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We encourage you to perform a real-time search of NLEBeta
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1

Geomechanical Study of Bakken Formation for Improved Oil Recovery  

SciTech Connect (OSTI)

On October 1, 2008 US DOE-sponsored research project entitled “Geomechanical Study of Bakken Formation for Improved Oil Recovery” under agreement DE-FC26-08NT0005643 officially started at The University of North Dakota (UND). This is the final report of the project; it covers the work performed during the project period of October 1, 2008 to December 31, 2013. The objectives of this project are to outline the methodology proposed to determine the in-situ stress field and geomechanical properties of the Bakken Formation in Williston Basin, North Dakota, USA to increase the success rate of horizontal drilling and hydraulic fracturing so as to improve the recovery factor of this unconventional crude oil resource from the current 3% to a higher level. The success of horizontal drilling and hydraulic fracturing depends on knowing local in-situ stress and geomechanical properties of the rocks. We propose a proactive approach to determine the in-situ stress and related geomechanical properties of the Bakken Formation in representative areas through integrated analysis of field and well data, core sample and lab experiments. Geomechanical properties are measured by AutoLab 1500 geomechanics testing system. By integrating lab testing, core observation, numerical simulation, well log and seismic image, drilling, completion, stimulation, and production data, in-situ stresses of Bakken formation are generated. These in-situ stress maps can be used as a guideline for future horizontal drilling and multi-stage fracturing design to improve the recovery of Bakken unconventional oil.

Ling, Kegang; Zeng, Zhengwen; He, Jun; Pei, Peng; Zhou, Xuejun; Liu, Hong; Huang, Luke; Ostadhassan, Mehdi; Jabbari, Hadi; Blanksma, Derrick; Feilen, Harry; Ahmed, Salowah; Benson, Steve; Mann, Michael; LeFever, Richard; Gosnold, Will

2013-12-31T23:59:59.000Z

2

Bakken Shale Oil Production Trends  

E-Print Network [OSTI]

) database and in the format of monthly production for oil, water and gas. Additional 95 well data including daily production rate, completion, Pressure Volume Temperature (PVT), pressure data are given from companies who sponsor for this research study...

Tran, Tan

2012-07-16T23:59:59.000Z

3

Technology-Based Oil and Natural Gas Plays: Shale Shock! Could There Be Billions in the Bakken?  

Gasoline and Diesel Fuel Update (EIA)

Technology-Based Technology-Based Oil and Natural Gas Plays: Shale Shock! Could There Be Billions in the Bakken? Through the use of technology, U.S. oil and natural gas operators are converting previously uneconomic oil and natural gas resources into proved reserves and production. The Bakken Formation of the Williston Basin is a success story of horizontal drilling, fracturing, and completion technologies. The recent, highly productive oil field discoveries within the Bakken Formation did not come from venturing out into deep uncharted waters heretofore untapped by man, nor from blazing a trail into pristine environs never open to drilling before. Instead, success came from analysis of geologic data on a decades-old producing area, identification of uptapped resources, and application of the new drilling and completion technology necessary to exploit them. In short, it came from using technology

4

SUBTASK 1.7 EVALUATION OF KEY FACTORS AFFECTING SUCCESSFUL OIL PRODUCTION IN THE BAKKEN FORMATION, NORTH DAKOTA PHASE II  

SciTech Connect (OSTI)

Production from the Bakken and Three Forks Formations continues to trend upward as forecasts predict significant production of oil from unconventional resources nationwide. As the U.S. Geological Survey reevaluates the 3.65 billion bbl technically recoverable estimate of 2008, technological advancements continue to unlock greater unconventional oil resources, and new discoveries continue within North Dakota. It is expected that the play will continue to expand to the southwest, newly develop in the northeastern and northwestern corners of the basin in North Dakota, and fully develop in between. Although not all wells are economical, the economic success rate has been near 75% with more than 90% of wells finding oil. Currently, only about 15% of the play has been drilled, and recovery rates are less than 5%, providing a significant future of wells to be drilled and untouched hydrocarbons to be pursued through improved stimulation practices or enhanced oil recovery. This study provides the technical characterizations that are necessary to improve knowledge, provide characterization, validate generalizations, and provide insight relative to hydrocarbon recovery in the Bakken and Three Forks Formations. Oil-saturated rock charged from the Bakken shales and prospective Three Forks can be produced given appropriate stimulation treatments. Highly concentrated fracture stimulations with ceramic- and sand-based proppants appear to be providing the best success for areas outside the Parshall and Sanish Fields. Targeting of specific lithologies can influence production from both natural and induced fracture conductivity. Porosity and permeability are low, but various lithofacies units within the formation are highly saturated and, when targeted with appropriate technology, release highly economical quantities of hydrocarbons.

