri-Taleghani, Morteza; Mahmoudifar, Mehrzad; Shokrollahi, Amin; Tatar, Afshin; Karimi-Khaledi, Mina

    2015-04-01

    Most oil production all over the world is from carbonated reservoirs. Carbonate reservoirs are abundant in the Middle East, the Gulf of Mexico and in other major petroleum fields that are regarded as the main oil producers. Due to the nature of such reservoirs that are associated with low matrix permeability, the fracture is the key parameter that governs the fluid flow in porous media and consequently oil production. Conventional methods to determine the fracture density include utilizing core data and the image log family, which are both time consuming and costly processes. In addition, the cores are limited to certain intervals and there is no image log for the well drilled before the introduction of this tool. These limitations motivate petroleum engineers to try to find appropriate alternatives. Recently, intelligent systems on the basis of machine learning have been applied to various branches of science and engineering. The objective of this study is to develop a mathematical model to predict the fracture density using full set log data as inputs based on a combination of three intelligent systems namely, the radial basis function neural network, the multilayer perceptron neural network and the least square supported vector machine. The developed committee machine intelligent system (CMIS) is the weighted average of the individual results of each expert. Proper corresponding weights are determined using a genetic algorithm (GA). The other important feature of the proposed model is its generalization capability. The ability of this model to predict data that have not been introduced during the training stage is very good.

  9. Paclobutrazol treatment as a potential strategy for higher seed and oil yield in field-grown camelina sativa L. Crantz

    PubMed Central

    2012-01-01

    Background Camelina (Camelina sativa L. Crantz) is a non-food oilseed crop which holds promise as an alternative biofuel energy resource. Its ability to grow in a variety of climatic and soil conditions and minimal requirements of agronomical inputs than other oilseed crops makes it economically viable for advanced biofuel production. We designed a study to investigate the effect of paclobutrazol [2RS, 3RS)-1-(4-Chlorophenyl)-4,4-dimethyl-2-(1H-1,2,4-triazol-1-yl)pentan-3-ol] (PBZ), a popular plant growth regulator, on the seed and oil yield of Camelina sativa (cv. Celine). Results A field-based micro-trial setup was established in a randomized block design and the study was performed twice within a span of five months (October 2010 to February 2011) and five different PBZ treatments (Control: T0; 25 mg l-1: T1; 50 mg l-1: T2; 75 mg l-1: T3; 100 mg l-1: T4; 125 mg l-1: T5) were applied (soil application) at the time of initiation of flowering. PBZ at 100 mg l-1 concentration (T4) resulted in highest seed and oil yield by 80% and 15%, respectively. The seed yield increment was mainly due to enhanced number of siliques per plant when compared to control. The PBZ - treated plants displayed better photosynthetic leaf gas exchange characteristics, higher chlorophyll contents and possessed dark green leaves which were photosynthetically active for a longer period and facilitated higher photoassimilation. Conclusion We report for the first time that application of optimized PBZ dose can be a potential strategy to achieve higher seed and oil yield from Camelina sativa that holds great promise as a biofuel crop in future. PMID:22410213

  10. ADAPTIVE MANAGEMENT AND PLANNING MODELS FOR CULTURAL RESOURCES IN OIL & GAS FIELDS IN NEW MEXICO AND WYOMING

    SciTech Connect

    Peggy Robinson

    2005-07-01

    This report summarizes activities that have taken place in the last six (6) months (January 2005-June 2005) under the DOE-NETL cooperative agreement ''Adaptive Management and Planning Models for Cultural Resources in Oil and Gas Fields, New Mexico and Wyoming'' DE-FC26-02NT15445. This project examines the practices and results of cultural resource investigation and management in two different oil and gas producing areas of the United States: southeastern New Mexico and the Powder River Basin of Wyoming. The project evaluates how cultural resource investigations have been conducted in the past and considers how investigation and management could be pursued differently in the future. The study relies upon full database population for cultural resource inventories and resources and geomorphological studies. These are the basis for analysis of cultural resource occurrence, strategies for finding and evaluating cultural resources, and recommendations for future management practices. Activities can be summarized as occurring in either Wyoming or New Mexico. Gnomon as project lead, worked in both areas.

