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Sample records for bouri oil field

  1. Remains of Homo erectus from Bouri, Middle Awash, Ethiopia.

    PubMed

    Asfaw, Berhane; Gilbert, W Henry; Beyene, Yonas; Hart, William K; Renne, Paul R; WoldeGabriel, Giday; Vrba, Elisabeth S; White, Tim D

    2002-03-21

    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 these issues has obscured the place of H. erectus in human evolution. A hominid calvaria and postcranial remains recently recovered from the Dakanihylo Member of the Bouri Formation, Middle Awash, Ethiopia, bear directly on these issues. These approximately 1.0-million-year (Myr)-old Pleistocene sediments contain abundant early Acheulean stone tools and a diverse vertebrate fauna that indicates a predominantly savannah environment. Here we report that the 'Daka' calvaria's metric and morphological attributes centre it firmly within H. erectus. Daka's resemblance to Asian counterparts indicates that the early African and Eurasian fossil hominids represent demes of a widespread palaeospecies. Daka's anatomical intermediacy between earlier and later African fossils provides evidence of evolutionary change. Its temporal and geographic position indicates that African H. erectus was the ancestor of Homo sapiens. PMID:11907576

  2. 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.

  3. 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.

  4. Field performance of a premium heating oil

    SciTech Connect

    Santa, T.; Jetter, S.

    1997-01-01

    As part of ongoing research to provide quality improvements to heating oil, Mobil Oil together with Santa Fuel conducted a field trial to investigate the performance of a new premium heating oil. This premium heating oil contains an additive system designed to minimize sludge related problems in the fuel delivery system of residential home heating systems. The additive used was similar to others reported at this and earlier BNL conferences, but was further developed to enhance its performance in oil heat systems. The premium heating oil was bulk additized and delivered to a subset of the customer base. The performance of this premium heating oil is discussed.

  5. Oil field redevelopment -- some lessons learned

    SciTech Connect

    Robertson, M.

    1996-12-31

    This paper presents a summary of some oil field redevelopment experiences that resulted in unanticipated expenses or other inconveniences and consequently became learning experiences. Compared with many other types of contaminated properties, oil fields are relatively easy to remediate. The primary contaminant is crude oil ranging in nature from hard and weathered tar to fresh crude with a notable fraction of light end hydrocarbons. Groundwater is usually not impacted due to the low mobility and solubility of crude oil. Crude oil overall has a relatively low toxicity, is not considered a hazardous material and can usually be easily remediated using bioremediation. All of these factors contribute to the notion that oil fields are low risk in terms of cleanup. However, experience has shown that oil field redevelopment does have some risks as is illustrated by examples.

  6. Abandoned oil fields of Texas Gulf Coast

    SciTech Connect

    Dutton, S.P.

    1984-04-01

    One nonconventional oil target in Texas is the oil that remains in abandoned fields, defined as those fields that had no oil or gas production in 1977 and 1982. This target includes oil that has not been tapped by conventional field development because of reservoir heterogeneity and oil in reservoirs that have not been subjected to any secondary or tertiary recovery efforts. A total of 138 abandoned oil fields having individual cumulative production greater than 500,000 bbl are located in the Texas Gulf Coast (railroad Commission of Texas Districts 2, 3, and 4). These 138 onshore fields produced 276 million barrels of oil before being abandoned. Nongiant fields in the Texas Gulf Coast average about 40% ultimate recovery, so these fields probably originally contained about 700 million bbl of oil in place. Therefore, about 424 million bbl of oil remain unrecovered. Reservoirs in these abandoned fields are Tertiary sandstones. The 44 abandoned fields in the upper Texas Gulf Coast (District 3) produced from a wide range of plays; those plays with the largest number of abandoned fields are Yegua and Frio deep-seated domes, Eocene deltaic sandstone, and Frio barrier/strand-plain sandstone. The 19 abandoned fields in the middle Texas Gulf Coast (District 2) produced mainly from Wilcox and Frio fluvial/deltaic sandstones and from Frio and Jackson-Yegua barrier/strand-plain sandstones. The lower Texas Gulf Coast (District 4) contains 75 abandoned fields that produced from Frio fluvial/deltaic and barrier/strand-plain sandstones and from Jackson-Yegua barrier/strand-plain sandstones.

  7. Crude oil from Tengiz field

    SciTech Connect

    Dorogochinskaya, V.A.; Shul'zhenko, E.D.; Varshaver, V.P.; Khabibulina, R.K.; Kochuleva, L.R.

    1988-03-01

    Analyses were performed on samples taken from exploratory wells. Physicochemical characteristics of the oil were determined as light, low-pour, and high-wax, with low percentages of resins, asphaltenes, and sulfur; the oil contained practically no vanadium or nickel. The kerosine cuts were high in acidity and sulfur content, and diesel fuel cuts met all requirements for L-0.5-61 diesel fuel. The potential contents and properties of distillate and residual lube base stocks are shown and yields of oil base stocks with 96 and 90 V.I. are presented. The residues had high solid points, low viscosities, and high levels of carbon residue, ash, and sulfur content.

  8. Field performance of a premium heating oil

    SciTech Connect

    Santa, T.; Jetter, S.M.

    1996-07-01

    As part of our ongoing research to provide quality improvements to heating oil, Mobil Oil together with Santa Fuel, Inc., conducted a field trial to investigate the performance of a new premium heating oil. This premium heating oil contains an additive system designed to minimize sludge related problems in the fuel delivery system of residential home heating systems. The additive used was similar to others reported at this and earlier BNL conferences, but was further developed to enhance its performance in oil heat systems. The premium heating oil was bulk additized and delivered to a subset of the customer base. Fuel related, unscheduled service calls were monitored in this test area, as well as in a similar baseline area that did not receive the premium heating oil. Overall, the premium fuel provided a 45% reduction in the occurrence of fuel related, unscheduled service calls as compared to the baseline area. Within this population, there was a reduction of 38% in systems with 275 gallon tanks, and 55% in systems that had >275 gallon tanks showing that the additive is effective in the various configurations of residential oil heat systems. In addition, photographic documentation collected at two accounts supported this improvement by clearly showing that the equipment remained cleaner with the premium heating oil than with regular heating oil. Based on these results, a full marketing trial of this new product has been initiated by Mobil and Santa Fuel, Inc., during the 1995-1996 heating season.

  9. Fault seals in oil fields in Nevada

    SciTech Connect

    Foster, N.H.; Veal, H.K.; Bortz, L.C.

    1987-08-01

    Faults forms seals for oil accumulations in the Eagle Springs, Trap Spring, and Blackburn fields, and probably in the Grant Canyon field, in Nevada. The main boundary fault on the east side of the Pine Valley graben forms a seal in the Blackburn field. A fault on the west side of the trap Spring field forms a seal. In Grant Canyon field, it is interpreted that the main boundary fault on the east side of the Railroad Valley graben forms a seal. Calcite is deposited by hot spring activity, plugging up many fault zones and, in some cases, forming seals. Some fault zones have calcite mineralization up to several thousand feet wide. Within the Eagle Springs field on the east side of the Railroad Valley graben, a northeast-trending fault separates oil accumulations with different oil-water contacts. This separation indicates that the fault forms at least a partial seal within the accumulation.

  10. Grant Canyon oil field, Nye County, Nevada

    SciTech Connect

    Veal, H.K.; Duey, H.D.; Bortz, L.C.; Foster, N.H.

    1987-08-01

    The Grant Canyon field is located on the east side of Railroad Valley, 8 mi south of the Eagle Springs oil field. The discovery well, 1 Grant Canyon Unit (SW 1/4 NW 1/4, Sec. 21, T7S, R57E), was completed by Northwest Exploration Co. on September 11, 1983, flowing 1816 BOPD from the Devonian Simonson(.) dolomite (4374-4448 ft). Two additional wells have been completed in the field. Cumulative oil production through December 31, 1986, is 5,260,430 bbl of oil. During December 1986, wells 3 and 4 flowed an average of 5189 BOPD. Well 4 averaged 4065 BOPD for a recent monthly total. The discovery well (1) has been shut-in. The productive area is about 240 acres. The trap is a high fault block in the boundary fault zone that separates Railroad Valley from the Grant Range to the east. The Devonian Simonson(.) reservoir is an intensely fractured, vuggy dolomite with some intercrystalline porosity. The top seal is the Tertiary valley fill which unconformably overlies the Simonson(.) dolomite. The oil column is about 400 ft thick and the field apparently has an active water drive, inasmuch as the 1 Unit had to be shut-in because of water production. The oil is black, 26/sup 0/ API gravity, a pour point of 10/sup 0/F and 0.5% sulfur. Estimated ultimate recoverable oil reserves are 13,000,000 bbl of oil. The adjacent Bacon Flat field is a one-well field (SW 1/4 SW 1/4, Sec. 17, T7N, R57E) that was completed by Northwest Exploration Co. on July 5, 1981, for 200 BOPD and 1050 BWPD from the Devonian Guilmette(.) limestone (5316-5333 ft). Cumulative production through December 31, 1986, is 209,649 bbl of oil, and this well averaged 215 BOPD during December 1986.

  11. Grant Canyon oil field, Nye County, Nevada

    SciTech Connect

    Duey, H.D.; Veal, H.K.; Bortz, L.C.; Foster, N.H.

    1988-03-01

    The Grant Canyon field is located on the east side of Railroad Valley, Nevada, 8 mi south of the Eagle Springs oil field. The discovery well, 1 Grant Canyon Unit (SW1/4NW1/4, Sec. 21, T7S, T57E), was completed by Northwest Exploration Company on September 11, 1983, flowing 1816 BOPD, probably from the Devonian Simonson Dolomite (4375-4448 ft). Two additional wells have been completed in the field. Cumulative oil production through December 31, 1986, is 5,260,430 bbl of oil. During December 1986, wells 3 and 4 flowed an average of 5189 BOPD. Well 4 averaged 4065 BOPD for a recent month. The discovery well has been shut-in. The productive area is about 240 ac. The trap is a high fault block in the boundary fault zone that separates Railroad Valley from the Grant Range to the east. The Devonian Simonson reservoir is an intensely fractured, vuggy dolomite with some intercrystalline porosity. The top seal is the Tertiary valley fill, which unconformably overlies the Simonson Dolomite. The oil column is about 400 ft and the field apparently has an active water drive, inasmuch as the 1 Grant Canyon Unit had to be shut-in because of water production. The oil is black, 26/sup 0/API gravity, with a pour point of 10/sup 0/F and 0.5% sulfur. Estimated ultimate recoverable oil reserves are 13,000,000 bbl. The adjacent Bacon Flat field is a one-well field (SW1/4SW1/4, Sec. 17, T7N, R57E) that was completed by Northwest Exploration Company on July 5, 1981, for 200 BOPD and 1050 BWPD from the Devonian Guilmette Limestone (5316-5333 ft). Cumulative production through December 31, 1986, was 209,649 bbl of oil. This well averaged 215 BOPD during December 1986.

  12. 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 (δ13CCH4 and δDCH4, respectively), and the bulk isotopic discrimination (Δδ13C) 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

  13. Reclamation planning for oil and gas fields

    SciTech Connect

    Lahti, T.

    1990-12-31

    Oil and gas activity began in Rocky Mountain Region during the early 1900`s. Many of the early fields are still producing today. During the initial development of these older fields, little emphasis was placed upon environmental protection activities and reclamation of disturbed areas. Today, many of the {open_quotes}older fields{close_quotes} continue to change without a plan for environmental protection and reclamation. Reclamation of producing fields should begin immediately after a well site is equipped for production. Disturbed areas, no longer needed for operations, should be recontoured and revegetated to stabilize the site and reduce erosion. The Wyoming Bureau of Land Management (BLM) has developed a planning process for use by petroleum industry representatives, in conjunction with the BLM, whenever they are proposing expansion of new fields or planning the reclamation of existing disturbances. The procedures contained in this planning process can help resolve conflicts while guiding operators as they develop reasonable measures to mitigate the impacts of oil and gas development and production. The oil and gas operators, working with the BLM, or other land management entities, should establish a planned priority schedule for completing necessary maintenance and reclamation-related field work. This plan will help the operator budget his resources and work with the land manager to meet present and future responsibilities for environmental protection, reclamation, and final abandonment. Development and implementation of a field reclamation plan encourages the operator to condition a field for reclamation prior to final abandonment. The primary objective of this paper is to describe a procedure for the development of oil and gas field reclamation plans. This procedure establishes guidelines for reclamation planning of existing oil and gas fields on the Bureau of Land Management administered public lands in Wyoming.

  14. Amposta oil field (Spanish Mediterranean offshore)

    SciTech Connect

    Seeman, U. )

    1988-08-01

    The Amposta oil field lies some 20 km off the Mediterranean coast of Spain directly south of the Ebro delta in 70 m of water. The field is operated by Shell in association with Repsol Exploracion (the Spanish national oil company) and Coparex. The field was discovered in 1970 and came on stream in 1972, reaching a maximum production of 40,000 bbl/day. The current cumulative production of 55.7 million bbl is just 300,000 bbl short of the field's expected ultimate primary recovery. Original production was established via a single-buoy mooring system (SBM) with a permanently moored tanker acting as a floating storage vessel. Oil is produced from a fractured, karstified Lower Cretaceous limestone reservoir in a tilted fault-block structure (areal closure is 900 ha), sealed by overlying Miocene clastics. The top of the reservoir is at 1,746 m; the original oil column was 194 m. Designing the optimal production/drainage scheme for a complex reservoir such as the Amposta field with its intricate pore geometry (channels, caves, and fractures) formed an interesting challenge. The field has produced from 7 wells so far. Until recently pressure could be maintained and dry oil produced. Enhanced recovery tests (gas injection) are presently being undertaken. The heavy, undersaturated, high-sulfur crude (17{degree} API, gas-oil ratio of 380 scf/bbl, and 5.5% sulfur) is an early expulsion product generated from a marly/chalky type II source rock sequence of latest Jurassic-earliest Cretaceous age, underlying the field.

  15. A field laboratory for improved oil recovery

    SciTech Connect

    Hildebrandt, A.F.; McDonald, J.; Claridge, E.; Killough, J.

    1992-09-01

    The purpose of Annex III of the Memorandum of Understanding, undertaken by the Houston Petroleum Research Center at the University of Houston, was to develop a field laboratory for research in improved oil recovery using a Gulf Coast reservoir in Texas. The participants: (1) make a field site selection and conducted a high resolution seismic survey in the demonstration field, (2) obtained characteristics of the reservoir (3) developed an evaluation of local flood efficiency in different parts of the demonstration reservoir, (4) used diverse methodology to evaluate the potential recovery of the remaining oil in the test reservoir, (5) developed cross-well seismic tomography, and (6) will transfer the learned technologies to oil operators through publication and workshops. This abstract is an overview of these tasks.

  16. 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.

  17. Sacha oil field of Ecuadorian Oriente

    SciTech Connect

    Canfield, R.W.; Bonilla, G.; Robbins, R.K.

    1982-08-01

    The Sacha oil field in the Ecuadorian Oriente was discovered in early 1969. Production began in July 1972, and at the end of 1980 had exceeded 190 million bbl. Drilling through 1980 had resulted in 91 oil wells and 2 dry holes. Estimated original primary recoverable reserves surpass 632 million bbl. The field is on a very low-relief anticline about 17.5 mi (28 km) long and averaging 4 mi (6.5 km) wide. Vertical closure amounts to 200 ft (60 m) and there are 41,000 acres (16,600 ha.) of areal closure on top of the principal reservoir. The Cretaceous sandstones, at drilled depths between 9,300 and 10,100 ft (2,835 and 3,080 m) provide excellent reservoirs. The Hollin Formation, the basal Cretaceous sandstone, is the principal reservoir, having produced 80% of the oil through 1980 and containing about 68% of the original reserves.

  18. Field evaluations of marine oil spill bioremediation.

    PubMed

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

    1996-06-01

    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

  19. 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

  20. Clathria (Thalysias) (Poecilosclerida: Demospongiae: Porifera) from Brazil:
    New species and redescription of Clathria (Thalysias) basiarenacea (Boury-Esnault, 1973).

    PubMed

    Galindo, Helcy; Hooper, John N A; Pinheiro, Ulisses

    2014-01-01

    The subgenus Clathria (Thalysias) Duchassaing & Michelotti, 1864 has 97 valid species, of which 27 are recorded in the Atlantic Ocean. However, only three species are known from Brazil so far. Here we provide the redescription of Clathria (Thalysias) basiarenacea (Boury- Esnault, 1973), based on the discovery of new characters (additional category of auxiliary styles, and details of spicules), and describe a new species of Clathria (Thalysias) repens sp. nov., that differs from sister species in having a live orange color, a massively encrusting repent growth form with lamellate folds and anastomosed projections, and three categories of structural styles, of which the two auxiliary styles have microspined heads. We also invalidate the record of Clathria (Thalysias) procera (Ridley, 1884) for Brazil.  PMID:25544467

  1. Predicting pavement distress in oil field areas

    SciTech Connect

    Mason, J.M.; Scullion, T.; Stampley, B.E.

    1984-05-01

    A study on oil field traffic characteristics was performed and a procedure was developed for assessing current and future effects of oil field truck traffic on surface-treated (stage construction type) pavements. A computer program calculates several types of pavement distress and serviceability parameters to evaluate pavement performance under various axle load repetitions. Stepwise regression analysis of 132 surface-treated pavement sections led to the development of individual distress equations for rutting, raveling, flushing, alligator cracking, patching, longitudinal and transverse cracking, and failures (potholes). The versatility of the program provides a means of anticipating early pavement failures due to increased axle load repetitions. The program also provides the basic framework for computing the effects of other ''special-use'' truck traffic demands.

  2. Predicting pavement distress in oil field areas

    SciTech Connect

    Mason, J.M.; Scullion, T.; Stampley, B.E.

    1983-05-01

    A study on oil field traffic characteristics was performed and a procedure was developed for assessing current and future effects of oil field truck traffic on surface-treated (stage construction type) pavements. A computer program calculates several types of pavement distress and serviceability parameters to evaluate pavement performance under various axle load repetitions. Stepwise regression analysis of 132 surface-treated pavement sections led to the development of individual distress equations for rutting, raveling, flushing, alligator cracking, patching, longitudinal and transverse cracking, and failures (potholes). The versatility of the program provides a means of anticipating early pavement failures due to increased axle load repetitions. The program also provides the basic framework for computing the effects of other ''special-use'' truck traffic demands.

  3. A model of peak production in oil fields

    NASA Astrophysics Data System (ADS)

    Abrams, Daniel M.; Wiener, Richard J.

    2010-01-01

    We developed a model for oil production on the basis of simple physical considerations. The model provides a basic understanding of Hubbert's empirical observation that the production rate for an oil-producing region reaches its maximum when approximately half the recoverable oil has been produced. According to the model, the oil production rate at a large field must peak before drilling peaks. We use the model to investigate the effects of several drilling strategies on oil production. Despite the model's simplicity, predictions for the timing and magnitude of peak production match data on oil production from major oil fields throughout the world.

  4. 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, E.D.; Freeman, P.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.

  5. 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.

  6. Gullfaks oil field - From challenge to success

    SciTech Connect

    Carlsen, H.; Nygaard, O. )

    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.

  7. Assessment of microorganisms from Indonesian Oil Fields

    SciTech Connect

    Kadarwati, S.; Udiharto, M.; Rahman, M.; Jasjfi, E.; Legowo, E.H.

    1995-12-31

    Petroleum resources have been the mainstay of the national development in Indonesia. However, resources are being depleted after over a century of exploitation, while the demand continues to grow with the rapid economic development of the country. In facing the problem, EOR has been applied in Indonesia, such as the steamflooding project in Duri field, but a more energy efficient technology would be preferable. Therefore, MEOR has been recommended as a promising solution. Our study, aimed at finding indigenous microorganisms which can be developed for application in MEOR, has isolated microbes from some oil fields of Indonesia. These microorganisms have been identified, their activities studied, and the effects of their metabolisms examined. This paper describes the research carried out by LEMIGAS in this respect, giving details on the methods of sampling, incubation, identification, and activation of the microbes as well as tests on the effects of their metabolites, with particular attention to those with potential for application in MEOR.

  8. Salt caverns for oil field waste disposal.

    SciTech Connect

    Veil, J.; Ford, J.; Rawn-Schatzinger, V.; Environmental Assessment; RMC, Consultants, Inc.

    2000-07-01

    Salt caverns used for oil field waste disposal are created in salt formations by solution mining. When created, caverns are filled with brine. Wastes are introduced into the cavern by pumping them under low pressure. Each barrel of waste injected to the cavern displaces a barrel of brine to the surface. The brine is either used for drilling mud or is disposed of in an injection well. Figure 8 shows an injection pump used at disposal cavern facilities in west Texas. Several types of oil field waste may be pumped into caverns for disposal. These include drilling muds, drill cuttings, produced sands, tank bottoms, contaminated soil, and completion and stimulation wastes. Waste blending facilities are constructed at the site of cavern disposal to mix the waste into a brine solution prior to injection. Overall advantages of salt cavern disposal include a medium price range for disposal cost, large capacity and availability of salt caverns, limited surface land requirement, increased safety, and ease of establishment of individual state regulations.

  9. Halophilic archaebacteria from the Kalamkass oil field

    SciTech Connect

    Zvyagintseva, I.S.; Belyaev, S.S.; Borzenkov, I.A.; Kostrikina, N.A.; Milekhina, E.I.; Ivanov, M.V.

    1995-01-01

    Two strains of halophilic archaebacteria, growing in a medium containing from 10 to 25% NaCl, were isolated from the brines of the Kalamkass (Mangyshlak) oil field. Both strains are extremely halophilic archaebacteria according to the complex of their phenotypic properties. Strain M-11 was identified as Haloferax mediterranei on the basis of the composition of polar lipids and DNA-DNA homology. The composition of polar lipids and 16S rRNA sequence of strain M-18 allowed us to assign it to the genus Haloferax. This strain differs from the approved species of the genus Haloferax, H. volcanii, and H. mediterranei. However, to describe it as a new species, additional investigations are necessary. 13 refs., 3 figs.

  10. 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.

  11. Tires fuel oil field cement manufacturing

    SciTech Connect

    Caveny, B.; Ashford, D.; Garcia, J.G.; Hammack, R.

    1998-08-31

    In a new process, waste automobile tires added to the fuel mix of gas, coal, and coke help fire kilns to produce API-quality oil field cement. Capital Cement uses this process in its cement-manufacturing plant in San Antonio, in which it also produces construction cement. The tires provide a lower-cost fuel and boost the temperature at a critical stage in the kiln burn process. Also, steel-belted tires add iron content to the mix. According to lab results, tire-burned cement slurries will perform the same as conventionally burned cement slurries. Actual field applications have proven that cement produced by burning tires performs no different than conventionally produced slurries. Capital`s plant uses both dry and wet processes, with separate kilns running both processes at the same time. Cement clinker is partially fired by waste tires in both kiln processes. The tires represent 12% of the fuel consumed by the plant, a number that is expected to increase. Capital burns about 200 tires/hr, or about 1.6 million tires/year.

  12. Method of determining interwell oil field fluid saturation distribution

    DOEpatents

    Donaldson, Erle C.; Sutterfield, F. Dexter

    1981-01-01

    A method of determining the oil and brine saturation distribution in an oil field by taking electrical current and potential measurements among a plurality of open-hole wells geometrically distributed throughout the oil field. Poisson's equation is utilized to develop fluid saturation distributions from the electrical current and potential measurement. Both signal generating equipment and chemical means are used to develop current flow among the several open-hole wells.

  13. 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.

  14. 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

  15. Polymer flooding increases production in giant oil field

    SciTech Connect

    Delamaide, E.; Corlay, P. )

    1994-12-01

    Daqing field, discovered in 1959, is the largest oil field in the People's Republic of China, with original oil in place exceeding two billion tons. Reservoir heterogeneity and oil viscosity have resulted in moderate displacement efficiency and high watercut. To increase recovery, polymer injection was tested in two pilots between 1987 and 1992, after lab and reservoir studies. Both pilots proved highly successful and led to the decision to extend polymer injection to the whole field. This article presents the history of Daqing polymer flooding, from preliminary studies to full-field extension.

  16. Kill fluid for oil field operations

    SciTech Connect

    Sydansk, R.D.

    1990-08-14

    This patent describes a process employing a kill fluid to substantially reduce the volumetric flow of formation fluid into a wellbore penetrating a formation containing the formation fluid below an earthen surface. It comprises: admixing components of a continuous flowing gel at the surface comprising of water-soluble carboxylate-containing polymer, a complex capable of crosslinking the polymer and formed of at least one electropositive chromium III species and at least one electronegative carboxylatespecies, and an aqueous solvent for the polymer and the complex; crosslinking the polymer and the complex to form the gel, wherein the kill fluid comprises the gel; placing a volume of the kill fluid in the wellbore sufficient to create a hydrostatic head which exerts a kill fluid pressure against the formation fluid substantially equal to or greater than the formation fluid pressure and thereby substantially reduces the volumetric flow of the formation fluid into the wellbore; performing an oil field operation after placing the volume of the kill fluid in the wellbore; and removing the gel from the wellbore to substantially restore the volumetric flow of the formation fluid into the wellbore.

  17. Plans to revive oil fields in Venezuela on track

    SciTech Connect

    Not Available

    1992-02-24

    This paper reports on the three operating units of Venezuela's state owned oil company Petroleos de Venezuela SA which will begin receiving bids Feb. 28 from companies interested in operating 55 inactive oil fields in nine producing areas of Venezuela. Francisco Pradas, Pdvsa executive in charge of the program, the the company expects 88 companies or combines of foreign and domestic private companies to participate in the bidding. The program, announced last year, aims to reactivate production in marginal oil fields. It will involve the first direct participation by private companies in Venezuela's oil production since nationalization in 1976.

  18. Coreflood assay using extremophile microorganisms for recovery of heavy oil in Mexican oil fields.

    PubMed

    Castorena-Cortés, Gladys; Roldán-Carrillo, Teresa; Reyes-Avila, Jesús; Zapata-Peñasco, Icoquih; Mayol-Castillo, Martha; Olguín-Lora, Patricia

    2012-10-01

    A considerable portion of oil reserves in Mexico corresponds to heavy oils. This feature makes it more difficult to recover the remaining oil in the reservoir after extraction with conventional techniques. Microbial enhanced oil recovery (MEOR) has been considered as a promising technique to further increase oil recovery, but its application has been developed mainly with light oils; therefore, more research is required for heavy oil. In this study, the recovery of Mexican heavy oil (11.1°API and viscosity 32,906 mPa s) in a coreflood experiment was evaluated using the extremophile mixed culture A7, which was isolated from a Mexican oil field. Culture A7 includes fermentative, thermophilic, and anaerobic microorganisms. The experiments included waterflooding and MEOR stages, and were carried out under reservoir conditions (70°C and 9.65 MPa). MEOR consisted of injections of nutrients and microorganisms followed by confinement periods. In the MEOR stages, the mixed culture A7 produced surface-active agents (surface tension reduction 27 mN m⁻¹), solvents (ethanol, 1738 mg L⁻¹), acids (693 mg L⁻¹), and gases, and also degraded heavy hydrocarbon fractions in an extreme environment. The interactions of these metabolites with the oil, as well as the bioconversion of heavy oil fractions to lighter fractions (increased alkanes in the C₈-C₃₀ range), were the mechanisms responsible for the mobility and recovery of heavy oil from the porous media. Oil recovery by MEOR was 19.48% of the residual oil in the core after waterflooding. These results show that MEOR is a potential alternative to heavy oil recovery in Mexican oil fields. PMID:22704814

  19. Exploitation of multizones by waterflooding in the Daqing oil field

    SciTech Connect

    Jinyusun; Yangwanli; Wangzhiwu

    1982-01-01

    The distribution of oil and water in the pay zones and the constant changes of relationship taking place among the zones in the course of development of a sandstone oil reservoir by waterflooding bear closely on its stable production and ultimate recovery. So, the result of development of an oil field depends largely on knowledge of the changing conditions and the ability to cope with them by regulatory or reconstructive measures. All the pay zones in the Daqing oil field have been clearly segregated, and on this basis, different zones in the one and same well may be flooded and produced separately. The development of the Daqing oil field has been successful, comparable to similar oil fields in the U.S. and Soviet Union in the following respects, which are disucssed: reservoir pressure maintained; wells kept flowing; stable average daily output; long, stable high- yielding period; and less water consumed than in oil fields of other countries producing oil of similar viscosity. (12 refs.)

  20. 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.

  1. Using InSAR to Analyze the Effects of Oil Extraction on the Kuparuk Oil Field

    NASA Astrophysics Data System (ADS)

    Baluyut, E.; Liu, L.; Zebker, H. A.

    2012-12-01

    Ground deformation around oil fields is a major concern in regards to the impacts of this human-induced change on the environment. Interferometric synthetic aperture radar (InSAR) was used to map the ground deformation in the area of the Kuparuk Oil Field in Northern Alaska from 2007 to 2010. Data packages from the Advanced Land Observation Satellite (ALOS) and corresponding data for the digital elevation model (DEM) were used to create interferograms and the DEM. This was done using MATLAB and Python on a Linux operating system. Selected interferograms were cropped and errors from noise, topography, or atmosphere were minimized through fitting and stacking techniques. After analysis, the InSAR data yielded a chronology of a change in ground deformation around the Kuparuk Oil Field, which is correlated to a history of recovery techniques. Analysis of interferograms from before, in transition, and after application of different techniques can determine patterns of ground deformation in the field. It was found that positive ground deformation was more prevalent before the implementation of new oil recovery techniques as opposed to after implementation, with negative ground deformation occurring during the transition of the applications that allowed for more productive oil extraction. These results quantitatively demonstrate the magnitude of land subsidence that actively recovered oil fields induce. They also suggest that new methods of enhanced oil recovery are stabilizing the subterranean layers being drilled, creating a decrease in positive land deformation. This could support the continuation of research in fields of enhanced oil recovery and carbon sequestration.

  2. Oil and Gas field code master list 1995

    SciTech Connect

    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.

  3. Oil field waste disposal costs at commercial disposal facilities

    SciTech Connect

    Veil, J.A.

    1997-10-01

    The exploration and production segment of the U.S. oil and gas industry generates millions of barrels of nonhazardous oil field wastes annually. In most cases, operators can dispose of their oil fields wastes at a lower cost on-site than off site and, thus, will choose on-site disposal. However, a significant quantity of oil field wastes are still sent to off-site commercial facilities for disposal. This paper provides information on the availability of commercial disposal companies in different states, the treatment and disposal methods they employ, and how much they charge. There appear to be two major off-site disposal trends. Numerous commercial disposal companies that handle oil field wastes exclusively are located in nine oil-and gas-producing states. They use the same disposal methods as those used for on-site disposal. In addition, the Railroad Commission of Texas has issued permits to allow several salt caverns to be used for disposal of oil field wastes. Twenty-two other oil- and gas-producing states contain few or no disposal companies dedicated to oil and gas industry waste. The only off-site commercial disposal companies available handle general industrial wastes or are sanitary landfills. In those states, operators needing to dispose of oil field wastes off-site must send them to a local landfill or out of state. The cost of off-site commercial disposal varies substantially, depending on the disposal method used, the state in which the disposal company is located, and the degree of competition in the area.

  4. Characterizing Air Toxics from Oil Field Operations in Los Angeles

    NASA Astrophysics Data System (ADS)

    McCarthy, M. C.; Brown, S. G.; DeWinter, J. L.; Bai, S.; O'Brien, T.; Vaughn, D.; Peltier, R.; Soltis, J.; Field, R. A.; Murphy, S. M.; Roberts, P. T.

    2014-12-01

    The Inglewood Oil Field in urban Los Angeles has been in operation for more than 70 years. Neighborhoods surrounding the oil field are concerned with the potential emissions of air toxics from oil field operations. The Baldwin Hills Air Quality Study focused on (1) quantifying air toxics concentrations originating from the Inglewood Oil Field operations, including drilling and well workovers, and (2) assessing the health risk of both acute and chronic exposure to air toxics emitted from oil field operations. Key pollutants identified for characterization included diesel particulate matter (DPM), cadmium, benzene, nickel, formaldehyde, mercury, manganese, acrolein, arsenic, and lead. The field study began in November 2012 and ended in November 2013. Four types of instruments were used to characterize oil field operations: (1) Aethalometers to measure black carbon (BC; as a proxy for DPM); (2) X-ray fluorescence spectrometer (XRF) for metals; (3) Proton-Transfer-Reaction Time-of-Flight Mass Spectrometry (PTR-TOFMS) for volatile organic compounds; and (4) meteorological sensors to help assess the wind patterns, temperature, and humidity that influence pollutant concentrations. Overall concentrations of most of the species measured in the study were quite low for an urban area. We determined that there were statistically significant increases in concentrations of DPM associated with oil field operations when winds were from the west-southwest. BC concentrations increased by 0.036 to 0.056 μg/m3, on average, when winds originated from the west-southwest, compared to annual mean BC concentrations of approximately 0.67 μg/m3. West-southwest winds occurred 53% of the time during the study. No other pollutants showed strong statistical evidence of chronic or acute risk from oil field operations.

  5. 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, E.D.; Freeman, P.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.

  6. Oil fields of northern Railroad Valley, Nye County, Nevada

    SciTech Connect

    Duey, H.D.

    1989-03-01

    Since 1954 four oil fields have been discovered in northern Railroad Valley: Eagle Springs, Trap Springs, Currant, and Kate Spring. Though similar in many aspects, each is unique in structure, stratigraphy, and reservoir conditions. Oil accumulation in all four fields is related to faulting, and all reservoirs are either fractured or enhanced by fractures. The reservoir rocks vary from Tertiary ignimbrites to Tertiary lacustrine sediments to Paleozoic carbonates. A Tertiary unconformity controls the seal at Trap Spring, Eagle Springs, and Kate Spring. At Currant the seal is the Tertiary Sheep Pass shale. There are two basic oil types. Oil has been generated from shales of the Tertiary Sheep Pass Formation and the Mississippian Chainman Formation. Oil generation is probably recent and continuing. These oils are mixed in at least two reservoirs. Over 10 million bbl of oil have been produced in northern Railroad Valley, and despite the variability of the stratigraphy, structure, and oil generation, the area is still a viable hunting ground for modest reserves. Using these fields along with their permutations and combinations as models makes exploration in the rest of the Basin and Range province inspiring.

  7. Geology and geochemistry of crude oils, Bolivar coastal fields, Venezuela

    SciTech Connect

    Bockmeulen, H.; Barker, C.; Dickey, P.A.

    1983-02-01

    The Bolivar Coastal Fields (BCF) are located on the eastern margin of Lake Maracaibo, Venezuela. They form the largest oil field outside of the Middle East and contain mostly heavy oil with a gravity less than 22/sup 0/ API. Thirty crude oils from the BCF were collected along two parallel and generally southwest-northeast trends. These oils were characterized by their API gravity, percent saturates, aromatics, NSO and asphalitic compounds, gas chromatograms for whole oils, C/sub 4/-C/sub 7/ fractions, and aromatics. Also, 24 associated waters were sampled and analyzed for Ca/sup + +/, Mg/sup + +/, Na/sup +/, HCO/sub 3//sup -/, CO/sub 3//sup - -/, SO/sub 4//sup - -/, pH, and total dissolved solids (TDS). The geological and geochemical significances of these analyses are discussed with particular emphasis on the genesis of the petroleum.

  8. 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.

  9. 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.

  10. Oil and gas field code master list 1997

    SciTech Connect

    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.

  11. Polarimetric SAR Models for Oil Fields Monitoring in China Seas

    NASA Astrophysics Data System (ADS)

    Buono, A.; Nunziata, F.; Li, X.; Wei, Y.; Ding, X.

    2014-11-01

    In this study, physical-based models for polarimetric Synthetic Aperture Radar (SAR) oil fields monitoring are proposed. They all share a physical rationale relying on the different scattering mechanisms that characterize a free sea surface, an oil slick-covered sea surface, and a metallic target. In fact, sea surface scattering is well modeled by a Bragg-like behaviour, while a strong departure from Bragg scattering is in place when dealing with oil slicks and targets. Furthermore, the proposed polarimetric models aim at addressing simultaneously target and oil slick detection, providing useful extra information with respect to single-pol SAR data in order to approach oil discrimination and classification. Experiments undertaken over East and South China Sea from actual C-band RadarSAT-2 full-pol SAR data witness the soundness of the proposed rationale.

  12. Salt caverns show promise for nonhazardous oil field waste disposal

    SciTech Connect

    Veil, J.A.

    1996-11-18

    Salt caverns show promise for the disposal of non-hazardous oil field wastes, and there are no apparent regulatory barriers to this application. Solution-mined salt caverns have been used for many years for storing hydrocarbon products. Argonne National laboratory has reviewed the legality, technical suitability, and feasibility of disposing of nonhazardous oil and gas exploration and production wastes in salt caverns. An analysis of regulations indicates that there are no outright regulatory prohibitions on cavern disposal of oil field wastes at either the federal level or in the 11 oil-producing states that were studied (Kansas, Louisiana, Michigan, Mississippi, New Mexico, New York, North Dakota, Ohio, Oklahoma, Pennsylvania, and Texas). The paper discusses the two types of salt deposits in the US, regulatory concerns, wastes, cavern design, disposal operations, closure and remediation, and results of the feasibility study.

  13. 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.

  14. Verifying a Simplified Fuel Oil Field Measurement Protocol

    SciTech Connect

    Henderson, Hugh; Dentz, Jordan; Doty, Chris

    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.

  15. 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.; Bragg, J.R.; Douglas, G.S.

    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.

  16. Hydrocarbon emissions in the Bakken oil field in North Dakota

    NASA Astrophysics Data System (ADS)

    Mielke-Maday, I.; Petron, G.; Miller, B.; Frost, G. J.; Peischl, J.; Kort, E. A.; Smith, M. L.; Karion, A.; Dlugokencky, E. J.; Montzka, S. A.; Sweeney, C.; Ryerson, T. B.; Tans, P. P.; Schnell, R. C.

    2014-12-01

    Within the past five years, the production of oil and natural gas in the United States from tight formations has increased rapidly due to advances in technology, such as horizontal drilling and hydraulic fracturing. With the expansion of oil and natural gas extraction operations comes the need to better quantify their emissions and potential impacts on climate forcing and air quality. The Bakken formation within the Williston Basin in North Dakota has emerged as a large contributor to the recent growth in oil production and accounts for over 10% of domestic production. Close to 30% of associated gas co-produced with the oil is flared. Very little independent information is currently available to assess the oil and gas industry emissions and their impacts on regional air quality. In May 2014, an airborne field campaign was conducted by the National Oceanic and Atmospheric Administration's (NOAA) Earth System Research Laboratory and the University of Michigan to investigate hydrocarbon emissions from operations in the oil field. Here, we present results from the analysis for methane, several non-methane hydrocarbons and combustion tracers in 72 discrete air samples collected by the aircraft on nine different flights. Samples were obtained in the boundary layer upwind and downwind of the operations and in the free troposphere. We will show results of a multiple species analysis and compare them with field campaign data from other U.S. oil and gas fields, measurements from NOAA's Global Monitoring Division long-term observing network, and available bottom-up information on emissions from oil and gas operations.

  17. Crude oil from the Samgori field

    SciTech Connect

    Dorogochinskaya, V.A.; Manovyan, A.K.; Shigapova, A.K.; Shul'zhenko, E.D.; Varshaver, V.P.

    1984-04-01

    This article analyzes the chemical composition and physical properties of petroleum from the Georgian SSR. The crude oil is light in color, light in distillation range, low-viscosity, and medium-wax, with low contents of resin-asphaltene compounds, sulfur, and metals. This petroleum is characterized by its high content of naphtha cuts with low sulfur contents, low octane numbers (owing to the high contents of paraffin hydrocarbons), and low contents of aromatics. It is determined that the best flow plan for processing the crude is either a fuel scheme or a fuel/lube scheme, depending on the specific product demands.

  18. Microbial consortia in Oman oil fields: a possible use in enhanced oil recovery.

    PubMed

    Al-Bahry, Saif N; Elshafie, Abdulkader E; Al-Wahaibi, Yahya M; Al-Bemani, Ali S; Joshi, Sanket J; Al-Maaini, Ratiba A; Al-Alawi, Wafa J; Sugai, Yuichi; Al-Mandhari, Mussalam

    2013-01-01

    Microbial enhanced oil recovery (MEOR) is one of the most economical and efficient methods for extending the life of production wells in a declining reservoir. Microbial consortia from Wafra oil wells and Suwaihat production water, Al-Wusta region, Oman were screened. Microbial consortia in brine samples were identified using denaturing gradient gel electrophoresis and 16S rRNA gene sequences. The detected microbial consortia of Wafra oil wells were completely different from microbial consortia of Suwaihat formation water. A total of 33 genera and 58 species were identified in Wafra oil wells and Suwaihat production water. All of the identified microbial genera were first reported in Oman, with Caminicella sporogenes for the first time reported from oil fields. Most of the identified microorganisms were found to be anaerobic, thermophilic, and halophilic, and produced biogases, biosolvants, and biosurfactants as by-products, which may be good candidates for MEOR. PMID:23314376

  19. A field laboratory for improved oil recovery. Final report

    SciTech Connect

    Hildebrandt, A.F.; McDonald, J.; Claridge, E.; Killough, J.