Darren D. Schmidt; Steven A. Smith; James A. Sorensen; Damion J. Knudsen; John A. Harju; Edward N. Steadman

2011-10-31T23:59:59.000Z

5

New Models Help Optimize Development of Bakken Shale Resources | Department  

Broader source: Energy.gov (indexed) [DOE]

Models Help Optimize Development of Bakken Shale Resources Models Help Optimize Development of Bakken Shale Resources New Models Help Optimize Development of Bakken Shale Resources February 7, 2012 - 12:00pm Addthis Washington, DC - Exploration and field development in the largest continuous oil play in the lower 48 states, located in North Dakota and eastern Montana, will be guided by new geo-models developed with funding from the Department of Energy's (DOE) Office of Fossil Energy (FE). The three-year project to develop exploration and reservoir models for the Bakken Shale resource play was conducted by the Colorado School of Mines (CSM), through research funded by FE's Oil and Natural Gas Program. A "play" is a shale formation containing significant accumulations of natural gas or oil. The U.S. Geological Survey estimates the Bakken Shale

6

New Models Help Optimize Development of Bakken Shale Resources | Department  

Broader source: Energy.gov (indexed) [DOE]

New Models Help Optimize Development of Bakken Shale Resources New Models Help Optimize Development of Bakken Shale Resources New Models Help Optimize Development of Bakken Shale Resources February 7, 2012 - 12:00pm Addthis Washington, DC - Exploration and field development in the largest continuous oil play in the lower 48 states, located in North Dakota and eastern Montana, will be guided by new geo-models developed with funding from the Department of Energy's (DOE) Office of Fossil Energy (FE). The three-year project to develop exploration and reservoir models for the Bakken Shale resource play was conducted by the Colorado School of Mines (CSM), through research funded by FE's Oil and Natural Gas Program. A "play" is a shale formation containing significant accumulations of natural gas or oil. The U.S. Geological Survey estimates the Bakken Shale

7

Treating-pressure analysis in the Bakken formation  

SciTech Connect (OSTI)

The Bakken formation is an oil-producing interval in the Williston basin. Usually, commercial Bakken wells are linked to an anisotropic natural fracture network. Hydraulic fracturing treatments have been used extensively in vertical wells and to a limited extent in horizontal wells. In this paper, bottom hole treating pressure (BHTP's) are analyzed to improve understanding of hydraulic fracture propagation in the Bakken.

Cramer, D.D. (BJ Services (US))

1992-01-01T23:59:59.000Z

8

Correlation and Stratigraphic Analysis of the Bakken and Sappington Formations in Montana  

E-Print Network [OSTI]

The Upper Devonian-Lower Mississippian (Late Fammenian-Tournaisian) Bakken Formation in the Williston Basin is one of the largest continuous oil fields in the U.S. The upper and the lower shale members are organic rich source rocks that supplied oil...

Adiguzel, Zeynep 1986-

2012-09-24T23:59:59.000Z

9

Bakken shale typifies horizontal drilling success  

SciTech Connect (OSTI)

Given the favorable production response that has been obtained from horizontal drilling in vertical- fractured reservoirs such as the Bakken shale and, more recently, the Austin chalk, industry interest in this technology has mushroomed in the U.S. Indeed, it is difficult to find a good-sized oil company these days that is not involved in a horizontal drilling project or is giving it serious consideration. In response to growing evidence of successful field applications, the realization is dawning on the investment community that horizontal drilling represents a significant technological development with positive implications for both the exploration and production business, and the oilfield services industry.

Leibman, P.R. (Petrie Parkman and Co., Denver, CO (US))

1990-12-01T23:59:59.000Z

10

Sensitivity of seismic reflections to variations in anisotropy in the Bakken Formation, Williston Basin, North Dakota.  

E-Print Network [OSTI]

??The Upper Devonian–Lower Mississippian Bakken Formation in the Williston Basin is estimated to have significant amount of technically recoverable oil and gas. The objective of… (more)

Ye, Fang, geophysicist.