  11. Depositional setting and reservoir geology of Kuparuk River oil field, North Slope, Alaska

    Microsoft Academic Search

    C. E. Paris; D. W. Masterson

    1985-01-01

    The Kuparuk River field is located approximately 20 mi (32 km) west of the Prudhoe Bay field and produces from the Lower Cretaceous Kuparuk River formation. The lower member of the Kuparuk is a sequence of interbedded sandstone, siltstone, and mudstone. Individual sandstone beds in the lower member are up to 5 ft (1.5 m) thick and consist of fine-grained,

  12. New Acid Stimulation Treatment to Sustain Production - Los Angeles Downtown Oil Field

    Microsoft Academic Search

    Richard C

    2003-01-01

    Hydrochloric acid stimulation was successfully used on several wells in the Los Angeles Downtown Field, in the past. The decline rates after stimulation were relatively high and generally within six months to a year, production rates have returned to their prestimulation rates. The wells in Los Angeles Downtown Field have strong scale producing tendencies and many wells are treated for

  13. Field-scale evidence for biogeophysical signatures resulting from natural attenuation of a well characterized crude oil spill

    NASA Astrophysics Data System (ADS)

    Slater, L. D.; Revil, A.; Atekwana, E. A.; Mewafy, F.; Bekins, B. A.; Cozzarelli, I.; Herkelrath, W. N.; Skold, M.; Ntarlagiannis, D.; Trost, J.; Erickson, M.; Heenan, J. W.; Lane, J. W.; Werkema, D. D.

    2012-12-01

    Recent biogeophysical research has indicated that unique geophysical signatures are associated with the long-term biodegradation of organic contaminants. However, field-scale demonstrations of the presence of these signatures at sites of organic contamination are lacking. For the last three years, we have performed geophysical measurements at the National Crude Oil Spill Fate and Natural Attenuation Research Site, a unique field laboratory situated just outside of Bemidji, MN. At this site, a ruptured pipeline spilled 1,700,000 L of crude oil into an uninhabited area in 1979. Natural attenuation of the spill has been extensively documented and a geochemical database extending back over 20 years is available to constrain interpretation of the geophysical signatures. We report compelling evidence of a transient geobattery associated with biodegradation of this mature hydrocarbon spill. Using an array of boreholes, self-potential measurements acquired from land surface, passing through the smear zone, capture a diagnostic dipole (peak to peak voltages up to 64 mV) indicating a current source centered on the smear zone, with anodic and cathodic reactions below and above the smear zone respectively. Down borehole measurements reveal that the smear zone is characterized by high magnetic susceptibility (MS); laboratory measurements show that this MS enhancement results from precipitation of iron mineral byproducts of biodegradation. These iron minerals presumably facilitate the electron transport between anode and cathode required to support a geobattery. Furthermore, laboratory and field-scale complex resistivity measurements reveal an enhancement in the complex surface conductivity within the smear zone most likely due to these biodegradation byproducts. The geobattery is not permanent, but instead periodically shuts down, presumably due to changes in the gradient of the redox species driving anodic and cathodic reactions. Gas samples show that conditions are anaerobic immediately above the iron mineral byproducts; this suggests that the geobattery is not driven by an aerobic to aerobic transition but instead requires an alternative driving redox couple excluding oxygen. Although further work is needed to fully decipher the origins of these signals, our results at this unique field laboratory indicate that strong field-scale biogeophysical signatures may be expected over mature hydrocarbon spill sites.

  14. Predicting Interfacial Tension In Oil-Water-Surfactant Systems Using Lattice Self-Consistent Mean Field Model

    NASA Astrophysics Data System (ADS)

    Ginzburg, Valeriy; Bicerano, Jozef

    2004-03-01

    We apply a lattice version of Self-Consistent Mean-Field Theory (l-SCMFT) of polymers to describe interfacial tension in oil-water-surfactant systems as function of temperature and surfactant volume fraction. This approach is similar to the model of Israels et al. [1] for the case of block copolymer-compatibilized polymer blend. In our analysis, we compare model predictions with experimental measurements for several water/hydrocarbon mixtures with alkyl-ethoxylate nonionic surfactants, and find a reasonable qualitative and semi-quantitative agreement. We also look at the relationship between interfacial tension and surfactant structure and architecture. [1] R. Israels, D. Jasnow, A. C. Balazs, L. Guo, G. Krausch, J. Sokolov, M. Rafailovich, J. Chem. Phys. 102, 8149 (1995).

  15. ADAPTIVE MANAGEMENT AND PLANNING MODELS FOR CULTURAL RESOURCES IN OIL & GAS FIELDS IN NEW MEXICO AND WYOMING

    SciTech Connect

    Peggy Robinson

    2004-07-01

    This report contains a summary of activities of Gnomon, Inc. and five subcontractors that have taken place during the first six months of 2004 (January 1, 2004-June 30, 2004) under the DOE-NETL cooperative agreement: ''Adaptive Management and Planning Models for Cultural Resources in Oil & Gas Fields in New Mexico and Wyoming'', DE-FC26-02NT15445. Although Gnomon and all five subcontractors completed tasks during these six months, most of the technical experimental work was conducted by the subcontractor, SRI Foundation (SRIF). SRIF created a sensitivity model for the Azotea Mesa area of southeastern New Mexico that rates areas as having a very good chance, a good chance, or a very poor chance of containing cultural resource sites. SRIF suggested that the results of the sensitivity model might influence possible changes in cultural resource management (CRM) practices in the Azote Mesa area of southeastern New Mexico.