    1992-09-01

    The purpose of Annex III of the Memorandum of Understanding, undertaken by the Houston Petroleum Research Center at the University of Houston, was to develop a field laboratory for research in improved oil recovery using a Gulf Coast reservoir in Texas. The participants: (1) make a field site selection and conducted a high resolution seismic survey in the demonstration field, (2) obtained characteristics of the reservoir (3) developed an evaluation of local flood efficiency in different parts of the demonstration reservoir, (4) used diverse methodology to evaluate the potential recovery of the remaining oil in the test reservoir, (5) developed cross-well seismic tomography, and (6) will transfer the learned technologies to oil operators through publication and workshops. This abstract is an overview of these tasks.

  20. Composition and placement process for oil field chemicals

    SciTech Connect

    Cantu, L.A.; Yost, M.E.

    1991-01-22

    This patent describes a process for the continuous release of an oil field chemical within a subterranean hydrocarbon bearing formation or wellbore penetrating such formation. It comprises placing the oil field chemical in a polymeric microcapsule; dispersing such polymeric microcapsules; introducing the wellbore fluid containing the microcapsules into a well bore or subterranean formation through a wellbore; then allowing water and temperature at formation conditions to degrade; continuously releasing the chemical from the degraded microcapsules. This patent describes a composition comprising an oil field chemical incorporated in a polymeric microcapsule comprising the condensation product of hydroxyacetic acid monomer or hydroxyacetic acid co-condensed with up to 15 percent by weight of other hydroxy-, carboxylic acid-, or hydroxycarboxylic acid- containing moieties. The product has a number average molecular weight of from about 200 to about 4000.

  1. Alkanes in shrimp from the Buccaneer Oil Field

    SciTech Connect

    Middleditch, B.S.; Basile, B.; Chang, E.S.

    1982-07-01

    A total of 36 samples of shrimp were examined from the region of the Buccaneer oil field, eighteen of which were representatives of the commercial species Penaeus aztecus and the rest were various other species: Penaeus duorarum (pink shrimp), Trachypenaeus duorarum (sugar shrimp), Squilla empusa (mantis shrimp), and Sicyonia dorsalis (chevron shrimp). The alkanes and deuteriated alkanes were completely separated by GC, so a mass spectrometer was not required for their detection and quantitation. To confirm the identities of individual compounds, however, some samples were examined by combined gas chromatography-mass spectrometry. Results show that only thirteen of the forty shrimp collected from the region of the Buccaneer oil field contained petroleum alkanes, and the majority of these were obtained from trawls immediately adjacent to the production platforms. It appears that shrimp caught in the region of the Buccaneer oil field are not appreciably tainted with hydrocarbons discharged from the production platforms. (JMT)

  2. 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

  3. Oil-field equipment in Romania. Export trade information

    SciTech Connect

    Tinis, R.

    1991-09-01

    The Industry Sector Analyses (I.S.A.) for oil field equipment contains statistical and narrative information on projected market demand, end-users, receptivity of Romanian consumers to U.S. products, the competitive situation - Romanian production, total import market, U.S. market position, foreign competition, and competitive factors, and market access - Romanian tariffs, non-tariff barriers, standards, taxes and distribution channels. The I.S.A. provides the United States industry with meaningful information regarding the Romanian market for oil field equipment.

  4. Subtle history and geology of Villeperdue oil field

    SciTech Connect

    Duval, B.C.; Arbin, P. )

    1990-09-01

    Villeperdue oil field is located in the Paris basin 80 km east of Paris. The first well was drilled in 1959 and tested some oil. But it was not until 1982, after a subtle seismic and drilling history, that exploration resumed and the field proved commercial. The reservoir is an oolitic limestone of early Callovian age (late Dogger); it has an average thickness of about 30 m and is 1,850 m below ground level. The trap, not obvious from seismic data, is a combination of stratigraphic, structural, and diagenetic features. The structure is a western-plunging nose, and the eastward updip closure is supposedly controlled by permeability change with the possible influence of gentle faults and pressure barriers. The producing surface is about 70 km{sup 2}, with a 60-m oil column. Gross porosity, ranging from 8 to 20%, is highly variable, the result of numerous porosity types. As a result, each well has its own characteristics, and field development is mainly controlled by this problem. Thus, porosity detection over the field, and consequently delineation, are dependent on subtle seismic facies studies. Today, 145 wells have been drilled, of which 120 are producing and 19 are used for water injection. Horizontal wells are planned to increase productivity. Production of this giant oil field (based on the Paris basin scale) has been of 3 million m{sup 3} to date, with an average weekly production of about 13,000 m{sup 3}.

  5. Oil field slim hole drilling technology improving

    SciTech Connect

    Not Available

    1992-11-23

    Recent advances in slim hole drilling technology have improved the application of this drilling technique to oil and gas exploration and development wells. These advancements include Optimization of slim hole drilling hydraulics, Application of a small particle weighing agent to improve well control and coring operations, Use of slim hole techniques to drill horizontal wells, Use of a new polycrystalline diamond compact cutter to allow economical re-entry of small diameter wells in hard rock. Slim hole continuous coring and drilling is becoming more accepted as a viable drilling method, especially as exploration budgets become smaller. Typical applications for slim hole equipment include drilling in frontier areas where logistics can be a problem and reentry operations in which the existing well has a small diameter. Typically, slim hole drilling operations use technology borrowed from the mining industry. The rigs are smaller and drill with much higher rotational speeds. Definitions of slim holes vary from a well with 90% drilled, with a diameter of less than 7 in. To a well with 70% drilled with less than 5 in. A goal of slim hole, however it is defined, is the drilling of a well with a diameter smaller than that used on conventional wells in the area. The reduced diameter helps cut rig time and cost and reduces the cost of the tubulars. Another goal of slim hole drilling is the ability to retrieve cores from the entire well during drilling.

  6. Biodiesel Prepared From Field Pennycress Oil

    Technology Transfer Automated Retrieval System (TEKTRAN)

    Field pennycress (Thlaspi arvense L., FP) is a winter annual species of the mustard family (Brassicaceae) which is widely distributed throughout temperate North America that can serve as a winter rotational crop for conventional crops, thus not displacing farm land or negatively impacting the food s...

  7. Spectral anomaly over Railroad Valley oil field, Nevada

    SciTech Connect

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

    1990-05-01

    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 prolific wells onshore in the continental US. Production in the Railroad Valley fields is from Oligocene volcanic and sedimentary rocks and Paleozoic carbonate formations. Traps are structural or structural and stratigraphic, and reservoir seals are indurated or clayey valley fill, weathered tuff, and shales in Tertiary sediments. Reservoir temperatures range between 95 and 309{degree}F. Previous workers have identified a statistically significant positive correlation between hydrocarbon microseepage and vegetation anomalies over the Railroad Valley oil fields with Landsat Multispectral Scanner (MSS) imagery. Several flight lines of high spectral and spatial resolution imagery in the visible, near infrared, shortwave infrared, and thermal infrared regions of the spectrum were flown with Geoscan's MkII Airborne Multispectral Scanner to determine if there was a mineralogical signature associated with the oil fields. The 24-channel scanner collected 8-m resolution picture elements over a swath of about 8 km. Image processing strategies were developed from a knowledge of the spectral curves of minerals in the laboratory. The results from processing Geoscans MkII data were also compared with those obtained from processing Landsat Thematic Mapper (TM) imagery over the same area. An 8 {times} 6 km carbonate and iron anomaly was detected on the processed MkII imagery over the Trap Spring oil field. This anomaly may be related to hot spring activity, reported by other workers, that has formed extensive calcite deposits along faults.

  8. 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.

  9. 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...

  10. Crosshole EM for oil field characterization and EOR monitoring: Field examples

    SciTech Connect

    Wilt, M.; Schenkel, C.; Lee, K.; Torrses-Verdin, C.; Tseng, H.

    1994-12-31

    Crosshole and surface-to-borehole electromagnetic (EM) imaging is applied to reservoir characterization and steam flood monitoring in a central California oil field. Steam was injected into 3 stacked eastward dipping unconsolidated oil sands. EM measurements were made from two fiberglass-cased observation wells straddling the steam injector on a northeast-southwest profile. Field data were collected before the initiation of a steam drive to map the distribution of the oil sands and then six months after the steam was injected to monitor the progress of the steam chest. Resistivity images derived from the collected data could clearly delineate the distribution and dipping structure on the target oil sands. Difference images from data collected before and after steam flooding indicate that the steam chest has developed only in the deeper oil sands and it has preferentially migrated eastward.

  11. Carcinogenic potential of PAHs in oil-contaminated soils from the main oil fields across China.

    PubMed

    Wang, Jie; Cao, Xiaofeng; Liao, Jingqiu; Huang, Yi; Tang, Xiaoyan

    2015-07-01

    The concentrations, composition profiles, and sources of polycyclic aromatic hydrocarbons (PAHs) were analyzed in 55 surface soil samples collected from four oil fields across China (Daqing, DQ; Shengli, SL; Xinjiang, XJ; and Huabei, HB). The total 16 priority PAHs concentrations of DQ, SL, XJ, and HB ranged from 857 to 27,816; 480 to 20,625; 497 to 43,210; and 12,112 to 45,325 ng/g, respectively, with means of 9160; 6394; 13,569; and 22,954 ng/g and the seven possible carcinogenic PAHs accounted for 8-25.7 % of the total PAHs. Almost all the samples were heavily contaminated, and phenanthrene, chrysene, and pyrene were the most dominant components. The PAH isomeric ratios indicated that PAHs in oil fields mainly originated from petroleum. The toxic assessment illustrated that people living and working in oil fields would suffer low carcinogenic risk, which was somehow coincided with the results of epidemiological survey on cancer incidence. It seems essential to pay more attention to the chronic human health effects of exposure to oil fields and to focus new studies on the public health field that involves a large number of people all over the world. PMID:25772862

  12. Giant oil fields of the Gulf Coast area

    SciTech Connect

    Haeberle, F.R.

    1993-09-01

    The 134 giant fields in the Gulf Coastal area contain 29% of the total giant-field reserves. Cumulative production is 32% of the giant-field cumulative total and 20% of the United States cumulative production. Eighty-nine of the giant fields are offshore with 22% of the reserves, 11 fields are in east Texas with 24% of the reserves, and 1 field is in Florida with 1% of the reserves. In 106 of the giant fields the primary producing interval is Cenozoic with 65% of the reserves, and in 28 giant fields the producing interval is Mesozoic with 35% of the reserves. The primary producing interval is Mesozoic with 35% of the reserves. The primary producing interval in 124 giant fields consists of clastics with 91% of the reserves, in 7 fields the primary lithology is carbonates with 6% of the reserves, and in 3 giant fields the lithology is mixed clastics and carbonates. A total of 127 fields are in structural traps with all of the reserves, 4 fields are stratigraphic traps (3%) with 18% of the reserves, and 3 fields are combination traps with 1% of the reserves. Over 50 of the giant oil fields in structural traps are salt domes. The most prevalent types of giant fields in the Gulf Coastal area are onshore structural traps with Cenozoic clastics as the primary producing intervals.

  13. Disposal of nonhazardous oil field wastes into salt caverns

    SciTech Connect

    Veil, J.; Elcock, D.; Raivel, M.; Caudle, D.

    1996-12-31

    Bedded and domal salt deposits occur in many states. If salt deposits are thick enough, salt caverns can be formed through solution mining. These caverns are created either incidentally as a result of salt recovery or intentionally to create an underground chamber that can be used for storing hydrocarbon products or disposing of wastes. This paper evaluates the legality, feasibility, and suitability 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.

  14. Stratigraphy of Citronelle Oil Field, AL: Perspectives from Enhanced Oil Recovery and Potential CO2 Sequestration

    NASA Astrophysics Data System (ADS)

    Hills, D. J.; Pashin, J. C.; Kopaska-Merkel, D. C.; Esposito, R. A.

    2008-12-01

    The Citronelle Dome is a giant salt-cored anticline in the eastern Mississippi Interior Salt Basin of south Alabama. The dome forms an elliptical structural closure containing multiple opportunities for enhanced oil recovery (EOR) and large-capacity saline reservoir CO2 sequestration. The Citronelle Oil Field, which is on the crest of the dome, has produced more than 168 MMbbl of 42° gravity oil from marginal marine sandstone in the Lower Cretaceous Donovan Sand. Recently, EOR field tests have begun in the northeastern part of the oil field. Citronelle Unit B-19-10 #2 well (Alabama State Oil and Gas Board Permit No. 3232) will serve as the CO2 injector for the first field test. CO2 will be injected into the Upper Donovan 14-1 and 16-2 sandstone units. All well logs in the 4-square-mile area surrounding the test site have been digitized and used to construct a network of nineteen stratigraphic cross sections correlating Sands 12 through 20A in the Upper Donovan. Detailed study of Citronelle cores has shown that depositional environments in the Donovan Sand differed significantly from the earlier model that has guided past development of the Citronelle Field. The cross sections demonstrate the extreme facies heterogeneity of the Upper Donovan, and this heterogeneity is well expressed within the five-spot well pattern where the field test will be conducted. Many other features bearing on the performance of the CO2 injection test have been discovered. Of particular interest is the 16-2 sand, which is interpreted as a composite of two tiers of channel fills. Pay strata are typically developed in the lower tier, and this is where CO2 will be injected. The upper tier is highly heterogeneous and is interpreted to contain sandstone fills of variable reservoir quality, as well as mudstone plugs.

  15. Oil field experiments of microbial improved oil recovery in Vyngapour, West Siberia, Russia

    SciTech Connect

    Murygina, V.P.; Mats, A.A.; Arinbasarov, M.U.; Salamov, Z.Z.; Cherkasov, A.B.

    1995-12-31

    Experiments on microbial improved oil recovery (MIOR) have been performed in the Vyngapour oil field in West Siberia for two years. Now, the product of some producing wells of the Vyngapour oil field is 98-99% water cut. The operation of such wells approaches an economic limit. The nutritious composition containing local industry wastes and sources of nitrogen, phosphorus and potassium was pumped into an injection well on the pilot area. This method is called {open_quotes}nutritional flooding.{close_quotes} The mechanism of nutritional flooding is based on intensification of biosynthesis of oil-displacing metabolites by indigenous bacteria and bacteria from food industry wastes in the stratum. 272.5 m{sup 3} of nutritious composition was introduced into the reservoir during the summer of 1993, and 450 m3 of nutritious composition-in 1994. The positive effect of the injections in 1993 showed up in 2-2.5 months and reached its maximum in 7 months after the injections were stopped. By July 1, 1994, 2,268.6 tons of oil was produced over the base variant, and the simultaneous water extraction reduced by 33,902 m{sup 3} as compared with the base variant. The injections in 1994 were carried out on the same pilot area.

  16. DOE tallies Class III oil recovery field projects

    SciTech Connect

    Not Available

    1994-07-25

    Here are details from midterm proposals submitted as part of the US Department of Energy's Class 3 oil recovery field demonstration candidate projects. All of the proposals emphasize dissemination of project details so that the results, if successful, can be applied widely in similar reservoirs. Project results will also be fed into a national petroleum technology transfer network. The proposals include: Gulf of Mexico, Gulf coast, offshore California, a California thermal, immiscible CO[sub 2], produced/potable water, microbial EOR, California diatomite, West Texas Spraberry field, and other Permian Basin fields.

  17. Toxicology of oil field pollutants in cattle: a review.

    PubMed

    Coppock, R W; Mostrom, M S; Khan, A A; Semalulu, S S

    1995-12-01

    Cattle are poisoned by petroleum and substances used in drilling and operating oil and gas wells. The most common reported route of exposure for non-gaseous material is oral. Exposures occur when the petroleum or chemicals used in oil and gas field activities are available to cattle and when water and feed-stuffs are contaminated. Cattle, as a leisure activity, explore and ingest crude oil. Based on morbidity patterns in cattle herds, the amount of toxic substance ingested is variable. When water and feedstuffs are contaminated, a larger number in a herd generally are affected. Cattle have been poisoned by a wide variety of chemical mixtures. For substances high in volatile hydrocarbons, the lung is a target organ. Hydrocarbons also target the kidney, liver and brain. Exposure-linked abortions have been reported in cattle. Diethylene glycol targets the brain, liver and kidney. The reported threshold dose of unweathered oil for cattle ranges from 2.5 to 5.0 ml/kg bw, and the reported threshold dose for weathered oil is 8.0 ml/kg. PMID:8588300

  18. 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.

  19. Evaluating oil quality and monitoring production from heavy oil reservoirs using geochemical methods: Application to the Boscan Field, Venezuela

    SciTech Connect

    Kaufman, R.L.; Noguera, V.H.; Bantz, D.M.; Rodriguez, R.

    1996-08-01

    Many oil fields worldwide contain heavy oil in one or more reservoir units. The low gravity of these oils is most frequently due to biodegradation and/or low maturity. The challenge is to find ways to economically recover this oil. Methods which reduce the operating costs of producing heavy oil add significant value to such projects. Geochemical techniques which use the composition of the reservoir fluids as natural tracers offer cost effective methods to assist with reservoir management. The low viscosity and gravity of heavy oil, combined with frequent high water cuts, low flow rates, and the presence of downhole artificial lift equipment, make many conventional production logging methods difficult to apply. Therefore, monitoring production, especially if the produced oil is commingled from multiple reservoirs, can be difficult. Geochemical methods can be used to identify oil/water contacts, tubing string leaks and to allocate production to individual zones from commingled production. An example of a giant heavy oil field where geochemical methods may be applicable is the Boscan Field in Venezuela. Low maturity oil, averaging 10{degrees} API gravity, is produced from the Eocene Upper and Lower Boscan (Miosa) Sands. Geochemical, stratigraphic and engineering data have helped to better define the controls on oil quality within the field, identified new reservoir compartments and defined unique characteristics of the Upper and Lower Boscan oils. This information can be used to identify existing wells in need of workovers due to mechanical problems and to monitor production from new infill wells.

  20. Clay-oil droplet suspensions in electric fields

    NASA Astrophysics Data System (ADS)

    Rozynek, Zbigniew; Fossum, Jon Otto; Kjerstad, Knut; Mikkelsen, Alexander; Castberg, Rene

    2012-02-01

    Silicone oil droplets containing synthetic smectite clay submerged in immiscible organic oil have been studied by observing clay particle movement and oil circulation when an electric field is applied. Results show how electric field strength, dielectric and electrorheological properties as well as electrohydrodynamics determine the fluid flow and clay particle formation. In a presence of the DC electric fields the clay particles formed a ribbon-like structure onto the inner surface of the droplet. The structure consists of short chain-like clay elements orienting parallel to the electric field direction. It is suggested that a combination of two phenomena, namely the induced viscous flow (electrohydrodynamic effect) and the polarization of the clay particles (dielectric effect), contribute to the ribbon-like structure formation. -/abstract- References [1] G. Taylor, Proceedings of the Royal Society of London. Series A. Mathematical and Physical Sciences 291 (1966) 159--166. [2] J. R. Melcher and G. I. Taylor, Annual Review of Fluid Mechanics 1 (1969) 111--146. [3] H. Sato, N. Kaji, T. Mochizuki, and Y. H. Mori, Physics of Fluids 18 (2006) 127101. [4] D. A. Saville, Annual Review of Fluid Mechanics 29 (1997) 27--64. [5] J. O. Fossum, Y. M'eheust, K. P. S. Parmar, K. D. Knudsen, K. J. Måløy, and D. M. Fonseca Europhysics Letters 74

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

    SciTech Connect

    Isaacs, E.E.; Ivory, J.; Law, D.H.S.

    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.

  2. Source rock identification and oil generation related to trap formation: Southeast Constantine oil field

    SciTech Connect

    Boudjema, A.; Rahmani, A.; Belhadi, E.M.; Hamel, M.; Bourmouche, R. )

    1990-05-01

    Petroleum exploration began in the Southeast Constantine basin in the late 1940s. Despite the very early discovery of Djebel Onk field (1954), exploration remains very sparse and relatively unsuccessful due mainly to the geological complexity of the region. The Ras-Toumb oil field was discovered only twenty years later. In 1988, a new discovery, the Guerguit-El-Kihal oil field renewed the interest of explorationists in this region. The Southeast Constantine Mesozoic-Cenozoic basin has a sedimentary sequence of shales and carbonates with a thickness exceeding 7,000 m. Structural traps are related to pyrenean and post-Villafranchian phases. Potential reservoirs with good petrophysical characteristics and seals can be found throughout the section and are mainly Cenomanian-Turonian and Coniacian limestones and dolomites. The known source rocks are Cenomanian-Turonian and Campanian carbonate shales. Kerogen is a mixture of type II and type III for the Campanian. The kerogen has a fair petroleum potential and is often immature or low mature. The Cenomanian-Turonian kerogen is type II amorphous, with a variable but important petroleum potential. Total organic carbon values range from 1.5% to 7%. Maturity corresponds to the oil window. This source rock is well known throughout the Mediterranean region and is related to the oceanic anoxic event. Kinetic modeling of this organic matter evolution indicates favorable oil generation timing related to trap formation ages.

  3. 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.

  4. Earthquakes in the oil field at Rangely, Colorado

    USGS Publications Warehouse

    Gibbs, James F.; Healy, John H.; Raleigh, C. Barry; Coakley, John M.

    1972-01-01

    Seven years of seismic data recorded at the Uinta Basin Observatory were searched for earthquakes originating near an oil field at Rangely, Colorado, located 65 km ESE of the observatory. Changes in the number of earthquakes recorded per year appear to correlate with changes in the quantity of fluid injected per year. Between November 1962 and January 1970, 976 earthquakes were detected near the oil field by the UBO station; 320 earthquakes were larger than magnitude 1. Richter magnitudes are estimated from both S-wave and P-wave measurements and a method based on the duration of the seismic signal is used to estimate the magnitude of the larger shocks. The two largest shocks had magnitudes of 3.4 and 3.3. The total seismic energy released was l0l7 ergs. During this same period the energy used for water injection, measured at the wellhead, was 1021 ergs.

  5. Design of gearbox for oil field hoisting equipment

    SciTech Connect

    Ibragimova, N.E.

    1995-07-01

    The kinematic diagram of the mechanical drive of oil field hoisting equipment is determined by the gear ratio for raising and lowering the down-hole equipment, the necessary hoist load capacity, and the power of the traction engine of the transport base. The choice of a rational gear ratio for raising the down-hole equipment is an important stage in the kinematic design of the transmission. The gear ratio of the gearbox of an oil-field hoist should be such as to ensure that the equipment is raised and lowered most rapidly and the utilization of the traction engine power is highest. The preferred gear train is one chosen in accordance with the geometric structure of the gear train of the gearbox. Such gearboxes are convenient to operate and easy to build. The design of these gearboxes is discussed.

  6. 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.

  7. 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.

  8. Crude oil from the var'egansk field. [Siberia

    SciTech Connect

    Driatskaya, Z.V.; Kaminskii, E.K.; Krylova, S.M.; Mkhchiyan, M.A.

    1982-09-01

    This article presents results from an investigation of a representative sample of the crude oil of the BV group (BV/sub 6/, BV/sub 7/, BV/sub 8/, and BV/sub 9/), taken at a central gathering point in the Tyumen Oblast. It indicates that Var'egansk crude is low-sulfur, medium-resin, and medium-wax. The Var'egansk field is a single-bed field, and its deposits are confined to the Jurassic and Cretaceous systems (Valanginian and Hauterivian-Barremian stages).

  9. Plans for first oil production revived in two Sudanese fields

    SciTech Connect

    Not Available

    1993-05-03

    A Vancouver, British Columbia, independent and its Sudanese partner have filed a development plan with the government of Sudan to produce an initial 40,000 b/d from Heglig and Unity oil fields in Sudan. Arakis Energy Corp., and the private Sudanese company State Petroleum Corp. (SPC) want to begin the first commercial hydrocarbon production in the destitute, war torn country. They are picking up where Chevron Corp. left off after years of grappling with an ambitious, costly - and ultimately futile - effort to export crude-oil from Sudan. After finding almost 300 million bbl of oil in Sudan during the early 1980s, Chevron scuttled a $2 billion project to export 50,000 b/d of Sudanese crude in 1986. It drilled 90 wells and sank more than $1 billion into the project. But it dropped the plan, citing the 1986 collapse of oil prices and concerns over security after repeated guerrilla attacks delayed work. The paper details the project.

  10. 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.

  11. Field observations of artificial sand and oil agglomerates

    USGS Publications Warehouse

    Dalyander, Patricia (Soupy); Long, Joseph W.; Plant, Nathaniel G.; McLaughlin, Molly R.; Mickey, Rangley C.

    2015-01-01

    Oil that comes into the surf zone following spills, such as occurred during the 2010 Deepwater Horizon (DWH) blowout, can mix with local sediment to form heavier-than-water sand and oil agglomerates (SOAs), at times in the form of mats a few centimeters thick and tens of meters long. Smaller agglomerates that form in situ or pieces that break off of larger mats, sometimes referred to as surface residual balls (SRBs), range in size from sand-sized grains to patty-shaped pieces several centimeters (cm) in diameter. These mobile SOAs can cause beach oiling for extended periods following the spill, on the scale of years as in the case of DWH. Limited research, including a prior effort by the U.S. Geological Survey (USGS) investigating SOA mobility, alongshore transport, and seafloor interaction using numerical model output, focused on the physical dynamics of SOAs. To address this data gap, we constructed artificial sand and oil agglomerates (aSOAs) with sand and paraffin wax to mimic the size and density of genuine SOAs. These aSOAs were deployed in the nearshore off the coast of St. Petersburg, Florida, during a field experiment to investigate their movement and seafloor interaction. This report presents the methodology for constructing aSOAs and describes the field experiment. Data acquired during the field campaign, including videos and images of aSOA movement in the nearshore (1.5-meter and 0.5-meter water depth) and in the swash zone, are also presented in this report.

  12. Greater Burgan of Kuwait: world's second largest oil field

    SciTech Connect

    Youash, Y.Y.

    1989-03-01

    Greater Burgan (Main burgan, Magwa, and Ahmadi) field is located in the Arabian Platform geologic province and the stable shelf tectonic environment of the Mesopotamian geosyncline, a sedimentary basin extending from the Arabian shield on the west to the complexly folded and faulted Zagros Mountains on the east. The structural development in Cretaceous time represents a major anticlinorium bounded by a basin to the west and a synclinorium to the east. Greater Burgan is located within this anticlinorium. The field consists of three dome structures 25 km wide and 65 km long with gentle dips of only few degrees. Faults have little throw and did not contribute to the trapping mechanism. The structural deformation may have been caused by halokinetic movements and most likely by basement block faulting that may have started in the Paleozoic. Greater Burgan was discovered in 1938. All production during the last 40 years has been by its natural pressure. Although natural gas injection has been carried out for some time, no waterflooding has been initiated yet. Recoverable reserves of the field are 87 billion bbl of oil. During the last 5 years giant reserves have been added in this field from the deeper strata of Jurassic age. Several deep wells have been drilled to the Permian for the purpose of discovering gas. So far, no Permian gas has been found in Kuwait. The Permian is 25,000 ft deep, and it is unlikely gas will be found there in the future. However, the potential of the Jurassic reservoirs will be a major target in the future. Also, there is a great possibility of discovering oil in stratigraphic traps, as several producing strata in the nearby fields pinch out on the flanks of this giant structure. Enhanced oil recovery should add significant reserves in the future.

  13. Crosshole EM for oil field characterization and EOR monitoring: Field examples

    SciTech Connect

    Wilt, M.; Schenkel, C.; Torres-Verdin, C.; Lee, Ki Ha; Tseng, Hung-Wen

    1994-09-01

    Crosshole and surface-to-borehole electromagnetic (EM) imaging is applied to reservoir characterization and steam flood monitoring in a central California oil field. Steam was injected into three stacked, eastward-dipping, unconsolidated oil sands within the upper 200 in. The steam plume is expected to develop as an ellipse aligned with the regional northwest-southeast strike. EM measurements were made from two flberglass-cased observation wells straddling the steam injector on a northeast-southwest profile. Field data were collected before the initiation of a steam drive to map the distribution of the oil sands and then six months after the steam was injected to monitor the progress of the steam chest. Resisitivity images derived from the EM data collected before steam injection clearly delineate the distribution and dipping structure on the target oil sands. Difference images from data collected before and after steam flooding indicate that the steam chest has developed only in the deeper oil sands, and it has preferentially migrated eastward. Surface-to-borehole measurements were useful in mapping the distribution of the major oil sands, but they were insensitive to resisitivity changes in the early stages of the steam flood.

  14. 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.

  15. Gas condensate and oil from Verkhnechonsk field of eastern Siberia

    SciTech Connect

    Bezhanidze, A.M.; Titkina, G.I.; Krylova, S.M.; Kolevatova, V.P.

    1988-05-01

    Two condensates and three crudes from different sectors and depths of the Verkhnechonsk oil and gas field were assessed for their viscosities, molecular weights, densities, flash and solid and boiling points, cetane and octane numbers, and chemical compositions, including sulfur, nitrogen, nickel, vanadium, wax, resin, and asphaltene contents. The samples were distilled into 10-20 C fractions, reblended in proportion to their contents in the original feedstock, and analyzed by gas-liquid chromatography for product quality and hydrocarbon group composition. Distillation requirements were calculated for generating kerosene, gasoline, and diesel, jet engine, and boiler fuels from the feedstocks. Potential yields of these cuts, as well as yields of lubricating oils and paving asphalts, were evaluated for the five samples.

  16. Floating oil production unit slated in small field off Gabon

    SciTech Connect

    Not Available

    1991-10-14

    This paper reports on the first U.S. tanker converted to a floating production, storage, and offloading (FPSO) unit which takes up station in Gombe-Beta field off Gabon by Dec. 1. FPSO Ocean Producer will work under a 3 year, day rate contract let late in 1990 by Amoco-Gabon Bombe Marin co., a unit of Amoco Production Co. (OGJ, Dec. 24, 1990, p. 27). Gombe-Beta field is in the Atlantic Ocean about 70 miles south of Port Gentil, Gabon. Ocean Producer will be moored in 50 ft of water 3.7 miles off Gabon, with Bombe-Beta's unmanned production platform about 820 ft astern. The vessel will be held in position by a disconnectable, asymmetric, six point, spread mooring system, It is owned and operated by Oceaneering International Services Ltd. (OISL). Affiliate Oceaneering Production Systems (OPS) converted the 78,061 dwt oil tanker MT Baltimore Sea at a capital cost of $25 million at Gulf Copper Manufacturing Corp.'s Port Arthur, Tex., shipyard. Both companies are units of Oceaneering International Inc., Houston. OPS the Ocean Producer's use in Gombe-Beta field is the shallowest water FPSO application in the world. Amoco-Gabon chose an FPSO production system for Gombe-Beta because it expects the remote field to have a short economic life, and the oil requires extensive processing.

  17. Oil gravity distribution in the diatomite at South Belridge Field, Kern County, CA: Implications for oil sourcing and migration

    SciTech Connect

    Hill, D.W.; Sande, J.J.; Doe, P.H.

    1995-04-01

    Understanding oil gravity distribution in the Belridge Diatomite has led to economic infill development and specific enhanced recovery methods for targeted oil properties. To date more than 100 wells have provided samples used to determining vertical and areal distribution of oil gravity in the field. Detailed geochemical analyses were also conducted on many of the oil samples to establish different oil types, relative maturities, and to identify transformed oils. The geochemical analysis also helped identify source rock expulsion temperatures and depositional environments. The data suggests that the Belridge diatomite has been charged by a single hydrocarbon source rock type and was generated over a relatively wide range of temperatures. Map and statistical data support two distinct oil segregation processes occurring post expulsion. Normal gravity segregation within depositional cycles of diatomite have caused lightest oils to migrate to the crests of individual cycle structures. Some data suggests a loss of the light end oils in the uppermost cycles to the Tulare Formation above, or through early biodegradation. Structural rotation post early oil expulsion has also left older, heavier oils concentrated on the east flank of the structure. With the addition of other samples from the south central San Joaquin area, we have been able to tie the Belridge diatomite hydrocarbon charge into a regional framework. We have also enhanced our ability to predict oil gravity and well primary recovery by unraveling some key components of the diatomite oil source and migration history.

  18. 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

  19. Qualitative identification of group composition in crude oil from different oil fields using terahertz time-domain spectroscopy

    NASA Astrophysics Data System (ADS)

    Feng, Cheng J.; Miao, Xin Y.; Li, Yi Z.; Bao, Ri M.; Zhao, Kun

    2015-11-01

    Optical properties of the group components in crude oil were studied using terahertz time-domain spectroscopy (THz-TDS) under nitrogen environment at ambient temperature. The group composition of crude oil from different oil fields were analyzed on the basis of terahertz spectra. Both time delay and amplitude of terahertz wave were modulated in accordance with group composition. The features of terahertz spectra which contain information from different parts of the crude oil group composition can be qualitatively analyzed to detect the group components of the crude oil.

  20. 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 μm 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

  1. Microbial biodiversity in a Malaysian oil field and a systematic comparison with oil reservoirs worldwide.

    PubMed

    Li, Dongmei; Midgley, David J; Ross, Jason P; Oytam, Yalchin; Abell, Guy C J; Volk, Herbert; Daud, Wan Ata Wan; Hendry, Philip

    2012-06-01

    Microbial diversity within formation water and oil from two compartments in Bokor oil reservoir from a Malaysian petroleum oil field was examined. A total of 1,056 16S rRNA gene clones were screened from each location by amplified ribosomal DNA restriction analysis. All samples were dominated by clones affiliated with Marinobacter, some novel Deferribacteraceae genera and various clones allied to the Methanococci. In addition, either Marinobacterium- or Pseudomonas-like operational taxonomic units were detected from either compartment. A systematic comparison with the existing pertinent studies was undertaken by analysing the microbial amplicons detected and the PCR primers used. The analyses demonstrated that bacterial communities were site specific, while Archaea co-occurred more frequently. Amplicons related to Marinobacter, Marinobacterium and Pseudomonas were detected in a number of the studies examined, suggesting they may be ubiquitous members in oil reservoirs. Further analysis of primers used in those studies suggested that most primer pairs had fairly broad but low matches across the bacterial and archaeal domains, while a minority had selective matches to certain taxa or low matches to all the microbial taxa tested. Thus, it indicated that primers may play an important role in determining which taxa would be detected. PMID:22245906

  2. Methanococcus thermolithotrophicus Isolated from North Sea Oil Field Reservoir Water

    PubMed Central

    Nilsen, R. K.; Torsvik, T.

    1996-01-01

    Methanococcus thermolithotrophicus ST22 was isolated from produced water of a North Sea oil field, on mineral medium with H(inf2)-CO(inf2) as the sole source of carbon and energy. The isolate grew at 17 to 62(deg)C, with an optimum at 60(deg)C. The pH range was 4.9 to 9.8, with optimal growth at pH 5.1 to 5.9; these characteristics reflected its habitat. Strain ST22 was quickly identified and distinguished from the type strain by immunoblotting. PMID:16535247

  3. Applications of water-soluble polymers in the oil field

    SciTech Connect

    Chatterji, J.; Borchardt, J.K.

    1981-11-01

    Water-soluble polymers commonly used in the oil field are reviewed. The properties of guar, guar derivatives, cellulose derivatives, xanthan gum, locust bean gum, starches, and synthetic polymers, especially polyacrylamides, are discussed and related to chemical structures of the polymers. Original data comparing polymer solution viscosity properties under identical conditions are presented. These data include effect of polymer concentration on solution viscosity, temperature effect on solution viscosity, viscosity in acidic solution, and polymer solution viscosity in the presence of a hemicellulase enzyme. 105 refs.

  4. Corrosion of alloy steels in oil field fluids

    SciTech Connect

    Martin, R.L.

    1987-01-01

    Laboratory and field tests have been conducted on two low alloy and two higher alloy steels at a range of brine salinities and sulfide contents typical of oil well production fluids. AISI types 4130 and 4340 show the same behavior in these fluids as mild steel. AISI type 410 stainless steel and 9% chromium - 1% molybdenum steel corrode at rates as great as that of mild steel at higher chloride or sulfide concentrations. Special corrosion inhibitors are required for higher alloy steels when they are exposed to these conditions.

  5. Premium performance heating oil - Part 2, Field trial results

    SciTech Connect

    Jetter, S.M.; Hoskin, D.; McClintock, W.R.

    1996-07-01

    Limited field trial results of a heating oil additive package developed to minimize unscheduled maintenance indicate that it achieves its goal of keeping heating oil systems cleaner. The multifunctional additive package was developed to provide improved fuel oxidation stability, improved corrosion protection, and dispersency. This combination of performance benefits was chosen because we believed it would retard the formation of sludge, as well as allow sludge already present to be carried through the system without fouling the fuel system components (dispersency should keep sludge particles small so they pass through the filtering system). Since many unscheduled maintenance calls are linked to fouling of the fuel filtering system, the overall goal of this technology is to reduce these maintenance calls. Photographic evidence shows that the additive package not only reduces the amount of sludge formed, but even removes existing sludge from filters and pump strainers. This {open_quotes}clean-up{close_quotes} performance is provided trouble free: we found no indication that nozzle/burner performance was impaired by dispersing sludge from filters and pump strainers. Qualitative assessments from specific accounts that used the premium heating oil also show marked reductions in unscheduled maintenance.

  6. 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.

  7. Crude oil from the El'Darovo field

    SciTech Connect

    Dorogochinskaya, V.A.; Fadeev, V.S.; Shul'zhenko, E.D.

    1985-11-01

    The crudes from the El'darovo field are analyzed. They are light, low-sulfur, low-viscosity, and low pour, with a wax content of 1.2-2.8% by weight and low contents of asphaltenes and nitrogen. The oils from the Lower Cretaceous deposits differ from those from the Upper Creataceous deposits in that they are lower in density, viscosity, and carbon residue, with low contents of resins and asphaltenes, sulfur and nitrogen, and high yields of light fractions. The hydrocarbon composition of the IBP-62 degrees C cut was determined chromatographically in a column packed with CaA zeolite. The properties of the crudes are typical for crudes produced in this region. It is recommended that these crudes should be processed in mixtures with crudes from other fields in the Checheno-Ingush ASSR.

  8. Field testing the prototype BNL fan-atomized oil burner

    SciTech Connect

    McDonald, R.; Celebi, Y.

    1995-04-01

    BNL has developed a new oil burner design referred to as the Fan Atomized burner System. The primary objective of the field study was to evaluate and demonstrate the reliable operation of the Fan Atomized Burner. The secondary objective was to establish and validate the ability of a low firing rate burner (0.3-0.4 gph) to fully satisfy the heating and domestic hot water load demands of an average household in a climate zone with over 5,000 heating-degree-days. The field activity was also used to evaluate the practicality of side-wall venting with the Fan Atomized Burner with a low stack temperature (300F) and illustrate the potential for very high efficiency with an integrated heating system approach based on the Fan Atomized Burner.

  9. 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.

  10. Work Related Injuries in an Oil field in Oman

    PubMed Central

    Al-Rubaee, Faisal Rabia; Al-Maniri, Abdullah

    2011-01-01

    Objectives The aim of this paper is to describe the epidemiology of occupational injuries in the Harweel oil field, Oman. Methods The study is based on data gathered from a computerized database maintained by Petroleum Development of Oman (PDO). All non-fatal work-related occupational injuries registered between April 2007 and December 2009 were gathered and analyzed. Results A total of 170 work-related injuries were reported during the study period. Foreign body to the eye was the most common type of injury (27.6%) encountered among all injuries, followed by man falls/slips (11.8%). Injury to the upper extremities accounted for the largest percentage (38.8%) among other body parts. While, a significant portion of the injuries (52%) affected workers aged less than 30 years. The average injury rate per 1000 exposed workers per year was 19.8. Conclusion The study outlines the types of injuries most commonly encountered in the oil field in Oman. Additional data is required in order to devise proper epidemiological analysis. Establishing a comprehensive surveillance system for injuries is essential to ascertain factors influencing such injuries. PMID:22125724

  11. 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.

  12. Tukau Field: Finding new oil in matured and complex field after 20 years of production

    SciTech Connect

    Shariff, M.D.; Ridza, M. ); Majid, P. )

    1996-01-01

    The Tukau Field is located some 30 km offshore Sarawak, Malaysia. in water depth of about 160 ft. The field, discovered by TK-2 in 1966 found 235 ft net oil sand and 16 ft wet gas sand. After further seismic data acquisition and interpretation, six (6) appraisal wells were drilled from 1973 to 1975 before the field could be commercially developed. The Tukau structure is a structurally complex feature formed as a domal anticlinal uplift, located along the Tukau I Bakau / Baram trend. It is dissected at the shallow level by normal synthetic and antithetic faults. These fault system divide the field into seven (7) fault blocks. The major hydrocarbon accumulations are between 2400 ftss and 7500 ftss and the main prospective sequence consists of fine to very fine grained sand of the upper cycle V of late Miocene age and deposited in a deltaic, fluviomarine, coastal to near shore environment. Development drilling commenced in 1975 with a total of 23 wells. To date a total of nine (9) rounds of development activities were carried out resulting in 55 wells being drilled and nine (9) well jackets installed. In 1975, based on the seismic and well data. the field is estimated to contain some 300 MMSTB of oil. Following subsequent field reviews Incorporating some 50 odd well data and seismic reinterpretation in 1987. the field STOIIP increased to 500 MMST. 3D seismic was acquired in 1992 and field review carried out In 1995 resulted In some development potential and appraisal / exploration opportunities. The appraisal well drilled in October 1995, increased the field STOIIP by some 50 MMSTB. Preliminary evaluation based on geological, engineering and economic information indicated that Tukau field will be further developed with additional well jacket and this will boost the field production by about 50%.