2010-01-01T23:59:59.000Z

11

Horizontal drilling in the Bakken Formation - The hunt for an elephant that never left the source system  

SciTech Connect (OSTI)

New organic-geochemical studies show that bitumen extracted from the upper and lower shale members of the Mississippian Madison Group oils, and that the Bakken shales have contributed only a minor percentage of the conventionally produced oil in the Williston basin. Instead, organic-rich madison marls are an adequate source for the Madison oils. Also, few pathways exist for vertical migration of Bakken-generated oil to shallower Madison reservoirs. Vertical wells in older Bakken oil pools are perforated in one or all of the three units adjacent to the two Bakken shales but are not necessarily perforated in the Bakken shales. Rock-Eval analyses of 6- to 12-in. spaced core samples show that where Bakken shales are thermally mature, the three adjacent organic-poor units contain 10-20 times the hydrocarbons (HCs) they could have generated. Thus, Bakken-generated HCs appear to have moved into the three adjacent units, probably via fractures created by volume expansion of organic matter during HC generation in the Bakken shales. Bakken well histories reveal that unsuccessful Bakken wells appear due to questionable techniques during these operations and not a lack of fractures. If a large in-place resource base exists in the Bakken source system, its commercial recovery will depend on new exploration, drilling, completion, and production technologies and on how much of the generated oil is in fractures rather than dispersed throughout the rocks.

Price, L. (Geological Survey, Denver, CO (United States)); Le Fever, J. (North Dakota Geological Survey, Grand Forks (United States))

1991-06-01T23:59:59.000Z

12

NETL: Oil & Natural Gas Projects  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

Subtask 1.2 – Evaluation of Key Factors Affecting Successful Oil Production in the Bakken Formation, North Dakota Subtask 1.2 – Evaluation of Key Factors Affecting Successful Oil Production in the Bakken Formation, North Dakota DE-FC26-08NT43291 – 01.2 Goal The goal of this project is to quantitatively describe and understand the Bakken Formation in the Williston Basin by collecting and analyzing a wide range of parameters, including seismic and geochemical data, that impact well productivity/oil recovery. Performer Energy & Environmental Research Center, Grand Forks, ND 58202-9018 Background The Bakken Formation is rapidly emerging as an important source of oil in the Williston Basin. The formation typically consists of three members, with the upper and lower members being shales and the middle member being dolomitic siltstone and sandstone. Total organic carbon (TOC) within the shales may be as high as 40%, with estimates of total hydrocarbon generation across the entire Bakken Formation ranging from 200 to 400 billion barrels. While the formation is productive in numerous reservoirs throughout Montana and North Dakota, with the Elm Coulee Field in Montana and the Parshall area in North Dakota being the most prolific examples of Bakken success, many Bakken wells have yielded disappointing results. While variable productivity within a play is nothing unusual to the petroleum industry, the Bakken play is noteworthy because of the wide variety of approaches and technologies that have been applied with apparently inconsistent and all too often underachieving results. This project will implement a robust, systematic, scientific, and engineering research effort to overcome these challenges and unlock the vast resource potential of the Bakken Formation in the Williston Basin.

13

A comparison of the rates of hydrocarbon generation from Lodgepole, False Bakken, and Bakken formation petroleum source rocks, Williston Basin, USA  

SciTech Connect (OSTI)

Recent successes in the Lodgepole Waulsortian Mound play have resulted in the reevaluation of the Williston Basin petroleum systems. It has been postulated that hydrocarbons were generated from organic-rich Bakken Formation source rocks in the Williston Basin. However, Canadian geoscientists have indicated that the Lodgepole Formation is responsible for oil entrapped in Lodgepole Formation and other Madison traps in portions of the Canadian Williston Basin. Furthermore, geoscientists in the U.S. have recently shown oils from mid-Madison conventional reservoirs in the U.S. Williston Basin were not derived from Bakken Formation source rocks. Kinetic data showing the rate of hydrocarbon formation from petroleum source rocks were measured on source rocks from the Lodgepole, False Bakken, and Bakken Formations. These results show a wide range of values in the rate of hydrocarbon generation. Oil prone facies within the Lodgepole Formation tend to generate hydrocarbons earlier than the oil prone facies in the Bakken Formation and mixed oil/gas prone and gas prone facies in the Lodgepole Formation. A comparison of these source rocks using a geological model of hydrocarbon generation reveals differences in the timing of generation and the required level of maturity to generate significant amounts of hydrocarbons.