  16. ADAPTIVE MANAGEMENT AND PLANNING MODELS FOR CULTURAL RESOURCES IN OIL & GAS FIELDS IN NEW MEXICO AND WYOMING

    SciTech Connect

    Peggy Robinson

    2004-01-01

    This report contains a summary of activities of Gnomon, Inc. and five subcontractors that have taken place during the second six months (July 1, 2003-December 31, 2003) under the DOE-NETL cooperative agreement: ''Adaptive Management and Planning Models for Cultural Resources in Oil & Gas Fields in New Mexico and Wyoming'', DE-FC26-02NT15445. Although Gnomon and all five subcontractors completed tasks during these six months, most of the technical experimental work was conducted by the subcontractor, SRI Foundation (SRIF). SRIF created a sensitivity model for the Loco Hills area of southeastern New Mexico that rates areas as having a very good chance, a good chance, or a very poor chance of containing cultural resource sites. SRIF suggested that the results of the sensitivity model might influence possible changes in cultural resource management (CRM) practices in the Loco Hills area of southeastern New Mexico.

  17. Measurement of ²²?Ra in soil from oil field: advantages of ?-ray spectrometry and application to the IAEA-448 CRM.

    PubMed

    Ceccatelli, A; Katona, R; Kis-Benedek, G; Pitois, A

    2014-05-01

    The analytical performance of gamma-ray spectrometry for the measurement of (226)Ra in TENORM (Technically Enhanced Naturally Occurring Radioactive Material) soil was investigated by the IAEA. Fast results were obtained for characterization and certification of a new TENORM Certified Reference Material (CRM), identified as IAEA-448 (soil from oil field). The combined standard uncertainty of the gamma-ray spectrometry results is of the order of 2-3% for massic activity measurement values ranging from 16500 Bq kg(-1) to 21500 Bq kg(-1). Methodologies used for the production and certification of the IAEA-448 CRM are presented. Analytical results were confirmed by alpha spectrometry. The "t" test showed agreement between alpha and gamma results at 95% confidence level. PMID:24332337

  18. Leaching of polycyclic aromatic hydrocarbons from oil shale processing waste deposit: a long-term field study.

    PubMed

    Jefimova, Jekaterina; Irha, Natalya; Reinik, Janek; Kirso, Uuve; Steinnes, Eiliv

    2014-05-15

    The leaching behavior of selected polycyclic aromatic hydrocarbons (PAHs) from an oil shale processing waste deposit was monitored during 2005-2009. Samples were collected from the deposit using a special device for leachate sampling at field conditions without disturbance of the upper layers. Contents of 16 priority PAHs in leachate samples collected from aged and fresh parts of the deposit were determined by GC-MS. The sum of the detected PAHs in leachates varied significantly throughout the study period: 19-315 ?g/l from aged spent shale, and 36-151 ?g/l from fresh spent shale. Among the studied PAHs the low-molecular weight compounds phenanthrene, naphthalene, acenaphthylene, and anthracene predominated. Among the high-molecular weight PAHs benzo[a]anthracene and pyrene leached in the highest concentrations. A spent shale deposit is a source of PAHs that could infiltrate into the surrounding environment for a long period of time. PMID:24631927

  19. Improved Oil Recovery from Upper Jurassic Smackover Carbonates through the Application of Advanced Technologies at Womack Hill Oil Field, Choctaw and Clarke Counties, Alabama, Eastern Gulf Coastal Plan (Phase II)

    SciTech Connect

    Ernest A. Mancini; Joe Benson; David Hilton; David Cate; Lewis Brown

    2006-05-29

    The principal research efforts for Phase II of the project were drilling an infill well strategically located in Section 13, T. 10 N., R. 2 W., of the Womack Hill Field, Choctaw and Clarke Counties, Alabama, and obtaining fresh core from the upper Smackover reservoir to test the feasibility of implementing an immobilized enzyme technology project in this field. The Turner Land and Timber Company 13-10 No. 1 well was successfully drilled and tested at a daily rate of 132 barrels of oil in Section 13. The well has produced 27,720 barrels of oil, and is currently producing at a rate of 60 barrels of oil per day. The 13-10 well confirmed the presence of 175,000 barrels of attic (undrained) oil in Section 13. As predicted from reservoir characterization, modeling and simulation, the top of the Smackover reservoir in the 13-10 well is structurally high to the tops of the Smackover in offsetting wells, and the 13-10 well has significantly more net pay than the offsetting wells. The drilling and testing of the 13-10 well showed that the eastern part of the field continues to have a strong water drive and that there is no need to implement a pressure maintenance program in this part of the Womack Hill Field at this time. The success achieved in drilling and testing the 13-10 infill well demonstrates the benefits of building a geologic model to target areas in mature fields that have the potential to contain undrained oil, thus increasing the productivity and profitability of these fields. Microbial cultures that grew at 90 C and converted ethanol to acid were recovered from fresh cuttings from the Smackover carbonate reservoir in an analogous field to the Womack Hill Field in southwest Alabama; however, no viable microorganisms were found in the Smackover cores recovered from the drilling of the 13-10 well in Womack Hill Field. Further evaluation is, therefore, required prior to implementing an immobilized enzyme technology project in the Womack Hill Field.