  13. Tukau Field: Finding new oil in matured and complex field after 20 years of production

    SciTech Connect

    Shariff, M.D.; Ridza, M.; Majid, P.

    1996-12-31

    The Tukau Field is located some 30 km offshore Sarawak, Malaysia. in water depth of about 160 ft. The field, discovered by TK-2 in 1966 found 235 ft net oil sand and 16 ft wet gas sand. After further seismic data acquisition and interpretation, six (6) appraisal wells were drilled from 1973 to 1975 before the field could be commercially developed. The Tukau structure is a structurally complex feature formed as a domal anticlinal uplift, located along the Tukau I Bakau / Baram trend. It is dissected at the shallow level by normal synthetic and antithetic faults. These fault system divide the field into seven (7) fault blocks. The major hydrocarbon accumulations are between 2400 ftss and 7500 ftss and the main prospective sequence consists of fine to very fine grained sand of the upper cycle V of late Miocene age and deposited in a deltaic, fluviomarine, coastal to near shore environment. Development drilling commenced in 1975 with a total of 23 wells. To date a total of nine (9) rounds of development activities were carried out resulting in 55 wells being drilled and nine (9) well jackets installed. In 1975, based on the seismic and well data. the field is estimated to contain some 300 MMSTB of oil. Following subsequent field reviews Incorporating some 50 odd well data and seismic reinterpretation in 1987. the field STOIIP increased to 500 MMST. 3D seismic was acquired in 1992 and field review carried out In 1995 resulted In some development potential and appraisal / exploration opportunities. The appraisal well drilled in October 1995, increased the field STOIIP by some 50 MMSTB. Preliminary evaluation based on geological, engineering and economic information indicated that Tukau field will be further developed with additional well jacket and this will boost the field production by about 50%.

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

    DOEpatents

    Wagh, Arun S.; Jeong, Seung-Young; McDaniel, Richard

    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.

  15. 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.

  16. Indexes of pumps for oil field pumping units

    SciTech Connect

    Ibragimov, E.S.

    1995-07-01

    As reported previously, a series of oil field pumping units has been developed with power outputs of 125, 250, 500, and 1000 kW, designed for injecting working fluids in cementing operations in oil and gas wells, hydraulic fracturing of formations, washing out sand plugs, and other production operations. The units are designed for the use of three-plunger pumps with individual power outputs of 125 or 500 kW. In the 250- and 1000-kW units, two such pumps are used. The 1000-kW pumping unit serves mainly for deep-penetration hydraulic fracturing of formations, and also for fracturing deep formations. The hydraulic fracturing process does not require the use of units with two pumps; this has been demonstrated by experience, both here and in other countries. All units intended for use in hydraulic fracturing are built with a single pump, transmission, and drive. Pumping units for well cementing must have two pumps that will give a high delivery rate. At the start of the operation, a single pump can be used to feed water into the cement mixer, with the second pump used to transfer the cement slurry to the well. Then both pumps are connected to the slurry injection line. The operation of these pumps is described.

  17. 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...

  18. Sword field, offshore California: challenges in making this giant oil field commercial

    SciTech Connect

    Ballard, J.H.

    1988-03-01

    The major obstacles and challenges involved in exploration and development of a giant deep-water low-gravity oil field are exemplified in the undeveloped Sword field of offshore southern California. In 1979, Conoco Exploration identified a northeast-southwest-trending basement high in 800-2000 ft deep federal waters 12 mi southwest of Pt. Conception at the western end of the Santa Barbara Channel. The intended reservoir was fractured Miocene Monterey chert, siliceous shales or siltstones, and dolomites that are draped over the axially faulted anticlinal structure. Drilling of the initial well in OCS P-0322 in 1982 resulted in discovering the giant Sword field. A confirmation well drilled in OCS P-0320 indicates in-place reserves of well over 1 billion bbl. Although the discovered potential is significant, the low gravity (8.5/sup 0/-10.5/sup 0/ API) of the oils discovered to date, along with water depths in excess of 1500 ft, currently pose economic challenges to successful field development. Conoco and its partners are addressing the current economic barriers on several fronts. A three-dimensional seismic survey has been conducted to delineate reservoir geometry and to define probable variations in pay thickness and fracturing. A market feasibility study will be undertaken to assess the demand for low gravity crude from offshore California. Finally, Conoco has developed proprietary technology called OCHOS (Offshore California Heavy Oil System), which uses an innovative oil and/or water emulsion technique to allow for more economic recovery of high-velocity or low-gravity crudes.

  19. 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

    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

  20. Alkanes in benthic organisms from the Buccaneer oil field

    SciTech Connect

    Middleditch, B.S.; Basile, B.

    1980-06-01

    About 200 g per day of alkanes are present in brine discharged from each of two production platforms in the Buccaneer oil field in the NW Gulf of Mexico. These alkanes disperse rapidly in the water column, so that seawater concentrations of petroleum alkanes in this region are generally very low. They can be taken up to some extent by plankton, fish, and barnacles, but the petroleum alkane concentrations in these organisms are also relatively low. The largest pool of petroleum alkanes is in the surficial sediments, where concentrations of up to 25 ppM are observed, with concentration gradients extending more than 20 m from the production platforms. Organisms are examined which are exposed to these sediments and, for comparison, other specimens from control sites around structures from which there are no discharges.

  1. Magnetotelluric signature of anticlines in Iran's Sehqanat oil field

    NASA Astrophysics Data System (ADS)

    Mansoori, Isa; Oskooi, Behrooz; Pedersen, Laust B.

    2015-07-01

    The magnetotelluric (MT) method has proved to be an effective tool in hydrocarbon exploration especially in areas with geological structures/formations where seismic reflection provides neither good quality data nor images. The Sehqanat oil field located in the sedimentary zone of Zagros in SW of Iran is a typical example. It is covered by the high velocity and heterogeneous formation of Gachsaran, which is exposed at the surface and has a thickness varying from 500 m to more than 2 km in the region. Gachsaran is composed mainly of salt and evaporites overlying, as a cap rock, the Asmari limestone formation which is the main reservoir in all oil fields of Iran along the Zagros range. The main geological interface which is targeted to be imaged with the MT method is the contact between the highly conductive evaporites of the Gachsaran formation and the underlying more resistive carbonates of the Asmari formation. MT data at more than 600 stations along five parallel SW-NE profiles crossing the main geological trend of the study area and transient electromagnetic data over 400 stations to be used for static shift corrections of the MT data were available. Dimensionality and strike analysis of the MT data show dominant two-dimensional (2-D) conditions in almost all sites and periods. The 2-D resistivity models resolved the boundary between Gachsaran and Asmari formations as a transition zone from highly conductive to resistive structures. The Sehqanat anticline has also been delineated throughout the 2-D resistivity sections as a resistive dome-shaped body located in the middle part of the MT profiles. There is a considerable correlation between the 2-D resistivity models and the adjacent 2-D reflection seismic sections so that a more reliable interpretation on the hydrocarbon trap of the Sehqanat anticline can be obtained.

  2. 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

  3. 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

  4. Grant Canyon and Bacon Flat oil fields, Railroad Valley, Nye County, Nevada

    SciTech Connect

    Veal, H.K.; Duey, H.D.; Bortz, L.C.; Foster, N.H.

    1989-03-01

    The Grant Canyon field is located on the eastern side of Railroad Valley, 8 mi south of the Eagle Springs oil field. The discovery well, Grant Canyon Unit 1 was completed by Northwest Exploration Co. on September 11, 1983, flowing 1816 bbl of oil/day from the Devonian Guilmette dolomite (4374-4448 ft). Two additional wells have been completed in the field. Through April 1988, cumulative oil production was 8,211,149 bbl of oil. During March and April 1988, wells 3 and 4 flowed an average of 6089 bbl of oil/day. For these months, well 3 averaged 4144 bbl of oil/day with 1935 bbl of oil/day coming from well 4. Production area appears to be 240 ac. The trap is a high fault block in the boundary fault zone that separates Railroad Valley from the Grant Range to the east. The Devonian Guilmette reservoir is an intensely fractured vuggy dolomite with some intercrystalline porosity. The top seal is the Tertiary Valley Fill, which unconformably overlies the Guilmette dolomite. The oil column is about 400 ft thick and the field apparently has an active water drive, inasmuch as unit 1 had to be shut in because of water production. The oil is black, 26/degree/API, 0.5% sulfur, and has a pour point of 10/degree/F. Estimated ultimate recoverable oil reserves are 13 million bbl. The adjacent Bacon Flat field is a one-well field completed by Northwest Exploration CO. on July 5, 1981, for 200 bbl of oil/day and 1050 bbl of water/day from the Devonian Guilmette Limestone (5316-5332 ft). Cumulative production through April 1988 was 303,860 bbl of oil. During March 1988, the well averaged 108 bbl of oil/day plus an unreported amount of water. Estimated ultimate recoverable oil reserves are 400,000 bbl.

  5. PVTX characteristics of oil inclusions from Asmari formation in Kuh-e-Mond heavy oil field in Iran

    NASA Astrophysics Data System (ADS)

    Shariatinia, Zeinab; Haghighi, Manouchehr; Shafiei, Ali; Feiznia, Sadat; Zendehboudi, Sohrab

    2015-04-01

    Incorporating PVT properties and compositional evolution of oil inclusions into reservoir engineering simulator protocols can enhance understanding of oil accumulation, reservoir charge history, and migration events. Microthermometry and volumetric analysis have proven to be useful tools in compositional reconstitution and PT studies of oil inclusions and were used to determine composition, thermodynamic conditions, physical properties, and gas-to-oil ratios of heavy oil samples from Asmari carbonate reservoir in Kuh-e-Mond heavy oil field in Iran. PVT properties were predicted using a PVT black-oil model, and an acceptable agreement was observed between the experiments and the simulations. Homogenization temperatures were determined using microthermometry techniques in dolomite and calcite cements of the Asmari Formation, as well. Based on the homogenization temperature data, the undersaturated hydrocarbon mixture prior to formation of the gas cap migrated with a higher gas-to-oil ratio from a source rock. According to the oil inclusion data, the onset of carbonate cementation occurred at temperatures above 45 °C and that cementation was progressive through burial diagenesis. PVT black-oil simulator results showed that the reservoir pressure and temperature were set at 100 bar and 54 °C during the initial stages of oil migration. Compositional modeling implies that primary and secondary cracking in source rocks were responsible for retention of heavy components and migration of miscible three-phase flow during hydrocarbon evolution. The PT evolution of the petroleum inclusions indicates changes in thermodynamic properties and mobility due to phenomena such as cracking, mixing, or/and transport at various stages of oil migration.

  6. 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...

  7. Air injection project breathes fire into aging West Hackberry oil field

    SciTech Connect

    Duey, R.

    1996-02-01

    Amoco, the DOE and LSU seek more oil from Gulf Coast salt dome fields with air injection technique. The West Hackberry Field in Louisiana is a water-driven reservoir. By injecting air into the high-pressure, high-temperature reservoir rock, the water is backed down, allowing the oil to drain off the steeply dipped rock.

  8. Infrared spectrometry field-method for identification of natural seep-oils.

    PubMed

    Grant, D F; Eastwood, D

    1983-11-01

    An infrared field-method has been developed which is capable of distinguishing between oils originating from natural seepage in the Santa Barbara (California) Channel region and closely similar oils from onshore drilling platforms. The technique involves a minimum of sample preparation and the use of simple infrared instrumentation which can be operated by non-technical personnel. Natural seep-oil samples were collected from the surface of the water, underwater, and from beaches in the area. The non-seep oils were obtained from production wells which were located in the same geographical areas as the seepage and were from several different well depths corresponding to different geological zones. Natural seep-oils are more aromatic than the production oils, and this difference is evidenced by observed differences in the spectra for both weathered and unweathered oils. These spectral differences between seep and non-seep oils have been found to persist after exposure to weathering for a week. PMID:18963475

  9. 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.

  10. 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.

  11. 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

  12. Vertical magnetic field and its analytic signal applicability in oil field underground pipeline detection

    NASA Astrophysics Data System (ADS)

    Guo, Zhiyong; Liu, Dejun; Pan, Qi; Zhang, Yingying; Li, Yi; Wang, Zheng

    2015-06-01

    We propose using the vertical component of the magnetic anomaly (vertical magnetic field (VMF)) and its analytic signal (AS) to detect oil field underground pipelines. The connection between two peaks of the VMF curves or the AS curves was used to calculate the pipeline azimuth, and the peak coordinates of the AS were used to determine the horizontal position of pipelines. Then, the effect of the pipeline magnetization direction and pipeline buried depth on the horizontal locating error was analyzed. Three typical pipeline models were used for verifying this method. Results indicate that this method can be used to precisely calculate the stretch direction of the pipeline and effectively improve the identification capability in detecting parallel pipelines. The horizontal position of the pipeline axis can be accurately located by the peak of the AS and the locating error increases with the increase in pipeline buried depth, but it is not affected by pipeline outer diameter, thickness, susceptibility. The instrument design and the VMF measurement strategy are realistic and applicable. The VMF detection with its AS provides a new effective method for horizontal locating and direction calculating of oil field underground pipelines.

  13. Computer simulation of nonstationary thermal fields in design and operation of northern oil and gas fields

    NASA Astrophysics Data System (ADS)

    Vaganova, N. A.; Filimonov, M. Yu.

    2015-11-01

    A mathematical model, numerical algorithm and program code for simulation and long-term forecasting of changes in permafrost as a result of operation of a multiple well pad of northern oil and gas field are presented. In the model the most significant climatic and physical factors are taken into account such as solar radiation, determined by specific geographical location, heterogeneous structure of frozen soil, thermal stabilization of soil, possible insulation of the objects, seasonal fluctuations in air temperature, and freezing and thawing of the upper soil layer. Results of computing are presented.

  14. Computer simulation of nonstationary thermal fields in design and operation of northern oil and gas fields

    SciTech Connect

    Vaganova, N. A.; Filimonov, M. Yu.

    2015-11-30

    A mathematical model, numerical algorithm and program code for simulation and long-term forecasting of changes in permafrost as a result of operation of a multiple well pad of northern oil and gas field are presented. In the model the most significant climatic and physical factors are taken into account such as solar radiation, determined by specific geographical location, heterogeneous structure of frozen soil, thermal stabilization of soil, possible insulation of the objects, seasonal fluctuations in air temperature, and freezing and thawing of the upper soil layer. Results of computing are presented.

  15. Microseismic monitoring of the Chaveroo oil field, New Mexico

    SciTech Connect

    Rutledge, J.T.; Albright, J.N.; Fairbanks, T.D.; Murphy, M.B.; Roberts, P.M.

    1990-01-01

    Induced microseismicity was monitored in the Chaveroo oil field in southeastern New Mexico during a pressurized stimulation of a well being prepared as an injector for a waterflood operation. In addition, the microseismicity was monitored for 5 weeks following the stimulation while the area was under normal waterflood production. Little seismicity was detected during the 5.5 hour stimulation in which three thousand barrels of water were injected into the reservoir at pressures ranging from 96 to 257 bars in excess of hydrostatic pressure. Intermittent monitoring over the 5-week period indicated detectable seismicity occurred during waterflood production. Monitoring during the 5 weeks, however, was not complete enough to draw general conclusions on temporal variations of observed microseismicity. Seventy-three good quality events recorded over a cumulative 24 hours of intermittent monitoring were located using the hodogram technique. Events were detected at distances up to 1700 m from the monitor well but most occurred within 900 m. The map of microearthquake locations indicated that events occurred in the vicinity of producing wells and away from injection wells. The first half of the sequence of mappable events occurred along linear trends, but the pattern became more scattered during the later half of the sequence. The lack of seismicity during the pressurized injection and the increased seismicity levels occurring away from injection wells during waterflood production, suggest seismicity is not induced by Mohr-Coulomb failure. 6 refs., 6 figs.

  16. Take home lead exposure in children of oil field workers.

    PubMed

    Khan, Fahad

    2011-06-01

    Childhood lead poisoning is a major, preventable environmental health problem. While residential lead-based paint and lead contaminated dust and soil are the most common sources of childhood lead poisoning, children can also be at risk if they live with an adult with a job or hobby that involves exposure to lead. Currently, the Oklahoma Childhood Lead Poisoning Prevention Program (OCLPPP) has a small number of cases of "take home" lead exposure in children of oil field workers. These workers may come in contact with a threading compound, "pipe dope" that can contain large amounts of lead. Workers handling this product may be exposed to lead by not following safety instructions. Additionally workers may not be provided the facilities to shower and change out of the contaminated clothing before leaving the work location. The OCLPPP recommends employers and worksites should consider effective alternative options like lead free biodegradable pipe dopes or dope free connections to prevent workers and their families from adverse health effects associated with lead. PMID:21888039

  17. Driving mechanism for plunger pumps in oil field installations

    SciTech Connect

    Gazarov, R.E.; Zaslavskii, Yu.V.

    1995-07-01

    Mobile oil field pumping installations of up to 1600 kW power at a pressure up to 140 MPa are widely used in hydraulic fracturing of beds, acid treatment of the near-face zone, cementation of wells, and other flushing and pressure operations. Equipment in these installations, which include high-pressure plunger pumps of high unit capacity, are mounted on mobile bases of limited lifting capacity (KrAZ automobile chassis, T-130 tractors, etc.). Very strict demands are made on the reliability, durability, and mass/size characteristics of the pumps and on all the equipment of the mobile installations. In modern pumps, an axial load of up to 100 tons or more, which is transmitted to the crankshaft, acts on each plunger. The engine of the installation rotates the crankshaft through a multiple-speed transmission and the transmission shaft of the pump. The forces acting on the elements of the driving part of a pump with a connecting rod - crank drive and a single-reduction tooth gear are described.

  18. Copper removal from oil-field brine by coprecipitation.

    PubMed

    Khosravi, Jafar; Alamdari, Abdolmohammad

    2009-07-30

    The present study aims at investigation of copper removal from oil-field brine by coprecipitation process. The produced brine containing heavy metals is usually returned to the reservoir for water flooding or is discarded to the surroundings. Therefore, surface waters or underground waters may be polluted due to probable contact to these discarded waters. Removal experiments were carried out at room temperature in a bench-scale crystallizer equipped with a draft tube. In order to gain an insight into the influence of soluble compounds in the industrial natural brine on the precipitation process, some comparative experiments were performed both on a sample of natural brine and on a synthetic simulated brine in the absence of natural impurities. A metal removal practice by coprecipitation of copper through CaCO(3) precipitates induced by reaction of Na(2)CO(3) and CaCl(2) reduced the copper concentration (Cu(2+)) from 0.27 ppm in the synthetic brine to 0.06 ppm. This removal of 78% required only 1g of precipitate per 0.15 mg copper metal. Analysis of the experimental results suggested that about 5% of the copper removal from the synthetic brine was through the mechanism of incorporation into the crystal lattice, and around 95% was through the adsorption on the crystal faces. PMID:19157701

  19. 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.

  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. 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

  2. Biodegradation of diesel oil by an Arabian Sea sediment culture isolated from the vicinity of an oil field.

    PubMed

    Mukherji, Suparna; Jagadevan, Sheeja; Mohapatra, Gita; Vijay, Avinash

    2004-12-01

    Laboratory scale batch studies were performed to test the diesel oil biodegradation ability of ES1 cultures isolated from Arabian Sea sediments obtained from the vicinity of an oil field. This culture could utilize diesel as the sole source of carbon and energy. Under aerobic conditions, 39% loss of diesel oil was observed over 8 days where 80% of the loss was due to aliphatic constituents. Under anoxic nitrate reducing conditions the rate and extent of degradation was significantly lower, i.e., 18% over 50 days. Salt acclimatized cultures could tolerate salinities up to 3.5% and demonstrated optimal performance at a salinity of 0.5%. The optimum N/P ratio for these cultures was found to be in the range of 2:1-5:1. Addition of two trace elemental substance formulations exhibited a significant inhibitory effect on culture growth. This culture has good potential for decontamination of oil-contaminated marine and subsurface environments. PMID:15288270

  3. Economic evaluation on CO₂-EOR of onshore oil fields in China

    SciTech Connect

    Wei, Ning; Li, Xiaochun; Dahowski, Robert T.; Davidson, Casie L.; Liu, Shengnan; Zha, Yongjin

    2015-06-01

    Carbon dioxide enhanced oil recovery (CO₂-EOR) and sequestration in depleted oil reservoirs is a plausible option for utilizing anthropogenic CO₂ to increase oil production while storing CO₂ underground. Evaluation of the storage resources and cost of potential CO₂-EOR projects is an essential step before the commencement of large-scale deployment of such activities. In this paper, a hybrid techno-economic evaluation method, including a performance model and cost model for onshore CO₂-EOR projects, has been developed based on previous studies. Total 296 onshore oil fields, accounting for about 70% of total mature onshore oil fields in China, were evaluated by the techno-economic method. The key findings of this study are summarized as follows: (1) deterministic analysis shows there are approximately 1.1 billion tons (7.7 billion barrels) of incremental crude oil and 2.2 billion tons CO₂ storage resource for onshore CO₂-EOR at net positive revenue within the Chinese oil fields reviewed under the given operating strategy and economic assumptions. (2) Sensitivity study highlights that the cumulative oil production and cumulative CO₂ storage resource are very sensitive to crude oil price, CO₂ cost, project lifetime, discount rate and tax policy. High oil price, short project lifetime, low discount rate, low CO₂ cost, and low tax policy can greatly increase the net income of the oil enterprise, incremental oil recovery and CO₂ storage resource. (3) From this techno-economic evaluation, the major barriers to large-scale deployment of CO₂-EOR include complex geological conditions, low API of crude oil, high tax policy, and lack of incentives for the CO₂-EOR project.

  4. Economic evaluation on CO₂-EOR of onshore oil fields in China

    DOE PAGESBeta

    Wei, Ning; Li, Xiaochun; Dahowski, Robert T.; Davidson, Casie L.; Liu, Shengnan; Zha, Yongjin

    2015-06-01

    Carbon dioxide enhanced oil recovery (CO₂-EOR) and sequestration in depleted oil reservoirs is a plausible option for utilizing anthropogenic CO₂ to increase oil production while storing CO₂ underground. Evaluation of the storage resources and cost of potential CO₂-EOR projects is an essential step before the commencement of large-scale deployment of such activities. In this paper, a hybrid techno-economic evaluation method, including a performance model and cost model for onshore CO₂-EOR projects, has been developed based on previous studies. Total 296 onshore oil fields, accounting for about 70% of total mature onshore oil fields in China, were evaluated by the techno-economicmore » method. The key findings of this study are summarized as follows: (1) deterministic analysis shows there are approximately 1.1 billion tons (7.7 billion barrels) of incremental crude oil and 2.2 billion tons CO₂ storage resource for onshore CO₂-EOR at net positive revenue within the Chinese oil fields reviewed under the given operating strategy and economic assumptions. (2) Sensitivity study highlights that the cumulative oil production and cumulative CO₂ storage resource are very sensitive to crude oil price, CO₂ cost, project lifetime, discount rate and tax policy. High oil price, short project lifetime, low discount rate, low CO₂ cost, and low tax policy can greatly increase the net income of the oil enterprise, incremental oil recovery and CO₂ storage resource. (3) From this techno-economic evaluation, the major barriers to large-scale deployment of CO₂-EOR include complex geological conditions, low API of crude oil, high tax policy, and lack of incentives for the CO₂-EOR project.« less

  5. 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

  6. Environmental effects of the Kuwaiti oil field fires

    SciTech Connect

    Hahn, J. )

    1991-09-01

    Theory suggests that the rates of smoke emission and heat generation and, consequently, the atmospheric injection height and residence time of the smoke are crucial in determining whether the environmental effects are of global or only regional importance. Confirming the results of model calculations, observations have shown that, up to now, the smoke did not rise higher than to the top of the planetary boundary layer (PBL), about 3,300 m at a maximum. The photochemistry within the smoke cloud very likely is significantly different from that of the smoke-free troposphere. Also, because there is very little precipitation in the greater Gulf region from May through October, it is difficult to predict how and where NO{sub x}, SO{sub 2}, and their oxidation products HNO{sub 3} and H{sub 2}SO{sub 4} will be deposited. Photochemical oxidation should be largely suppressed in the denser parts of the smoke cloud, so major acid deposition is likely to occur at some distance from the source area, probably as far away as 2,000 km. Results of model calculations suggest that the effect of the smoke emission in Kuwait on the Asian summer monsoon is small. In summary, one should expect severe environmental consequences of the Kuwaiti oil field fires for the territory of Kuwait and for parts of Iraq, Jordan, and Saudi Arabia. Serious effects also may be felt in Iran and the other Gulf states, and perhaps even as far away as Turkey and Afghanistan. The surface waters of the Gulf also may be severely affected by smoke deposition. Significant environmental effects on a global or even hemispheric scale, however, are not likely to occur.

  7. 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...

  8. Composition and structure of asphalthene components of oils from the Krapivinskoye oil field

    NASA Astrophysics Data System (ADS)

    Sergun, Valery P.; Cheshkova, Tatiana V.; Sagachenko, Tatiana A.; Min, Raissa S.

    2015-10-01

    Asphaltene substances of oil are characterized via the methods of extraction, adsorption chromatography, chemical degradation, and chromatography-mass spectrometry. The data on the structure of the high- and low molecular weight asphaltenes of methane-naphthene oils and composition of the compounds adsorbed/occluded by their molecules are presented. These investigations are important for the development of efficient petroleum technologies.

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

    SciTech Connect

    Hulen, J.B. ); Goff, F. ); Ross, J.R. ); Bortz, L.C. ); Bereskin, S.R. )

    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. Uncertainty of oil field GHG emissions resulting from information gaps: a Monte Carlo approach.

    PubMed

    Vafi, Kourosh; Brandt, Adam R

    2014-09-01

    Regulations on greenhouse gas (GHG) emissions from liquid fuel production generally work with incomplete data about oil production operations. We study the effect of incomplete information on estimates of GHG emissions from oil production operations. Data from California oil fields are used to generate probability distributions for eight oil field parameters previously found to affect GHG emissions. We use Monte Carlo (MC) analysis on three example oil fields to assess the change in uncertainty associated with learning of information. Single factor uncertainties are most sensitive to ignorance about water-oil ratio (WOR) and steam-oil ratio (SOR), resulting in distributions with coefficients of variation (CV) of 0.1-0.9 and 0.5, respectively. Using a combinatorial uncertainty analysis, we find that only a small number of variables need to be learned to greatly improve on the accuracy of MC mean. At most, three pieces of data are required to reduce bias in MC mean to less than 5% (absolute). However, the parameters of key importance in reducing uncertainty depend on oil field characteristics and on the metric of uncertainty applied. Bias in MC mean can remain after multiple pieces of information are learned, if key pieces of information are left unknown. PMID:25110115

  11. 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...

  12. 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...

  13. Enhancement of the TORIS data base of Appalachian basin oil fields. Final report

    SciTech Connect

    1996-01-31

    The Tertiary Oil Recovery Information System, or TORIS, was developed by the Department of Energy in the early 1980s with a goal of accounting for 70% of the nation`s original oil in place (OOIP). More than 3,700 oil reservoirs were included in TORIS, but coverage in the Appalachian basin was poor. This TORIS enhancement project has two main objectives: to increase the coverage of oil fields in the Appalachian basin; and to evaluate data for reservoirs currently in TORIS, and to add, change or delete data as necessary. Both of these objectives have been accomplished. The geological surveys in Kentucky, Ohio, Pennsylvania and West Virginia have identified 113 fields in the Appalachian basin to be included in TORIS that collectively contained 80% of the original oil in place in the basin. Furthermore, data in TORIS at the outset of the project was checked and additional data were added to the original 20 TORIS oil fields. This final report is organized into four main sections: reservoir selection; evaluation of data already in TORIS; industry assistance; and data base creation and validation. Throughout the report the terms pool and reservoir may be used in reference to a single zone of oil accumulation and production within a field. Thus, a field is composed of one or more pools at various stratigraphic levels. These pools or reservoirs also are referred to as pay sands that may be individually named sandstones within a formation or group.

  14. 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

  15. 37. SAR2, SHOWING OIL CIRCUIT BREAKERS (ABOVE) AND GENERATOR FIELD ...

    Library of Congress Historic Buildings Survey, Historic Engineering Record, Historic Landscapes Survey

    37. SAR-2, SHOWING OIL CIRCUIT BREAKERS (ABOVE) AND GENERATOR FIELD COIL CONTROL RHEOSTATS (BELOW). SCE negative no. 10331, November 1, 1923. Photograph by G. Haven Bishop. - Santa Ana River Hydroelectric System, SAR-2 Powerhouse, Redlands, San Bernardino County, CA

  16. Geochemistry of Eagle Ford group source rocks and oils from the first shot field area, Texas

    USGS Publications Warehouse

    Edman, Janell D.; Pitman, Janet K.

    2010-01-01

    Total organic carbon, Rock-Eval pyrolysis, and vitrinite reflectance analyses performed on Eagle Ford Group core and cuttings samples from the First Shot field area, Texas demonstrate these samples have sufficient quantity, quality, and maturity of organic matter to have generated oil. Furthermore, gas chromatography and biomarker analyses performed on Eagle Ford Group oils and source rock extracts as well as weight percent sulfur analyses on the oils indicate the source rock facies for most of the oils are fairly similar. Specifically, these source rock facies vary in lithology from shales to marls, contain elevated levels of sulfur, and were deposited in a marine environment under anoxic conditions. It is these First Shot Eagle Ford source facies that have generated the oils in the First Shot Field. However, in contrast to the generally similar source rock facies and organic matter, maturity varies from early oil window to late oil window in the study area, and these maturity variations have a pronounced effect on both the source rock and oil characteristics. Finally, most of the oils appear to have been generated locally and have not experienced long distance migration. 

  17. 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.

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

    USGS Publications Warehouse

    Peters, K.E.; Scott, Ramos L.; Zumberge, J.E.; Valin, Z.C.; Bird, K.J.

    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 and clay rich Jurassic Kingak Shale and Cretaceous Hue Shale-gamma ray zone (Hue-GRZ) source rocks. ALS-C results for 23 oil samples from the prolific Ivishak Formation reservoir of the Prudhoe Bay Field indicate approximately equal contributions from Shublik Formation and Hue-GRZ source rocks (37% each), less from the Kingak Shale (26%), and little or no contribution from other source rocks. These results differ from published interpretations that most oil in the Prudhoe Bay Field originated from the Shublik Formation source rock. With few exceptions, the relative contribution of oil from the Shublik Formation decreases, while that from the Hue-GRZ increases in reservoirs along the Barrow arch from Point Barrow in the northwest to Point Thomson in the southeast (???250 miles or 400 km). The Shublik contribution also decreases to a lesser degree between fault blocks within the Ivishak pool from west to east across the Prudhoe Bay Field. ALS-C provides a robust means to calculate the relative amounts of two or more oil types in a mixture. Furthermore, ALS-C does not require that pure end member oils be identified prior to analysis or that laboratory mixtures of these oils be prepared to evaluate mixing. ALS-C of biomarkers reliably de-convolutes mixtures because the concentrations of compounds in mixtures vary as linear functions of the amount of each oil type. ALS of biomarker ratios (ALS-R) cannot be used to de-convolute mixtures because compound ratios vary as nonlinear functions of the amount of each oil type.

  19. 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.

  20. 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...

  1. 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.

  2. Anaerobic thermophilic bacteria isolated from a Venezuelan oil field and its potential use in microbial improved oil recovery

    SciTech Connect

    Trebbau, G.; Fernandez, B.; Marin, A.

    1995-12-31

    The objective of this work is to determine the ability of indigenous bacteria from a Venezuelan oil field to grow under reservoir conditions inside a porous media, and to produce metabolites capable of recovering residual crude oil. For this purpose, samples of formation waters from a central-eastern Venezuelan oil reservoir were enriched with different carbon sources and a mineral basal media. Formation water was used as a source of trace metals. The enrichments obtained were incubated at reservoir temperature (71{degrees}C), reservoir pressure (1,200 psi), and under anaerobic conditions for both outside and inside porous media (Berea core). Growth and metabolic activity was followed outside porous media by measuring absorbance at 660 nm, increases in pressure, and decreases in pH. Inside porous media bacterial activity was determined by visual examination of the produced waters (gas bubbles and bacterial cells). All the carbohydrates tested outside porous media showed good growth at reservoir conditions. The pH was lowered, gases such as CO{sub 2} and CH{sub 4} were identified by GC. Surface tension was lowered in some enrichments by 30% when compared to controls. Growth was decreased inside porous media, but gases were produced and helped displace oil. In addition, 10% residual oil was recovered from the Berea core. Mathematical modeling was applied to the laboratory coreflood experiment to evaluate the reproducibility of the results obtained.

  3. 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.

  4. Update on cavern disposal of NORM-contaminated oil field wastes.

    SciTech Connect

    Veil, J. A.

    1998-09-22

    Some types of oil and gas production and processing wastes contain naturally occurring radioactive material (NORM). If NORM is present at concentrations above regulatory levels in oil field waste, the waste requires special disposal practices. The existing disposal options for wastes containing NORM are limited and costly. Argonne National Laboratory has previously evaluated the feasibility, legality, risk and economics of disposing of nonhazardous oil field wastes, other than NORM waste, in salt caverns. Cavern disposal of nonhazardous oil field waste, other than NORM waste, is occurring at four Texas facilities, in several Canadian facilities, and reportedly in Europe. This paper evaluates the legality, technical feasibility, economics, and human health risk of disposing of NORM-contaminated oil field wastes in salt caverns as well. Cavern disposal of NORM waste is technically feasible and poses a very low human health risk. From a legal perspective, a review of federal regulations and regulations from several states indicated that there are no outright prohibitions against NORM disposal in salt caverns or other Class II wells, except for Louisiana which prohibits disposal of radioactive wastes or other radioactive materials in salt domes. Currently, however, only Texas and New Mexico are working on disposal cavern regulations, and no states have issued permits to allow cavern disposal of NORM waste. On the basis of the costs currently charged for cavern disposal of nonhazardous oil field waste (NOW), NORM waste disposal in caverns is likely to be cost competitive with existing NORM waste disposal methods when regulatory agencies approve the practice.

  5. Field test of re-refined automotive engine oil in RCMP vehicles

    SciTech Connect

    Armstrong, J.

    1980-11-01

    A field test has been designed to isolate the performance characteristics of the virgin and re-refined base oils being studied. The conditions selected for the test are those normally experienced by Royal Canadian Mounted Police vehicles in similar service. All test and reference vehicles have been subjected to as equal treatment as possible, in both driving conditions and maintenance schedules. The primary conclusion that can be made with the data obtained to date is that there are statistically significant differences occurring in certain measured properties of used crankcase oil from the two test groups of vehicles. These differences are no doubt attributable, at least in part, to performance differences between the two finished oils, but other factors such as the observed differences in length of oil change interval and top-up requirements are also contributing to the responses being measured. Given the methods by which the test and reference oils were defined and chosen, it might be expected that differences in performance characteristics would be observed, and also that the reference oil might exhibit better performance characteristics than the test oil. However, the final magnitudes of any differences between the oils will not be known until the field test period is completed, and the real significance of these differences, in terms of their effect on the engines, cannot be determined until the engine examinations have been completed.

  6. An overview of giant oil and gas fields of the decade: 1978-1988

    SciTech Connect

    Halbouty, M.T. )

    1990-09-01

    Scientific studies and projections of future world energy demand indicate that although alternate-energy fuel sources must be actively pursued and developed, there must be adequate petroleum supplies to bridge the gap. For the international petroleum industry, the years covered by this conference, 1978-1988, were complex. They were years of boom and bust. The world's energy consciousness was boosted sharply by the effects of the 1979 Iranian revolution and the resulting embargo that sent world oil prices to record heights. Global petroleum exploration soon surged, leading to the industry's all-time drilling high in 1981. Then came the oil price collapse in 1985, and the following years were characterized by falling oil prices and drastic budget cuts for exploration and development. Although exploration dropped sharply, there was a steady flow of giant oil and gas field discoveries. Using the giant field designation criteria of 500 million bbl of oil recoverable for fields in Asiatic Russia, North Africa, and the Middle East; 100 million bbl of oil recoverable for the fields in the remainder of the world; and 3 tcf and 1 tcf of gas reserves recoverable for the same areas, respectively, it is estimated that at least 182 oil and gas fields containing an estimated 140 billion BOE were discovered in 46 countries during the years covered by this conference. Today, exploration is slowly gaining momentum in all types of petroleum provinces-intensely explored, partially explored, moderately explored, and essentially unexplored - and as long as exploration continues in whatever area of the world, there will always be opportunities to find giant oil and gas fields.

  7. Grant Canyon and Bacon Flat oil fields, Railroad Valley, Nye County, Nevada

    SciTech Connect

    Bortz, L.C. ); Forster, N.H. ); Veal, H.K.; Duey, H.D.

    1988-10-01

    The Grant Canyon field is located on the east side of Railroad Valley, 8 mi south of the Eagle Springs oil field. The discovery well, Grant Canyon Unit 1, was completed by Northwest Exploration Co. on September 11, 1983, flowing 1816 BOPD from the Devonian Guilmette Dolomite. Two additional wells have been completed in the field. Cumulative oil production through April 1988 is 8,211,149 barrels of oil. During March and April 1988, wells 3 and 4 flowed an average of 6081 BOPD. For these months, well 3 average 4144 BOPD with 1935 BOPD coming from well 4. Production area appears to be 240 acres. The trap is a high fault block in the boundary fault zone that separates Railroad Valley from the Grant Range to the east. The Devonian Guilmette reservoir is an intensely fractured, vuggy dolomite with some intercrystalline porosity. The top seal is the Tertiary Valley Fill which unconformably overlies Guilmette Dolomite. The oil column is about 400 ft thick and the field apparently has an active water drive, inasmuch as the 1 Unit had to be shut-in because of water production. The oil is black, 26 degree API gty, a pour of 10 F and 0.5% sulfur. Estimated ultimate recoverable oil reserves are 13 MMBO. The adjacent Bacon Flat field is a one-well field that was completed by Northwest Exploration Co. on July 5, 1981, for 200 BOPD and 1050 BWPD from the Devonian Guilmette Limestone (5316-5332 ft). Cumulative production through April 1988 is 303,860 barrels of oil. During March 1988 the well averaged 108 BOPD plus an unreported amount of water. Estimated ultimate recoverable oil reserves are 400 MBO.

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

    SciTech Connect

    Umekwe, Pascal; Mongrain, Joanna; Ahmadi, Mohabbat; Hanks, Catherine

    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.

  9. Microbial Methane Production Associated with Carbon Steel Corrosion in a Nigerian Oil Field

    PubMed Central

    Mand, Jaspreet; Park, Hyung S.; Okoro, Chuma; Lomans, Bart P.; Smith, Seun; Chiejina, Leo; Voordouw, Gerrit

    2016-01-01

    Microbially influenced corrosion (MIC) in oil field pipeline systems can be attributed to many different types of hydrogenotrophic microorganisms including sulfate reducers, methanogens and acetogens. Samples from a low temperature oil reservoir in Nigeria were analyzed using DNA pyrotag sequencing. The microbial community compositions of these samples revealed an abundance of anaerobic methanogenic archaea. Activity of methanogens was demonstrated by incubating samples anaerobically in a basal salts medium, in the presence of carbon steel and carbon dioxide. Methane formation was measured in all enrichments and correlated with metal weight loss. Methanogens were prominently represented in pipeline solids samples, scraped from the inside of a pipeline, comprising over 85% of all pyrosequencing reads. Methane production was only witnessed when carbon steel beads were added to these pipeline solids samples, indicating that no methane was formed as a result of degradation of the oil organics present in these samples. These results were compared to those obtained for samples taken from a low temperature oil field in Canada, which had been incubated with oil, either in the presence or in the absence of carbon steel. Again, methanogens present in these samples catalyzed methane production only when carbon steel was present. Moreover, acetate production was also found in these enrichments only in the presence of carbon steel. From these studies it appears that carbon steel, not oil organics, was the predominant electron donor for acetate production and methane formation in these low temperature oil fields, indicating that the methanogens and acetogens found may contribute significantly to MIC. PMID:26793176

  10. Microbial Methane Production Associated with Carbon Steel Corrosion in a Nigerian Oil Field.

    PubMed

    Mand, Jaspreet; Park, Hyung S; Okoro, Chuma; Lomans, Bart P; Smith, Seun; Chiejina, Leo; Voordouw, Gerrit

    2015-01-01

    Microbially influenced corrosion (MIC) in oil field pipeline systems can be attributed to many different types of hydrogenotrophic microorganisms including sulfate reducers, methanogens and acetogens. Samples from a low temperature oil reservoir in Nigeria were analyzed using DNA pyrotag sequencing. The microbial community compositions of these samples revealed an abundance of anaerobic methanogenic archaea. Activity of methanogens was demonstrated by incubating samples anaerobically in a basal salts medium, in the presence of carbon steel and carbon dioxide. Methane formation was measured in all enrichments and correlated with metal weight loss. Methanogens were prominently represented in pipeline solids samples, scraped from the inside of a pipeline, comprising over 85% of all pyrosequencing reads. Methane production was only witnessed when carbon steel beads were added to these pipeline solids samples, indicating that no methane was formed as a result of degradation of the oil organics present in these samples. These results were compared to those obtained for samples taken from a low temperature oil field in Canada, which had been incubated with oil, either in the presence or in the absence of carbon steel. Again, methanogens present in these samples catalyzed methane production only when carbon steel was present. Moreover, acetate production was also found in these enrichments only in the presence of carbon steel. From these studies it appears that carbon steel, not oil organics, was the predominant electron donor for acetate production and methane formation in these low temperature oil fields, indicating that the methanogens and acetogens found may contribute significantly to MIC. PMID:26793176

  11. Field test and mathematical modeling of bioremediation of an oil-contaminated soil. Part 1: Field test

    SciTech Connect

    Li, K.Y.; Xu, T.; Colapret, J.A. ); Cawley, W.A. ); Bonner, J.S. . Civil Engineering Dept.); Ernest, A.; Verramachaneni, P.B. . Environmental Engineering Dept.)