  20. Ex situ bioremediation of a soil contaminated by mazut (heavy residual fuel oil)--a field experiment.

    PubMed

    Beškoski, Vladimir P; Gojgi?-Cvijovi?, Gordana; Mili?, Jelena; Ili?, Mila; Mileti?, Srdjan; Solevi?, Tatjana; Vrvi?, Miroslav M

    2011-03-01

    Mazut (heavy residual fuel oil)-polluted soil was exposed to bioremediation in an ex situ field-scale (600 m(3)) study. Re-inoculation was performed periodically with biomasses of microbial consortia isolated from the mazut-contaminated soil. Biostimulation was conducted by adding nutritional elements (N, P and K). The biopile (depth 0.4m) was comprised of mechanically mixed polluted soil with softwood sawdust and crude river sand. Aeration was improved by systematic mixing. The biopile was protected from direct external influences by a polyethylene cover. Part (10 m(3)) of the material prepared for bioremediation was set aside uninoculated, and maintained as an untreated control pile (CP). Biostimulation and re-inoculation with zymogenous microorganisms increased the number of hydrocarbon degraders after 50 d by more than 20 times in the treated soil. During the 5 months, the total petroleum hydrocarbon (TPH) content of the contaminated soil was reduced to 6% of the initial value, from 5.2 to 0.3 g kg(-1) dry matter, while TPH reduced to only 90% of the initial value in the CP. After 150 d there were 96%, 97% and 83% reductions for the aliphatic, aromatic, and nitrogen-sulphur-oxygen and asphaltene fractions, respectively. The isoprenoids, pristane and phytane, were more than 55% biodegraded, which indicated that they are not suitable biomarkers for following bioremediation. According to the available data, this is the first field-scale study of the bioremediation of mazut and mazut sediment-polluted soil, and the efficiency achieved was far above that described in the literature to date for heavy fuel oil. PMID:21288552

  1. U(VI) bioreduction with emulsified vegetable oil as the electron donor-Model application to a field test

    SciTech Connect

    Tang, Guoping [ORNL; Watson, David B [ORNL; Wu, Wei-min [Stanford University; Schadt, Christopher Warren [ORNL; Parker, Jack C [ORNL; Brooks, Scott C [ORNL

    2013-01-01

    A one-time 2-hour emulsified vegetable oil (EVO) injection in a fast flowing aquifer decreased U discharge to a stream for over a year. Using a comprehensive biogeochemical model developed in the companion article based on microcosm tests, we approximately matched the observed acetate, nitrate, Fe, U, and sulfate concentrations, and described the major evolution trends of multiple microbial functional groups in the field test. While the lab-determined parameters were generally applicable in the field-scale simulation, the EVO hydrolysis rate constant was estimated to be an order of magnitude greater in the field than in the microcosms. The model predicted substantial biomass (sulfate reducers) and U(IV) accumulation near the injection wells and along the side boundaries of the treatment zone where electron donors (long-chain fatty acids) from the injection wells met electron acceptors (sulfate) from the surrounding environment. While EVO retention and hydrolysis characteristics were expected to control treatment longevity, modeling results indicated that electron acceptors such as sulfate may not only compete for electrons but also play a conducive role in degrading complex substrates and enhancing U(VI) reduction and immobilization. As a result, the spacing of the injection wells could be optimized for effective sustainable bioremediation.

  2. Measuring ignitability for in situ burning of oil spills weathered under Arctic conditions: from laboratory studies to large-scale field experiments.

    PubMed

    Fritt-Rasmussen, Janne; Brandvik, Per Johan

    2011-08-01

    This paper compares the ignitability of Troll B crude oil weathered under simulated Arctic conditions (0%, 50% and 90% ice cover). The experiments were performed in different scales at SINTEF's laboratories in Trondheim, field research station on Svalbard and in broken ice (70-90% ice cover) in the Barents Sea. Samples from the weathering experiments were tested for ignitability using the same laboratory burning cell. The measured ignitability from the experiments in these different scales showed a good agreement for samples with similar weathering. The ice conditions clearly affected the weathering process, and 70% ice or more reduces the weathering and allows a longer time window for in situ burning. The results from the Barents Sea revealed that weathering and ignitability can vary within an oil slick. This field use of the burning cell demonstrated that it can be used as an operational tool to monitor the ignitability of oil spills. PMID:21714974

  3. Sensitive low field Kerr electro-optic measurements in transformer oil

    Microsoft Academic Search

    D. Sheen; T. Fujiwara; M. Zahn

    1988-01-01

    A frequency-selective amplifier was used to make sensitive Kerr electro-optic field mapping measurements with a small signal AC voltage superimposed on a DC level. With several different electrode materials, including brass, stainless steel, and aluminium, the authors have observed very significant levels of field distortion due to positive space charge on the order of 400 ?C\\/m3. It was possible to

  4. Novel simulation techniques used in a gas reservoir with a thin oil zone; Troll field

    SciTech Connect

    Henriquez, A.; Apeland, O.J.; Lie, O. (Statoil (Norway)); Cheshire, I. (Intera Petroleum Production Services (United Kingdom))

    1992-11-01

    Choice of production strategy in modern reservoir management relies heavily on numerical simulation. Large fields may require prohibitively large computer times. This paper reports on new techniques developed to save computer and engineering time: local grid refinement with small timesteps and flux boundary conditions for simulating regions of special interest. The combined use of these techniques allowed flexible, non-time-consuming, user-friendly reservoir simulation of a variety of reservoir management scenarios for Troll field.

  5. High temperature annealing of fission tracks in fluorapatite, Santa Fe Springs oil field, Los Angeles Basin, California

    USGS Publications Warehouse

    Naeser, Nancy D.; Crowley, Kevin D.; McCulloh, Thane H.; Reaves, Chris M.

    1990-01-01

    Annealing of fission tracks is a kinetic process dependent primarily on temperature and to a laser extent on time. Several kinetic models of apatite annealing have been proposed. The predictive capabilities of these models for long-term geologic annealing have been limited to qualitative or semiquantitative at best, because of uncertainties associated with (1) the extrapolation of laboratory observations to geologic conditions, (2) the thermal histories of field samples, and (3) to some extent, the effect of apatite composition on reported annealing temperatures. Thermal history in the Santa Fe Springs oil field, Los Angeles Basin, California, is constrained by an exceptionally well known burial history and present-day temperature gradient. Sediment burial histories are continuous and tightly constrained from about 9 Ma to present, with an important tie at 3.4 Ma. No surface erosion and virtually no uplift were recorded during or since deposition of these sediments, so the burial history is simple and uniquely defined. Temperature gradient (???40??C km-1) is well established from oil-field operations. Fission-track data from the Santa Fe Springs area should thus provide one critical field test of kinetic annealing models for apatite. Fission-track analysis has been performed on apatites from sandstones of Pliocene to Miocene age from a deep drill hole at Santa Fe Springs. Apatite composition, determined by electron microprobe, is fluorapatite [average composition (F1.78Cl0.01OH0.21)] with very low chlorine content [less than Durango apatite; sample means range from 0.0 to 0.04 Cl atoms, calculated on the basis of 26(O, F, Cl, OH)], suggesting that the apatite is not unusually resistant to annealing. Fission tracks are preserved in these apatites at exceptionally high present-day temperatures. Track loss is not complete until temperatures reach the extreme of 167-178??C (at 3795-4090 m depth). The temperature-time annealing relationships indicated by the new data from Santa Fe Springs conflict with predictions based on previously published, commonly used, kinetic annealing models for apatite. Work is proceeding on samples from another area of the basin that may resolve this discrepancy.

  6. Field Evaluation of a Kudzu/Cottonseed Oil Formulation on the Persistence of the Beet Armyworm Nucleopolyhedrovirus

    Technology Transfer Automated Retrieval System (TEKTRAN)

    A plant extract (kudzu) was tested as a UV protectant for SeMNPV, with and without the addition of an oil/emulsifier (cottonseed oil/lecithin) formulation. Aqueous and oil emulsion formulations of the beet armyworm, Spodoptera exigua (Hübner), nucleopolyhedrovirus SeMNPV were applied to collards an...