    1994-01-01

    A fire-wall area (about 270 ft x 310 ft) with the Bunker C oil contaminated soil was selected for the bioremediation field test. This fire-wall area was separated into 18 plots by dirt dikes to test 6 bioremediation methods with three tests of each method. The six treatment methods were: (a) aeration with basic nutrients and indigenous organisms (BNIO); (b) aeration with basic nutrients and inoculation from a refinery wastewater treatment facility (BNSIWT); (c) aeration with an oleophilic fertilizer and indigenous organisms (INIPOL); (d) aeration with basic nutrients and biosurfactant organisms (EPA Seal Beach consortia) (EPA); (e) aeration with proprietary nutrients and organisms (PRO); and (f) aeration only for active control (CONTROL). This field test was conducted for 91 days. In general the oil contents in 18 plots were reduced, but the results showed significant fluctuations. A statistical method was used to examine if the oil reductions of six methods were the results from the random error of sampling and sample analysis or biodegradation. The results of the statistical analysis showed that oil reduction was concluded from all but the plots of PRO. From the data analysis, it may be concluded that the oil reduction rate in these studies is controlled by oil transfer from soil into the aqueous solution. An example of calculation was used to illustrate this conclusion.

  12. 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

  13. Increased Oil Recovery from Mature Oil Fields Using Gelled Polymer Treatments

    SciTech Connect

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

    2001-03-28

    Gelled polymer treatments were applied to oil reservoirs to increase oil production and to reduce water production by altering the fluid movement within the reservoir. This report is aimed at reducing barriers to the widespread use of these treatments by developing methods to predict gel behavior during placement in matrix rock and fractures, determining the persistence of permeability reduction after gel placement, and by developing methods to design production well treatments to control water production. Procedures were developed to determine the weight-average molecular weight and average size of polyacrylamide samples in aqueous solutions. Sample preparation techniques were key to achieving reproducible results.

  14. 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

  15. 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.

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

    SciTech Connect

    Edwards, W.C.; Gregory, D.G. )

    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.

  17. Intelligent fiber sensing system for the oil field area

    NASA Astrophysics Data System (ADS)

    Sun, Wenju; Ma, Linping

    2010-08-01

    Optical Fiber strain sensor using fiber Bragg grating are poised to play a major role in structural health from military to civil engineering. Fiber Bragg Grating sensor is a practical type of fiber optic sensors. Its measurement is encoded with the wavelength of the optical signal reflected from fiber Bragg grating. The method of measuring the absolute optical wavelength is a critical component of the fiber optic sensing system. To reliably detect very small changes in the environment at the sensor, the interrogation system must provide accurate and repeatable wavelength measurements. Energy sources are increasingly scarce in the world. Getting oil from the oil-wells has become more and more difficult. Therefore, new technology to monitor the oil-well condition has become extremely important. The traditional electrical sensor system is no longer useful because of the down-hole's high temperature and high pressure environment. The optical fiber sensing system is the first choice to monitor this condition. This system will reduce the cost and increase the productivity. In the high pressure and high temperature environment, the traditional packed fiber grating pressure-temperature sensor will be no longer reliability. We have to find a new fiber grating temperature-pressure sensor element and the interrogation system. In this work we use the very narrow bandwidth birefringent fiber grating as the sensing element. We obtain the interrogation system has 0.1 pm resolution.

  18. Geological setting of North Slope oil fields, Alaska

    SciTech Connect

    Edrich, S.P.

    1985-04-01

    The North Slope is a prolific hydrocarbon province in which discoveries to date amount to some 60 billion bbl of oil in place and 50 tcf of gas in place. Reservoirs and prolific source rocks occur throughout the stratigraphic column, which consists of a lower (or Ellesmerian) megasequence of Carboniferous to Jurassic age and an upper (or Brookian) megasequence of Early Cretaceous to Recent age. Discovered oil is almost equally divided between Ellesmerian and Brookian reservoirs. Patterns of hydrocarbon generation and migration have been controlled by deposition of clastic sedimentary wedges derived from the Brooks Range orogen. In the Late Jurassic to Early Cretaceous, the main oil kitchen was located in the Western Colville trough. Clastic depocenters and associated kitchen areas migrated progressively eastward with time and are now located in the East Beaufort offshore. Important source rocks include the Jurassic Kingak and Late Triassic Shublik Formations of the Ellesmerian megasequence, and the Aptian-Cenomanian HRZ and Turonian-Paleocene Shale Wall formations of the Brookian megasequence.

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

    SciTech Connect

    Boliang, Hu; Jiajing, Yang,

    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.

  20. Evidence of hydrocarbon contamination from the Burgan oil field, Kuwait: interpretations from thermal remote sensing data.

    PubMed

    ud Din, Saif; Al Dousari, Ahmad; Literathy, Peter

    2008-03-01

    The paper presents the application of thermal remote sensing for mapping hydrocarbon polluted sites. This has been achieved by mono-window algorithm for land surface temperature (LST) measurements, using multi-date band 6 data of Landsat Thematic Mapper (TM). The emissivity, transmittance and mean atmospheric temperature were used as critical factors to estimate LST. The changes in the surface emissivity due to oil pollution alter the apparent temperature, which was used as a recognition element to map out oil polluted surfaces. The LST contrast was successfully used to map spatial distribution of hydrocarbon pollution in the Burgan Oil field area of Kuwait. The methodology can be positively used to detect waste dumping, oil spills in oceans and ports, besides environmental management of oil pollution at or near the land surface. PMID:17291680

  1. Laboratory and field observations of stress-wave induced changes in oil flow behavior

    SciTech Connect

    Roberts, P. M.; Majer, Ernest Luther; Wooden, W.; Daley, T. M.

    2001-01-01

    We present recent results of laboratory and field experiments designed to validate and quantify the phenomenon of seismically enhanced oil production in marginal reservoirs. Controlled laboratory experiments were performed where mechanical stress oscillations at 100 Hz or less were applied to sandstone cores while flowing oil and/or brine at constant flow rates. Steady-state flow and simulated flooding experiments indicated that stress stimulation causes significant changes in the ability of one fluid to displace the other and on the preference that the rock has for trapping one fluid over the other. For Berea sandstone, which is highly water wet, stress stimulation caused oil production to be impeded during water floods and caused the bulk fluid pressure drop across the core to increase during steady-state simultaneous flow of oil and brine. A possible explanation of these observations is that stimulation caused the core to become more oil wet. Field stimulation tests on producing reservoirs at Lost Hills, California were performed using a downhole fluid pressure pulsation device. Stimulation was applied in one well for 50 days total during July - November 2000. Two groups of producing wells were monitored for changes in oil cut and oil production during the test. A control group of 26 wells displayed an oil-cut increase of 29% and an oil production increase of 26% which are clearly correlated with the stimulation treatment. A larger group of 60 wells showed 11% oil-cut and 17v0 production increases. Similar increases were observed during the October 1999 Hector Mine earthquake, magnitude 7.1, in the Mojave Desert about 230 miles from Lost Hills. Downhole seismic monitoring of the stimulation wavefield is being used to help quantify the frequency range and energy threshold required for effective production enhancement.

  2. Strontium isotope constraint on the genesis of crude oils, oil-field brines and Kuroko ore deposits from the Green Tuff region of northeastern Japan

    NASA Astrophysics Data System (ADS)

    Nakano, Takanori; Kajiwara, Yoshimichi; Farrell, Clifton W.

    1989-10-01

    Crude oils from Akita to northern Niigata oil fields in the Green Tuff region of northeastern Japan have distinctly uniform 87Sr/86Sr ratios (0.7080-0.7082), while those from the southern Niigata oil field contain more radiogenic strontium (0.7095-0.7102). The regional variation in the strontium isotopic composition of crude oils is also reflected in their sulfur contents and sulfur isotopic compositions, and may be attributed to the regional heterogeneity of marine organic sediments from which the crude oils were ultimately derived. The 87Sr/86Sr ratios of most oil-field brines (0.7061-0.7084), however, are different from and vary more locally than those of the accompanying crude oils. This finding supports the view that strontium, and by inference some other dissolved solutes in the brines, may have evolved during diagenesis by reaction of a connate and/or a meteoric water with rocks in the Green Tuff region. Barites in the sulfide ore and anhydrites and gypsums in the sulfate (sekko) ore from the Fukazawa and Kosaka Kuroko deposits in the Hokuroku district are divided by the 87Sr/86Sr ratio of 0.7081 (±0.0001), which is identical to that of crude oils from nearby oil fields. This similarity in ratios lends support to the conclusion that the Kuroko base metal deposits and crude oil deposits were ultimately derived from a common organic sediment named PUMOS (Primitive Undifferentiated Metalliferous Organic Sediments).

  3. Electric field and space charge distribution measurement in transformer oil struck by impulsive high voltage

    NASA Astrophysics Data System (ADS)

    Sima, Wenxia; Guo, Hongda; Yang, Qing; Song, He; Yang, Ming; Yu, Fei

    2015-08-01

    Transformer oil is widely used in power systems because of its excellent insulation properties. The accurate measurement of electric field and space charge distribution in transformer oil under high voltage impulse has important theoretical and practical significance, but still remains challenging to date because of its low Kerr constant. In this study, the continuous electric field and space charge distribution over time between parallel-plate electrodes in high-voltage pulsed transformer oil based on the Kerr effect is directly measured using a linear array photoelectrical detector. Experimental results demonstrate the applicability and reliability of this method. This study provides a feasible approach to further study the space charge effects and breakdown mechanisms in transformer oil.

  4. Computer Simulation of Stress-Strain State of Oil Gathering Pipeline Designed for Ugut Field

    NASA Astrophysics Data System (ADS)

    Burkov, P. V.; Burkova, S. P.; Samigullin, V. D.

    2016-04-01

    The paper presents the stress and strain state modeling of infield pipeline in Ugut oil field. The finite element models of the stress field distribution in the pipeline wall are presented in this paper. The attention is paid to the pipeline reliability under stress conditions induced by the internal pressure and external compressive or tensile loads.

  5. Forecasting populations of undiscovered oil fields with the log-Pareto distribution

    SciTech Connect

    Bettini, C.

    1987-01-01

    The search for a statistical representation of parent populations of oil field sizes in sedimentary basins has yielded a new probability distribution, termed the log-Pareto distribution. The log-Pareto law, related to the log-Pareto distribution, describes the medians of oil field sizes (either volumes or areas) associated with size-ranks in a parent population of fields. The name proposed for the new distribution stems from the assumption that an algebraic transformation involving logarithms of the volumes (or areas) of a parent population of oil fields yields a frequency distribution of transformed sizes that accords with the Pareto distribution. The derivation of the log-Pareto law and the log-Pareto distribution involved two steps, namely, (1) simulating a parent population of oil fields such that the population is conditioned to both the proportion of a basin's area occupied by fields and their geographic variability, and (2) finding a mathematical function that fits the log-log plot of field ranks versus simulated field areas. Both the log-Pareto law and log-Pareto distribution are useful for estimating the size distribution of the oil fields that remain to be discovered in a basin. A log-Pareto law fitted to the range of the largest fields discovered in maturely explored basins tends to underestimate the subpopulation of undiscovered fields, while Pareto's law tends to overestimate the undiscovered subpopulation. Therefore the log-Pareto law is more appropriate for risk-averse decision makers, and Pareto law for risk-seeking decision makers. The log-Pareto law has been validated with both simulated data and actual data from Nigeria, the Denver-Julesburg Basin, and the Campos Basin in Brazil.

  6. 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.

  7. Rapid detection of peanut oil adulteration using low-field nuclear magnetic resonance and chemometrics.

    PubMed

    Zhu, Wenran; Wang, Xin; Chen, Lihua

    2017-02-01

    (1)H low-field nuclear magnetic resonance (LF-NMR) and chemometrics were employed to screen the quality changes of peanut oil (PEO) adulterated with soybean oil (SO), rapeseed oil (RO), or palm oil (PAO) in ratios ranging from 0% to 100%. Significant differences in the LF-NMR parameters, single component relaxation time (T2W), and peak area proportion (S21 and S22), were detected between pure and adulterated peanut oil samples. As the ratio of adulteration increased, the T2W, S21, and S22 changed linearly; however, the multicomponent relaxation times (T21 and T22) changed slightly. The established principal component analysis or discriminant analysis models can correctly differentiate authentic PEO from fake and adulterated samples with at least 10% of SO, RO, or PAO. The binary blends of oils can be clearly classified by discriminant analysis when the adulteration ratio is above 30%, illustrating possible applications in screening the oil species in peanut oil blends. PMID:27596419

  8. 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.

  9. Economic assessment of environmental impact in the course of oil field development and production

    NASA Astrophysics Data System (ADS)

    Tsibulnikova, M. R.; Kupriyanova, O. S.; Strelnikova, A. B.

    2015-11-01

    The article considers the variety of impacts that oil exploration and production operations have on the environment at different stages of the process. To provide accurate economic assessment, an oil field development project was designed, with various development options. These options being analyzed, the strategy with the minimal environmental impact was identified. This has allowed preparation of a guideline on how to prevent deterioration of the environment and to reduce the negative environmental impact

  10. 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.

  11. Arctic National Wildlife Refuge: oil field or wilderness

    SciTech Connect

    Spitler, A.

    1987-11-01

    The second session of the 100th Congress will see continued debate over the prospect of oil and gas drilling on a 19-million-acre expanse of mountains and tundra known as the Arctic National Wildlife Refuge (ANWR). The arctic refuge, most of which lies above the Arctic Circle, is larger than any refuges in the lower 48 states. Because of its size, the area supports a broad range of linked ecosystems. Of particular concern is the 1.5-million-acre coastal plain, which may be targeted for development. The coastal plain provides a home, at least part of the year, to Alaska's porcupine caribou. The coastal plain also supports many other forms of wildlife-including the wolf, arctic fox, brown bear, polar bear, and arctic peregrine falcon, which is listed as a threatened species. The potential effects of drilling projects extend beyond loss of wildlife; they include desecration of the land itself. Although few members of Congress deny the value of protecting the amazing variety of life on the coastal plain, some insist that limited drilling could be conducted without destroying crucial habitat. Last July, the department tentatively divided some of the targeted lands among native corporations in preparation for leasing to oil companies. In response to what was felt to be an attempt to overstep congressional authority, the House passed HR 2629, banning this kind of land deal without congressional approval. In essence, the measure reiterated congressional authority provided by the Alaska National Interest Lands Conservation Act (ANILCA) of 1980. This act mandated the study of environmental threats and oil potential by the Department of Interior, while putting the ANWR coastal plain off-limits to development without an explicit congressional directive.

  12. Can nonhazardous oil field wastes be disposed of in salt caverns?

    SciTech Connect

    Veil, J.A.

    1996-10-01

    Solution-mined salt caverns have been used for many years for storing hydrocarbon products. This paper summarizes an Argonne National Laboratory report that reviews the legality, technical suitability, and feasibility of disposing of nonhazardous oil and gas exploration and production wastes in salt caverns. An analysis of regulations indicated that there are no outright regulatory prohibitions on cavern disposal -of oil field wastes at either the federal level or in the 11 oil-producing states that were studied. There is no actual field experience on the long-term impacts that might arise following closure of waste disposal caverns. Although research has found that pressures will build up in a closed cavern, none has specifically addressed caverns filled with oil field wastes. More field research on pressure build up in closed caverns is needed. On the basis of preliminary investigations, we believe that disposal of oil field wastes in salt caverns is legal and feasible. The technical suitability of the practice depends on whether the caverns are well-sited and well-designed, carefully operated, properly closed, and routinely monitored.

  13. New information on disposal of oil field wastes in salt caverns

    SciTech Connect

    Veil, J.A.

    1996-10-01

    Solution-mined salt caverns have been used for many years for storing hydrocarbon products. This paper summarizes an Argonne National Laboratory report that reviews the legality, technical suitability, and feasibility of disposing of nonhazardous oil and gas exploration and production wastes in salt caverns. An analysis of regulations indicated that there are no outright regulatory prohibitions on cavern disposal of oil field wastes at either the federal level or in the 11 oil-producing states that were studied. There is no actual field experience on the long-term impacts that might arise following closure of waste disposal caverns. Although research has found that pressures will build-up in a closed cavern, none has specifically addressed caverns filled with oil field wastes. More field research on pressure build-up in closed caverns is needed. On the basis of preliminary investigations, we believe that disposal of oil field wastes in salt caverns is legal and feasible. The technical suitability of the practice depends on whether the caverns are well-sited and well-designed, carefully operated, properly closed, and routinely monitored.

  14. 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.

  15. Observed oil and gas field size distributions: a consequence of the discovery process and prices of oil and gas

    SciTech Connect

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

    1988-11-01

    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.

  16. Reservoir Model of the Jacksonburg-Stringtown Oil Field; Northwestern West Virginia: Potential for Miscible Carbon Dioxide Enhanced Oil Recovery

    NASA Astrophysics Data System (ADS)

    Bergerud, Blake

    Located in northwestern West Virginia, the Jacksonburg-Stringtown field has produced over 22 million barrels of oil (MMBO) since its discovery in 1895. The primary producing interval within the field is the Late Devonian Gordon Stray. Log analysis shows this formation to represent an estuarine depositional system. Four subunits within the formation are defined based on depositional framework: barrier sand, central bay shale, estuarine channels, and fluvial channel subunits. RHOmaa/Umaa lithological composition plots support the conclusion of a marine-influenced estuarine depositional framework. Structural and isopach maps generated with data from 73 local wells reveal a northeast-southwest trending sand deposit of 15-35 foot thickness, which is interpreted as the depocenter for the incised valley of the Gordon Stray. Analysis of formation horizon maps shows that the reservoir is synclinal and, as a result, contains a stratigraphic trap as opposed to the more common structural traps found in the immediate area. Porosity and pore-feet distribution maps indicate high porosity regions in southern regions of the field and high pore volume in northern areas. A miscible CO2 flood model estimates that an additional 7.3 MMBO could be recovered from the high porosity regions in the southern half of the field. The Jacksonburg-Stringtown field is well-suited for enhanced oil recovery and/or geologic CO2 sequestration.

  17. 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.

  18. Increased oil recovery from mature oil fields using gelled polymer treatments

    SciTech Connect

    Willhite, G. Paul; Green, Down W.; McCool, Stan

    2000-02-23

    Gelled polymer treatments are applied to oil reservoirs to increase oil production to reduce water production by altering the fluid movement within the reservoir. This research program is aimed at reducing barriers to the widespread use of these treatments by developing methods to predict gel behavior during placement in matrix rock and fractures, determining the persistence of permeability reduction after gel placement, and by developing methods to design production well treatments to control water production. This report describes the progress of the research during the first six months of work. A Dawn EOS multi-angle laser light scattering detector was purchased, installed and calibrated. Experiments were conducted to determine the permeabilities of a bulk gel and of a filter cake which forms when a gel is dehydrated. The pressure at which a gel in a tube is ruptured was measured and was correlated to the length and diameter of the gel.

  19. 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

    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

  20. 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

  1. ROLE OF SMALL OIL AND GAS FIELDS IN THE UNITED STATES.

    USGS Publications Warehouse

    Meyer, Richard F.; Fleming, Mary L.

    1985-01-01

    The actual economic size cutoff is a function of such factors as depth, water depth offshore, and accessibility to transportation infrastructure. Because of the constraint of resource availability, price is now the principal force driving drilling activity. The proportion of new-field wildcats to other exploratory wells has fallen in recent years, but success in new-field wildcats has risen to about 20%. However, only very small fields, less than 1 million BOE, are being found in large numbers. Through 1979, almost 93% of known gas fields and 94. 5% of known oil fields were small, yet they contain only 14. 5% of the ultimately recoverable gas and 12. 5% of the oil. However, small fields are less capital intensive than equivalent-capacity synthetic-fuel plants, they are extremely numerous, and they are relatively easy and inexpensive to find and put on production. Refs.

  2. 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 ...

  3. Disposal of oil field wastes into salt caverns: Feasibility, legality, risk, and costs

    SciTech Connect

    Veil, J.A.

    1997-10-01

    Salt caverns can be formed through solution mining in the bedded or domal salt formations that are found in many states. Salt caverns have traditionally been used for hydrocarbon storage, but caverns have also been used to dispose of some types of wastes. This paper provides an overview of several years of research by Argonne National Laboratory on the feasibility and legality of using salt caverns for disposing of oil field wastes, the risks to human populations from this disposal method, and the cost of cavern disposal. Costs are compared between the four operating US disposal caverns and other commercial disposal options located in the same geographic area as the caverns. Argonne`s research indicates that disposal of oil field wastes into salt caverns is feasible and legal. The risk from cavern disposal of oil field wastes appears to be below accepted safe risk thresholds. Disposal caverns are economically competitive with other disposal options.

  4. Visualization by light transmission of oil and water contents in transient two-phase flow fields

    NASA Astrophysics Data System (ADS)

    Darnault, Christophe J. G.; Throop, James A.; DiCarlo, David A.; Rimmer, Alon; Steenhuis, Tammo S.; Parlange, J.-Yves

    1998-06-01

    The difficulty of determining transient fluid contents in a soil-oil-water system is hampering an understanding of the system's flow characteristics. In this paper, we describe a light transmission method (LTM) which can rapidly obtain oil and water contents throughout a large two-dimensional flow field of silica sand. By appropriately coloring the water with 0.005% FD&C blue #1, the hue of the transmitted light is found to be directly related to the water content within the porous media. The hue provides a high resolution measurement of the water and oil contents in transient flow fields (such as unstable flow). Evaluation of the reliability of LTM was assessed by checking the mass balance for a known water injection and its utility in visualizing a whole flow field was exemplified for unstable fingered flow by comparing fluid contents to those obtained with synchrotron X-ray radiation.

  5. Elastomers in mud motors for oil field applications

    SciTech Connect

    Hendrik, J.

    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.

  6. 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.

  7. Sterilization of oil-field re-injection water using combination treatment of pulsed electric field and ultrasound.

    PubMed

    Xin, Qing; Zhang, Xingwang; Li, Zhongjian; Lei, Lecheng

    2009-01-01

    It was necessary to sterilize the oil-field re-injection water for biocorrosion inhibition. Saprophytic bacteria, iron bacteria and sulfate reducing bacteria were the three main microorganisms resulting in the microbial contamination. To enhance the sterilization efficiency of oil-field re-injection water by pulsed electric field (PEF), the combined treatment of PEF and ultrasound was explored in the study. Meanwhile, the effects of PEF, ultrasound and the combination treatment on the three bacteria inactivation were investigated. The combination treatment had higher inactivation efficiency than independent PEF as well as ultrasound. Obvious synergistic effects were also observed on the inactivation of saprophytic bacteria and iron bacteria by the combined treatment. PMID:18567526

  8. 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.

  9. Characterising oil and water in porous media using decay due to diffusion in the internal field

    NASA Astrophysics Data System (ADS)

    Lewis, Rhiannon T.; Djurhuus, Ketil; Seland, John Georg

    2015-10-01

    In the method Decay due to Diffusion in the Internal Field (DDIF), the diffusion behaviour of water molecules in the internal magnetic field makes it possible to determine a distribution of pore sizes in a sample. The DDIF experiment can also be extended to a DDIF-Carr-Purcell-Meiboom-Gill (DDIF-CPMG) experiment to measure correlations between the pore size and the transverse relaxation time, T2 . In this study we have for the first time applied the DDIF experiment and the DDIF-CPMG experiment to porous materials saturated with both water and oil. Because of the large difference in diffusion rates between water and oil molecules, the DDIF experiment will act as a filter for the signal from oil, and we are left with the DDIF-signal from water only. This has been verified in model systems consisting of glass beads immersed in separate layers of water and oil, and in a sandstone sample saturated with water and oil. The results show that the DDIF and DDIF-CPMG experiments enable the determination of the confining geometry of the water phase, and how this geometry is correlated to T2 . Data obtained in the sandstone sample saturated with water and oil also show that with the exception of the smallest pores there is no clear correlation between pore size and the relaxation time of water.

  10. Genome Sequence of Hydrocarbon-Degrading Cronobacter sp. Strain DJ34 Isolated from Crude Oil-Containing Sludge from the Duliajan Oil Fields, Assam, India.

    PubMed

    Pal, Siddhartha; Das Banerjee, Tirtha; Roy, Ajoy; Sar, Pinaki; Kazy, Sufia K

    2015-01-01

    We report here the 4,856,096-bp draft genome sequence of hydrocarbon-degrading Cronobacter sp. strain DJ34 isolated from crude oil-containing sludge from the Duliajan oil fields, India. DJ34 contains genes that mediate hydrocarbon degradation, metal resistance, and biosurfactant production. This is the first report of the genome sequence of Cronobacter sp. inhabiting an oil-contaminated environment. PMID:26564043

  11. Genome Sequence of Hydrocarbon-Degrading Cronobacter sp. Strain DJ34 Isolated from Crude Oil-Containing Sludge from the Duliajan Oil Fields, Assam, India

    PubMed Central

    Pal, Siddhartha; Das Banerjee, Tirtha; Roy, Ajoy; Sar, Pinaki

    2015-01-01

    We report here the 4,856,096-bp draft genome sequence of hydrocarbon-degrading Cronobacter sp. strain DJ34 isolated from crude oil-containing sludge from the Duliajan oil fields, India. DJ34 contains genes that mediate hydrocarbon degradation, metal resistance, and biosurfactant production. This is the first report of the genome sequence of Cronobacter sp. inhabiting an oil-contaminated environment. PMID:26564043

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

    SciTech Connect

    Elcock, D.

    1998-03-10

    Salt caverns can be formed in underground salt formations incidentally as a result of mining or intentionally to create underground chambers for product storage or waste disposal. For more than 50 years, salt caverns have been used to store hydrocarbon products. Recently, concerns over the costs and environmental effects of land disposal and incineration have sparked interest in using salt caverns for waste disposal. Countries using or considering using salt caverns for waste disposal include Canada (oil-production wastes), Mexico (purged sulfates from salt evaporators), Germany (contaminated soils and ashes), the United Kingdom (organic residues), and the Netherlands (brine purification wastes). In the US, industry and the regulatory community are pursuing the use of salt caverns for disposal of oil-field wastes. In 1988, the US Environmental Protection Agency (EPA) issued a regulatory determination exempting wastes generated during oil and gas exploration and production (oil-field wastes) from federal hazardous waste regulations--even though such wastes may contain hazardous constituents. At the same time, EPA urged states to tighten their oil-field waste management regulations. The resulting restrictions have generated industry interest in the use of salt caverns for potentially economical and environmentally safe oil-field waste disposal. Before the practice can be implemented commercially, however, regulators need assurance that disposing of oil-field wastes in salt caverns is technically and legally feasible and that potential health effects associated with the practice are acceptable. In 1996, Argonne National Laboratory (ANL) conducted a preliminary technical and legal evaluation of disposing of nonhazardous oil-field wastes (NOW) into salt caverns. It investigated regulatory issues; the types of oil-field wastes suitable for cavern disposal; cavern design and location considerations; and disposal operations, closure and remediation issues. It determined

  13. Analysis of the ecological risk of opening new oil and gas fields

    SciTech Connect

    Anikiev, V.V.; Mansurov, M.N.; Fleishman, B.S.

    1995-01-01

    Practical recommendations that would ensure the ecological safety of opening new marine oil and gas fields should include analysis of ecological risk. Such an analysis should precede the studies of ecological safety and resolve a sequence of problems in evaluating the ecological risk, the probability and scale of accidents at the oil and gas extraction complex, and economic damage that could occur. This paper presents a method of evaluation of risks for fish populations incurred by marine extraction of oil and gas, calculates the required limit of probability of accidents excluding the possibility of degradation of flatfish populations, estimates expenses incurred by accidental oil spills, and presents data on level of pollution. 9 refs., 1 tab.

  14. Application of bio-huff-`n`-puff technology at Jilin oil field

    SciTech Connect

    Xiu-Yuan Wang; Yan-Fed Xue; Gang Dai; Ling Zhao

    1995-12-31

    An enriched culture 48, capable of adapting to the reservoir conditions and fermenting molasses to produce gas and acid, was used as an inoculum for bio- huff-`n`-puff tests at Fuyu oil area of Jilin oil field. The production well was injected with water containing 4-6% (v/v) molasses and inoculum, and then shut in. After 15-21 days, the well was placed back in operation. A total of 44 wells were treated, of which only two wells showed no effects. The daily oil production of treated wells increased by 33.3-733.3%. Up to the end of 1994, the oil production was increased by 204 tons per well on average. Results obtained from various types of production wells were discussed.

  15. Hydrocarbon charging histories of the Ordovician reservoir in the Tahe oil field, Tarim Basin, China.

    PubMed

    Li, Chun-Quan; Chen, Hong-Han; Li, Si-Tian; Zhang, Xi-Ming; Chen, Han-Lin

    2004-08-01

    The Ordovician reservoir of the Tahe oil field went through many tectonic reconstructions, and was characterized by multiple hydrocarbon chargings. The aim of this study was to unravel the complex charging histories. Systematic analysis of fluid inclusions was employed to complete the investigation. Fluorescence observation of oil inclusions under UV light, and microthermometry of both oil and aqueous inclusions in 105 core samples taken from the Ordovician reservoir indicated that the Ordovician reservoir underwent four oil chargings and a gas charging. The hydrocarbon chargings occurred at the late Hercynian, the Indo-Sinian and Yanshan, the early Himalaya, the middle Himalaya, and the late Himalaya, respectively. The critical hydrocarbon charging time was at the late Hercynian. PMID:15236484

  16. 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

  17. Microseismic Monitoring Using Surface and Borehole Seismic Stations in an Oil Field, North Oman

    NASA Astrophysics Data System (ADS)

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

    2009-05-01

    Five shallow borehole seismic stations were installed to monitor microearthquake activities in a carbonate oil field in northern Oman since 1999. This shallow network of seismic station operated continuously until 2002 after which intermittent seismic recording took place due to lack of maintenance and failure of some stations. The objectives of the study are to determine the microseismic parameters in the oil field and to determine the spatial and temporal distribution of these events to evaluate possible triggering mechanism. Well over 400 microearthquakes per year were recorded in the first three years of operation and after that the level of seismic recording fell to less than 200 microearthquakes per year due to failure of some stations. In March 2008, temporary seismic experiment consisting of five near surface seismic stations were installed in the oil field to augment the shallow network station and to evaluate surface installment of seismic instrument to monitor microseismic activities. It has been recognized that microearthquakes data such as size, spatial, and temporal distribution provide information on the pressure waves initiated by either production of or injection of fluids into reservoirs. A total of 44 local microearthquake events were analyzed and located during the temporary seismic stations deployment using a non-linear location software that allows the use of variable accurate velocity model of the subsurface. The events location is confined to oil field reservoir boundary during the recording period and more events occurring at shallow depth. The correlation coefficient between gas production and number of events is the higher compared with the oil production or water injection. The focal plane solution for the largest event in the sequence indicates normal faulting with extensional stress consistent with the existing mapped normal faults in the oil field. Microseismic signal clearly detected by the collocated sensors of the near surface

  18. 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.

  19. Analysis of radiolabelled thiocyanate tracer in oil field brines

    NASA Astrophysics Data System (ADS)

    Bjørnstad, T.; Brendsdal, E.; Michelsen, O. B.; Rogde, S. A.

    1990-12-01

    Thiocyanate (SCN -) labelled with 14C or 35S is applicable for the tracing of the water flow in water-driven oil production. This work describes two improved methods for increasing the concentration of S 14CN - with sample sizes up to 1000 ml of sampled brine. The radioactivity detection is carried out by low-background liquid scintillation counting using standard-size counting vials of 20 ml. The first method is based on solvent extraction: two extraction/strip steps reduce the volume by the required factor of 100 down to 10 ml. The extraction agent is 0.5M tri-isooctylamine (TiOA) in Solvesso-150 and the stripping agent is 5M NH 3. A chemical yield of 70-75%, a somewhat unfavourable quenching factor and a moderate reproducibility lead to a detection limit LD of 0.04 Bq/1. The second method is based on anion exchange. 1000 ml tracer-containing brine may be loaded onto 6.1 ml of the anion-exchange resin AG1-x8 before significant breakthrough of the tracer. More than 98.4% is absorbed. By elution with 2.8M sodiumperchlorate, more than 99.5% of the absorbed tracer is concentrated in a sharp elution peak of 10 ml. With a total chemical yield of 98%, a lower quenching factor and higher reproducibility than for the solvent extraction method, an LD-value of 0.005 Bq/1 is obtained.

  20. 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.

  1. 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.

  2. Neutron scattering studies of crude oil viscosity reduction with electric field

    NASA Astrophysics Data System (ADS)

    Du, Enpeng

    topic. Dr. Tao with his group at Temple University, using his electro or magnetic rheological viscosity theory has developed a new technology, which utilizes electric or magnetic fields to change the rheology of complex fluids to reduce the viscosity, while keeping the temperature unchanged. After we successfully reduced the viscosity of crude oil with field and investigated the microstructure changing in various crude oil samples with SANS, we have continued to reduce the viscosity of heavy crude oil, bunker diesel, ultra low sulfur diesel, bio-diesel and crude oil and ultra low temperature with electric field treatment. Our research group developed the viscosity electrorheology theory and investigated flow rate with laboratory and field pipeline. But we never visualize this aggregation. The small angle neutron scattering experiment has confirmed the theoretical prediction that a strong electric field induces the suspended nano-particles inside crude oil to aggregate into short chains along the field direction. This aggregation breaks the symmetry, making the viscosity anisotropic: along the field direction, the viscosity is significantly reduced. The experiment enables us to determine the induced chain size and shape, verifies that the electric field works for all kinds of crude oils, paraffin-based, asphalt-based, and mix-based. The basic physics of such field induced viscosity reduction is applicable to all kinds of suspensions.

  3. Characteristics of enriched cultures for bio-huff-`n`-puff tests at Jilin oil field

    SciTech Connect

    Xiu-Yuan Wang; Gang Dai; Yan-Fen Xue; Shu-Hua Xie

    1995-12-31

    Three enriched cultures (48, 15a, and 26a), selected from more than 80 soil and water samples, could grow anaerobically in the presence of crude oil at 30{degrees}C and could ferment molasses to gases and organic acids. Oil recovery by culture 48 in the laboratory model experiment was enhanced by 25.2% over the original reserves and by 53.7% over the residual reserves. Enriched culture 48 was composed of at least 4 species belonging to the genera Eubacterium, Fusobacterium, and Bacteroides. This enriched culture was used as inoculum for MEOR field trials at Jilin oil field with satisfactory results. The importance of the role of these isolates in EOR was confirmed by their presence and behavior in the fluids produced from the microbiologically treated reservoir.

  4. 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

  5. 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

  6. 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

  7. 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

  8. Special ESP configurations designed to test and produce Yemen oil field. [Electric-Submersible Pump

    SciTech Connect

    Wilkie, D.I. )

    1993-09-27

    Innovative electric-submersible-pump (ESP) configurations were used in the exploration phase of a Yemen oil field discovered by Canadian Occidental Petroleum Ltd. Because of subnormal reservoir pressure, CanOxy developed the field with ESPs and had to install surface components that could operate at the high, 130 F., ambient temperatures common in Yemen. The field is in a remote area that has seen very little development. The reservoirs produce a medium-to-heavy crude with a low gas/oil ratio, typically less than 20 scf/bbl. Problems faced in evaluating the field included drilling through unconsolidated sands with high flow capacity and subnormal reservoir pressure. CanOxy had to develop the technology to test the wells during the exploration phase, and intends to use new, or at least uncommon technology, for producing the wells. The paper describes testing the wells, the electric generators and variable speed drives, and the use of these pumps on production wells.

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

    SciTech Connect

    Johnson, E.H. )

    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.

  10. The 1-AB block fields-a giant oil accumulation in Eastern Peru

    SciTech Connect

    Jarvis, H.A.; Lay, V. ); Orosco, C. )

    1993-02-01

    The 1-Ab block fields are located in the northeastern part of Peru. Geologically, the area is the sub-Andean Maranon Basin, a continuation of the Napo Basin from eastern Ecuador. During the 20 years that Occidental has operated Block 1-AB, approximately 11,500 km of seismic data has been recorded and 34 exploratory wells have been drilled, resulting in the discovery of 18 fields, or 53% exploration success. The 1-AB oil accumulation discovered in 1972 is a group of medium to small asymmetric anticlines distributed along six northwest-southeast trending structural alignments: North Capahuari-South Capahuari-Tambo, Carmen-North San Jaacinto and Bartra. This concentration of productive structures in a relative small area is unique within the Maranon basin. The controlling factors include exceptional pre-Cretaceous uplifting and the presence of very good to excellent Cretaceous sandstones reservoirs. The two major Cretaceous producing zones, the Chonta and Vivian sandstones, have been defined within the Coniacian and Campanian ages respectively. The Chonta sands are related to shelfal deposition across Block 1-AB, represented by strand plain and barrier island sediments. The Vivian formation is a massive fluvial sandstone covering all of the Maranon basin and ranging in thickness between 40 and 200 feet. After oil was accumulated, fresh water influxes into the reservoirs of the northern and eastern fields caused oil biodegradation and salinity variation of the reservoir waters, depending upon the intensity of biodegradation. Oil remigration also has been documented for the South Huayari field.

  11. 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...

  12. 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.

  13. 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...

  14. [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; Mikhaĭlova, 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

  15. Molecular dynamics and composition of crude oil by low-field nuclear magnetic resonance.

    PubMed

    Jia, Zijian; Xiao, Lizhi; Wang, Zhizhan; Liao, Guangzhi; Zhang, Yan; Liang, Can

    2016-08-01

    Nuclear magnetic resonance (NMR) techniques are widely used to identify pure substances and probe protein dynamics. Oil is a complex mixture composed of hydrocarbons, which have a wide range of molecular size distribution. Previous work show that empirical correlations of relaxation times and diffusion coefficients were found for simple alkane mixtures, and also the shape of the relaxation and diffusion distribution functions are related to the composition of the fluids. The 2D NMR is a promising qualitative evaluation method for oil composition. But uncertainty in the interpretation of crude oil indicated further study was required. In this research, the effect of each composition on relaxation distribution functions is analyzed in detail. We also suggest a new method for prediction of the rotational correlation time distribution of crude oil molecules using low field NMR (LF-NMR) relaxation time distributions. A set of down-hole NMR fluid analysis system is independently designed and developed for fluid measurement. We illustrate this with relaxation-relaxation correlation experiments and rotational correlation time distributions on a series of hydrocarbon mixtures that employ our laboratory-designed downhole NMR fluid analyzer. The LF-NMR is a useful tool for detecting oil composition and monitoring oil property changes. Copyright © 2016 John Wiley & Sons, Ltd. PMID:26990450

  16. 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.

  17. Estimation of oil recovery by in-situ combustion in the Jobo Field of Eastern Venezuela

    SciTech Connect

    Luengo-C, J.R.; Sanyal, S.K.

    1981-03-01

    A laboratory combustion experiment using samples from Jobo Field was completed. The data obtained by this experiment could be used for an approximate estimation of recovery for a pilot project in this field. An isolated pilot test would give enough information to determine the behavior of the combustion process for field applications. Aplication of recovery correlations indicate that a pilot test in an inverted 5-spot pattern (10 to 20 acres spacing) appears adequate for these field conditions. Air injection rates should be calculated and compared with injectivity tests, the ability of the producing wells to handle the oil, and the maximum pressure the reservoir can handle without fracturing.

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

    SciTech Connect

    Milton, J.D. ); Edwards, E.B. ); Heck, R.G. )

    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.

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

    SciTech Connect

    Milton, J.D.; Edwards, E.B.; Heck, R.G.

    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.

  20. Application of electrical submersible pumps in heavy crude oil in Boscan Field

    SciTech Connect

    Bortolin, L.L.

    1995-12-31

    During recent years optimization of artificial lift methods has been applied in the oil industry, in order to evaluate the effect on oil well production and to establish a company`s optimal investment policies. Higher costs on new artificial lifting equipment and facilities for new fields have created the necessity to review the latest available technology of different lifting methods and specially that related to electrical submersible pumps (ESP). Few studies in the area of heavy crude oil production optimization using ESP as a lifting method have been published. This paper discusses the results of an ESP pilot project performed in 24 wells in Boscan field, and analyzes the performance of the equipment and its application range. The ESP equipment was installed in completions at depths ranging from 7000 to 9000 feet, with a 10{degrees}API gravity crude and bottomhole temperature of 180{degrees}F. It was concluded that despite a reduction of the pump`s efficiency, the ESP equipment does qualify as a good alternative lifting method for heavy oil production. It is also possible to obtain higher production rates. The results obtained in this pilot project, confirm that submersible pumps are an alternative method for lifting heavy crude oil from relatively deep reservoirs.

  1. Real-time oil-saturation monitoring in rock cores with low-field NMR.

    PubMed

    Mitchell, J; Howe, A M; Clarke, A

    2015-07-01

    Nuclear magnetic resonance (NMR) provides a powerful suite of tools for studying oil in reservoir core plugs at the laboratory scale. Low-field magnets are preferred for well-log calibration and to minimize magnetic-susceptibility-induced internal gradients in the porous medium. We demonstrate that careful data processing, combined with prior knowledge of the sample properties, enables real-time acquisition and interpretation of saturation state (relative amount of oil and water in the pores of a rock). Robust discrimination of oil and brine is achieved with diffusion weighting. We use this real-time analysis to monitor the forced displacement of oil from porous materials (sintered glass beads and sandstones) and to generate capillary desaturation curves. The real-time output enables in situ modification of the flood protocol and accurate control of the saturation state prior to the acquisition of standard NMR core analysis data, such as diffusion-relaxation correlations. Although applications to oil recovery and core analysis are demonstrated, the implementation highlights the general practicality of low-field NMR as an inline sensor for real-time industrial process control. PMID:25996514

  2. 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.

  3. 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.

  4. 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)

  5. 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

  6. 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

  7. Airborne measurements of atmospheric methane over oil fields in western Siberia

    NASA Astrophysics Data System (ADS)

    Tohjima, Y.; Maksyutov, S.; Machida, T.; Inoue, G.

    Airborne measurements of atmospheric methane (CH4) over oil fields in western Siberia were carried out on August 1, 1994. Extremely sharp CH4 peaks were observed in the horizontal distribution of CH4 at an altitude of 150 m above the ground surface; the half widths of the peaks were 3-4 km and the concentration of the largest peak exceeded 2.9 ppmv. Since the CH4 distribution was considered to reflect the distribution of CH4 emission strength on the surface, there was strong CH4 emission at the peak positions. All of the observed CH4 peak positions were located at or near oil production sites and/or oil pipelines, suggesting that natural gas was emitted from the facilities. Leakage or venting of natural gas are the probable CH4 sources.

  8. Evaluation of Slime-Producing Bacteria in Oil Field Core Flood Experiments

    PubMed Central

    Geesey, G. G.; Mittelman, M. W.; Lieu, V. T.

    1987-01-01

    Epifluorescence microscopy and carbohydrate determinations indicated that the decrease in permeability of oil reservoir sand to reclaimed sewage water was partially the result of biological plugging. Filtration and biocide addition studies demonstrated that the increase in bacterial densities and slime concentrations in flooded oil field cores appeared to be due to both deposition from the reclaimed water and in situ microbial growth and slime production. Although these biological components increased throughout the cores during flooding, the region where the water entered the core exhibited the highest cell densities and slime concentrations. The approach described in this report should be useful in predicting the potential of a water source to induce biological plugging of oil reservoir sand. PMID:16347276

  9. 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.

  10. 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

    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.

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

    SciTech Connect

    Scott Hara

    1998-03-03

    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

  12. 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

  13. Mapping three-dimensional oil distribution with π-EPI MRI measurements at low magnetic field

    NASA Astrophysics Data System (ADS)

    Li, Ming; Xiao, Dan; Romero-Zerón, Laura; Marica, Florea; MacMillan, Bryce; Balcom, Bruce J.

    2016-08-01

    Magnetic resonance imaging (MRI) is a robust tool to image oil saturation distribution in rock cores during oil displacement processes. However, a lengthy measurement time for 3D measurements at low magnetic field can hinder monitoring the displacement. 1D and 2D MRI measurements are instead often undertaken to monitor the oil displacement since they are faster. However, 1D and 2D images may not completely reflect the oil distribution in heterogeneous rock cores. In this work, a high-speed 3D MRI technique, π Echo Planar Imaging (π-EPI), was employed at 0.2 T to monitor oil displacement. Centric scan interleaved sampling with view sharing in k-t space was employed to improve the temporal resolution of the π-EPI measurements. A D2O brine was employed to distinguish the hydrocarbon and water phases. A relatively homogenous glass bead pack and a heterogeneous Spynie core plug were employed to show different oil displacement behaviors. High quality 3D images were acquired with π-EPI MRI measurements. Fluid quantification with π-EPI compared favorably with FID, CPMG, 1D-DHK-SPRITE, 3D Fast Spin Echo (FSE) and 3D Conical SPRITE measurements. π-EPI greatly reduced the gradient duty cycle and improved sensitivity, compared to FSE and Conical SPRITE measurements, enabling dynamic monitoring of oil displacement processes. For core plug samples with sufficiently long lived T2, T2∗, π-EPI is an ideal method for rapid 3D saturation imaging.

  14. Mapping three-dimensional oil distribution with π-EPI MRI measurements at low magnetic field.

    PubMed

    Li, Ming; Xiao, Dan; Romero-Zerón, Laura; Marica, Florea; MacMillan, Bryce; Balcom, Bruce J

    2016-08-01

    Magnetic resonance imaging (MRI) is a robust tool to image oil saturation distribution in rock cores during oil displacement processes. However, a lengthy measurement time for 3D measurements at low magnetic field can hinder monitoring the displacement. 1D and 2D MRI measurements are instead often undertaken to monitor the oil displacement since they are faster. However, 1D and 2D images may not completely reflect the oil distribution in heterogeneous rock cores. In this work, a high-speed 3D MRI technique, π Echo Planar Imaging (π-EPI), was employed at 0.2T to monitor oil displacement. Centric scan interleaved sampling with view sharing in k-t space was employed to improve the temporal resolution of the π-EPI measurements. A D2O brine was employed to distinguish the hydrocarbon and water phases. A relatively homogenous glass bead pack and a heterogeneous Spynie core plug were employed to show different oil displacement behaviors. High quality 3D images were acquired with π-EPI MRI measurements. Fluid quantification with π-EPI compared favorably with FID, CPMG, 1D-DHK-SPRITE, 3D Fast Spin Echo (FSE) and 3D Conical SPRITE measurements. π-EPI greatly reduced the gradient duty cycle and improved sensitivity, compared to FSE and Conical SPRITE measurements, enabling dynamic monitoring of oil displacement processes. For core plug samples with sufficiently long lived T2, T2(∗), π-EPI is an ideal method for rapid 3D saturation imaging. PMID:27208417

  15. Exploitation of oil in a volcanic cone by horizontal drilling in the Elaine field, south Texas

    SciTech Connect

    Martinez, P.A.; Kushner, P.L.; Harbaugh, J.W.

    1991-03-01

    The Uvalde volcanic field west and southwest of San Antonio contains many buried volcanic cones that offer attractive places to exploit with horizontal drilling. These buried cones were formed by eruption of basaltic flows and cinders during the Cretaceous when the Austin Chalk and immediately overlying strate were deposited. The cones vary in size, some being as much as 2 mi in diameter and 1000 ft in vertical dimension. During eruptions, flows and ejecta reacted with sea water, producing intermixtures of basaltic material and limestone. These cones provide attractive targets for oil exploration. The Elaine field about 90 mi southwest of San Antonio is associated with a buried volcanic cone that is now being exploited with horizontal drilling. Horizontal Drilling and Production, Inc., ('HDP') drilled the Autumn 1 as the initial horizontal well at Elaine. A vertical hole was drilled through the cone and underlying Austin Chalk, reconfirming the presence of the oil zone at the contact between volcanics and chalk. Moving back up the hole, a cement plug was set within the volcanics, and a horizontal hole was directed on a N 70W azimuth. The inclined hole's vertical angle had progressively decreased with distance to about 30{degree} from the horizontal when the oil zone was reentered. The hole's inclination continued to decrease within the oil zone, becoming horizontal after about 600 ft. With further distance, the hole passed beneath the oil zone, where its inclination was then reversed so that it climbed gradually and reentered the oil zone before reaching its terminal distance of 1500 horizontal feet. The well was completed on August 17, 1990, with an indicated initial production of 1609 BOPD.

  16. Sulfate-reducing bacteria release barium and radium from naturally occurring radioactive material in oil-field barite

    USGS Publications Warehouse

    Phillips, E.J.P.; Landa, E.R.; Kraemer, T.; Zielinski, R.

    2001-01-01

    Scale and sludge deposits formed during oil production can contain elevated levels of Ra, often coprecipitated with barium sulfate (barite). The potential for sulfate-reducing bacteria to release 226 Ra and Ba (a Ra analog) from oil-field barite was evaluated. The concentration of dissolved Ba increased when samples containing pipe scale, tank sludge, or oil-field brine pond sediment were incubated with sulfate-reducing bacteria Desulfovibrio sp., Str LZKI, isolated from an oil-field brine pond. However, Ba release was not stoichiometric with sulfide production in oil-field samples, and <0.1% of the Ba was released. Potential for the release of 226Ra was demonstrated, and the 226 Ra release associated with sulfate-reducing activity was predictable from the amount of Ba released. As with Ba, only a fraction of the 226Ra expected from the amount of sulfide produced was released, and most of the Ra remained associated with the solid material.

  17. How to make a billion-barrel oil field in offshore California commercial

    SciTech Connect

    Patterson, J.C.; Ballard, J.H.

    1988-02-01

    The major obstacles and challenges involved in exploration and development of a giant deep-water low-gravity oil field are exemplified in the undeveloped Sword field of offshore southern California. In 1979, Conoco Exploration identified a northeast-southwest-trending basement high in the 800 to 2000-ft deep federal waters 12 mi southwest of Pt. Conception at the western end of the Santa Barbara Channel. The intended reservoir was fractured Miocene Monterey chert, silicic shales/siltstones, and dolomites that are draped over the axially faulted structure. Drilling of the initial well in OCS P-0322 in 1982 resulted in discovering the giant Sword field. A confirmation well drilled in OCS P-0320 indicates in-place reserves of well over 1 billion bbl. While the discovered potential is significant, the low gravity (8.5/degree/-10.5/degree/ API) of the oils discovered to date, along with water depths in excess of 1500 ft, currently pose economic challenges to successful field development. Conoco and its partners are addressing the current economic barriers on a number of fronts. Three-dimensional seismic surveys are being conducted to better delineate reservoir geometry and to define probable variations in lithology, fracturing, and oil gravity. A market feasibility study will be undertaken to assess the demand for low-gravity crude from offshore California.

  18. Oil fields and new plays in the Rioni foreland basin, Republic of Georgia

    SciTech Connect

    Robinson, A.G.; Griffith, E.T. ); Sargeant, J. )

    1996-01-01

    The Rioni Basin in West Georgia is an Oligocene foredeep that evolved into a Miocene to Pliocene foreland basin, north of the Achara-Trialeti thrust belt and south of the Greater Caucasus. It extends to the west into the Black Sea. A large number of exploration wildcats have been drilled onshore since the nineteenth century and have led to the discovery of three fields. Exploration was prompted by seeps and restricted to frontal ramp anticlines mapped at surface. No wells have been drilled offshore. Supsa (discovered 1889) contains 29 MMbbl oil in clastic Sarmatian reservoirs. The field has around 50 wells but less than 0.5 MMbbl have been produced. Shromisubani (discovered 1973) contains oil within Maeotian and Pontian clastic reservoirs, Chaladidi oil within Upper Cretaceous chalk. Despite this long and apparently intensive exploration effort, several factors make the basin an exciting target for field redevelopment and further exploration. The quality of existing seismic is very poor both on-and offshore. Reinterpretation of the structure of the fold and thrust belt has suggested the presence of new targets and plays which may be imaged by modern seismic methods. In addition, due to problems associated with central planning, discovered fields have not been optimally developed or even fully appraised. The application of new technology, geological interpretation and investment promises to delineate substantial remaining reserves even after more than one hundred years of exploration.

  19. Oil fields and new plays in the Rioni foreland basin, Republic of Georgia

    SciTech Connect

    Robinson, A.G.; Griffith, E.T.; Sargeant, J.

    1996-12-31

    The Rioni Basin in West Georgia is an Oligocene foredeep that evolved into a Miocene to Pliocene foreland basin, north of the Achara-Trialeti thrust belt and south of the Greater Caucasus. It extends to the west into the Black Sea. A large number of exploration wildcats have been drilled onshore since the nineteenth century and have led to the discovery of three fields. Exploration was prompted by seeps and restricted to frontal ramp anticlines mapped at surface. No wells have been drilled offshore. Supsa (discovered 1889) contains 29 MMbbl oil in clastic Sarmatian reservoirs. The field has around 50 wells but less than 0.5 MMbbl have been produced. Shromisubani (discovered 1973) contains oil within Maeotian and Pontian clastic reservoirs, Chaladidi oil within Upper Cretaceous chalk. Despite this long and apparently intensive exploration effort, several factors make the basin an exciting target for field redevelopment and further exploration. The quality of existing seismic is very poor both on-and offshore. Reinterpretation of the structure of the fold and thrust belt has suggested the presence of new targets and plays which may be imaged by modern seismic methods. In addition, due to problems associated with central planning, discovered fields have not been optimally developed or even fully appraised. The application of new technology, geological interpretation and investment promises to delineate substantial remaining reserves even after more than one hundred years of exploration.

  20. 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

  1. Interpretation of the magnetic anomaly over the Omaha Oil Field, Gallatin County, Illinois

    SciTech Connect

    Sparlin, M.A. ); Lewis, R.D. . Waterways Experiment Station)

    1994-07-01

    A 40 nanoTesla (nT) magnetic anomaly identified in an aeromagnetic survey over southern Illinois contours as a localized magnetic high on the west flank of a regional magnetic low. This magnetic anomaly is generally coincident with the Omaha Oil Field in northwest Gallatin County, Illinois. It was initially assumed that cultural sources of steel associated with this oil field were the primary source of the magnetic feature; however, similar oil fields overflown by the survey do not exhibit magnetic anomalies in the data set. The Luther Rister et ux [number sign]1 well, drilled near the apex of the Omaha structural dome, encountered two zones of ultramafic intrusive rock containing 9.0% by volume magnetite. These intrusives were identified to be alnoeites which are a class of mantle-derived ultramafic rock that can be associated with the incipient stages of crustal rifting. A ground magnetic survey verified the presence of the anomaly, and provided detailed data for 3-D modeling of the source. Petrophysical evaluations, magnetic susceptibility measurements and thin section modal analysis were made on drill cuttings from the ultramafic intrusives encountered in the Luther Rister [number sign]1 well. These measurements were made to constrain the 3-D magnetic modeling by the petrophysical characteristics of the source. After removal of the regional magnetic field, the resulting 140 nT residual magnetic anomaly was successfully modeled using two ultramafic sills with an igneous feeder plug. The two igneous sills adequately account for the structural closure exhibited in the Omaha Oil Field and raise the interesting possibility of other hydrocarbon trapping structures generated by intrusives emplaced into the sedimentary section.

  2. Evaluating GIS for establishing and monitoring environmental conditions of oil fields

    SciTech Connect

    Pfeil, R.W.; Ellis, J.W.

    1995-04-01

    Good management of an oil field and compliance with ever-increasing environmental regulations is enhanced by technologies that improve a company`s understanding of field/production facilities and environmental conditions that have occurred to both through time. In Nigeria, Kazakhstan, Indonesia, and offshore Cabinda, remote sensing, computer-aided drafting (CAD) and Global Positioning System (GPF) technologies have effectively been used by Chevron to provide accurate maps of facilities and to better understand environmental conditions. Together these proven technologies have provided a solid and cost-effective base for planning field operation, verifying well and seismic locations, and locating sampling sites. The end product of these technologies is often locations, and locating sampling sites. The end product of these technologies is often cartographic-quality hardcopy images and maps for use in the office and field. Chevron has been evaluating the capability of Geographical Information System (GIS) technology to integrate images, maps, and tabular data into a useful database that can help managers and workers better evaluate conditions in an oil field, plan new facilities, and monitor/predict trends (for example, of air emissions, groundwater, soil chemistry, subsidence, etc.). Remote sensing, CAD (if formatted properly), and GPS data can be integrated to establish the spatial or cartographic base of the GIS. A major obstacle to establishing a sophisticated GIS for an overseas operation is the initial cost of data collection and conversion from legacy data base management systems and hardcopy to appropriate digital format. However, Chevron routinely uses GIS for oil spill modeling and is now using GIS in the field for integrating GPS data with field observations and programs.

  3. 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.

  4. Truncated shifted pareto distribution in assessing size distribution of oil and gas fields

    SciTech Connect

    Houghton, J.C.

    1988-11-01

    The truncated shifted Pareto (TSP) distribution, a variant of the two-parameter Pareto distribution, in which one parameter is added to shift the distribution right and left and the right-hand side is truncated, is used to model size distributions of oil and gas fields for resource assessment. Assumptions about limits to the left-hand and right-hand side reduce the number of parameters to two. The TSP distribution has advantages over the more customary lognormal distribution because it has a simple analytic expression, allowing exact computation of several statistics of interest, has a J-shape, and has more flexibility in the thickness of the right-hand tail. Oil field sizes from the Minnelusa play in the Powder River Basin, Wyoming and Montana, are used as a case study. Probability plotting procedures allow easy visualization of the fit and help the assessment.

  5. Use of the truncated shifted Pareto distribution in assessing size distribution of oil and gas fields

    USGS Publications Warehouse

    Houghton, J.C.

    1988-01-01

    The truncated shifted Pareto (TSP) distribution, a variant of the two-parameter Pareto distribution, in which one parameter is added to shift the distribution right and left and the right-hand side is truncated, is used to model size distributions of oil and gas fields for resource assessment. Assumptions about limits to the left-hand and right-hand side reduce the number of parameters to two. The TSP distribution has advantages over the more customary lognormal distribution because it has a simple analytic expression, allowing exact computation of several statistics of interest, has a "J-shape," and has more flexibility in the thickness of the right-hand tail. Oil field sizes from the Minnelusa play in the Powder River Basin, Wyoming and Montana, are used as a case study. Probability plotting procedures allow easy visualization of the fit and help the assessment. ?? 1988 International Association for Mathematical Geology.

  6. Bohai Oil corporation conceptual engineering of overall development scheme for SZ 36-1 oil field. Final report. Export trade information

    SciTech Connect

    Not Available

    1992-10-01

    SZ 36-1 oil field is located in the Liaodong Bay in the northeastern section of Bohai Bay, in approximately 32 meters water depth, 46 kilometers offshore the Suizhong Coast. The reservoir is highly heterogeneous and unconsolidated, and the crude has high viscosity, high specific gravity, and requires artificial lift for production. A phased development of the field is planned. The U.S. Trade and Development Program (TDP) contracted for engineering services to perform conceptual engineering of the overall development scheme for the SZ 36-1 oil field. The study consisted of two parts: (1) concept selection, to assess various schemes for developing the SZ 36-1 field and selecting one to recommend to the Bohai oil corporation (BOC); (2) conceptual engineering of the recommended development concept. The final report covers both the concept selection and concept engineering phases of the study.

  7. Applications of advanced petroleum production technology and water alternating gas injection for enhanced oil recovery - Mattoon Oil Field, Illinois. Final report

    SciTech Connect

    Baroni, M.

    1995-09-01

    Phase I results of a C0{sub 2}-assisted oil recovery demonstration project in selected Cypress Sandstone reservoirs at Mattoon Field, Illinois are reported. The design and scope of this project included C0{sub 2} injectvity testing in the Pinnell and Sawyer units, well stimulaton treatments with C0{sub 2} in the Strong unit and infill well drilling, completion and oil production. The field activities were supported by extensive C0{sub 2}-oil-water coreflood experiments, CO{sub 2} oil-phase interaction experiments, and integrated geologic modeling and reservoir simulations. The progress of the project was made public through presentations at an industry meeting and a DOEs contractors` symposium, through quarterly reports and one-to-one consultations with interested operators. Phase II of this project was not implemented. It would have been a water-alternating-gas (WAG) project of longer duration.

  8. 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.

  9. 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

  10. Transformation of iron sulfide to greigite by nitrite produced by oil field bacteria.

    PubMed

    Lin, Shiping; Krause, Federico; Voordouw, Gerrit

    2009-05-01

    Nitrate, injected into oil fields, can oxidize sulfide formed by sulfate-reducing bacteria (SRB) through the action of nitrate-reducing sulfide-oxidizing bacteria (NR-SOB). When reservoir rock contains siderite (FeCO(3)), the sulfide formed is immobilized as iron sulfide minerals, e.g. mackinawite (FeS). The aim of our study was to determine the extent to which oil field NR-SOB can oxidize or transform FeS. Because no NR-SOB capable of growth with FeS were isolated, the well-characterized oil field isolate Sulfurimonas sp. strain CVO was used. When strain CVO was presented with a mixture of chemically formed FeS and dissolved sulfide (HS(-)), it only oxidized the HS(-). The FeS remained acid soluble and non-magnetic indicating that it was not transformed. In contrast, when the FeS was formed by adding FeCl(2) to a culture of SRB which gradually produced sulfide, precipitating FeS, and to which strain CVO and nitrate were subsequently added, transformation of the FeS to a magnetic, less acid-soluble form was observed. X-ray diffraction and energy-dispersive spectrometry indicated the transformed mineral to be greigite (Fe(3)S(4)). Addition of nitrite to cultures of SRB, containing microbially formed FeS, was similarly effective. Nitrite reacts chemically with HS(-) to form polysulfide and sulfur (S(0)), which then transforms SRB-formed FeS to greigite, possibly via a sulfur addition pathway (3FeS + S(0) --> Fe(3)S(4)). Further chemical transformation to pyrite (FeS(2)) is expected at higher temperatures (>60 degrees C). Hence, nitrate injection into oil fields may lead to NR-SOB-mediated and chemical mineral transformations, increasing the sulfide-binding capacity of reservoir rock. Because of mineral volume decreases, these transformations may also increase reservoir injectivity. PMID:19290520

  11. Short chain aliphatic acid anions in oil field waters and their contribution to the measured alkalinity

    USGS Publications Warehouse

    Willey, L.M.; Kharaka, Y.K.; Presser, T.S.; Rapp, J.B.; Barnes, I.

    1975-01-01

    High alkalinity values found in some formation waters from Kettleman North Dome oil field are due chiefly to acetate and propionate ions, with some contribution from higher molecular weight organic acid ions. Some of these waters contain no detectable bicarbonate alkalinity. For waters such as these, high supersaturation with respect to calcite will be incorrectly indicated by thermodynamic calculations based upon carbonate concentrations inferred from traditional alkalinity measurements. ?? 1975.

  12. Static Electric Field Mapping Using a Mosquito Racket and Baby Oil

    ERIC Educational Resources Information Center

    Rediansyah, Herfien; Khairurrijal; Viridi, Sparisoma

    2015-01-01

    The aim of this research was to design a simple experimental device to see electric field force lines using common components which are readily available in everyday life. A solution of baby oil was placed in a plastic container, 4.5 × 4.5 × 1 inches, with both ends of the electrodes (metal wire) immersed in the solution at a depth of 0.2 inches.…

  13. Estimated human health risks of disposing of nonhazardous oil field waste in salt caverns

    SciTech Connect

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

    1997-09-01

    Argonne National Laboratory (ANL) has completed an evaluation of the possibility that adverse human health effects (carcinogenic and noncarcinogenic) could result from exposure to contaminants released from nonhazardous oil field wastes (NOW) disposed in domal salt caverns. In this assessment, several steps were used to evaluate potential human health risks: identifying potential contaminants of concern, determining how humans could be exposed to these contaminants, assessing the contaminants` toxicities, estimating contaminant intakes, and, finally, calculating human cancer and noncancer risks.

  14. 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.

  15. Disposal of NORM-contaminated oil field wastes in Salt Caverns.

    SciTech Connect

    Veil, J. A.; Smith, K. P.; Tomasko, D.; Elcock, D.; Blunt, D.; Williams, G. P.

    1998-08-28

    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

  16. 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.

  17. Depositional environments of Upper Triassic sandstones, El Borma oil field, southwestern Tunisia

    SciTech Connect

    Bentahar, H.; Ethridge, F.G. )

    1991-03-01

    El Borma oil field in southwestern Tunisia is located on the Algerian border and produces from five Upper Triassic sandstone reservoirs at depths ranging from 2,300 to 2,400 m. The 250 km{sup 2} field has recoverable reserves of 770 mm bbl of equivalent oil. Reservoir sandstones rest unconformably on south-dipping Lower Devonian clastic deposits. Silurian shale represents the major oil source rock and the field is capped by 550 m of shale, carbonate, and evaporite. Hercynian, topography below the reservoir sandstones comprises an 18 km wide, northeast-oriented paleovalley. Each of the four lower reservoir sandstones, bounded by a lower scour surface and a basal lag deposit, is commonly discontinuous and separated by lenticular shale beds. These 5 to 15 m thick sandstones display in channels flowing to the northeast. The overlying 12 m thick transgressive marine dolomitic shale contains carbonized bivalves and is capped by a paleosoil with root structures and siderite cement indicating subaerial exposure. The clay-rich and locally bioturbated uppermost reservoir sandstone was probably deposited in a tidally influenced estuary. Overall, the Upper Triassic reservoirs at El Borma consists of valley-fill estuary deposits that were formed during transgression of the sea from the northeast.

  18. 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.

  19. Distribution and origin of groundwater methane in the Wattenberg oil and gas field of northern Colorado.

    PubMed

    Li, Huishu; Carlson, Kenneth H

    2014-01-01

    Public concerns over potential environmental contamination associated with oil and gas well drilling and fracturing in the Wattenberg field in northeast Colorado are increasing. One of the issues of concern is the migration of oil, gas, or produced water to a groundwater aquifer resulting in contamination of drinking water. Since methane is the major component of natural gas and it can be dissolved and transported with groundwater, stray gas in aquifers has elicited attention. The initial step toward understanding the environmental impacts of oil and gas activities, such as well drilling and fracturing, is to determine the occurrence, where it is and where it came from. In this study, groundwater methane data that has been collected in response to a relatively new regulation in Colorado is analyzed. Dissolved methane was detected in 78% of groundwater wells with an average concentration of 4.0 mg/L and a range of 0-37.1 mg/L. Greater than 95% of the methane found in groundwater wells was classified as having a microbial origin, and there was minimal overlap between the C and H isotopic characterization of the produced gas and dissolved methane measured in the aquifer. Neither density of oil/gas wells nor distance to oil/gas wells had a significant impact on methane concentration suggesting other important factors were influencing methane generation and distribution. Thermogenic methane was detected in two aquifer wells indicating a potential contamination pathway from the producing formation, but microbial-origin gas was by far the predominant source of dissolved methane in the Wattenberg field. PMID:24456231

  20. Significant role of structural fractures in Ren-Qiu buried-block oil field, eastern China

    SciTech Connect

    Fei, Q.; Xie-Pei, W.

    1983-03-01

    Ren-qui oil field is in a buried block of Sinian (upper Proterozoic) rocks located in the Ji-zhong depression of the western Bohai Bay basin in eastern China. The main reservoir consists of Sinian dolomite rocks. It is a fault block with a large growth fault on the west side which trends north-northeast with throws of up to 1 km (0.6 mi) or more. The source rocks for the oil are Paleogene age and overlie the Sinian dolomite rocks. The structural fractures are the main factor forming the reservoir of the buried-block oil field. Three structural lines, trending northeast, north-northeast, and northwest, form the regional netted fracture system. The north-northeast growth fault controlled the structural development of the buried block. The block was raised and eroded before the Tertiary sediments were deposited. In the Eocene Epoch, the Ji-zhong depression subsided, but the deposition, faulting, and related uplift of the block happened synchronously as the block was gradually submerged. At the same time, several horizontal and vertical karst zones were formed by the karst water along the netted structural fractures. The Eocene oil source rocks lapped onto the block and so the buried block, with many developed karst fractures, was surrounded by a great thickness of source rocks. As the growth fault developed, the height of the block was increased from 400 m (1300 ft) before the Oligocene to 1300 m (4250 ft) after. As the petroleum was generated, it migrated immediately into the karst fractures of the buried block along the growth fault. The karst-fractured block reservoir has an 800-m (2600-ft) high oil-bearing closure and good connections developed between the karst fractures.

  1. 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.

  2. Missa Keswal oil field Potwar, Pakistan, a failure turned into success

    SciTech Connect

    Zaman, A.S.H.; Zahidi, S.A.

    1996-12-31

    Missa Keswal oil and gas field is located 70 kms. SSE of Islamabad in the eastern part of Potwar basin. On surface, it is a thrust bounded anticline striking in SW-NE direction. First seismic work was carried out in 1980, followed by drilling of an unsuccessful well. Another well was drilled after an improved seismic programme which resulted in discovery of oil and gas in seven different reservoir units of Cambrian, Permian, Paleocene, Eocene and Miocene age. Among these, three reservoir units namely Jutana, Baganwala and Kussak of Cambarian age had never produced in the Potwar basin earlier. The field had original, in place, proven reserves of 37.650 MMSTB of oil and 27.900 BSCF of gas. Current production from three wells is around 4500 barrels of oil and 7.3 MMSCFD of gas a day. This production comes from fractured limestone and porous sandstone rocks. It is an exploration case history, making a comparison between old and new seismic work. Low density of seismic profiles, inaccurate acquisition and processing parameters and lack of local interpretation experience contributed to earlier failures. Interpretation of new seismic data reveals that strata of platform sequence display a duplex geometry overlain by a passive roof complex of Siwaliks sequence as against earlier interpretation of a pop up structure. Closed area at Eocene level is 30 sq. kms., structure is bounded by a main thrust fault in the strike direction. Few orthognal faults exist which may provide lateral barriers to the flow during production. Probably upward migration of oil from the underthrusted block of the duplex has contributed to the occurrence of a multi-reservoir system in the upper block.

  3. 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.

  4. 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.

  5. 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

  6. 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

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

    SciTech Connect

    Scott Hara

    2002-01-31

    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.

  8. A new reserve growth model for United States oil and gas fields

    USGS Publications Warehouse

    Verma, M.K.

    2005-01-01

    Reserve (or field) growth, which is an appreciation of total ultimate reserves through time, is a well-recognized phenomenon, particularly in mature petroleum provinces. The importance of forecasting reserve growth accurately in a mature petroleum province made it necessary to develop improved growth functions, and a critical review of the original Arrington method was undertaken. During a five-year (1992-1996), the original Arrington method gave 1.03% higher than the actual oil reserve growth, whereas the proposed modified method gave a value within 0.3% of the actual growth, and therefore it was accepted for the development for reserve growth models. During a five-year (1992-1996), the USGS 1995 National Assessment gave 39.3% higher oil and 33.6% lower gas than the actual growths, whereas the new model based on Modified Arrington method gave 11.9% higher oil and 29.8% lower gas than the actual growths. The new models forecast predict reserve growths of 4.2 billion barrels of oil (2.7%) and 30.2 trillion cubic feet of gas (5.4%) for the conterminous U.S. for the next five years (1997-2001). ?? 2005 International Association for Mathematical Geology.

  9. 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.

  10. Methanotrophy in a Paleoproterozoic oil field ecosystem, Zaonega Formation, Karelia, Russia.

    PubMed

    Qu, Y; Crne, A E; Lepland, A; van Zuilen, M A

    2012-11-01

    Organic carbon rich rocks in the c. 2.0 Ga Zaonega Formation (ZF), Karelia, Russia, preserve isotopic characteristics of a Paleoproterozoic ecosystem and record some of the oldest known oil generation and migration. Isotopic data derived from drill core material from the ZF show a shift in δ(13) C(org) from c. -25‰ in the lower part of the succession to c. -40‰ in the upper part. This stratigraphic shift is a primary feature and cannot be explained by oil migration, maturation effects, or metamorphic overprints. The shift toward (13) C-depleted organic matter (δ(13) C(org) < -25‰) broadly coincides with lithological evidence for the generation of oil and gas in the underlying sediments and seepage onto the sea floor. We propose that the availability of thermogenic CH(4) triggered the activity of methanotrophic organisms, resulting in the production of anomalously (13) C-depleted biomass. The stratigraphic shift in δ(13) C(org) records the change from CO(2) -fixing autotrophic biomass to biomass containing a significant contribution from methanotrophy. It has been suggested recently that this shift in δ(13) C(org) reflects global forcing and progressive oxidation of the Earth. However, the lithologic indication for local thermogenic CH(4) , sourced within the oil field, is consistent with basinal methanotrophy. This indicates that regional/basinal processes can also explain the δ(13) C(org) negative isotopic shift observed in the ZF. PMID:23009699

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

    SciTech Connect

    Krylov, N.A. ); Avrov, V.P. ); 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.

  12. 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.

  13. 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.

  14. 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

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

    SciTech Connect

    Parkinson, W. J. ,; Smith, R. E.; Mortensen, F. N.; Wantuck, P. J.; Ross, Timothy J.; Jamshidi, Mohammad; Miller, N.

    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

  16. Geologic Sequestration of CO2 in a Depleted Oil Reservoir: A Field Demonstration

    NASA Astrophysics Data System (ADS)

    Westrich, H. R.; Zhang, D.; Grigg, R. B.

    2002-12-01

    Carbon dioxide (CO2) sequestration in geologic formations is the most direct carbon management strategy for long-term removal of anthropogenic CO2 from the atmosphere, and is likely to be needed for continuation of the US fossil fuel-based economy and high standard of living. Subsurface injection of CO2 into depleted oil reservoirs is a carbon sequestration strategy that might prove to be both cost effective and environmentally safe. However, there are significant R&D gaps that need to be addressed prior to sequestration of CO2 in depleted oil reservoirs, including the need of coupled physicochemical processes involving CO2, water, oil and reservoir rock, better estimates of the capacity of reservoir for long-term sequestration and ultimate fate of injected CO2, and improved geophysical monitoring technologies for accurately determining the presence and location of injected CO2. Our project is part of the DOE Carbon Sequestration program and it is directed at predicting and monitoring the migration and ultimate fate of CO2 after injection in a depleted oil reservoir. We utilize computer simulations of multiphase oil-brine-CO2 flow in the reservoir, laboratory measurements of geochemical brine-rock reactions, and geophysical surveys to monitor CO2 plume migration after injection. A principal component of this project is characterization and validation of predicted CO2 migration and fate through a field demonstration experiment. The reservoir under investigation is part of the West Pearl Queen field in southeastern New Mexico. Geologic modeling and numerical flow simulations (ECLIPSE code) have been used to study the feasibility of injection, and these techniques were used to help in designing geophysical monitoring studies to track the injected plume. Long-term static brine-rock reactions and short-term brine-CO2-oil flow through tests were performed to better understand the likely geochemical reactions that might be influence CO2 sequestration or injection. Results

  17. 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.

  18. 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.

  19. Groundwater compatibility with formation water and pay zone rocks in Pervomaysk oil-gas-condensate field to maintain formation pressure

    NASA Astrophysics Data System (ADS)

    Trifonov, N.; Nazarov, A.; Alekseev, S.

    2016-03-01

    The paper describes the research results in determining the compatibility of groundwater from Aptain-Albian-Cenomanian aquifer with formation water and pay zone rocks in U1 layer sediments, Pervomaysk oil field.

  20. Weathering of field-collected floating and stranded Macondo oils during and shortly after the Deepwater Horizon oil spill.

    PubMed

    Stout, Scott A; Payne, James R; Emsbo-Mattingly, Stephen D; Baker, Gregory

    2016-04-15

    Chemical analysis of large populations of floating (n=62) and stranded (n=1174) Macondo oils collected from the northern Gulf of Mexico sea surface and shorelines during or within seven weeks of the end of the Deepwater Horizon oil spill demonstrates the range, rates, and processes affecting surface oil weathering. Oil collected immediately upon reaching the sea surface had already lost most mass below n-C8 from dissolution of soluble aliphatics, monoaromatics, and naphthalenes during the oil's ascent with further reductions extending up to n-C13 due to the onset of evaporation. With additional time, weathering of the floating and stranded oils advanced with total PAH (TPAH50) depletions averaging 69±23% for floating oils and 94±3% for stranded oils caused by the combined effects of evaporation, dissolution, and photo-oxidation, the latter of which also reduced triaromatic steroid biomarkers. Biodegradation was not evident among the coalesced floating oils studied, but had commenced in some stranded oils. PMID:26936118

  1. 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

  2. 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

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

    SciTech Connect

    Kliger, J.A. )

    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.

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

    SciTech Connect

    Parkinson, W.J.; Smith, R.E.; Wantuck, P.J.; Miller, N.

    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.

  5. Reasons for production decline in the diatomite, Belridge oil field: a rock mechanics view

    SciTech Connect

    Strickland, F.G.

    1982-01-01

    This work summarized research conducted on diatomite cores from the Belridge oil field in Kern County. The study was undertaken to try to explain the rapid decline in oil production in diatomite wells. Characterization of the rock showed that the rock was composed principally of amorphous opaline silica diatoms with only a trace of crystoballite quartz or chert quartz. Physical properties tests showed the diatomite to be of low strength and plastic. Finally, it was established that long-term creep of diatomite into a propped fracture proceeds at a rate of approximately 6 x 10-5 in./day, a phenomenon which may be a primary cause of rapid production declines. The testing program also revealed a matrix stength for the formation of calculated 1325 PSI, a value to consider when depleting the reservoir. This also may help to explain the phase transformation of opal ct at calculated 2000 to 2500 ft depth.

  6. How to make a billion-barrel oil field in offshore California commercial

    SciTech Connect

    Patterson, J.C.; Ballard, J.H.

    1988-01-01

    The major obstacles and challenges involved in exploration and development of a giant deep-water low-gravity oil field are exemplified in the undeveloped Sword field of offshore southern California. In 1979, Conoco Exploration identified a northeast-southwest-trending basement high in the 800 to 2,000-ft deep federal waters 12 mi southwest of Pt. Conception at the western end of the Santa Barbara Channel. The intended reservoir was fractured Miocene Monterey chert, silicic shales/siltstones,m and dolomites that are draped over the axially faulted structure. Drilling of the initial well in OCS P-0322 in 1982 resulted in discovering the giant Sword field. A confirmation well drilled in OCS P-0320 indicates in-place reserves of well over 1 billion bbl. while the discovered potential is significant, the low gravity (8.5/sup 0/-10.5/sup 0/ API) of the oils discovered to data, along with water depths in excess of 1,500 ft, currently pose economic challenges to successful field development.

  7. 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

  8. Microbial diversity in methanogenic hydrocarbon-degrading enrichment cultures isolated from a water-flooded oil reservoir (Dagang oil field, China)

    NASA Astrophysics Data System (ADS)

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

    2015-04-01

    Microbial transformation of oil to methane is one of the main degradation processes taking place in oil reservoirs, and it has important consequences as it negatively affects the quality and economic value of the oil. Nevertheless, methane could constitute a recovery method of carbon from exhausted reservoirs. Previous studies combining geochemical and isotopic analysis with molecular methods showed evidence for in situ methanogenic oil degradation in the Dagang oil field, China (Jiménez et al., 2012). However, the main key microbial players and the underlying mechanisms are still relatively unknown. In order to better characterize these processes and identify the main microorganisms involved, laboratory biodegradation experiments under methanogenic conditions were performed. Microcosms were inoculated with production and injection waters from the reservoir, and oil or 13C-labelled single hydrocarbons (e.g. n-hexadecane or 2-methylnaphthalene) were added as sole substrates. Indigenous microbiota were able to extensively degrade oil within months, depleting most of the n-alkanes in 200 days, and producing methane at a rate of 76 ± 6 µmol day-1 g-1 oil added. They could also produce heavy methane from 13C-labeled 2-methylnaphthalene, suggesting that further methanogenesis may occur from the aromatic and polyaromatic fractions of Dagang reservoir fluids. Microbial communities from oil and 2-methyl-naphthalene enrichment cultures were slightly different. Although, in both cases Deltaproteobacteria, mainly belonging to Syntrophobacterales (e.g. Syntrophobacter, Smithella or Syntrophus) and Clostridia, mostly Clostridiales, were among the most represented taxa, Gammaproteobacteria could be only identified in oil-degrading cultures. The proportion of Chloroflexi, exclusively belonging to Anaerolineales (e.g. Leptolinea, Bellilinea) was considerably higher in 2-methyl-naphthalene degrading cultures. Archaeal communities consisted almost exclusively of representatives of

  9. 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.

  10. 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.

  11. 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.

  12. 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.

  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. Geology and habitat of oil in Ras Budran field, Gulf of Suez, Egypt

    SciTech Connect

    Chowdhary, L.R.; Taha, S.

    1987-05-01

    Deminex discovered the Ras Budran oil field in 1978. Discovery well EE 85-1 was drilled in about 140 ft of water, 4 km off the Sinai coast of the Gulf of Suez. Appraisal drilling (EE 85-2, 3, and 4 wells) confirmed the presence of a major field with an estimated 700 million bbl oil in place. The field, developed from three wellhead platforms, went on production in April 1983. To date, 20 development wells have been drilled. The Ras Budran structure at the deepest mappable seismic reflector, top Kareem (middle Miocene), is a broad northeast-southwest-trending anticlinal feature striking nearly at right angles to the main Gulf of Suez trend. At pre-Miocene producing horizons, the structure is complex and consists of a northeast-dipping flank (14-15) broken into several blocks by faults and limited to the south and west by major bounding faults. Oil is produced from three units of Nubian sandstone at a depth of 11,000 to 12,000 ft. The lower unit of Paleozoic age averages 10% porosity and up to 200 md in -situ permeability. The wells completed in this unit produce up to 2000 BOPD. In contrast, the sands of the upper two units of Lower Cretaceous age have a 15-20% porosity and up to 700 md permeability. The wells completed in these units produce 6000-8000 BOPD. The Ras Budran structure was primarily formed during the intra-Rudeis tectonic phase (lower Miocene). Migration of oil for accumulation in Ras Budran started late in the upper Miocene or Pliocene when the Santonian Brown Limestone and the Eocene Thebes Formation, the main source beds in the Gulf, reached the threshold of oil generation at a burial depth of about 10,000 ft (3000 m). At these depths, the organic matter in the source beds have a transformation ratio (0.10 to 0.15), increased yields of C15 + soluble organic matter and C15 + saturated hydrocarbons, a vitrinite reflectance of 0.62%, and a TTI value of 15.