  7. Case report: Profound neurobehavioral deficits in an oil field worker overcome by hydrogen sulfide

    SciTech Connect

    Kilburn, K.H. (Univ. of Southern California, Los Angeles (United States))

    1993-11-01

    A 24-year-old oil well tester was rendered semiconscious by hydrogen sulfide (H2S). He received oxygen and was hospitalized but released in 30 minutes. The next day, nausea, vomiting, diarrhea, and incontinence of urine and stool led to rehospitalization. These problems and leg shaking, dizziness, sweating, trouble sleeping, and nightmares prevented his return to work. A physical examination, chest x-ray, and pulmonary function tests were normal 39 months after the episode but vibration sense was diminished. Two choice visual reaction times were delayed. Balance was highly abnormal (5 to 6 cm/sec) with eyes closed. Blink reflex latency was slow (R-1 17.5 msec versus normal 14.3 msec). Numbers written on finger tips were not recognized. Verbal and visual recall were impaired but overlearned memory was intact. Cognitive functions measured by Culture Fair, block design, and digit symbol were impaired. Perceptual motor was slow. Scores for confusion, tension-anxiety, depression, and fatigue were elevated and vigor was reduced. Forty-nine months after exposure his reaction time, sway speed, and color vision had not improved. His recall and his cognitive, constructional, and psychomotor speeds had improved but remained abnormal. These deficits are most likely due to H2S. Similar testing of other survivors is recommended.

  8. Study on detailed geological modelling for fluvial sandstone reservoir in Daqing oil field

    SciTech Connect

    Zhao Hanqing; Fu Zhiguo; Lu Xiaoguang [Institute of Petroleum Exploration and Development, Daqing (China)

    1997-08-01

    Guided by the sedimentation theory and knowledge of modern and ancient fluvial deposition and utilizing the abundant information of sedimentary series, microfacies type and petrophysical parameters from well logging curves of close spaced thousands of wells located in a large area. A new method for establishing detailed sedimentation and permeability distribution models for fluvial reservoirs have been developed successfully. This study aimed at the geometry and internal architecture of sandbodies, in accordance to their hierarchical levels of heterogeneity and building up sedimentation and permeability distribution models of fluvial reservoirs, describing the reservoir heterogeneity on the light of the river sedimentary rules. The results and methods obtained in outcrop and modem sedimentation studies have successfully supported the study. Taking advantage of this method, the major producing layers (PI{sub 1-2}), which have been considered as heterogeneous and thick fluvial reservoirs extending widely in lateral are researched in detail. These layers are subdivided into single sedimentary units vertically and the microfacies are identified horizontally. Furthermore, a complex system is recognized according to their hierarchical levels from large to small, meander belt, single channel sandbody, meander scroll, point bar, and lateral accretion bodies of point bar. The achieved results improved the description of areal distribution of point bar sandbodies, provide an accurate and detailed framework model for establishing high resolution predicting model. By using geostatistic technique, it also plays an important role in searching for enriched zone of residual oil distribution.

  9. Essential oils as potential adulticides against two populations of Aedes aegypti , the laboratory and natural field strains, in Chiang Mai province, northern Thailand

    Microsoft Academic Search

    Dana Chaiyasit; Wej Choochote; Eumporn Rattanachanpichai; Udom Chaithong; Prasong Chaiwong; Atchariya Jitpakdi; Pongsri Tippawangkosol; Doungrat Riyong; Benjawan Pitasawat

    2006-01-01

    Essential oils derived from five plant species, celery (Apium graveolens), caraway (Carum carvi), zedoary (Curcuma zedoaria), long pepper (Piper longum), and Chinese star anise (Illicium verum), were subjected to investigation of adulticidal activity against mosquito vectors. Two populations of Aedes aegypti, the laboratory and natural field strains, collected in Chiang Mai province, northern Thailand were tested in pyrethroid-susceptibility bioassays. The

  10. Formation of oil and gas fields based on carbon-isotope data for methane (as in the Kuybyshev and Orenburg areas)

    Microsoft Academic Search

    Ye. Ya. Gavrilov; G. I. Teplinskiy

    1981-01-01

    The carbon-isotope composition of methane from certain Devonian and Carboniferous oil fields, and gas pools in the Permian from the Kuybyshev and Orenburg regions were studied. It was concluded that the comparatively wide fluctuations in delta C-13 in the gases of the Carboniferous and Devonian deposits reflect a genetic heterogeneity and could scarcely maintain such an intermixing of isotope composition

  11. Contracts for field projects and supporting research on enhanced oil recovery. Progress review No. 82, quarterly report, January--March 1995

    SciTech Connect

    NONE

    1996-06-01

    This document consists of a list of projects supporting work on oil recovery programs. A publications list and index of companies and institutions is provided. The remaining portion of the document provides brief descriptions on projects in chemical flooding, gas displacement, thermal recovery, geoscience, resource assessment, and reservoir class field demonstrations.