  15. Detailed Study of Seismic Wave Attenuation in Carbonate Rocks: Application on Abu Dhabi Oil Fields

    NASA Astrophysics Data System (ADS)

    Bouchaala, F.; Ali, M. Y.; Matsushima, J.

    2015-12-01

    Seismic wave attenuation is a promising attribute for the petroleum exploration, thanks to its high sensitivity to physical properties of subsurface. It can be used to enhance the seismic imaging and improve the geophysical interpretation which is crucial for reservoir characterization. However getting an accurate attenuation profile is not an easy task, this is due to complex mechanism of this parameter, although that many studies were carried out to understand it. The degree of difficulty increases for the media composed of carbonate rocks, known to be highly heterogeneous and with complex lithology. That is why few attenuation studies were done successfully in carbonate rocks. The main objectives of this study are, Getting an accurate and high resolution attenuation profiles from several oil fields. The resolution is very important target for us, because many reservoirs in Abu Dhabi oil fields are tight.Separation between different modes of wave attenuation (scattering and intrinsic attenuations).Correlation between the attenuation profiles and other logs (Porosity, resistivity, oil saturation…), in order to establish a relationship which can be used to detect the reservoir properties from the attenuation profiles.Comparison of attenuation estimated from VSP and sonic waveforms. Provide spatial distribution of attenuation in Abu Dhabi oil fields.To reach these objectives we implemented a robust processing flow and new methodology to estimate the attenuation from the downgoing waves of the compressional VSP data and waveforms acquired from several wells drilled in Abu Dhabi. The subsurface geology of this area is primarily composed of carbonate rocks and it is known to be highly fractured which complicates more the situation, then we separated successfully the intrinsic attenuation from the scattering. The results show that the scattering is significant and cannot be ignored. We found also a very interesting correlation between the attenuation profiles and the

  16. 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

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

    SciTech Connect

    Scott Hara

    2000-12-06

    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

  18. Electrorheology of a zeolite/silicone oil suspension under dc fields

    NASA Astrophysics Data System (ADS)

    Tian, Yu; Meng, Yonggang; Wen, Shizhu

    2001-07-01

    The electrorheology of electrorheological (ER) fluids based on zeolite and silicone oil under dc fields was investigated at room temperature. ER fluids with volume fractions of 27% and 30% were prepared and tested. When a 5 kV/mm dc field was applied, shear yield stress of 26.7 kPa was obtained for the latter. The ER fluid with a higher volume fraction of zeolite had a higher current density and a higher shear yield stress under the same electric field. Compared with other ER fluids based on zeolite particles with low shear yield stress, the zeolite employed by us was found to have high dielectric constant and conductivity. The high permittivity mismatch and the high conductivity mismatch of the components of the fluids were considered responsible for the high shear yield stress.

  19. Disposal of NORM-contaminated oil field wastes in salt caverns -- Legality, technical feasibility, economics, and risk

    SciTech Connect

    Veil, J.A.; Smith, K.P.; Tomasko, D.; Elcock, D.; Blunt, D.; Williams, G.P.

    1998-07-01

    Some types of oil and gas production and processing wastes contain naturally occurring radioactive materials (NORM). If NORM is present at concentrations above regulatory levels in oil field waste, the waste requires special disposal practices. The existing disposal options for wastes containing NORM are limited and costly. This paper evaluates the legality, technical feasibility, economics, and human health risk of disposing of NORM-contaminated oil field wastes in salt caverns. Cavern disposal of NORM waste is technically feasible and poses a very low human health risk. From a legal perspective, there are no fatal flaws that would prevent a state regulatory agency from approaching cavern disposal of NORM. On the basis of the costs charged by caverns currently used for disposal of nonhazardous oil field waste (NOW), NORM waste disposal caverns could be cost competitive with existing NORM waste disposal methods when regulatory agencies approve the practice.

  20. Chemical comparison and acute toxicity of water accommodated fraction (WAF) of source and field collected Macondo oils from the Deepwater Horizon spill.

    PubMed

    Faksness, Liv-Guri; Altin, Dag; Nordtug, Trond; Daling, Per S; Hansen, Bjørn Henrik

    2015-02-15

    Two Source oils and five field collected oil residues from the Deepwater Horizon incident were chemically characterized. Water accommodated fractions (WAFs) of the Source oils and two of the field-weathered oils were prepared to evaluate the impact of natural weathering on the chemical composition and the acute toxicity of the WAFs. Toxicity test species representing different tropic levels were used (the primary producer Skeletonema costatum (algae) and the herbivorous copepod Acartia tonsa). The results suggest that the potential for acute toxicity is higher in WAFs from non-weathered oils than WAFs from the field weathered oils. The Source oils contained a large fraction of soluble and bioavailable components (such as BTEX (benzene, toluene, ethyl benzene, xylenes) and naphthalene), whereas in the surface collected oils these components were depleted by dissolution into the water column as the oil rose to the surface and by evaporative loss after reaching the sea surface. PMID:25534626

  1. 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.

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

    PubMed

    Gan, Wei; Frohlich, Cliff

    2013-11-19

    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

  3. 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

  4. Local and Global Impacts of Carbon Capture and Storage Combined with Enhanced Oil Recovery in Four Depleted Oil Fields, Kern County, California

    NASA Astrophysics Data System (ADS)

    Gillespie, J.; Jordan, P. D.; Goodell, J. A.; Harrington, K.; Jameson, S.

    2015-12-01

    Depleted oil reservoirs are attractive targets for geologic carbon storage (GCS) because they possess proven trapping mechanisms and large amounts of data pertaining to production and reservoir geometry. In addition, CO2 enhanced oil recovery (EOR) can improve recovery of the remaining oil at recovery factors of 6 to 20% of original oil in place in appropriate reservoirs. CO2 EOR increases the attractiveness of depleted oil and gas reservoirs as a starting point for CCS because the CO2 becomes a commodity that can be purchased by field operators for EOR purposes thereby offsetting the costs of CO2 capture at the power plant. In California, Kern County contains the largest oil reservoirs and produces 76% of California's oil. Most of the production at depths suitable for CCS combined with CO2 EOR comes from three reservoirs: the Vedder and Temblor formations and the Stevens Sandstone of the Monterey Formation. These formations were evaluated for GCS and CO2 EOR potential at the North and South Coles Levee (Stevens Sandstone), Greeley (Vedder) and McKittrick (Temblor) fields. CO2 EOR could be expected to produce an additional 150 million bbls of oil. The total storage space created by pre- and post-EOR fluid production for all three reservoirs is approximately 104 million metric tons (MMT). Large fixed sources in California produce 156 MMT/yr of CO2, and sources in Kern County produce 26 MMT/yr (WESTCARB, 2012). Therefore, the fields could store about four years of local large fixed source emissions and about two thirds of statewide emissions. However, from a global perspective, burning the additional oil produced by CO2 EOR would generate an additional 65 MMT of CO2 if not captured. This would result in a net reduction of greenhouse gas of only 39 MMT rather than the full 104 MMT. If the water produced along with the oil recovered during CO2 EOR operations is not reinjected into the reservoir, the storage space could be much higher.

  5. 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

  6. 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.

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

    PubMed

    Chen, Gang; Zhang, Min; Zhao, Jingrui; Zhou, Rui; Meng, Zuchao; Zhang, Jie

    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

  8. Streamer initiation and propagation in insulating oil in weakly non-uniform fields under impulse conditions

    SciTech Connect

    Badent, R.; Kist, K.; Schwab, A.J.

    1996-12-31

    This paper deals with the investigation of prebreakdown phenomenon in insulating oil in weakly non-uniform fields of rod-plane geometries with gaps up to 100 mm under impulse voltages of both polarities up to 700 kV. As with the point-plane configuration, the rod-plane geometry shows a decrease of the time to breakdown with increasing voltage rate-of-rise. At a specific rate, a significantly shorter breakdown time is observed both for positive and negative polarities. Beyond this discontinuity range breakdown time decreases again but with lower rates.

  9. Feasibility study of enhanced oil recovery for fields in decline. Export trade information (Final)

    SciTech Connect

    Not Available

    1991-08-01

    The report, generated by Scientific Software-Intercomp, Inc. for Yacimientos Petroliferos Fiscales Bolivianos, documents the results of a feasibility study which addressed the viability of developing petroleum areas in Bolivia. The primary objective of the project was to describe the reservoirs that have been discovered and their reserves, describe which would be the best alternatives for development of these reservoirs, and to determine the best alternatives for development of all the reserves together. The report, volume 4 of 4, concerns the feasibility of enhancing the oil or condensate recovery from a chosen group of fields (Yapacani, Humberto Suarez Roca, Vibora, La Pena, San Roque, and Camiri).

  10. 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.

  11. Pressure boosting technology recovers reserves in low pressure oil and gas fields

    SciTech Connect

    Sarshar, M.M.

    1999-01-01

    Fragmentation of reservoirs or production from different zones often results in oil or gas wells having different flowing wellhead pressures (FWHP). In many fields, the wells flow to a manifold, then the oil and gas is transported by pipeline to a processing plant. Production from the low-pressure (LP) wells is often restricted because of the backpressure imposed by the high-pressure (HP) wells or by the transportation pipeline. To minimize the production restrictions from LP wells, HP wells are usually choked down and their high energy is thus wasted through the choke. A team of engineers from CALTEC, the oil and gas division of BHR Group, have developed a system which harnesses the energy from HP wells to boost production from LP wells. The system is called WELLCOM, short for WELL COMmingling system. This patented system has won the 1998 British Royal Society Esso Energy award for an outstanding contribution to the advancement of science or engineering or technology that leads to a more efficient mobilization, conservation, or use of energy sources.

  12. The boomerang area: An example of oil and gas fields related to a transfer zone development

    SciTech Connect

    Specht, M.; Colletta, B.; Letouzey, J. ); Baby, P. ); Oller, J.; Montemuro, G. ); Guillier, B. )

    1993-02-01

    We present results of a study realized from petroleum data of Yacimientos Petroliferos Fiscales Bolivianos of the most important transfer zone of the Bolivian Andean belt: the Santa Cruz transfer zone. Frontal part of the Bolivian Andean belt consists of a thick series (6 to 8 km) of paleozoic to cenozoic sedimentary rocks thrusted eastwards on a sole thrust located in paleozoic series. The frontal part of the belt, globally N-S oriented, undergoes an important deviation East of Santa Cruz with a left lateral offset of 100 Km. Taking into account the E-W shortening direction, this transfer zone can be interpreted as a lateral ramp. The Santa Cruz transfer zone coincide with a set of small oil and gas fields whereas frontal structures lack hydrocarbon occurrences. We are then faced with a two-fold problem: (1) what is the origin of the transfer zone (2) why are the oil and gas concentrated in the transfer zone Our synthesis shows that the transfer zone is superimposed on the limit of a detached Paleozoic basin whose border direction is oblique to the regional shortening direction. We then interpret the oil and gas formation in two steps: (1) source rock maturation and hydrocarbon migration towards the top of the Paleozoic sedimentary wedge before Andean deformation. (2) hydrocarbon dismigration towards anticlinal structures developed during the lateral ramp propagation. In order to test our interpretation we performed a set of analog model experiments whose 3D visualization was analyzed by computerized X-ray tomography.

  13. 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.

  14. El Furrial oil field, Northeastern Venezuela: First giant in foreland fold and thrust belts of Western Hemisphere

    SciTech Connect

    Not Available

    1988-01-01

    The El Furrial giant oil field lies on the northern flank of the prolific Eastern Venezuela basin. Major tectonic elements of the region consist of a fold and thrust belt and a deep foreland basin, whose deformation is a product of right-oblique arc-continent collision. This mountain-front oil province displays parallel bands of thrusts and associated folds that extend over 150 mi and have relay trend patterns. The El Furrial structure is a long, doubly plunging anticline, flanked by imbricated, blind thrusts. Seismic data indicate vertical closure of about 3,000 ft over an area of 17,300 ac. The prospective section, of middle Tertiary to Late Cretaceous age, is mainly clastic, with an oil column of 1,800 ft. The interval of greater hydrocarbon potential is equated with shallow marine platform sandstones. Production tests reach sustained daily flow rates exceeding 9,500 bbl of 28/sup 0/API oil and 9,100 mcf of gas. Analysis of the oil suggests a marine Cretaceous source. Although in an early stage of development, the field is estimated to contain approximately 2 billion bbl of recoverable oil reserves. This places El Furrial in the forefront of the giant oil fields in the foreland fold and thrust belt provinces of the Western Hemisphere, second only to the supergiant accumulations of the Zagros zone in the Persian Gulf. The eastern Venezuela basin probably contains on the order of 2 trillion bbl of oil in place, making it the largest oil-bearing basin in the world. An ultimate recovery of 500 billion bbl is estimated. Therefore, the basin offers significant geologic scope for exploration for other giant fields.

  15. 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

  16. Commercial application of steamflooding in an oil field comprised of multiple thin-sand reservoirs

    SciTech Connect

    Powers, M.L.; Dosdon, C.J.; Ghassemi, F.; Moore, J.S.

    1984-09-01

    Steamfloods conducted in thin reservoirs generally provide marginal economics because of relatively high field development costs per barrel of oil-in-place and excessive heat losses from the productive zone. Techniques are being employed which include the utilization of induced horizontal fractures to circumvent these detriments attributed to thin zones, as well as the problems of steam distribution and confinement inherent in any steamflood. This paper documents the successful application of steamflooding in the multiple thin-sand reservoirs of the Loco Unit, Stephens County, Oklahoma. These reservoirs occur at depths from 50 ft (15 m) to 1,200 ft (366 m), and range in thickness up to 40 ft (12 m). Porosities of the productive zones vary from 20 percent to over 30 percent, and permeabilities range from 100 md to over 4,000 md. Oil gravities of the various zones range from 16 degrees to 24 degrees API. Reservoirs that occur at depths above approximately 700 ft (213 m) had little or no natural reservoir energy and generally contain viscous oils, ranging up to 10,000 cp. Consequently, there was no primary production from these reservoirs and potential for waterflooding was marginal. Steamflooding has been the only recovery process successfully applied to these zones, except for one isolated instance. Reservoirs of depths greater than 700 ft (213 m) normally contain lower viscosity oils. Six of these zones were produced by solution gas drive and were later successfully waterflooded. To date two of these six zones have been tested and have proven to support commercial steamflooding operations, after 23 years of waterflooding.

  17. Habitat of oil in the Lindsborg field, Salina basin, north-central Kansas

    SciTech Connect

    Newell, K.D. )

    1991-03-01

    The Lindsborg field was discovered in 1938, and is now 14 mi in length and 1-2 mi in width. It has a projected ultimate recovery of 16 MMBO. Three pay zones (5-20 ft thick) produce in the field. The Simpson pay zone (Middle Ordovician) is a well-rounded, quartzitic sandstone that is interpreted to be a paralic, high-energy shelf deposit. The Viola pay (Middle Ordovician) appears to be a dolomitic, lime grainstone but no cores are available to confirm this. The uppermost pay zone, the Upper Ordovician Maquoketa, is a finely laminated, vuggy, cherry dolomite interpreted to have been deposited as a subtidal lime mudstone in a restricted lagoon. The Simpson and Viola pays are structurally trapped in culminations along the crest of the Lindsborg anticline. Although the Maquoketa pay is structurally trapped with the other pay zones in the southern half of the field, its locus of production in the north half of the fields extends 100 ft vertically down the western flank of the anticline. The trapping mechanism is unclear due to lack of core control and modern logging suites, but it may be subtle updip diagenetic change from vuggy to nonvuggy dolomite. The Simpson and Maquoketa oils are geochemically distinct. Both may reflect efficient local source-to-reservoir migration from originally rich but marginally mature Ordovician and Devonian shales that contact each pay zone. If oil in the Lindsborg field is locally generated, the prospectivity of the relatively unproductive and underexplored Salina basin may be enhanced.

  18. Bacterial Community Features Are Shaped by Geographic Location, Physicochemical Properties, and Oil Contamination of Soil in Main Oil Fields of China.

    PubMed

    Liao, Jingqiu; Wang, Jie; Huang, Yi

    2015-08-01

    Geographic location and physicochemical properties are thought to represent major factors that shape soil bacterial community abundance and diversity. Crude oil contamination is becoming a notable concern with respect to soil property variation; however, the quantifiable influences of geographic location, physicochemical properties, and oil contamination are still poorly understood. In this study, the 16S ribosomal RNA genes of bacteria in the four oil fields in China were analyzed by using pyrosequencing. Results showed that physicochemical properties were the most dominant factor of bacterial community distribution, followed by geographical location. Oil contamination was a driving factor whose indirect influence was stronger than its direct influence. Under the impact of these three factors, different oil fields presented diversified and distinguishable bacterial community features. The soil of sites with the highest total petroleum hydrocarbon content (HB), nitrogen content (DQ), and phosphorus content (XJ) contained the largest proportion of functional groups participating in hydrocarbon degradation, nitrogen turnover, and phosphorus turnover, respectively. The first dominant phylum of the site with loam soil texture (HB) was Actinobacteria instead of Proteobacteria in other sites with sandy or sandy loam soil texture (DQ, SL, XJ). The site with the highest salinization and alkalization (SL) exhibited the largest proportion of unique local bacteria. The site that was located in the desert with extremely low precipitation (XJ) had the most diversified bacteria distribution. The bacterial community diversity was strongly influenced by soil physicochemical properties. PMID:25676171

  19. Activity, distribution, and abundance of methane-oxidizing bacteria in the near surface soils of onshore oil and gas fields.

    PubMed

    Xu, Kewei; Tang, Yuping; Ren, Chun; Zhao, Kebin; Wang, Wanmeng; Sun, Yongge

    2013-09-01

    Methane-oxidizing bacteria (MOB) have long been used as an important biological indicator for oil and gas prospecting, but the ecological characteristics of MOB in hydrocarbon microseep systems are still poorly understood. In this study, the activity, distribution, and abundance of aerobic methanotrophic communities in the surface soils underlying an oil and gas field were investigated using biogeochemical and molecular ecological techniques. Measurements of potential methane oxidation rates and pmoA gene copy numbers showed that soils inside an oil and gas field are hot spots of methane oxidation and MOB abundance. Correspondingly, terminal restriction fragment length polymorphism analyses in combination with cloning and sequencing of pmoA genes also revealed considerable differences in the methanotrophic community composition between oil and gas fields and the surrounding soils. Principal component analysis ordination furthermore indicated a coincidence between elevated CH4 oxidation activity and the methanotrophic community structure with type I methanotrophic Methylococcus and Methylobacter, in particular, as indicator species of oil and gas fields. Collectively, our results show that trace methane migrated from oil and gas reservoirs can considerably influence not only the quantity but also the structure of the methanotrophic community. PMID:23090054

  20. 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

  1. 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

  2. 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.

  3. 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.

  4. 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.

  5. Water-in-oil emulsification in a non-uniform alternating electric field

    NASA Astrophysics Data System (ADS)

    Choi, Suhwan; Saveliev, Alexei

    2015-11-01

    The emulsification of a water microdroplet placed in castor oil was performed using a non-uniform alternating electric field formed in the pin-to-plate geometry. A non-uniform electric field of ~40 kV/mm alternating with a frequency of 6.7 kHz was generated near the pin electrode. The applied frequency exceeded charge relaxation frequency of castor oil (0.3 Hz) and was below charge relaxation frequency of deionized water (7.8 kHz) used in the experiments. The emulsification process was captured with a CCD camera. The emulsification process started with entrainment of the water droplet in the high electric filed region near the pin electrode under the dielectrophoretic force. Upon touching the pin, the microdroplet was disintegrated in numerous channels and secondary droplets. The process continued by entrainment of secondary droplets and continuous size reduction. Three droplet breakup mechanisms were identified: drop elongation and capillary breakup, ac electrospraying of individual droplets, chain and bridge formation and decay. The quasi-steady narrow size distribution of emulsified water droplets with diameters close to 1 μm was formed after a few minutes. The generated emulsion was confined near the needle electrode due to the dielectrophoretic force. The emulsion had a well-defined boundary with a shape resembling a pendant drop suspended on the pin electrode.

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

    SciTech Connect

    Scott Hara

    2000-12-06

    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 Wilmington Field are economical with low oil prices due to the availability of inexpensive steam from an existing 50 MMBTU/hr steam generator that can utilize non-commercial low Btu produced gas. Such favorable terms for obtaining steam are not expected to be available in the future.

  7. Impact of an indigenous microbial enhanced oil recovery field trial on microbial community structure in a high pour-point oil reservoir.

    PubMed

    Zhang, Fan; She, Yue-Hui; Li, Hua-Min; Zhang, Xiao-Tao; Shu, Fu-Chang; Wang, Zheng-Liang; Yu, Long-Jiang; Hou, Du-Jie

    2012-08-01

    Based on preliminary investigation of microbial populations in a high pour-point oil reservoir, an indigenous microbial enhanced oil recovery (MEOR) field trial was carried out. The purpose of the study is to reveal the impact of the indigenous MEOR process on microbial community structure in the oil reservoir using 16Sr DNA clone library technique. The detailed monitoring results showed significant response of microbial communities during the field trial and large discrepancies of stimulated microorganisms in the laboratory and in the natural oil reservoir. More specifically, after nutrients injection, the original dominant populations of Petrobacter and Alishewanella in the production wells almost disappeared. The expected desirable population of Pseudomonas aeruginosa, determined by enrichment experiments in laboratory, was stimulated successfully in two wells of the five monitored wells. Unexpectedly, another potential population of Pseudomonas pseudoalcaligenes which were not detected in the enrichment culture in laboratory was stimulated in the other three monitored production wells. In this study, monitoring of microbial community displayed a comprehensive alteration of microbial populations during the field trial to remedy the deficiency of culture-dependent monitoring methods. The results would help to develop and apply more MEOR processes. PMID:22159733

  8. Environmental assessment. Downhole steam generator field test project DEEP STEAM: enhanced oil recovery project (DOE No. 16), Kern County, California

    SciTech Connect

    Church, H.W.; Zak, B.D.

    1980-02-01

    Objective of DEEP STEAM is to develop the technology to economically produce heavy oil from reservoirs greater than 760 m deep using steam injection. The proposed site is in the Kern River Oil Field in the San Joaquin Valley. This document describes the project, existing environment, and possible impact of the project. It is concluded that the proposed action does not significantly affect the quality of the environment, and therefore an environmental impact statement is not required. (DLC)

  9. Oil-material fractionation in Gulf deep water horizontal intrusion layer: Field data analysis with chemodynamic fate model for Macondo 252 oil spill.

    PubMed

    Melvin, A T; Thibodeaux, L J; Parsons, A R; Overton, E; Valsaraj, K T; Nandakumar, K

    2016-04-15

    Among the discoveries of the Deepwater Horizon blowout was the so-called "sub-surface plume"; herein termed the "oil-trapping layer". Hydrocarbons were found positioned at ~1100-1300m with thickness ~100-150m and moving horizontally to the SW in a vertically stratified layer at the junction of the cold abyssal water and the permanent thermocline. This study focuses on its formation process and fate of the hydrocarbons within. The originality of this work to the field is two-fold, first it provides a conceptual framework which places layer origin in the context of a horizontal "intrusion" from the near-field, vertical, blow-out plume and second, it offers a theoretical model for the hydrocarbon chemicals within the horizontal layer as it moves far-afield. The model quantifies the oil-material fractionation process for the soluble and fine particle. The classical Box model, retrofitted with an internal gradient, the "G-Box", allows an approach that includes turbulent eddy diffusion coupled with droplet rise velocity and reactive decay to produce a simple, explicit, transparent, algebraic model with few parameters for the fate of the individual fractions. Computations show the soluble and smallest liquid droplets moving very slowly vertically through the layer appearing within the trapping layer at low concentration with high persistence. The larger droplets move-through this trapping zone quickly, attain high concentrations, and eventually form the sea surface slick. It impacts the field of oil spill engineering science by providing the conceptual idea and the algorithms for projecting the quantities and fractions of oil-material in a deep water, horizontal marine current being dispersed and moving far afield. In the field of oil spill modeling this work extends the current generation near-field plume source models to the far-field. The theory portrays the layer as an efficient oil-material trap. The model-forecasted concentration profiles for alkanes and aromatics

  10. 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

  11. 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

  12. 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.

  13. Potential CO2 Sequestration in Oil Field Reservoirs: Baseline Mineralogy and Natural Diagenesis, Kern County, California

    NASA Astrophysics Data System (ADS)

    Horton, R. A.; Kaess, A. B.; Nguyen, D. T.; Caffee, S. E.; Olabise, O. E.

    2015-12-01

    Depleted oil fields have been suggested as potential sites for sequestration of CO2 generated from the burning of hydrocarbons. However, to be effective for removing CO2 from the atmosphere, the injected CO2 must remain within the reservoir. The role of atmospheric CO2 in rock weathering is well known and a growing body of experimental work indicates that under reservoir conditions supercritical CO2 also reacts with sedimentary rocks. In order to predict the behavior of injected CO2 in a given reservoir, detailed knowledge of the mineralogy is required. In addition, post-injection monitoring may include analyzing core samples to examine interactions between reservoir rocks and the CO2. Thus, documentation of the natural diagenetic processes within the reservoir is necessary so that changes caused by reactions with CO2 can be recognized. Kern County, California has been a major petroleum producing area for over a century and has three oil fields that have been identified as potential sites for CO2 sequestration. Two of these, Rio Bravo-Greeley and McKittrick, have no previously published mineralogic studies. Samples from these (and nearby Wasco) oil fields were studied using transmitted-light petrography and scanning electron microscopy. At Rio Bravo-Greeley-Wasco, Kreyenhagen (Eocene) and Vedder (Oligocene) sandstones are mainly arkosic arenites with only small amounts of volcanic rock fragments. Detrital feldspars exhibit wide compositional ranges (up to Or75Ab25 & Ab50An50). Diagenesis has greatly altered the rocks. There are significant amounts of relatively pure authigenic K-feldspar and albite. Small amounts of authigenic quartz, calcite, dolomite, ankerite, kaolinite, illite/smectite, chlorite, zeolite, and pyrite are present. Plagioclase has been preferentially dissolved, with andesine more susceptible than oligoclase. Al3+ has been exported from the sandstones. At McKittrick, Temblor sandstones (Oligocene-Miocene) contain up to 33% volcanic rock fragments

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

    SciTech Connect

    Scott Hara

    2000-02-18

    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 1999, project work has been completed related to 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. Work is continuing on the stochastic geologic model, developing a 3-D stochastic thermal reservoir simulation model of the Fault Block IIA Tar (Tar II-A) Zone, and operational work and research studies to prevent thermal-related formation compaction. Thermal-related formation compaction is a concern of the project team due to observed surface subsidence in the local area above the steamflood project. Last quarter on January 12, 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. Seven water injection wells were placed in service in November and December 1998 on the flanks of the Phase 1 steamflood area to pressure up the reservoir to fill up the existing steam chest. Intensive reservoir engineering and geomechanics studies are continuing to determine the best ways to shut down the steamflood operations in Fault Block II while minimizing any future surface subsidence. The new 3-D deterministic thermal reservoir simulator model is being used to provide sensitivity cases to optimize production, steam injection, future flank cold water injection and reservoir temperature and pressure. According to the model, reservoir fill up of the steam chest at the current injection rate of 28,000 BPD and gross

  15. 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

  16. Near-surface study at the Valhall oil field from ambient noise surface wave tomography

    NASA Astrophysics Data System (ADS)

    Mordret, A.; Landès, M.; Shapiro, N. M.; Singh, S. C.; Roux, P.; Barkved, O. I.

    2013-06-01

    We used 6 hr of continuous seismic noise records from 2320 four-component sensors of the Valhall `Life of Field Seismic' network to compute cross-correlations (CCs) of ambient seismic noise. A beamforming analysis showed that at low frequencies (below 2 Hz) the seismic noise sources were spatially homogeneously distributed, whereas at higher frequencies (2-30 Hz), the dominant noise source was the oil platform at the centre of the network. Here, we performed an ambient noise surface wave tomography at frequencies below 2 Hz. We used vertical-component geophones CCs to extract and measure the Scholte waves group velocities dispersion curves that were then processed with a set of quality criteria and inverted to build group velocity maps of the Valhall area. Although Scholte wave group velocity depends on S wave, our group velocity maps show features similar to that was previously obtained from P-wave velocity full-waveform inversion of an active seismic data set. Since the dominant noise source at high frequency (above 3 Hz) was the oil platform, we determined a 2-D S-wave velocity model along a profile aligned with the platform by inverting group velocity dispersion curves of Love waves from transverse-component geophones CCs. We found that S-wave velocity down to 20 m was low and varied along the profile, and could be used to estimate S-wave static.

  17. Low-cost FPSO for service in the Zaafarana oil field

    SciTech Connect

    1997-04-01

    The Zaafarana oilfield development, operated by Zaafarana Oil Co. (Zafco) presented a series of unique challenges, including redeployment of an internal-turret mooring system, use of a turret-based electrical-cable jumper system, and permanent use of cable-deployed electric submersible pumps in the gravel-pack well completions. Following a detailed three-dimensional (3D) seismic program, the field was discovered by the first well in December 1990. Four subsequent appraisal wells were drilled. The discovery well and two of the appraisal wells tested oil at rates ranging from 2,000 to 10,100 B/D. Initial development plans called for the use of two conventional platforms with a pipeline to a shore-based treatment and storage terminal. Data acquired from subsequent wells were incorporated into the mapping and reserve estimates resulting in a sharp downgrade of the estimated recoverable reserves. The reduced estimate, combined with a revised pricing scenario, necessitated an amended development plan with significantly lower costs. A new plan that uses a floating production, storage, and offloading (FPSO) facility and a single drilling/wellhead platform, connected by a pipeline and by electrical and control umbilicals, was approved in October 1992.

  18. 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.

  19. 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.

  20. Refining Field Measurements of Methane Flux Rates from Abandoned Oil and Gas Wells

    NASA Astrophysics Data System (ADS)

    Lagron, C. S.; Kang, M.; Riqueros, N. S.; Jackson, R. B.

    2015-12-01

    Recent studies in Pennsylvania demonstrate the potential for significant methane emissions from abandoned oil and gas wells. A subset of tested wells was high emitting, with methane flux rates up to seven orders of magnitude greater than natural fluxes (up to 105 mg CH4/hour, or about 2.5LPM). These wells contribute disproportionately to the total methane emissions from abandoned oil and gas wells. The principles guiding the chamber design have been developed for lower flux rates, typically found in natural environments, and chamber design modifications may reduce uncertainty in flux rates associated with high-emitting wells. Kang et al. estimate errors of a factor of two in measured values based on previous studies. We conduct controlled releases of methane to refine error estimates and improve chamber design with a focus on high-emitters. Controlled releases of methane are conducted at 0.05 LPM, 0.50 LPM, 1.0 LPM, 2.0 LPM, 3.0 LPM, and 5.0 LPM, and at two chamber dimensions typically used in field measurements studies of abandoned wells. As most sources of error tabulated by Kang et al. tend to bias the results toward underreporting of methane emissions, a flux-targeted chamber design modification can reduce error margins and/or provide grounds for a potential upward revision of emission estimates.

  1. Reasons for production decline in the diatomite, Belridge oil field: a rock mechanics view

    SciTech Connect

    Strickland, F.G.

    1985-03-01

    This paper summarizes research conducted on diatomite cores from the Belridge oil field in Kern County, CA. The study was undertaken to explain the rapid decline in oil production in diatomite wells by investigating three of six possible reasons. Characterization of the rock indicated that the rock was composed of principally amorphous opaline silica diatoms with only a trace of crystoballite quartz or chert quartz. Physical properties tests showed the diatomite to be of very low strength and plastic. It was established that longterm creep of diatomite into a propped fracture proceeds at a rate of approximately 1.5 microns/D (1.5 ..mu..m/d), a phenomenon that may contribute to rapid production declines. Also revealed was a matrix strength for the formation of about 1,325 psi (9136 kPa), a critical value to consider when depleting the reservoir. This also may help to explain the phase transformation to Opal CT around 2,000to 2,500-ft (610- to 762-m) depth.

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

    SciTech Connect

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

    1994-08-01

    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 the use of average values for reservoir properties. The authors have developed the use of average values for calculating local and field-wide estimates, and have compared their results to published values. The study of the Lower Mississippian Big Injun sandstone reservoir in Rock Creek field, central West Virginia, used production data obtained from operators. Production for the first 10 yr was reconstructed, when necessary, by comparison to decline curves for 70 wells with complete production records. Similarly, curve fitting techniques were used to interpolate data for missing years. Cumulative production values for 667 producing wells were kriged over the extent of the field; the resulting grid was sampled to provide an estimate of cumulative production at each well location. Kriged estimates of pay thickness, porosity, and water saturation were used to calculate OOIP and recovery efficiency (cumulative production + OOIP), but not geographic distribution of these two parameters. An optimal radius of 270 ft gave recovery efficiencies ranging between 18.75% and 21.9%, comparing favorably with a published value of 22.3%. Summing the OOIP value for all producing wells in the field yields a value of 139.6 million bbl, significantly higher than the published value of 37.8 million bbl. The estimate reflects a more complete data set and revised values for reservoir parameters. Discussions with the principal operator in the field suggests that the higher figure is more correct.

  3. 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.

    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)

  4. 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

  5. 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.

  6. Chemical composition and structure of asphaltenes in crude oils from Azerbaidzhan offshore fields

    SciTech Connect

    Mir-Babaev, M.F.; Samedova, F.I.; Aliev, B.M.

    1986-11-01

    The authors present results from a study of the composition and structure of the asphaltenes recovered from crude oils produced in Azerbaidzhan offshore fields (Darwin Bank, 28 April, and Sangachaly-More). The original crudes that were used in these studies differ in depth of occurrence and type of enclosing rock, and hence in degree of catagenesis. The principal characteristics of the original crudes are listed. The Darwin Bank crude is low-wax, low-sulfur, and high-resin, and it does not contain any dissolved gas. The 28 April crude has the lowest density and sulfur content; in contrast to the Darwin Bank crude, it is low-resin and medium-wax. The Sangachaly-More crude is medium-resin, high-wax, and low-sulfur.

  7. Optimization of operation conditions for extracting lithium ions from calcium chloride-type oil field brine

    NASA Astrophysics Data System (ADS)

    Yang, Hong-jun; Li, Qing-hai; Li, Bing; Guo, Feng-qin; Meng, Qing-fen; Li, Wu

    2012-04-01

    Al(OH)3 was prepared to extract lithium ions from calcium chloride-type oil field brine. The influences of four factors, namely temperature, Al3+/Li+ molar ratio, OH-/Al3+ molar ratio, and contact time between Al(OH)3 and the brine, on the yield of lithium ions were investigated. It is found that their optimal values are 35°C, 4.5, 2.6, and 6 h, respectively. In the course of the experiment, the apparent pH value was observed. The results reveal that the apparent pH value has no remarkable influence on the yield of lithium ions. Meanwhile, the effects of the concentrations of calcium ions and magnesium ions in the brine on lithium recovery were studied. The results indicate that calcium ions have minor negative influence on the yield of lithium ions under optimal conditions, and magnesium ions slightly influence the yield of lithium ions.

  8. Turkey's largest oil field poised for CO/sub 2/ immiscible EOR project

    SciTech Connect

    Kantar, K.; Connor, T.E.

    1984-11-26

    The Bati Raman project uses some of the latest EOR technology to increase production from Turkey's largest oil field. Engineering for this challenging project has drawn upon the petroleum industry's recent experience in CO/sub 2/EOR, on laboratory testing, and on new applications of proven technology to meet the construction and operational requirements of the project facilities. Construction is now in progress and completion is scheduled for mid1985. The data obtained during operation of the facilities will be used to guide Turkish Petroleum Corp's continuing EOR program. It will also contribute to the petroleum industry's knowledge of carbon dioxide technology and the engineering community's ability to efficiently meet future EOR design challenges.

  9. 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. ); Jack, T.R. ); Westlake, W.S. )

    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.

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

    SciTech Connect

    Smith, R. E.; Parkinson, w; Miller, N.

    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

  11. Estimate of the risks of disposing nonhazardous oil field wastes into salt caverns

    SciTech Connect

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

    1997-12-31

    Argonne National Laboratory (ANL) has completed an evaluation of the possibility that adverse human health effects (carcinogenic and noncarcinogenic) could result from exposure to contaminants released from nonhazardous oil field wastes (NOW) disposed in domal salt caverns. Potential human health risks associated with hazardous substances (arsenic, benzene, cadmium, and chromium) in NOW were assessed under four postclosure cavern release scenarios: inadvertent cavern intrusion, failure of the cavern seal, failure of the cavern through cracks or leaky interbeds, and a partial collapse of the cavern roof. To estimate potential human health risks for these scenarios, contaminant concentrations at the receptor were calculated using a one-dimensional solution to an advection/dispersion equation that included first order degradation. Assuming a single, generic salt cavern and generic oil-field wastes, the best-estimate excess cancer risks ranged from 1.7 {times} 10{sup {minus}12} to 1.1 {times} 10{sup {minus}8} and hazard indices (referring to noncancer health effects) ranged from 7 {times} 10{sup {minus}9} to 7 {times} 10{sup {minus}4}. Under worse-case conditions in which the probability of cavern failure is 1.0, excess cancer risks ranged from 4.9 {times} 10{sup {minus}9} to 1.7 {times} 10{sup {minus}5} and hazard indices ranged from 7.0 {times} 10{sup {minus}4} to 0.07. Even under worst-case conditions, the risks are within the US Environmental Protection Agency (EPA) target range for acceptable exposure levels. From a human health risk perspective, salt caverns can, therefore, provide an acceptable disposal method for NOW.

  12. 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

  13. 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

  14. 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,...

  15. 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. ); Bereskin, S.R. ); 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.

  16. 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

  17. Establishment of an oil and gas database for increased recovery and characterization of oil and gas carbonate reservoir heterogeneity. Appendix 1, Volume 2

    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 plots, detailed core log, paragenetic sequence, and reservoir characterization sheet for the following fields in southwest Alabama: East Huxford oil field; Fanny Church oil field; Gin Creek oil field; Gulf Crest oil field; Hanberry Church oil field; Hatter`s Pond oil field; Healing Springs gas condensate field; Huxford oil field; Little Escambia Creek oil field; Little River oil field; Little Rock gas condensate field; Lovetts Creek oil field; Melvin oil field; Mill Creek oil field; Mineola oil field; Movico oil field; and North Choctaw Ridge oil field.

  18. 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 plots, detailed core log, paragenetic sequence, and reservoir characterization sheet for the following fields in southwest Alabama: East Huxford oil field; Fanny Church oil field; Gin Creek oil field; Gulf Crest oil field; Hanberry Church oil field; Hatter's Pond oil field; Healing Springs gas condensate field; Huxford oil field; Little Escambia Creek oil field; Little River oil field; Little Rock gas condensate field; Lovetts Creek oil field; Melvin oil field; Mill Creek oil field; Mineola oil field; Movico oil field; and North Choctaw Ridge oil field.

  19. Sedimentological sand grain orientation in oil-producing U1 layer Kazan oil-gas-condensate field (Tomsk Oblast)

    NASA Astrophysics Data System (ADS)

    Krasnoshchekova, L.; Cherdansteva, D.; Vologdina, I.

    2016-03-01

    The paper describes the results in identifying the prevalent directions of elongated quartz grains being the major oil-producing layer component in sand reservoirs. Studying the orientation of quartz to its grain shapes in paleogeographical oriented core samples made it possible to identify the hydrodynamic reservoir regimes and facies type. The spatial confinement of pore spaces and cataclasis fractures in grain material to the prevalent elongated quartz grain directions was defined.

  20. 77 FR 46640 - Hours of Service of Drivers of Commercial Motor Vehicles; Regulatory Guidance for Oil Field...

    Federal Register 2010, 2011, 2012, 2013, 2014

    2012-08-06

    ..., 2010 (75 FR 82133), or you may visit www.regulations.gov . ] Public Participation: The www.regulations... FR 33098). The regulatory guidance, effective June 5, 2012, was issued to ensure consistent... Motor Vehicles; Regulatory Guidance for Oil Field Exceptions AGENCY: Federal Motor Carrier...

  1. 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.

  2. 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.

  3. LABORATORY AND FIELD EVALUATION OF CRYSTALLIZED DOW 704 OIL ON THE PERFORMANCE OF THE PM2.5 WINS FRACTIONATOR

    EPA Science Inventory

    Subsequent to the PM2.5 FRM's 1997 promulgation, technicians at the CT Dept. of Env. Protection observed that the DOW 704 diffusion oil used in the method's WINS fractionator would occasionally crystallize during field use - particularly under wintertime conditions. While the f...

  4. Hydraulic Fracturing of 403 Shallow Diatomite Wells in South Belridge Oil Field, Kern County, California, in 2014

    NASA Astrophysics Data System (ADS)

    Wynne, D. B.; Agusiegbe, V.

    2015-12-01

    We examine all 403 Hydraulic Fracture (HF) jobs performed by Aera Energy, LLC, in the South Belridge oil field, Kern County, CA in 2014. HFs in the South Belridge oil field are atypical amongst North American plays because the reservoir is shallow and produced via vertical wells. Our data set constitutes 88% of all HF jobs performed in CA oil fields in calendar-2014. The South Belridge field produces 11% of California's oil and the shallow HFs performed here differ from most HFs performed elsewhere. We discuss fracture modeling and methods and summary statistics, and modelled dimensions of fractures and their relationships to depth and reservoir properties. The 403 HFs were made in the diatomite-dominated Reef Ridge member of the Monterey Formation. The HFs began at an average depth of 1047 feet below ground (ft TVD) and extended an average of 626 ft vertically downward. The deepest initiation of HF was at 2380 ft and the shallowest cessation was at 639 ft TVD. The average HF was performed using 1488 BBL (62,496 gallons) of water. The HFs were performed in no more than 6 stages and nearly all were completed within one day. We (1) compare metrics of the South Belridge sample group with recent, larger "all-CA" and nationwide samples; and (2) conclude that if relationships of reservoir properties, well completion and HF are well understood, shallow diatomite HF may be optimized to enhance production while minimizing environmental impact.

  5. 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

    ... Employment and Training Administration Wyatt VI, Inc., A Division of Wyatt Field Service Company, Working On-Site at Hovensa Oil Refinery, Christiansted, St. Croix, VI; Notice of Affirmative Determination... Adjustment Assistance (TAA) applicable to workers and former workers of Wyatt VI, Inc., a division of...

  6. 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 μm 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 μm, 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.

  7. 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.

  8. Environmental assessment of Buccaneer gas and oil field in the northwestern Gulf of Mexico, 1978-1979. Volume IV. Bacterial communities. Annual report

    SciTech Connect

    Sizemore, R.K.; Olsen, K.

    1980-12-01

    Bacterial numbers and taxonomic types were found to be the same in the oil field as in the control area. No difference in bacterial diversity or biomass was noted between stations but a change did occur between seasonal samples. Members of the genera Vibrio, Pseudomonas, Aeromonas and Acinetobacter were found to predominate in the sediment and fish samples. The bacterial population of the oil field sites contained more oil degrading and sulfur oxidizing bacteria than the control site.

  9. Microbial diversity and hydrocarbon degrading gene capacity of a crude oil field soil as determined by metagenomics analysis.

    PubMed

    Abbasian, Firouz; Palanisami, Thavamani; Megharaj, Mallavarapu; Naidu, Ravi; Lockington, Robin; Ramadass, Kavitha

    2016-05-01

    Soils contaminated with crude oil are rich sources of enzymes suitable for both degradation of hydrocarbons through bioremediation processes and improvement of crude oil during its refining steps. Due to the long term selection, crude oil fields are unique environments for the identification of microorganisms with the ability to produce these enzymes. In this metagenomic study, based on Hiseq Illumina sequencing of samples obtained from a crude oil field and analysis of data on MG-RAST, Actinomycetales (9.8%) were found to be the dominant microorganisms, followed by Rhizobiales (3.3%). Furthermore, several functional genes were found in this study, mostly belong to Actinobacteria (12.35%), which have a role in the metabolism of aliphatic and aromatic hydrocarbons (2.51%), desulfurization (0.03%), element shortage (5.6%), and resistance to heavy metals (1.1%). This information will be useful for assisting in the application of microorganisms in the removal of hydrocarbon contamination and/or for improving the quality of crude oil. © 2016 American Institute of Chemical Engineers Biotechnol. Prog., 32:638-648, 2016. PMID:26914145

  10. Source Mechanism, Stress Triggering, and Hazard Analysis of Induced Seismicity in Oil/Gas Fields in Oman and Kuwait

    NASA Astrophysics Data System (ADS)

    Gu, C.; Toksoz, M. N.; Ding, M.; Al-Enezi, A.; Al-Jeri, F.; Meng, C.

    2015-12-01

    Induced seismicity has drawn new attentions in both academia and industry in recent years as the increasing seismic activity in the regions of oil/gas fields due to fluid injection/extraction and hydraulic fracturing. Source mechanism and triggering stress 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. The induced seismic data in this study are from both Oman and Kuwait. For the Oman data, the induced seismicity is monitored by both surface network (0oil/gas field. The data used in the study consist of 800 events located by the surface network and 2000 events from the downhole network. For the Kuwait data a surface network is used to collect the local seismic data (0oil/gas fields from year 1999 to 2007 for Oman, and from year 2006 to 2015 for Kuwait. In addition, the local hazard corresponding to the induced seismicity in these oil/gas fields is assessed and compared to ground motion prediction due to large (M>5.0) regional tectonic earthquakes.

  11. Strontium isotopic signatures of oil-field waters: Applications for reservoir characterization

    USGS Publications Warehouse

    Barnaby, R.J.; Oetting, G.C.; Gao, G.

    2004-01-01

    The 87Sr/86Sr compositions of formation waters that were collected from 71 wells producing from a Pennsylvanian carbonate reservoir in New Mexico display a well-defined distribution, with radiogenic waters (up to 0.710129) at the updip western part of the reservoir, grading downdip to less radiogenic waters (as low as 0.708903 to the east. Salinity (2800-50,000 mg/L) displays a parallel trend; saline waters to the west pass downdip to brackish waters. Elemental and isotopic data indicate that the waters originated as meteoric precipitation and acquired their salinity and radiogenic 87Sr through dissolution of Upper Permian evaporites. These meteoric-derived waters descended, perhaps along deeply penetrating faults, driven by gravity and density, to depths of more than 7000 ft (2100 m). The 87 Sr/86Sr and salinity trends record influx of these waters along the western field margin and downdip flow across the field, consistent with the strong water drive, potentiometric gradient, and tilted gas-oil-water contacts. The formation water 87Sr/86Sr composition can be useful to evaluate subsurface flow and reservoir behavior, especially in immature fields with scarce pressure and production data. In mature reservoirs, Sr Sr isotopes can be used to differentiate original formation water from injected water for waterflood surveillance. Strontium isotopes thus provide a valuable tool for both static and dynamic reservoir characterization in conjunction with conventional studies using seismic, log, core, engineering, and production data. Copyright ??2004. The American Association of Petroleum Geologist. All rights reserved.

  12. 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

  13. Hydrocarbon degassing of the earth and origin of oil-gas fields (isotope-geochemical and geodynamic aspects)

    NASA Astrophysics Data System (ADS)

    Valyaev, Boris; Dremin, Ivan

    2016-04-01

    More than half a century ago, Academician PN Kropotkin substantiated the relationship of the formation and distribution of oil and gas fields with the processes of emanation hydrocarbon degassing of the Earth. Over the years, the concept of PN Kropotkin received further development and recognition of studies based on new factual material. Of particular importance are the following factors: a) the results of studies on global and regional uneven processes of traditional oil and gas and the role of deep faults in controlling the spread of oil and gas fields; b) the results of the research on gigantic volumes and localization of the discharges of hydrocarbon fluids (mud volcanoes, seeps) on land and into the atmosphere and through the bottom of the World ocean; c) the results of the studies on grand volumes of the spread of unconventional hydrocarbon resources in their non-traditional fields, especially on near-surface interval of unconventional oil and gas accumulation with gas hydrates, heavy oil and bitumen, as well as extraordinary resources of oil and gas in the shale and tight rocks. Deep mantle-crust nature of oil and gas in traditional and nontraditional deposits thus received further substantiation of geological and geophysical data and research results. However, isotopic and geochemical data are still interpreted in favor of the concept of the genesis of oil and gas in the processes of thermal catalytic conversion of organic matter of sedimentary rocks, at temperatures up to 200°C. In this report an alternative interpretation of the isotope carbon-hydrogen system (δ13C-δD) for gas and of oil deposits, isotope carbon system for methane and carbon dioxide (δ13C1-δ13C0) will be presented. An alternative interpretation will also be presented for the data on carbon-helium isotope geochemical system for oil and gas fields, volcanoes and mud volcanoes. These constructions agree with the geological data on the nature of deep hydrocarbon fluids involved in the

  14. Electrochemical pilot-scale plant for oil field produced wastewater by M/C/Fe electrodes for injection.

    PubMed

    Ma, Hongzhu; Wang, Bo

    2006-05-20

    Oil field produced water by separated with crude oil were treated by an electrochemical process in laboratory pilot-scale plant, using double anodes with active metal (M) and graphite (C) and iron as cathode and a noble metal content catalyst with big surface. Due to the strong oxidizing potential of the chemicals produced (Cl(2), O(2), OCl(-), HO and so on), when the wastewater pass through the laboratory pilot-scale plant the organic pollutants including bacteria were oxidized and coagulated by produced M(n+) ion. It can be concluded that the catalytic electrochemical treatment of oil field produced wastewater is effective. Both chemical oxygen demand (COD) and biochemical oxygen demand (BOD) were reduced by over 90% in 6 min, suspense solids (SS) by 99%, Ca(2+) content by 22%, corrosion rate by 98% and bacteria (sulphate reducing bacteria (SRB), saprophytic bacteria (TGB) and iron bacteria) by 99% in 3 min under 15V/120A. These results indicate that this catalytic electrochemical method could be used for effective oil field wastewater treatment for injection purpose. PMID:16300884

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

    SciTech Connect

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

    1998-04-01

    The Bluebell field is productive from the Tertiary lower Green River and Colton (Wasatch) Formations of the Uinta Basin, Utah. The productive interval consists of thousands of feet of interbedded fractured clastic and carbonate beds deposited in the ancestral Lake Uinta. Wells in the Bluebell field are typically completed by perforating 40 or more beds over 1000 to 3000 vertical ft (300-900 m), then stimulating the entire interval with hydrochloric acid. This technique is often referred to as the shot gun completion. Completion techniques used in the Bluebell field were discussed in detail in the Second Annual Report (Curtice, 1996). The shot-gun technique is believed to leave many potentially productive beds damaged and/or untreated, while allowing water-bearing and low-pressure (thief) zones to communicate with the wellbore. A two-year characterization study involved detailed examination of outcrop, core, well logs, surface and subsurface fractures, produced oil-field waters, engineering parameters of the two demonstration wells, and analysis of past completion techniques and effectiveness. The study was intended to improve the geologic characterization of the producing formations and thereby develop completion techniques specific to the producing beds or facies instead of a shot gun approach to stimulating all the beds. The characterization did not identify predictable-facies or predictable-fracture trends within the vertical stratigraphic column as originally hoped. Advanced logging techniques can identify productive beds in individual wells. A field-demonstration program was developed to use cased-hole advanced logging techniques in two wells and recompletion the wells at two different scales based on the logging. The first well was going to be completed at the interval scale using a multiple stage completion technique (about 500 ft [150 m] per stage). The second well will be recompleted at the bed-scale using bridge plug and packer to isolate three or more

  16. 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

    , 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

  17. 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

    , 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

  18. 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.

  19. 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.

  20. Chemical composition of oils from recently discovered fields in West Lithuania

    NASA Astrophysics Data System (ADS)

    Zdanavičiūtė, Onytė; Dakhnova, Marina; Kleinas, Arūnas

    2008-01-01

    Four minor oil discoveries have been made in West Lithuania in recent years. Studies of the oil composition show that its physical and chemical properties (density, viscosity, petrol content, etc.) and the group composition of hydrocarbons (content of saturated and aromatic hydrocarbons, tars and asphaltenes) mainly depend on the formation conditions and distances of migration between the kitchen and accumulation areas. According to the distribution patterns of n-alkanes and isoprenoids, the examined oils are comparable and generated from sapropel organic matter. There are certain differences in biomarker and carbon isotope data, indicating oil generation from different source rocks containing organic matter of different catagenesis.

  1. Aerobic biodegradation process of petroleum and pathway of main compounds in water flooding well of Dagang oil field.

    PubMed

    Cai, Minmin; Yao, Jun; Yang, Huaijun; Wang, Ruixia; Masakorala, Kanaji

    2013-09-01

    Aerobic biodegradation of crude oil and its pathways were investigated via in vitro culture and GC-MS analysis in water flooding wells of Dagang oil field. The in vitro aerobic culture lasted 90 days when 99.0% of n-alkanes and 43.03-99.9% of PAHs were degraded and the biomarkers and their ratios were changed. The spectra of components in the residual oil showed the similar biodegradation between aerobic process of 90 days and degradation in reservoir which may last for some millions years, and the potential of serious aerobic biodegradation of petroleum in reservoir. 24 Metabolites compounds were separated and identified from aerobic culture, including fatty acid, naphthenic acid, aromatic carboxylic acid, unsaturated acid, alcohols, ketones and aldehydes. The pathways of alkanes and aromatics were proposed, which suggests that oxidation of hydrocarbon to organic acid is an important process in the aerobic biodegradation of petroleum. PMID:23867530

  2. Visualizing heterogeneous clastic reservoirs: Price formation (early Mississippian) oil fields in West Virginia

    SciTech Connect

    Hohn, M.E.; McDowell, R.R.; Matchen, D.L. )

    1996-01-01

    A procedure has been developed using public-domain and published software for creating 3-D models of facies in structurally-deformed elastic reservoirs. The procedure was tested successfully on two oil fields in Early Mississippian sandstone reservoirs in central West Virginia. The procedure has four stages: removal of structural deformation; definition of electrofacies from digitized electric logs and cores; classification of additional logs; and 3-D kriging. Reconstruction of original bedding was needed before variography and kriging, but no datum was available: the reservoir sandstone lies just below an angular unconformity, and many wells were not drilled far enough below the reservoir to penetrate a potential datum. In a novel application of automated stratigraphic correlation, a published algorithm was used on digitized gamma-ray logs to find the relative vertical shift between pairs of wells giving the highest cross-correlation. Multidimensional scaling of a matrix of shifts yielded a vector of values necessary for restoring the relative elevation of each well. Cluster analysis of gamma-ray and density log responses from cored wells defined four groups matched through core descriptions with environments of deposition. Discriminant functions calculated for these groups were used to classify log responses from uncored wells. Kriging of electrofacies followed conventional variography. Results are displayed as cross-sections and maps.

  3. Visualizing heterogeneous clastic reservoirs: Price formation (early Mississippian) oil fields in West Virginia

    SciTech Connect

    Hohn, M.E.; McDowell, R.R.; Matchen, D.L.

    1996-12-31

    A procedure has been developed using public-domain and published software for creating 3-D models of facies in structurally-deformed elastic reservoirs. The procedure was tested successfully on two oil fields in Early Mississippian sandstone reservoirs in central West Virginia. The procedure has four stages: removal of structural deformation; definition of electrofacies from digitized electric logs and cores; classification of additional logs; and 3-D kriging. Reconstruction of original bedding was needed before variography and kriging, but no datum was available: the reservoir sandstone lies just below an angular unconformity, and many wells were not drilled far enough below the reservoir to penetrate a potential datum. In a novel application of automated stratigraphic correlation, a published algorithm was used on digitized gamma-ray logs to find the relative vertical shift between pairs of wells giving the highest cross-correlation. Multidimensional scaling of a matrix of shifts yielded a vector of values necessary for restoring the relative elevation of each well. Cluster analysis of gamma-ray and density log responses from cored wells defined four groups matched through core descriptions with environments of deposition. Discriminant functions calculated for these groups were used to classify log responses from uncored wells. Kriging of electrofacies followed conventional variography. Results are displayed as cross-sections and maps.

  4. Core acid treatment influence on well reservoir properties in Kazan oil-gas condensate field

    NASA Astrophysics Data System (ADS)

    Janishevskii, A.; Ezhova, A.

    2015-11-01

    The research involves investigation of the influence of hydrochloric acid (HCI-12%) and mud acid (mixture: HCl - 10% and HF - 3%) treatment on the Upper-Jurassic reservoir properties in Kazan oil-gas condensate field wells. The sample collection included three lots of core cylinders from one and the same depth (all in all 42). Two lots of core cylinders were distributed as following: first lot - reservoir properties were determined, and, then thin sections were cut off from cylinder faces; second lot- core cylinders were exposed to hydrochloric acid treatment, then, after flushing the reservoir properties were determined, and thin sections were prepared. Based on the quantitative petrographic rock analysis, involvin 42 thin sections, the following factors were determined: granulometric mineral composition, cement content, intergranular contacts and pore space structure. According to the comparative analysis of initial samples, the following was determined: content decrease of feldspar, clay and mica fragments, mica, clay and carbonate cement; increase of pore spaces while in the investigated samples- on exposure of rocks to acids effective porosity and permeability value range is ambiguous.

  5. Disposal of oil field wastes and NORM wastes into salt caverns.

    SciTech Connect

    Veil, J. A.

    1999-01-27

    Salt caverns can be formed through solution mining in the bedded or domal salt formations that are found in many states. Salt caverns have traditionally been used for hydrocarbon storage, but caverns have also been used to dispose of some types of wastes. This paper provides an overview of several years of research by Argonne National Laboratory on the feasibility and legality of using salt caverns for disposing of nonhazardous oil field wastes (NOW) and naturally occurring radioactive materials (NORM), the risk to human populations from this disposal method, and the cost of cavern disposal. Costs are compared between the four operating US disposal caverns and other commercial disposal options located in the same geographic area as the caverns. Argonne's research indicates that disposal of NOW into salt caverns is feasible and, in most cases, would not be prohibited by state agencies (although those agencies may need to revise their wastes management regulations). A risk analysis of several cavern leakage scenarios suggests that the risk from cavern disposal of NOW and NORM wastes is below accepted safe risk thresholds. Disposal caverns are economically competitive with other disposal options.

  6. Subsidence rate monitoring of Aghajari oil field based on Differential SAR Interferometry

    NASA Astrophysics Data System (ADS)

    Moghaddam, N. Fouladi; Sahebi, M. R.; Matkan, A. A.; Roostaei, M.

    2013-06-01

    Land subsidence, due to natural or anthropogenic processes, causes significant costs in both economic and structural aspects. That part of subsidence observed most is the result of human activities, which relates to underground exploitation. Since the gradual surface deformation is a consequence of hydrocarbon reservoirs extraction, the process of displacement monitoring is amongst the petroleum industry priorities. Nowadays, Differential SAR Interferometry, in which satellite images are utilized for elevation change detection and analysis - in a millimetre scale, has proved to be a more real-time and cost-effective technology in contrast to the traditional surveying method. In this study, surface displacements in Aghajari oil field, i.e. one of the most industrious Iranian hydrocarbon sites, are being examined using radar observations. As in a number of interferograms, the production wells inspection reveals that surface deformation signals develop likely due to extraction in a period of several months. In other words, different subsidence or uplift rates and deformation styles occur locally depending on the geological conditions and excavation rates in place.

  7. Probing Asphaltene Aggregation in Native Crude Oils with Low-Field NMR

    SciTech Connect

    Zielinski, Lukasz; Saha, Indrajit; Freed, Denise E.; Hrlimann, Martin D.; Liu, Yongsheng

    2010-04-13

    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 {zeta}, 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 {zeta} 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.

  8. Geochemical haloes as an indication of over oil and gas fields in the Arctic shelf

    NASA Astrophysics Data System (ADS)

    Kholmiansky, Mikhail; Anokhin, Vladimir

    2013-04-01

    Hydrocarbon deposits at the Arctic shelf of Russia are a source of jet dispersion of heavy metals that forms haloes in sediments and in the bottom layer of sea water. The intensity of the haloes and their spatial position are jointly determined by geological structure of their source and the environment, i.e., hydrocarbon deposits in host rocks, seafloor lithodynamics and oceanographic factors. Based on theoretical works of Kholmyansky and Putikov (2000; 2006; 2008), an application of electrochemical modification of electric prospecting for offshore hydrocarbon exploration and detailed survey of the morphology of deposits was developed. Specialized equipment was developed for studies of electrochemical features of bottom water layer. With this equipment one can detect ion anomalies in water and determine the type of deposit as gas, gas hydrate, gas condensate or oil. At operation, the unit with equipment is towed underwater off the stern of research vessel. Type and configuration of deposits are determined based on occurrence of trace heavy metals detected by ion-selective electrodes. The proposed method was applied to study a few hydrocarbon fields in Barents and Kara seas in 2001 -2012 including Shtokman, Medyn, Polyarnoe, Prirazlomnoye and others. The results allowed us to trace the margins of the deposits in more detail, and geochemical data, in addition, showed the type of deposits. In general, the method has proven efficient and applicable to a wide range of hydrocarbon deposits.

  9. Super-giant oil fields and future prospects in the Middle East

    SciTech Connect

    Christian, L.; Johnston, D.

    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.

  10. Trace element content and distribution in a single fluid inclusion from Dunbar Oil Field, North Sea

    NASA Astrophysics Data System (ADS)

    Foriel, J.; Philippot, P.; Menez, B.; Simionovici, A.; Bohic, S.

    2003-03-01

    Synchrotron X-ray fluorescence (SXRF) analysis of individual fluid inclusions was performed on a suite of samples collected above and beneath a well-documented connectivity barrier of the Dunbar oil field, North Sea. The fluid inclusion analyzed consists of two phases (liquid + vapor), low salinity aqueous brines lining overgrowth zone of detrital quartz that formed during secondary silicification of the host sandstone. SXRF measurements indicate that the inclusion fluid contains a large variety of major and trace elements including CI, K, Ca, Ti, V, Cr, Mn, Fe. Co, Ni, Cu. Zn, Ga, Se, Br, Rb, Sr. Zr, Nb, Cd, Ba, Pb. Chemical mapping of a large inclusion (30 μm) together with element correlation diagrams show that, with the exception of Ca, Sr, Br and in lesser extent Zn, which display an homogeneous distribution throughout the inclusion, most elements show small-scale distribution heterogeneities that are best interpreted in terms of infra-μm solid phases suspended in the fluid phase. Calculated concentration estimates are critically dependent of the interpretation made for the origin of these solid phases (heterogeneous trapping vs. precipitated from the ambient inclusion fluid).

  11. Ground water and oil field waste sites: a study in Vermilion Parish.

    PubMed

    Rainey, J M; Groves, F D; DeLeon, I R; Joubert, P E

    1990-06-01

    Water samples were obtained from 128 private water wells surrounding eight oil field waste sites in Vermilion Parish. The specimens were analyzed for five heavy metals: barium, arsenic, chromium, lead, and cadmium. Half of the specimens were then analyzed for 16 volatile organic compounds. A blood sample was obtained from healthy adults drinking water from the wells tested for volatile organic compounds and this blood sample was also analyzed for volatile organic compounds. None of the water samples had levels of heavy metals or volatile organic compounds that exceeded the National Primary Drinking Water Standards. Barium levels in excess of 250 parts per billion suggested that styrene, toluene, and chloroform might be present. Blood levels of volatile organic compounds were significantly higher than could be accounted for by water consumption with levels in smokers significantly higher than in nonsmokers. These data suggest that as yet there is no contamination of ground water supplies around these sites. Volatile organic accumulation in humans probably occurs from a respiratory rather than from an oral route. PMID:2362163

  12. 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.

  13. Location of oil fields in Forest City basin as related to Precambrian tectonics

    SciTech Connect

    Carlson, M.P. )

    1989-09-01

    Accumulation of petroleum in the Forest City basin is strongly influenced by the tectonic framework established during the Precambrian. A series of Late Proterozoic orogenies created a fracture pattern in the northern Mid-Continent, which was emphasized by the late Keweenawan, Mid-Continent Rift System (MRS). Reactivated basement structures have created both a structural and depositional imprint on younger rocks. The Southeast Nebraska arch is defined by Middle Ordovician (Simpson) overlap of Arbuckle equivalents. Continuing differential movement along segments of the MRS within the North Kansas basin influenced the regional facies distribution of both the Late Ordovician (Viola) and the Late Devonian (Hunton). Middle Pennsylvanian compression from the Ouachita orogeny produced the Nemaha uplift and reactivated transform faulting on the MRS. Extensions of these southeast-trending fractures created offsets on the Nemaha uplift/Humboldt fault system and enhanced structures that host oil production. Fields that lie upon these wrench-fault trends within the Forest City basin have produced from the Simpson (St. Peter), Viola, and Hunton formations. The Precambrian structures and rock types produce strong geophysical signatures in contrast to the subdued anomalies of the Paleozoic sediments. Analyses of magnetic and gravity data provide an interpretation of the basement rocks and, by extrapolation, an additional exploration tool for locating Paleozoic trends related to reactivation of Precambrian tectonics.

  14. Aneth oil field carbonate mound reservoir - Organic-rich mudbank origin

    SciTech Connect

    Peterson, J.A. )

    1989-09-01

    The Aneth oil field (approximately 400 million bbl ultimate recovery) occurs within an isolated southeast-northwest-trending Pennsylvanian (Desmoinesian) algal carbonate bank buildup located approximately 25 mi (40 km) basinward of the main carbonate shelf of the Paradox basin in Utah. Desmoinesian deposition was strongly cyclic, with as many as 30 main evaporite-carbonate cycles recognized. The Aneth algal bank is part of the Desert Creek cycle, which is the first cycle above that of the most widespread salt-bearing cycle. The Desert Creek carbonate facies grades basinward to increasingly prevalent evaporite facies, dominated by thick salt beds in the basin center. Within the isolated algal-mound facies, the Desert Creek cycle is characterized by a vertical succession that includes (1) basal black, organic-rich, dolomitic, silty shale, and (2) overlying dark chalky, finely crystalline dolomite which grades upward into (3) the main carbonate mound facies dominated by accumulations of calcareous, leafy green algae with associated brachiopods, fusulinids, small foraminifera, ostracods, and, rarely, corals. Mound buildups are overlain by a relatively thin, black, organic-rich shale unit, the basal bed of the succeeding mound-bearing Ismay cycle. This upper shale unit thickens markedly on the flanks of the Desert Creek and other mounds.

  15. Aneth oil field, giant carbonate stratigraphic trap, Paradox basin, Utah, U. S. A

    SciTech Connect

    Petterson, J.A. )

    1991-03-01

    The Aneth oil field (approximately 400 million bbl original primary reserves) occurs within an isolated southeast-northwest-trending Pennsylvanian (Desmoinesian) algal carbonate bank buildup located approximately 25 mi (40 km) basinward of the main carbonate shelf of the Paradox basin in Utah. Desmoinesian deposition was strongly cyclic, with as many as 30 main evaporite-carbonate cycles recognized. The Aneth algal bank is part of the Desert Creek cycle, which is the first cycle above that of the most widespread salt-bearing cycle. The Desert Creek carbonate facies grades basinward to increasingly prevalent evaporite facies, dominated by thick salt beds in the basin center. Within the isolated algal-mound facies, the Desert Creek cycle is characterized by a vertical succession that includes (1) basal black, organic-rich, dolomitic, silty shale, (2) overlying dark chalky, finely crystalline dolomite, which grades upward into (3) the main carbonate mound facies, dominated by accumulations of calcareous, leafy green algae with associated brachiopods, fusulinids, small foraminifera, ostracodes, and rare corals. Mound buildups are overlain by a relatively thin, black, organic-rich shale unit, the basal bed of the succeeding mound-bearing Ismay cycle. This unit thickens markedly on the flanks of the Desert Creek and other mound buildup. Interrelated depositional processes of these various sedimentary facies have resulted in a close association between source rock, large reservoir, and seal at Aneth, and contributed significantly toward the large size of the Aneth accumulation.

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

    SciTech Connect

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

    1997-09-01

    Argonne National Laboratory (ANL) has completed an evaluation of the possibility that adverse human health effects (carcinogenic and noncarcinogenic) could result from exposure to contaminants released from nonhazardous oil field wastes (NOW) disposed of in domal salt caverns. In this assessment, several steps were used to evaluate potential human health risks: identifying potential contaminants of concern; determining how humans could be exposed to these contaminants; assessing the contaminants` toxicities; estimating contaminant intakes; and, finally, calculating human cancer and noncancer risks. Potential human health risks associated with hazardous substances (arsenic, benzene, cadmium, and chromium) in NOW were assessed under four postclosure cavern release scenarios: inadvertent cavern intrusion, failure of the cavern seal, failure of the cavern through cracks or leaky interbeds, and a partial collapse of the cavern roof. To estimate potential human health risks for these scenarios, contaminant concentrations at the receptor were calculated using a one-dimensional solution to an advection/dispersion equation that included first order degradation. Even under worst-case conditions, the risks have been found to be within the US EPA target range for acceptable exposure levels. From a human health risk perspective, salt caverns can provide an acceptable disposal method for NOW.

  17. A perfluorocarbon tracer transport and dispersion experiment in the North Sea Ekofisk oil field

    SciTech Connect

    Senum, G.I.; Dietz, R.N.; D'Ottavio, T.W.; Goodrich, R.W.; Cote, E.A.; Spandau, D.J.

    1990-07-01

    A perfluorocarbon tracer (PFT) transport and dispersion experiment has been performed in the Ekofisk section of the North Sea Oil fields. Fifty grams each of three PFTs were injected into a well and 28 surrounding wells were sampled for the presence of PFT. Sampling was accomplished by initially collecting bottles of reservoir hydrocarbon gas and subsequently transferring 5 liter (gas phase) aliquots onto Capillary Adsorbent Tracer (CAT) samplers. The resulting CATS samplers were analyzed for PFT in a specially configured laboratory gas chromatograph with electron capture detection. The limit of detection for PFT as determined by standard addition experiments was circa 1 to 10 femtoliters (10{sup {minus}15} L) per liter of sampled reservoir gas. Sampling was performed up to two years past the injection time; approximately two hundred samples were analyzed. PFT was observed only in four sampling wells at four different times, though the PFT analysis of earlier samples lack sufficient sensitivity to PFT detection due to a hydrocarbon interferent problem which was resolved during this experiment. 5 refs., 28 figs.

  18. A perfluorocarbon tracer transport and dispersion experiment in the North Sea Ekofisk oil field

    SciTech Connect

    Senum, G.I.; Dietz, R.N.; D'Ottavio, T.W.; Goodrich, R.W.; Cote, E.A.; Spandau, D.J.

    1989-12-01

    A perfluorocarbon tracer (PFT) transport and dispersion experiment has been performed in the Ekofisk section of the North Sea oil fields. Fifty grams each of three PFTs were injected into a well and 28 surrounding wells were sampled for the presence of PFT. Sampling was accomplished by initially collecting bottles of reservoir hydrocarbon gas and subsequently transferring 5 liter (gas phase) aliquots onto Capillary Adsorbent Tracer (CAT) samplers. The resulting CATS samplers were analyzed for PFT in a specially configured laboratory gas chromatograph with electron capture detection. The limit of detection for PFT as determined by standard addition experiments was circa 1 to 10 femtoliters (10{sup {minus}15} L) per liter of sampled reservoir gas. Sampling was performed up to two years past the injection time; approximately two hundred samples were analyzed. PFT was performed only in four sampling wells at four different times, though the PFT analysis of earlier samples lack sufficient sensitivity to PFT detection due to a hydrocarbon interferent problem which was resolved during this experiment. The PFT concentrations observed in these four wells appeared to follow an exponential dilution law with a dilution half-life of approximately 70 days in the reservoir. Recommendations for future experiments of this nature are made based on the problems encountered in this initial study. 4 refs., 28 figs., 10 tabs.

  19. 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.

  20. 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.

  1. 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.

  2. A Field-Scale Simulation of the Reversible Nanoparticle Adsorption for Enhancing Oil Recovery Using Hydrophilic Nanofluids

    NASA Astrophysics Data System (ADS)

    Cao, Liyuan

    In order to develop and apply nanotechnology in oil industry, nanoparticles transport in porous media has been studied in the past few years. Theoretical modeling were carried out to evaluate nanoparticle mobility and investigate nanoparticle retention mechanism. In this study, a simulator based on Ju and Fan's mathematical model was used to study nanoparticles transport in porous media on a reservoir scale. The simulator was verified with two simulation software, Eclipse from Schlumberger and MNM1D (Micro- and Nanoparticle transport Model in porous media in 1D geometry) developed by Tosco et al. Different injection scenarios were simulated: continuous injection, slug injection, and postflush. The effect of injection time, injection rate, and slug size on oil recovery were studied. The result discovered that when nanofluids flooding is used after water flooding as tertiary recovery method, early nanofluids injection will lead to higher oil recovery, but with more nanoparticle loss. Higher injection rate of nanofluids could help improve the flooding efficiency, but not the ultimate oil recovery for field development. Also, it can cause more nanoparticle loss. Brine water postflush is recommended when doing nanoflooding. It can significantly improve the recovery of nanoparticles, and for a homogeneous or heterogeneous reservoir, oil recovery is better compared to water flooding.

  3. 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...

  4. Effectiveness of Zanthoxylum piperitum-derived essential oil as an alternative repellent under laboratory and field applications.

    PubMed

    Kamsuk, K; Choochote, W; Chaithong, U; Jitpakdi, A; Tippawangkosol, P; Riyong, D; Pitasawat, B

    2007-01-01

    Recently, there were considerable efforts made to promote the use of environmentally friendly and biodegradable natural insecticides and repellents, particularly from botanical sources. In this study, Zanthoxylum piperitum-derived essential oil isolated by steam distillation was investigated and compared to the standard synthetic repellent, N,N-diethyl-3-methylbenzamide (DEET), for repellency against mosquitoes under laboratory and field conditions. The oil of Z. piperitum alone and also with 5% vanillin added repelled laboratory-reared female Aedes aegypti with the median protection times of 1.5 and 2.5 h, respectively. These repellency times were proven to be significantly lower than those of DEET-based products: 25% DEET and 25% DEET + 5% vanillin demonstrating 3.5 and 5.5 h, respectively. However, when applied under field conditions, Z. piperitum oil + 5% vanillin was found to provide better protection against a wide range of natural mosquito populations than 25% DEET + 5% vanillin. While the product of DEET was effective in reducing bites with 99.7% protection, the protective effect of Z. piperitum oil product appeared complete (100%). It had a protective effect against Aedes gardnerii, Anopheles barbirostris, Armigeres subalbatus, Culex tritaeniorhynchus, Culex gelidus, Culex vishnui group, and Mansonia uniformis. The better repellency against a wide range of field mosquitoes derived from Z. piperitum oil products suggested an advantage of efficacy by providing a broad spectrum of activity. Therefore, Z. piperitum could have potential for use in the development of combined repellents as a natural active ingredient, synergist, or additive to conventional synthetic chemicals, particularly in situations when DEET is ineffective and impractical. PMID:16896651

  5. 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.

  6. 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.

  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

  8. The influence of bioaugmentation and biosurfactant addition on bioremediation efficiency of diesel-oil contaminated soil: feasibility during field studies.

    PubMed

    Szulc, Alicja; Ambrożewicz, Damian; Sydow, Mateusz; Ławniczak, Łukasz; Piotrowska-Cyplik, Agnieszka; Marecik, Roman; Chrzanowski, Łukasz

    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

  9. 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.

  10. 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.

  11. Contracts for field projects and supporting research on enhanced oil recovery. Progress review number 86, quarter ending March 31, 1996

    SciTech Connect

    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.

  12. 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

  13. Insecticidal Potential of Clove Essential Oil and Its Constituents on Cacopsylla chinensis (Hemiptera: Psyllidae) in Laboratory and Field.

    PubMed

    Tian, Bao-Liang; Liu, Qi-Zhi; Liu, Zhi-Long; Li, Peng; Wang, Jie-Wen

    2015-06-01

    Cacopsylla chinensis (Yang and Li) (Hemiptera: Psyllidae) is an important pest of pear in China. As an alternative to conventional chemical pesticides, botanicals including essential oils and their constituents could provide an eco-friendly and nonhazardous control method. In this study, the essential oil of clove buds (Syzygium aromaticum) was obtained by hydrodistillation. Five constituents, accounting for 99.89% of the oil, were identified by gas chromatography-mass spectrometry, and the major constituents were eugenol (88.61%) and eugenol acetate (8.89%), followed by β-caryophyllene (1.89%). In a laboratory bioassay, clove essential oil, commercial eugenol (99.00%) and β-caryophyllene (98.00%) exhibited strong contact toxicity against the summerform adults of C. chinensis with LD50 values of 0.730, 0.673, and 0.708 µg/adult, and against the nymphs with LD50 values of 1.795, 1.668, and 1.770 µg/nymph, respectively. In contrast, commercial eugenol acetate (98%) had LD50 values of 9.266 µg/adult and 9.942 µg/nymph. In a field trial, clove essential oil caused significant population reductions of 73.01% (4.80 mg/ml), 66.18% (2.40 mg/ml) and 46.56% (1.20 mg/ml), respectively. Our results demonstrated that clove essential oil and its constituents have potential as a source of natural insecticides. PMID:26470216

  14. Salvaging dipmeters using an oil field {open_quotes}Dinosaur{close_quotes}

    SciTech Connect

    Breimayer, A.R.P.; Puzio, L.B.

    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.

  15. Deposition and chemical diagenesis of tertiary carbonates, Kirkuk oil field, Iraq

    SciTech Connect

    Majid, A.H.; Veizer, J.

    1986-06-01

    The Tertiary carbonate rocks of the Kirkuk oil field in Iraq have been subdivided into 18 major lithologic facies. Their spatial relationships suggest that carbonate deposition proceeded in alternating carbonate ramp and carbonate rimmed shelf settings. Geochemically, these 18 facies can be grouped into three populations: namely, the nearshore (mud flat and bioherm), foreslope, and basinal populations. The nearshore population consists of mudstone, wackestone, packstone, and grainstone with bioclasts of miliolids, peneroplids, rotalids, red algae, corals, Nummulites, Lepidocyclina, and crinoids. The basinal population encompasses mudstone and wackestone with Globigerina, radiolarians, and tintinids. The foreslope population consists of packstone and grainstone with a mixture of Nummulites, Lepidocyclina, and traces of corals and red algae. The nearshore and foreslope groups are characterized by severe recrystallization and contain abundant cements. The porosity is of primary (intergranular and intraskeletal) and secondary (dissolution and fracture) types and is associated mainly with the bioherm and foreslope facies. The nearshore population is characterized by low sodium and strontium contents and light delta/sup 18/O and delta/sup 13/C, whereas the basinal one has the opposite attributes. The foreslope group represents a mixture of these two end members, with nearshore components being dominant. Comparison of the approximate composition of diagenetic solutions responsible for deposition and/or mineralogic stabilization of carbonate constituents with present-day waters of various geologic environments led to the conclusion that the nearshore population was stabilized in a near-surface, meteoric, well-oxygenated aquifer. In contrast, the basinal population was deposited and stabilized in waters of marine parentage.

  16. Petrophysical evaluation of the hydrocarbon potential of the Lower Cretaceous Kharita clastics, North Qarun oil field, Western Desert, Egypt

    NASA Astrophysics Data System (ADS)

    Teama, Mostafa A.; Nabawy, Bassem S.

    2016-09-01

    Based on the available well log data of six wells chosen in the North Qarun oil field in the Western Desert of Egypt, the petrophysical evaluation for the Lower Cretaceous Kharita Formation was accomplished. The lithology of Kharita Formation was analyzed using the neutron porosity-density and the neutron porosity-gamma ray crossplots as well as the litho-saturation plot. The petrophysical parameters, include shale volume, effective porosity, water saturation and hydrocarbon pore volume, were determined and traced laterally in the studied field through the iso-parametric maps. The lithology crossplots of the studied wells show that the sandstone is the main lithology of the Kharita Formation intercalated with some calcareous shale. The cutoff values of shale volume, porosity and water saturation for the productive hydrocarbon pay zones are defined to be 40%, 10% and 50%, respectively, which were determined, based on the applied crossplots approach and their limits. The iso-parametric contour maps for the average reservoir parameters; such as net-pay thickness, average porosity, shale volume, water saturation and the hydrocarbon pore volume were illustrated. From the present study, it is found that the Kharita Formation in the North Qarun oil field has promising reservoir characteristics, particularly in the northwestern part of the study area, which is considered as a prospective area for oil accumulation.

  17. 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

  18. Sand remobilization enhanced complexity to mounded geometry, Early Tertiary deep water sand reservoirs, Balder Oil Field North Sea

    SciTech Connect

    Bergslien, D.; Rye-Larsen, M.; Jenssen, A.I.

    1996-12-31

    Sand remobilization played a major role in generating the high relief mounded geometries that trap oil in the early Tertiary reservoirs at Balder Field in Norwegian North Sea blocks 25/10 and 25/11. The thick massive submarine-fan sandstones were shed from the East Shetland Platform and deposited from high density turbidity currents. These thick massive sandstones lie in the distal portions of the fan system on the northwestern margin of the Utsira High. An intricate interaction between deposition and soft sediment deformation processes generated the complex cluster of thick mounded sand geometries comprising the Balder oil field. Slumping, sliding and sand remobilization with associated sand injections into overlying shales were the dominant deformation processes that mainly occurred during the early Eocene. The field is comprised of three reservoirs, the Paleocene Heimdal and Hermod Formations and the Early Eocene Balder Formation. The sandstones, which have excellent reservoir properties, share a common pressure system and oil-water contact. This is probably related to the soft-sediment deformation and associated sand injections establishing cross-stratal communication.