  12. GREEN RIVER AIR QUALITY MODEL DEVELOPMENT: METEOROLOGICAL DATA - AUGUST 1980 FIELD STUDY IN THE PICEANCE CREEK BASIN OIL SHALE RESOURCES AREA

    EPA Science Inventory

    Special meteorological and air quality studies were conducted during August 1980 in the Piceance Creek Basin oil shale resource area of Northwestern Colorado as part of the EPA-sponsored Green River Ambient Model Assessment program. The objective of the limited field program was ...

  13. The steel pipe used in oil fields, as well as most other indus-trial tubing, is generally coiled for transport and storage. Un-

    E-print Network

    Entekhabi, Dara

    PROBLEM The steel pipe used in oil fields, as well as most other indus- trial tubing, is generally coiled for transport and storage. Un- fortunately, the coiling can create intrinsic natural curvature that affects mechanical behavior. In industrial tubing or any thin rod-like structure, this curvature can

  14. Helicopter electromagnetic and magnetic survey maps and data, East Poplar Oil Field area, August 2004, Fort Peck Indian Reservation, northeastern Montana

    USGS Publications Warehouse

    Smith, Bruce D.; Thamke, Joanna N.; Cain, Michael J.; Tyrrell, Christa; Hill, Patricia L.

    2006-01-01

    This report is a data release for a helicopter electromagnetic and magnetic survey that was conducted during August 2004 in a 275-square-kilometer area that includes the East Poplar oil field on the Fort Peck Indian Reservation. The electromagnetic equipment consisted of six different coil-pair orientations that measured resistivity at separate frequencies from about 400 hertz to about 140,000 hertz. The electromagnetic resistivity data were converted to six electrical conductivity grids, each representing different approximate depths of investigation. The range of subsurface investigation is comparable to the depth of shallow aquifers. Areas of high conductivity in shallow aquifers in the East Poplar oil field area are being delineated by the U.S. Geological Survey, in cooperation with the Fort Peck Assiniboine and Sioux Tribes, in order to map areas of saline-water plumes. Ground electromagnetic methods were first used during the early 1990s to delineate more than 31 square kilometers of high conductivity saline-water plumes in a portion of the East Poplar oil field area. In the 10 years since the first delineation, the quality of water from some wells completed in the shallow aquifers in the East Poplar oil field changed markedly. The extent of saline-water plumes in 2004 likely differs from that delineated in the early 1990s. The geophysical and hydrologic information from U.S. Geological Survey studies is being used by resource managers to develop ground-water resource plans for the area.

  15. Finite element simulation of wilmington oil field subsidence: II. Nonlinear modelling

    NASA Astrophysics Data System (ADS)

    Kosloff, D.; Scott, R. F.; Scranton, J.

    1980-12-01

    The numerical modelling of the first part of this work is extended to include a nonlinear elastic—plastic material response. The parameters for the rheological model are deduced from published soil tests and from the behavior of the field during the rebound phase which is assumed to be purely elastic. Unlike the linear case, the response of the plastic model is highly dependent on the stresses in the field prior to production. When these stresses are purely lithostatic and horizontally uniform the fit to observations is not significantly improved over the linear models. When a flexural prestress which accounts for the formation of the structural anticline of the field is included, simulations explain observations quite well.

  16. New Acid Stimulation Treatment to Sustain Production - Los Angeles Downtown Oil Field

    SciTech Connect

    Russell, Richard C.

    2003-03-10

    Hydrochloric acid stimulation was successfully used on several wells in the Los Angeles Downtown Field, in the past. The decline rates after stimulation were relatively high and generally within six months to a year, production rates have returned to their prestimulation rates. The wells in Los Angeles Downtown Field have strong scale producing tendencies and many wells are treated for scale control. Four wells were carefully selected that are representative of wells that had a tendency to form calcium carbonate scale and had shown substantial decline over the last few years.

  17. Field investigation on the toxicity of Alaska North Slope crude oil (ANSC) and dispersed ANSC crude to Gulf killifish, Eastern oyster and white shrimp.

    PubMed

    Liu, B; Romaire, R P; Delaune, R D; Lindau, C W

    2006-01-01

    A field investigation was conducted on a Louisiana Spartina alterniflora shoreline to evaluate the toxic effects of crude oil (Alaska North Slope crude oil, ANSC) and dispersed oil (ANSC + dispersant Corexit 9,500) on three aquatic species indigenous to the Gulf of Mexico: Fundulus grandis (Gulf killifish), Crassostrea virginica (Eastern oyster), and Litopenaeus setiferus (white shrimp). Results indicated that total hydrocarbons concentration value in oiled treatments decreased rapidly in 3h and were below 1 ppm at 24h after initial treatment. Corexit 9,500 facilitated more ANSC fractions to dissolve and disperse into the water column. L. setiferus showed short-term sensitivity to the ANSC and ANSC + 9,500 at 30 ppm. However, most test organisms (>83%) of each species survived well after 24h exposure to the treatments. Laboratory tests conducted concurrent with the field investigation indicated that concentrations of crude oil higher than 30 ppm were required for any significant toxic effect on the juvenile organisms tested. PMID:16098561

  18. [Microbiological investigations of high-temperature horizons of the Kongdian petroleum reservoir in connection with field trial of a biotechnology for enhancement of oil recovery].

    PubMed

    Nazina, T N; Grigor'ian, A A; Shestakova, N M; Babich, T L; Ivo?lov, V S; Feng, Q; Ni, F; Wang, J; She, Y; Xiang, T; Luo, Z; Beliaev, S S; Ivanov, M V

    2007-01-01

    The physicochemical conditions and microbiological characteristics of the formation waters of the Kongdian bed of the Dagang oil field (China) were studied. It was demonstrated that this bed is a high-temperature ecosystem with formation waters characterized by low mineralization. The concentrations of nitrogen and phosphorus compounds, as well as of electron acceptors, are low. Oil and oil gas are the main organic matter sources. The bed is exploited with water-flooding. The oil stratum was inhabited mostly by anaerobic thermophilic microorganisms, including fermentative (10(2)-10(5) cells/ml), sulfate-reducing (0-10(2) cells/ml), and methanogenic (0-10(3) cells/ml) microorganisms. Aerobic bacteria were detected mainly in the near-bottom zone of injection wells. The rate of sulfate reduction varied from 0.002 to 18.940 microg S(2-) l(-1) day(-1) and the rate of methanogenesis from 0.012 to 16.235 microg CH4 l(-1) day(-1). Microorganisms with great biotechnological potential inhabited the bed. Aerobic thermophilic bacteria were capable of oxidizing oil with the formation of biomass, the products of partial oxidation of oil (volatile acids), and surfactants. During growth on the culture liquid of oiloxidizing bacteria, methanogenic communities produced methane and carbon dioxide, which also had oil-releasing capabilities. Using various labeled tracers, the primary filtration flows of injected solutions at the testing site were studied. Our comprehensive investigations allowed us to conclude that the tested method for microbial enhancement of oil recovery based on the activation of the stratal microflora can be applied in the Kongdian bed horizons. PMID:17633408

  19. Integration of Well & Core Data of Carbonate Reservoirs with Surface Seismic in Garraf Oil Field, Southern Iraq

    NASA Astrophysics Data System (ADS)

    Mhuder, J. J.; Muhlhl, A. A.; Basra Geologiests

    2013-05-01

    The Garraf Field is situated in Southern Iraq in Nasiriya area, is located in Mesopotamian basin. The carbonate facies are dominant in main reservoirs in Garraf field (Mishrif and Yammama Formations) which is Cretaceous in age. The structure of the reservoir in this field are low relief gentle anticlinal structure aligned in NW to SE direction, and No fault were observed and interpreted in 3D seismic section. 3D seismic survey by Iraqi Oil Exploration Company No 2 was successfully conducted on the Garraf field at 2008-2009 using recording system SERCEL 408UL and Vibrators Nomad 65. Bin size: 25*25, Fold: 36, SP Interval: 50m, Lines Interval: 300m, 3 wells were drilled Ga (1, 2, 3) and it used for seismic to well tie in Petrel. Data analysis was conducted for each reservoirs for Lithological and sedimentological studies were based on core and well data .The study showed That the Mishrif Formation deposited in a broad carbonate platform with shallowing upward regressive succession and The depositional environment is extending from outer marine to shallow middle-inner shelf settings with restricted lagoons as supported by the present of Miliolid fossils. The fragmented rudist biostromes accumulated in the middle shelf. No rudist reef is presence in the studied cores. While the Major sequences are micritic limestone of lagoonal and oolitic/peloidal grainstone sandy shoal separated by mudstone of Yamama formation. Sedimentation feature are seen on seismic attributes and it is help for understanding of sedimentation environment and suitable structure interpretation. There is good relationship between Acustic Impedance and porosity, Acustic Impedance reflects porosity or facies change of carbonate rather than fluid content. Data input used for 3D Modeling include 3D seismic and AI data, petrophysical analysis, core and thin section description. 3D structure modeling were created base on the geophysical data interpretation and Al analysis. Data analysis for Al data were run as secondary input for 3D properties modeling.

  20. Field Pennycress (Thlaspi arvense L.) Oil: A Promising Source of Biodiesel.

    Technology Transfer Automated Retrieval System (TEKTRAN)

    Field pennycress (Thlaspi arvense L., FP) is a winter annual species of the mustard family (Brassicaceae) that is widely distributed throughout temperate North America and which can serve in a winter rotational cycle with conventional crops, thus not displacing existing agricultural production or ne...