  19. Sand remobilization enhanced complexity to mounded geometry, Early Tertiary deep water sand reservoirs, Balder Oil Field North Sea

    SciTech Connect

    Bergslien, D.; Rye-Larsen, M.; Jenssen, A.I. )

    1996-01-01

    Sand remobilization played a major role in generating the high relief mounded geometries that trap oil in the early Tertiary reservoirs at Balder Field in Norwegian North Sea blocks 25/10 and 25/11. The thick massive submarine-fan sandstones were shed from the East Shetland Platform and deposited from high density turbidity currents. These thick massive sandstones lie in the distal portions of the fan system on the northwestern margin of the Utsira High. An intricate interaction between deposition and soft sediment deformation processes generated the complex cluster of thick mounded sand geometries comprising the Balder oil field. Slumping, sliding and sand remobilization with associated sand injections into overlying shales were the dominant deformation processes that mainly occurred during the early Eocene. The field is comprised of three reservoirs, the Paleocene Heimdal and Hermod Formations and the Early Eocene Balder Formation. The sandstones, which have excellent reservoir properties, share a common pressure system and oil-water contact. This is probably related to the soft-sediment deformation and associated sand injections establishing cross-stratal communication.

  20. Analysis of data from a downhole oil/water separator field trial in east Texas.

    SciTech Connect

    Veil, J. A.; Langhus, B.

    2002-08-15

    The U.S. Department of Energy's (DOE's) National Petroleum Technology Office (NPTO) is interested in promoting new technologies that can produce oil and gas at a lower cost or with enhanced environmental protection at a reasonable cost. Several years ago, DOE became aware of a new technology for produced water management known as a downhole oil/water separator (or DOWS). A DOWS system separates oil from water at the bottom of a production well and injects the water directly to a disposal zone without lifting it to the surface. DOWS technology offered three potential advantages over traditional pumping systems. First, DOWS were reported to reduce the volume of produced water brought to the surface. Second, the volume of oil produced often increased. Third, because large volumes of produced water were not being lifted to the surface past drinking water zones and subsequently reinjected downward past the same drinking water zones, there was less opportunity for contamination of those zones.

  1. 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

  2. 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.

  3. Pacific region adds fields and technology to stretch and amplify huge oil reserves

    SciTech Connect

    Lyle, D.

    1995-12-01

    The Pacific region combines the best features of the oilpatch with three states that give operators plenty of exploration prospects and two states at the forefront of development technology. The region offers something for everyone, but it has been hamstrung by low oil prices. It looks as if the repeal on the ban on exports Alaskan oil will go a long way toward easing the low-price restriction.

  4. Successful field evaluation of the efficiency of a gas gravity drainage process by applying recent developments in Sponge coring technique in a major oil field

    SciTech Connect

    Durandeau, M.; El-Emam, M.; Anis, A.H.; Fanti, G.

    1995-11-01

    This paper describes the application and integration of new technologies and recent developments in Sponge coring and presents the methodology used to carry out successfully the various phases of well designed Sponge coring project, including the coring phase, the on-site measurements and the full evaluation of the Sponge core samples. A field case is presented where a Sponge coring project was accomplished to obtain accurate fluids distribution and evaluate the gas gravity drainage efficiency in one of the Arab D sub-reservoirs of a major oil field offshore Abu Dhabi. A Sponge coring technology team was created to optimize the methodology used during Sponge coring an minimize the uncertainties which persisted on some of the previous operations. The effectiveness of the technique is discussed, with comparison to open hole logs and SCAL data. Realistic petrophysical parameters were obtained from non-invaded, native-state core samples. The effective oil saturation obtained from the Sponge core analysis results showed that the gravity segregation mechanism has been very active and efficient to recover the oil in the reservoir.

  5. Preparation and fuel properties of field pennycress (Thlaspi arvense) seed oil ethyl esters and blends with ultra-low sulfur diesel fuel

    Technology Transfer Automated Retrieval System (TEKTRAN)

    Field pennycress (Thlaspi arvense L.) is a widely distributed winter annual with high seed oil content (36%) and is suitable as an off-season rotational crop in the Midwestern U.S. Erucic [(13Z)-docosenoic] acid (36.2%) is the most abundant constituent in the oil, with unsaturated and very long chai...

  6. Draft Genome Sequence of Aeribacillus pallidus Strain 8m3, a Thermophilic Hydrocarbon-Oxidizing Bacterium Isolated from the Dagang Oil Field (China)

    PubMed Central

    Poltaraus, Andrey B.; Sokolova, Diyana S.; Grouzdev, Denis S.; Ivanov, Timophey M.; Malakho, Sophia G.; Korshunova, Alena V.; Rozanov, Aleksey S.; Tourova, Tatiyana P.

    2016-01-01

    The draft genome sequence of Aeribacillus pallidus strain 8m3, a thermophilic aerobic oil-oxidizing bacterium isolated from production water from the Dagang high-temperature oil field, China, is presented here. The genome is annotated to provide insights into the genomic and phenotypic diversity of the genus Aeribacillus. PMID:27284131

  7. 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.

  8. 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.

    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.

  9. 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

  10. Fuzzy SPC filter for a feed-forward control system for a three-phase oil field centrifuge.

    SciTech Connect

    Parkinson, W. J. ,; Smith, R. E.; Mortensen, F. N.; Wantuck, P. 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.

  11. Peculiarities of the geologic structure of gigantic gas fields of the western Siberian oil and gas province

    SciTech Connect

    Belyi, N.

    1991-03-01

    The Western Siberian Oil and Gas Province is a unique one regarding the concentration of natural gas resources in Mesozoic terrigenous formations. Discovery of gigantic natural gas fields makes it possible to provide high level of gas production for future prospects. The USSR has enormous potential possibilities for discoveries of new natural gas fields onshore, as well as offshore. At present, three gigantic gas fields have been developed, namely Medvezhie, Urongoi, and Yamburg. The first one has been in operation for 18 years. In the Mesozoic section, three productive complexes can be noticed: Upper Cretaceous, Lower Cretaceous, and Jurassic. The Upper Cretaceous production complex is mostly explored, with unique gas resources containing mainly methane having been discovered. The Lower Cretaceous production complex is characterized by considerable lithofaceous uniformity of reservoirs. Gas pools of this complex contain considerable quantities of condensate quite often having oil rims. The Jurassic production complex, which is characterized by its complicated structure and considerable changeability of the filtration properties, is less studied. Study of the geological structural peculiarities of the gigantic gas fields of Western Siberia gives us the possibility to find new approval for the development and exploration of gas fields.

  12. Using δ87Sr values to identify sources of salinity to a freshwater aquifer, Greater Aneth Oil Field, Utah, USA

    USGS Publications Warehouse

    Naftz, D.L.; Peterman, Z.E.; Spangler, L.E.

    1997-01-01

    Salinity increases in water from the freshwater Navajo aquifer in the Aneth area have been documented in recent years. Previous studies during the 1980s in the Aneth area suggested that brines associated with oil production and their subsequent re-injection were the probable source of salinity in the Navajo aquifer. Differences in the delta strontium-87 (δ87Sr) composition of ground-water samples from southeastern Utah were used to determine if oil-field brine or water from the upper Paleozoic aquifer is a plausible source of salinity to the Navajo aquifer. The δ87Sr values of the oil-field brine samples (mean = −0.95%, range = −1.06 to −0.79%, n = 5) are substantially more negative than the values in water samples from wells completed in the Navajo aquifer (mean = 0.73, range = −0.85 to 2.02%, n = 48), indicating that oil-field brine is not a source of salinity. The δ87Sr values in water samples from wells completed in the upper Paleozoic aquifer (mean = 0.801% range = 0.34 to 1.10%, n = 4) are similar to the mean isotopic composition of the more saline water from the Navajo aquifer. The δ87Sr values in water from the Navajo aquifer confirm that two distinct flow areas are present. Mixing models using the δ87Sr values and Sr concentrations of non-saline water from the Navajo aquifer and saline water from the upper Paleozoic aquifer indicate that water from the upper Paleozoic aquifer is a plausible source of saline water to the Navajo aquifer. Most Navajo aquifer wells that contain water with a δ87Sr signature similar to water from the upper Paleozoic aquifer are located within or adjacent to an area where the hydraulic gradient is favorable for upward movement of water from the upper Paleozoic aquifer into the Navajo aquifer.

  13. Hydrocarbons and heavy metals in fine particulates in oil field air: possible impacts on production of natural silk.

    PubMed

    Devi, Gitumani; Devi, Arundhuti; Bhattacharyya, Krishna Gopal

    2016-02-01

    Analyses of fine particulates (PM2.5) from the upper Assam oil fields of India indicated considerable presence of higher hydrocarbons (C22-C35) and heavy metals, Cd, Co, Cr, Cu, Ni, Pb, and Zn. This has raised serious concern for the sustainability of the exotic Muga (Antheraea assama) silk production, which has been a prime activity of a large number of people living in the area. The Muga worm feeds on the leaves of Machilus bombycina plant, and the impacts of air quality on its survival were further investigated by analyzing the leaves of the plant, the plantation soil, and the Muga cocoons. PM2.5 content in the air was much more during the winter due to near calm conditions and high humidity. Fourier transform infrared (FTIR), thermogravimetric analysis (TGA), and gas chromatography-mass spectrometer (GC-MS) analysis of PM2.5 showed the presence of higher alkanes (C22-C35) that could be traced to crude oil. Cr, Ni, and Zn were found in higher concentrations in PM2.5, M. bombycina leaves, and the plantation soil indicating a common origin. The winter has been the best period for production of the silk cocoons, and the unhealthy air during this period is likely to affect the production, which is already reflected in the declining yield of Muga cocoons from the area. SEM and protein analyses of the Muga silk fiber produced in the oil field area have exhibited the deteriorating quality of the silk. This is the first report from India on hydrocarbons and associated metals in PM2.5 collected from an oil field and on their possible effects on production of silk by A. assama. PMID:26490906

  14. Use of radium isotopes to determine the age and origin of radioactive barite at oil-field production sites

    USGS Publications Warehouse

    Zielinski, R.A.; Otton, J.K.; Budahn, J.R.

    2001-01-01

    Radium-bearing barite (radiobarite) is a common constituent of scale and sludge deposits that form in oil-field production equipment. The barite forms as a precipitate from radium-bearing, saline formation water that is pumped to the surface along with oil. Radioactivity levels in some oil-field equipment and in soils contaminated by scale and sludge can be sufficiently high to pose a potential health threat. Accurate determinations of radium isotopes (226Ra+228Ra) in soils are required to establish the level of soil contamination and the volume of soil that may exceed regulatory limits for total radium content. In this study the radium isotopic data are used to provide estimates of the age of formation of the radiobarite contaminant. Age estimates require that highly insoluble radiobarite approximates a chemically closed system from the time of its formation. Age estimates are based on the decay of short-lived 228Ra (half-life=5.76 years) compared to 226Ra (half-life=1600 years). Present activity ratios of 228Ra/226Ra in radiobarite-rich scale or highly contaminated soil are compared to initial ratios at the time of radiobarite precipitation. Initial ratios are estimated by measurements of saline water or recent barite precipitates at the site or by considering a range of probable initial ratios based on reported values in modern oil-field brines. At sites that contain two distinct radiobarite sources of different age, the soils containing mixtures of sources can be identified, and mixing proportions quantified using radium concentration and isotopic data. These uses of radium isotope data provide more description of contamination history and can possibly address liability issues. Copyright ?? 2000 .

  15. 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. , Casteel, J.

    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

  16. 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

  17. Methanogenic Bacteria from the Bondyuzhskoe Oil Field: General Characterization and Analysis of Stable-Carbon Isotopic Fractionation

    PubMed Central

    Belyaev, S. S.; Wolkin, R.; Kenealy, W. R.; DeNiro, M. J.; Epstein, S.; Zeikus, J. G.

    1983-01-01

    Selective enrichment culture techniques were employed to obtain mixed cultures of methanogenic rods and sarcina from surface flooding waters and deep subsurface (∼1650 m) oil-bearing sedimentary rocks and formation waters sampled from an old oil field in the U.S.S.R. previously reported to display active biological methanogenesis. The methanogens were selectively isolated as colonies on agar petri dishes that were incubated in a novel container. The general cellular and growth features of three Methanobacterium isolates were determined. These strains grew optimally at 37 to 45°C in anaerobic pressure tube cultures with a doubling time of 16 to 18 h on H2-CO2 and proliferated as autotrophs. Acetate addition significantly enhanced the final cell yield. Growth of these strains was completely inhibited by either 0.6 g of sodium sulfide per liter or 31.0 of sodium chloride per liter, but growth was not inhibited by either 0.3 g of sodium sulfide per liter or 1.0 g of sodium sulfate per liter. One novel isolate, Methanobacterium sp. strain ivanov, was grown on H2-CO2, and the stable-carbon isotopic fractionations that occurred during synthesis of methane, cell carbon, and lipids were determined. The results of this study were used to examine the anomalous relationship between the isotopic and chemical compositions of natural gas occurring in the deep subsurface environment of the oil field. Images PMID:16346216

  18. Field evaluation of neem and canola oil for the selective control of the honey bee (Hymenoptera: Apidae) mite parasites Varroa jacobsoni (Acari: Varroidae) and Acarapis woodi (Acari: Tarsonemidae).

    PubMed

    Melathopoulos, A P; Winston, M L; Whittington, R; Higo, H; Le Doux, M

    2000-06-01

    Neem oil, neem extract (neem-aza), and canola oil were evaluated for the management of the honey bee mite parasites Varroa jacobsoni (Oudemans) and Acarapis woodi (Rennie) in field experiments. Spraying neem oil on bees was more effective at controlling V. jacobsoni than feeding oil in a sucrose-based matrix (patty), feeding neem-aza in syrup, or spraying canola oil. Neem oil sprays also protected susceptible bees from A. woodi infestation. Only neem oil provided V. jacobsoni control comparable to the known varroacide formic acid, but it was not as effective as the synthetic product Apistan (tau-fluvalinate). Neem oil was effective only when sprayed six times at 4-d intervals and not when applied three times at 8-d intervals. Neem oil spray treatments had no effect on adult honey bee populations, but treatments reduced the amount of sealed brood in colonies by 50% and caused queen loss at higher doses. Taken together, the results suggest that neem and canola oil show some promise for managing honey bee parasitic mites, but the negative effects of treatments to colonies and the lower efficacy against V. jacobsoni compared with synthetic acaricides may limit their usefulness to beekeepers. PMID:10902299

  19. The Effect of Oregano and Cinnamon Essential Oils on Fermentation Quality and Aerobic Stability of Field Pea Silages

    PubMed Central

    Soycan-Önenç, Sibel; Koc, Fisun; Coşkuntuna, Levent; Özdüven, M. Levent; Gümüş, Tuncay

    2015-01-01

    This study was performed to determine the effect of field pea silages which were the organic acid (OA) alternative of oregano and cinnamon essential oils on fermentation quality and aerobic stability. Whole crop pea was harvested at full pod stage and wilted in the laboratory at the 48 h. The chopped pea was mixed and divided into equal portions allocated to five groups: CON (non-treated), distilled water, denoted as control group; OA group, a mixture of 60% formic acid, 20% sodium formate and 20% water applied at a rate of 5 g/kg fresh forage (Silofarm Liquid, Farmavet); origanum (ORE) group, Origanum onites essential oil at 400 mg/kg fresh forage; cinnamon (CIN) group, cinnamon essential oil at 400 mg/kg fresh forage; origanum+cinnamon (ORECIN) group, a mixture of ORE and CIN applied at an equal rate of 400 mg/kg fresh forage. Cinnamon decreased acetic acid (AA), ammonia nitrogen (NH3-N) and weight loss (WL) at the end of 60 days silage. Crude protein (CP) and dry matter (DM) increased by cinnamon essential oil. Yeasts were not detected in any treatments, including the control, after 7 days of air exposure. The CO2 amount decreased and the formation mold was inhibited in the aerobic period by the addition of cinnamon oil. Oregano did not show a similar effect, but when it was used with cinnamon, it showed synergic effect on AA and during aerobic period, it showed antagonistic effect on mold formation and DM losses. It was found in this study that cinnamon can be an alternative to organic acids. PMID:26323518

  20. The Effect of Oregano and Cinnamon Essential Oils on Fermentation Quality and Aerobic Stability of Field Pea Silages.

    PubMed

    Soycan-Önenç, Sibel; Koc, Fisun; Coşkuntuna, Levent; Özdüven, M Levent; Gümüş, Tuncay

    2015-09-01

    This study was performed to determine the effect of field pea silages which were the organic acid (OA) alternative of oregano and cinnamon essential oils on fermentation quality and aerobic stability. Whole crop pea was harvested at full pod stage and wilted in the laboratory at the 48 h. The chopped pea was mixed and divided into equal portions allocated to five groups: CON (non-treated), distilled water, denoted as control group; OA group, a mixture of 60% formic acid, 20% sodium formate and 20% water applied at a rate of 5 g/kg fresh forage (Silofarm Liquid, Farmavet); origanum (ORE) group, Origanum onites essential oil at 400 mg/kg fresh forage; cinnamon (CIN) group, cinnamon essential oil at 400 mg/kg fresh forage; origanum+cinnamon (ORECIN) group, a mixture of ORE and CIN applied at an equal rate of 400 mg/kg fresh forage. Cinnamon decreased acetic acid (AA), ammonia nitrogen (NH3-N) and weight loss (WL) at the end of 60 days silage. Crude protein (CP) and dry matter (DM) increased by cinnamon essential oil. Yeasts were not detected in any treatments, including the control, after 7 days of air exposure. The CO2 amount decreased and the formation mold was inhibited in the aerobic period by the addition of cinnamon oil. Oregano did not show a similar effect, but when it was used with cinnamon, it showed synergic effect on AA and during aerobic period, it showed antagonistic effect on mold formation and DM losses. It was found in this study that cinnamon can be an alternative to organic acids. PMID:26323518

  1. 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.

  2. 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.

  3. The Itteville Oil Field: An example of a stratigraphic trap in mid-Jurassic carbonates of the Paris Basin

    SciTech Connect

    Bez, M.; Sambet, G.

    1995-08-01

    The Itteville Oil Field is located 30 km south of Paris. The top of the reservoir lies at an average depth of 1450 m below sealevel. The field is situated on a large scale monocline dipping gently toward the present center of the Paris Basin. At reservoir level, no anticline closure is seen to explain the oil accumulation. The reservoir is composed of oolitic, peloidal and bioclastic carbonates of Lower Callovian age, regionally known as {open_quotes}Dalle Nacree{close_quotes}. These carbonate sands were deposited by storm-dominated processes during a phase of major sealevel fall which caused the emersion of the main Burgundy Platform. This shoal is completely isolated from the main platform and surrounded by coeval marine shales. Marls corresponding to the Mid-Callovian major flooding event seal the reservoir. The occurrence of these shoals appears to be tectonically controlled. The Itteville Field is situated on a Liassic faulted block seated on the eastern flank of the so-called {open_quotes}Deep Magnetic Anomaly{close_quotes}. Sedimentological studies and high resolution sequential analysis, carried out on cores from 17 wells of the field, help define three main tabular correlable units within the reservoir. Geochemical studies, including cathodo-luminescence and isotope analysis, help define the diagenetic history. Original poroperm properties are strongly enhanced by contemporaneous dissolution events related to high frequency sealevel fluctuations.

  4. Clove oil as an anaesthetic for adult sockeye salmon: Field trials

    USGS Publications Warehouse

    Woody, C.A.; Nelson, Jack L.; Ramstad, K.

    2002-01-01

    Wild migrating sockeye salmon Oncorhynchus nerka exposed to 20, 50 and 80 mg 1-1 of clove oil could be handled within 3 min, recovered within 10 min, and survived 15 min exposure trials. Fish tested at 110 mg 1-1 did not recover from 15 min exposure trials. Response curves developed for induction and recovery time considered the following predictors: clove oil concentration, sex, fish length and depth. A significant positive dependence was observed between induction time and fish length for 20, 50 and 80 mg 1-1 test concentrations; no dependence was observed between induction time and length at 110 and 140 mg 1-1. Recovery time differed as a function of clove oil concentration, but not fish size. A concentration of 50 mg 1-1 is recommended for anaesthetizing sockeye salmon ranging in length from 400 to 550 mm at water temperatures averaging 9-10??C.

  5. 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.

    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.

  6. 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.

  7. The structure of Nevada`s Grant Canyon and Bacon Flat oil fields from 3-D seismic data

    SciTech Connect

    Johnson, E.H.; Zwart, D.W.

    1995-06-01

    The 20 million barrel Grant Canyon structure and its satellite feature, the one million barrel Bacon Flat field, are located at the eastern edge of Railroad Valley, Nevada. Utilizing an eleven square mile 3-D seismic survey, we have unraveled the complicated structure of the field area. The seismic data were calibrated to known geology with 21 wells drilled prior to the 1993 3-D survey, and 4 recent wells. The 3-D data cube provided vertical 2-D seismic lines every 60 feet. Horizontal slices of the data cube rendered {open_quotes}map views{close_quotes} of the structural trends. Still, the interpretation of this complex area was difficult, hampered by extreme velocity variations in the valley fill sediments that degraded data resolution and skewed the imaged structures. The Grant Canyon and Bacon Flat reservoirs are shown to be remnants of detached Devonian rocks that rest upon a northwest-trending salient of younger Paleozoic rocks. The Paleozoic rocks that form the salient are truncated to the southeast against the Troy Intrusive. Beneath the salient, the flank of the intrusive dips about 30 degrees northwest. We show Bacon Flat to be an isolated closure northwest of Grant Canyon field. However, on the south flank of the Grant Canyon reservoir, a significant oil accumulation was trapped on the down side of a normal fault, 400 feet low to the oil column of the field. This appears to be anomalous for a carbonate reservoir with extraordinary permeability, but suggests that more oil may be trapped in the area, on the flanks of producing structures.

  8. 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

  9. Eos modeling and reservoir simulation study of bakken gas injection improved oil recovery in the elm coulee field, Montana

    NASA Astrophysics Data System (ADS)

    Pu, Wanli

    The Bakken Formation in the Williston Basin is one of the most productive liquid-rich unconventional plays. The Bakken Formation is divided into three members, and the Middle Bakken Member is the primary target for horizontal wellbore landing and hydraulic fracturing because of its better rock properties. Even with this new technology, the primary recovery factor is believed to be only around 10%. This study is to evaluate various gas injection EOR methods to try to improve on that low recovery factor of 10%. In this study, the Elm Coulee Oil Field in the Williston Basin was selected as the area of interest. Static reservoir models featuring the rock property heterogeneity of the Middle Bakken Member were built, and fluid property models were built based on Bakken reservoir fluid sample PVT data. By employing both compositional model simulation and Todd-Longstaff solvent model simulation methods, miscible gas injections were simulated and the simulations speculated that oil recovery increased by 10% to 20% of OOIP in 30 years. The compositional simulations yielded lower oil recovery compared to the solvent model simulations. Compared to the homogeneous model, the reservoir model featuring rock property heterogeneity in the vertical direction resulted in slightly better oil recovery, but with earlier CO2 break-through and larger CO2 production, suggesting that rock property heterogeneity is an important property for modeling because it has a big effect on the simulation results. Long hydraulic fractures shortened CO2 break-through time greatly and increased CO 2 production. Water-alternating-gas injection schemes and injection-alternating-shut-in schemes can provide more options for gas injection EOR projects, especially for gas production management. Compared to CO2 injection, separator gas injection yielded slightly better oil recovery, meaning separator gas could be a good candidate for gas injection EOR; lean gas generated the worst results. Reservoir

  10. 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. )

    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.

  11. 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.

  12. Balanced-activity improved inverse emulsion to inhibit brittle lutite hydration in oil fields

    SciTech Connect

    Olmedo, E. P.; de J. Hernandez Alvarez, R.; Barrera, C. D.; Ramos, J. D. G.

    1984-10-02

    An improved inverse emulsion for use as a drilling fluid that inhibits brittle lutite hydration. The emulsion includes a heavy oil; brine; a viscosity agent with thermostabilizing properties; an emulsifying agent; a thickening agent; a gelatinizing additive; and an alkaline earth metal hydroxide. The emulsion avoids hole collapsing and improves well gage stability.

  13. Contracts for field projects and supporting research on enhanced oil recovery. Progress review number 87

    SciTech Connect

    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. 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

  15. 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.

  16. Field test for repellency of cedarwood oil and cedrol to little fire ants

    Technology Transfer Automated Retrieval System (TEKTRAN)

    Eastern red cedars (ERC) (Juniperus virginiana L.) are an abundant renewable resource and represent a vast potential source of valuable natural products that may serve as natural biocides. The aromatic wood can be extracted to obtain cedarwood oil (CWO) and critical carbon dioxide (CO2) extraction o...

  17. Geology and habitat of oil in Ras Budran field, Gulf of Suez, Egypt

    SciTech Connect

    Chowdhary, L.R.; Taha, S.

    1987-10-01

    The Ras Budran structure at the deepest mappable seismic reflector, the top of the Kareem Formation (middle Miocene), is a broad northeast-southwest-trending anticlinal feature with an anomalous strike nearly at right angles to the main Gulf of Suez trend. Oil is produced from three units of Nubian Formation sandstone from a depth of 11,000-12,000 ft (3352-3657 m). The lower unit of Paleozoic age averages 10% porosity and has up to 200 md in-situ permeability. Wells completed in this unit produce up to 2000 BOPD. In contrast, the sands to the upper two units of the Early Cretaceous have 15-20% porosity and up to 700 md permeability. Wells completed in this unit produce 6000-8000 BOPD. The Ras Budran structure was formed primarily during an intra-Rudeis tectonic phase (lower Miocene). Oil migration for accumulation in the structure started in the late Miocene or Pliocene when the Santonian Brown Limestone and the Eocene Thebes Formation, the main source beds in the Gulf of Suez, reached the threshold of oil generation at a burial depth of approximately 10,000 ft (3048 m). At this depth, the organic matter in the source beds had a high transformation ratio (0.10 to 0.15), high yields of C/sub 15+/ soluble organic matter and C/sub 15+/ saturated hydrocarbons, vitrinite reflectance (R/sub 0/) of 0.62%, and a time-temperature index (TTI) value of 15. Oil migration from mature source beds in adjoining lows into low-potential Nubian reservoirs is easily explained by fault planes that acted as conduits for oil migration. 16 figures, 3 tables.

  18. Effect of the Exxon Valdez oil spill on intertidal fish: A field study

    SciTech Connect

    Barber, W.E.; McDonald, L.L.; Erickson, W.P.

    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.

  19. 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.

  20. Neutron scattering studies of crude oil viscosity reduction with electric field

    NASA Astrophysics Data System (ADS)

    Du, Enpeng

    data that contains information on the properties of a sample. We can analyze the data acquisition from the detectors and get the information on size, shape, etc. This is why we choose SANS as our research tool. The world's top energy problems are security concerns, climate concerns and environmental concerns. So far, oil (37%) is still the No.1 fuel in world energy consumption (Oil 37%, Coal 25%, Bio-fuels 0.2%, Gas 23%, Nuclear 6%, Biomass 4%, Hydro 3%, Solar heat 0.5%, Wind 0.3%, Geothermal 0.2% and Solar photovoltaic 0.04%). Even more and more alternative energy: bio-fuels, nuclear and solar energy will be used in the future, but nuclear energy has a major safety issue after the Japanese Fukushima I nuclear accidents, and other energies contribute only a small percent. Thus, it is very important to improve the efficiency and reduce the population of petroleum products. There is probably one thing that we can all agree on: the world's energy reserves are not unlimited. Even though it is limited, only 30% of the oil reserves is conventional oil, so in order to produce, transport, and refine of heavy crude oil without wasting huge amounts of energy, we need to reduce the viscosity without using high temperature stream heating or diluent; As more and more off-shore oil is exploited at that we need reduce the viscosity without increasing temperature. The whole petroleum consumed in U.S. in 2009 was 18.7 million barrels per day and 35% of all the energy we consumed. Diesel is one of the very important fossil fuel which is about 20% of petroleum consumed. Most of the world's oils are non-conventional, 15 % of heavy oil, 25 % of extra heavy oil, 30 % of the oil sands and bitumen, and the conventional oil reserves is only 30%. The oil sand is closely related to the heavy crude oil, the main difference being that oil sands generally do not flow at all. For efficient energy production and conservation, how to lower the liquated fuel and crude oil viscosity is a very important

  1. 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

  2. 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.

  3. Explosively produced fracture of oil shale. Progress report, July-September 1981. [Field experiments; computer models; retort stability

    SciTech Connect

    1982-04-01

    The Los Alamos National Laboratory is conducting rock fragmentation research in oil shale to develop the blasting technologies and designs required to create a rubble bed for a modified in situ retort. This report outlines our first field experiments at the Anvil Points Mine in Colorado. These experiments are part of a research program, sponsored by the Laboratory through the Department of Energy and by a Consortium of oil companies. Also included are some typical numerical calculations made in support of proposed field experiments. Two papers detail our progress in computer modeling and theory. The first presents a method for eliminating hourglassing in two-dimensional finite-difference calculations of rock fracture without altering the physical results. The second discusses the significant effect of buoyancy on tracer gas flow through the retort. A paper on retort stability details a computer application of the Schmidt graphical method for calculating fine-scale temperature gradients in a retort wall. The final paper, which describes our approach to field experiments, presents the instrumentation and diagnostic techniques used in rock fragmentation experiments at Anvil Points Mine.

  4. [Microbiological and production characteristics of the high-temperature Kongdian bed revealed during field trial of biotechnology for the enhancement of oil recovery].

    PubMed

    Nazina, T N; Grigor'ian, A A; Feng, Ts; Shestakova, N M; Babich, T L; Pavlova, N K; Ivoĭlov, V S; Ni, F; Wang, J; She, Y; Xiang, T; Mei, B; Luo, Z; Beliaev, S S; Ivanov, M V

    2007-01-01

    Microbiological technology for the enhancement of oil recovery based on the activation of the stratal microflora was tested in the high-temperature horizons of the Kongdian bed (60 degrees C) of the Dagang oil field (China). This biotechnology consists in the pumping of a water-air mixture and nitrogen and phosphorus mineral salts into the oil stratum through injection wells in order to stimulate the activity of the stratal microflora which produce oil-releasing metabolites. Monitoring of the physicochemical, microbiological, and production characteristics of the test site has revealed large changes in the ecosystem as a result of the application of biotechnology. The cell numbers of thermophilic hydrocarbon-oxidizing, fermentative, sulfate-reducing, and methanogenic microorganisms increased 10-10 000-fold. The rates of methanogenesis and sulfate reduction increased in the near-bottom zone of the injection wells and of some production wells. The microbial oil transformation was accompanied by the accumulation of bicarbonate ions, volatile fatty acids, and biosurfactants in the formation waters, as well as of CH4 and CO2 both in the gas phase and in the oil. Microbial metabolites promoted the additional recovery of oil. As a result of the application of biotechnology, the water content in the production liquid from the test site decreased, and the oil content increased. This allowed the recovery of more than 14000 tons of additional oil over 3.5 years. PMID:17633409

  5. 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.

  6. 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

  7. Potential non-tertiary additional oil recovery from heterogeneous submarine-fan reservoirs, Spraberry-Benedum field, Midland basin, Texas

    SciTech Connect

    Guevara, E.H.; Worrall, J.G.; Walter, T.

    1987-05-01

    The Spraberry-Benedum field is a multipay, solution-gas drive, combined structural-stratigraphic trap. It contains approximately 200 million bbl of original oil in place and has been waterflooded since 1967. Producing intervals are in the Spraberry formation (Permian, Leonardian), which in this area consists of mixed-sediment submarine-fan deposits (upper and lower Spraberry) and basin-plain facies (middle Spraberry). Principal oil reservoirs, with 12% average porosity and permeabilities of less than 1 md, occur in the lower and upper Spraberry. They consist of naturally fractured, very fine-grained sandstones and coarse siltstones of braided and meandering, peripheral channels and associated outer fan facies. Complex facies architecture results in highly heterogeneous reservoirs. Oil accumulations are layered because basin-plain shales vertically separate submarine-fan reservoirs, and they are laterally compartmentalized due to the channelization of reservoir rocks. Production trends locally parallel to facies trends indicate that recovery is influenced by reservoir stratigraphy. Well locations, based only on structural position and fracture orientation, commonly do not conform to the axes of belts of greatest sandstone-siltstone thickness, which contain the best reservoirs. Furthermore, completion intervals do not systematically tap both lower and upper Spraberry reservoirs. Ultimate recovery will be improved by aggressive development programs aimed at producing from poorly drained traps created by reservoir heterogeneities. Recompletion and deepening of wells, strategic infill drilling, and injection patterns in such programs should be based on detailed reservoir stratigraphy, in addition to structure and fracture data.

  8. 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.

    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.

  9. Integrated petrophysical and lithofacies studies of lower-middle Miocene reservoirs in Belayim marine oil field, Gulf of Suez, Egypt

    NASA Astrophysics Data System (ADS)

    Ali Ali, El-Khadragy; Emad El Din Abd Elrazik, Eysa; Shebl Azam, Salah; Ahmed Hassan, Saleh

    2016-05-01

    The reservoir parameters (total gross thickness, shale volume, total porosity, effective porosity, water saturation, bulk pore volume, net pay thickness and oil in place indicator) of Kareem and Belayim formations are studied through nine wells and mapped to show the aerial distribution of these parameters. Interpretation of these maps showed that, the best locations of hydrocarbon accumulation in Belayim marine oil field are middle part, northeast and the south west directions for Kareem formation and southwest and northeast directions for Belayim formation. The petrophysical results of Belayim formation were presented in the form of 3D slicing models to exhibit the variation of these parameters in the different directions. Cross plots of Kareem formation were done using neutron, density and sonic logs which is directly influenced by the matrix composition. By using two or three porosity logs reading we determined the porosity and evaluated the matrix characteristics of Kareem formation as it is considered as a good reservoir for oil and gas and mainly composed of sand stone. Finally, facies maps for Kareem and Belayim formations which established using composite logs indicate that, the environment of deposition of Kareem formation was deep marine in the middle and northern parts and shallow in the southern parts of the study area, meanwhile in Belayim formation the environment of deposition was in lagoonal through the deposition of Baba and Feiran members and shallow to deep during the sedimentation of Sidri and Hammam Faraun members.

  10. 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. )

    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)

  11. Investments in oil field development by the example of Tomsk oblast

    NASA Astrophysics Data System (ADS)

    Shmidt, Ye I.; Il'ina, G. F.; Matveenko, I. A.

    2015-11-01

    The article describes the geologic structure of the formation located not far from Strezhevoy Tomsk Oblast. The formation has been poorly studied by seismic methods. The reserves categories C1 and C2 as well as hydrocarbon potential are presented. 4 exploratory and 39 production wells are designed to be drilled depending on geologic knowledge and formation conditions. The article deals with the investment plan including development, oil export expenditures and implementing cost calculation.

  12. Engine dynamometer evaluation of oil formulation factors for improved field sludge protection

    SciTech Connect

    Carroll, D.R.; Robson, R.

    1987-01-01

    Recent examples of sludge incidence in vehicles operated on API SF, SF/CC and SF/CD category oils in both severe duty and normal consumer service from Europe and North America are presented. A comparison of the chemical and morphological characteristics of sludge taken from these vehicles is summarized, as are the sludge-preventing capabilities of various North American and European reference oils. The design and execution of a series of oil formulation understanding programs aimed at evaluating the influence of viscosity modifier chemistry, viscosity grade and various detergent inhibitor package variables on sludge deposit prevention in the M102E and PV-2 (Sequence V-D replacement) engine test being developed by CEC and ASTM, respectively, is presented. The knowledge derived from these formulation programs is used to develop prototype technologies designed to meet the requirements of Volkswaggen 501.01 specifications for black sludge inhibition and the proposed API PS-3 (SG) category and Daimler Benz P.226.3.

  13. The Petrology and Diagenetic History of the Phacoides Sandstone, Temblor Formation at the McKittrick Oil Field, California

    NASA Astrophysics Data System (ADS)

    Kaess, A. B.; Horton, R. A.

    2015-12-01

    The McKittrick oil field is located near the western edge of the San Joaquin Basin, California. The oil field is currently in production with 480 wells producing from the Tulare, San Joaquin, Reef Ridge, Monterey, Temblor, Tumey, and Kreyenhagen formations. Within the Temblor Formation production is mainly from the Miocene Carneros and the Phacoides sandstones. Eighty-two samples from the Phacoides sandstone (2403 - 3045 m below surface) were obtained from the California Well Sample Repository to characterize and understand the diagenetic history and its influence on its reservoir properties. Petrographic thin sections were analyzed by quantitative optical petrography, energy dispersive X-ray spectrometry, and imaging with back-scatter electron and cathodoluminescence. The Phacoides sandstone consists of fine to very coarse, poorly to well-sorted, arkosic arenites, and wackes with detrital framework grains including sub-angular quartz, K-feldspar (microcline and orthoclase), plagioclase, and lithic fragments. Ba-free, Ba-rich, and perthitic K-feldspars are present. Accessory minerals include glauconite, biotite, muscovite, magnetite, titanomagnetite, sphene, zircon, apatite, corundum, and rutile. Diagenetic alteration includes: (1) compaction, (2) mineral dissolution, (3) albitization of feldspars, alteration of biotite to pyrite and chlorite, replacement of framework grains by calcite, (4) alteration of volcanic rock fragments, (5) cementation by kaolinite, calcite and dolomite, and (6) precipitation of K-feldspar and quartz overgrowths. Early-formed fractures were healed by authigenic quartz, albite, and K-feldspars. Precipitation of carbonates and clays, rearranging of broken grains, and formation of pseudomatrix reduced primary porosity. Secondary porosity is common and formed initially by the dissolution of plagioclase (excluding albite) and volcanic fragments, and later by dissolution of calcite, dolomite, and detrital K-feldspars. Hydrocarbon emplacement was

  14. Magnetotelluric survey for exploration of a volcanic-rock reservoir in the Yurihara oil and gas field, Japan

    SciTech Connect

    Mitsuhata, Yuji; Matsuo, Koichi; Minegishi, Masato

    1999-03-01

    The Yurihara oil and gas field is located on the southern edge of Akita Prefecture, northeastern Japan. In this area, drilling, surface geological surveys and many seismic surveys have been used to investigate the geological structure. Wells drilled into the Nishikurosawa Basalt Group (NBG) of Miocene age found oil and gas reservoirs at depths of 1.5--2 km. Oil and gas are now being produced commercially and further exploration is required in the surrounding areas. However, since the neighboring areas are covered with young volcanic products from the Chokai volcano, and have a rough topography, the subsurface distribution of the NBG must be investigated using other methods in addition to seismic reflection. According to the well data, the resistivity of the NBG is comparatively higher than that of the overlying sedimentary formations, and therefore the magnetotelluric (MT) method is expected to be useful for the estimation of the distribution of the NBG. An MT survey was conducted along three survey lines in this area. Each line trended east-west, perpendicular to the regional geological strike, and was composed of about 25 measurement sites. Induction vectors evaluated from the magnetic field show that this area has a two-dimensional structure. The evaluated resistivity sections are in agreement with the log data. In conclusion, the authors were able to detect resistive layers (the NBG) below conductive layers. The results indicate that the NBG becomes gradually less resistive from north to south. In the center of the northern line, an uplifted resistive area is interpreted as corresponding to the reservoir. By comparison with a seismic section, the authors prove the effectiveness of the integration of seismic and MT surveys for the investigation of the morphology and internal structure of the NBG. On other survey lines, the resistive uplifted zones are interpreted as possible prospective areas.

  15. 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.

  16. Carbonate platform evolution, Upper Paleozoic, southern Kazakhstan, USSR: A surface analog for the super giant Tengiz oil field western Kazakhstan

    SciTech Connect

    Cook, H.E. ); Gatosvseey, Y.A.; Ponoeearenko, S.B.; Styehtsyehnka, I.G.; Styehtsyennka, V.P.; Zoran, A.E. ); Zhemchuzhnikov, V. )

    1991-08-01

    The Upper Devonian and Carboniferous carbonate platform and associated bioherms in the Bolshoi Karatau Mountains of southern Kazakhstan are similar to coeval carbonate platform and biohermal reservoir facies recently described in the Tengiz oil field of western Kazakhstan on the southeastern margin of the Pre-Caspian basin. Like Tengiz, the Bolshoi Karatau carbonate platform developed upon Devonian siliciclastics. The size of the two platforms are also similar as both the Bolshoi Karatau and the Tengiz carbonate platform are about 2-4 km thick and about 100 km wide. In the Bolshoi Karatau Mountains, the carbonate platform trends northwest-southeast, with the continental land mass to the east, and the open ocean platform margin toward Tengiz. Within the Bolshoi Karatau carbonate platform are several types of bioherms and carbonate sand bodies that may be analogous to the reservoir facies in the Tengiz oil field. Some of these facies exhibit karsting and solution voids which probably developed during sea level fluctuation. The Bolshoi Karatau carbonate sequence provides new data on the stratigraphic and sedimentologic evolution of Upper Devonian and Carboniferous carbonate platforms in southern Kazakhstan. Depositional, diagenetic, and reservoir models of this outcrop belt that are currently being developed should be useful for making subsurface predictions in the Tengiz area and other stratigraphically similar areas of the Soviet Union.

  17. 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.

  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

  19. Silurian "Clinton" Sandstone Reservoir Characterization for Evaluation of CO2-EOR Potential in the East Canton Oil Field, Ohio

    SciTech Connect

    Ronald Riley; John Wicks; Christopher Perry

    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

  20. 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.; McKeever, S.R.

    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