Jarvie, D.M.; Elsinger, R.J. [Humble Geochemical Services Division, TX (United States); Inden, R.F. [Lithologic & Stratigraphic Solutions, Denver, CO (United States); Palacas, J.G. [Lakewood, CO (United States)

1996-06-01T23:59:59.000Z

14

Subtask 1.8 - Investigation of Improved Conductivity and Proppant Applications in the Bakken Formation  

SciTech Connect (OSTI)

Given the importance of hydraulic fracturing and proppant performance for development of the Bakken and Three Forks Formations within the Williston Basin, a study was conducted to evaluate the key factors that may result in conductivity loss within the reservoirs. Various proppants and reservoir rock cores were exposed to several different fracturing and formation fluids at reservoir conditions. The hardness of the rock cores and the strength of the proppants were evaluated prior to and following fluid exposure. In addition, the conductivity of various proppants, as well as formation embedment and spalling, was evaluated at reservoir temperatures and pressures using actual reservoir rock cores. The results of this work suggest that certain fluids may affect both rock and proppant strength, and therefore, fluid exposure needs to be considered in the field. In addition, conductivity decreases within the Bakken Formation appear to be a function of a variety of factors, including proppant and rock strength, as well as formation embedment and spalling. The results of this study highlight the need for advanced conductivity testing, coupled with quantification of formation embedment and spalling. Given the importance of proppant performance on conductivity loss and, ultimately, oil recovery, better understanding the effects of these various factors on proppant and rock strength in the field is vital for more efficient production within unconventional oil and gas reservoirs.

Bethany Kurz; Darren Schmidt; Steven Smith Christopher Beddoe; Corey Lindeman; Blaise Mibeck

2012-07-31T23:59:59.000Z

15

Abandoned oil fields in Oklahoma  

SciTech Connect (OSTI)

Data are presented for approximately 165 abandoned oil fields in Oklahoma that have produced 10,000 or more barrels of oil prior to abandonment. The following information is provided for each field: county; DOE field code; field name; AAPG geologic province code; discovery date of field; year of last production, if known; discovery well operator; proven acreage; formation thickness; depth of field; gravity of oil production; calendar year; yearly field oil production; yearly field gas production; cumulative oil production; cumulative gas production; number abandoned fields in county; cumulative production of oil from fields; and cumulative production of gas from fields. (ATT)

Chism, J.

1983-08-01T23:59:59.000Z

16

Shale Oil and Gas, Frac Sand, and Watershed  

E-Print Network [OSTI]

;Bakken Oil Shale scope · Light, Sweet crude ­ ideal for automotive fuels and mid-size refineries (Midwest

Minnesota, University of

17

Abandoned oil fields in Kansas and Nebraska  

SciTech Connect (OSTI)

Data on approximately 400 abandoned oil fields in Kansas and 90 abandoned oil fields in Nebraska are presented. The following information is obtained on each field: county; DOE field code; field name; AAPG geologic province code; discovery date; year of last production; discovery well operator; proven acreage; formation thickness; depth of field; API gravity; calendar year; yearly field oil production; yearly field gas production; cumulative oil production; cumulative gas production; number abandoned fields in county; cumulative production of oil from fields; and cumulative production of gas from fields. (DMC)

Not Available

1982-12-01T23:59:59.000Z

18

05643_GeoMech_Bakken | netl.doe.gov  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

from the Bakken Formation in eastern Montana, the horizontal drilling and hydraulic fracture stimulation technology applied in western North Dakota has been less successful, thus...

19

Fracture-enhanced porosity and permeability trends in Bakken Formation, Williston basin, western North Dakota  

SciTech Connect (OSTI)

Fractures play a critical role in oil production from the Bakken Formation (Devonian and Mississippian) in the North Dakota portion of the Williston basin. The Bakken Formation in the study area is known for its low matrix porosity and permeability, high organic content, thermal maturity, and relative lateral homogeneity. Core analysis has shown the effective porosity and permeability development within the Bakken Formation to be related primarily to fracturing. In theory, lineaments mapped on the surface reflect the geometry of basement blocks and the zones of fracturing propagated upward from them. Fracturing in the Williston basin is thought to have occurred along reactivated basement-block boundaries in response to varying tectonic stresses and crustal flexure throughout the Phanerozoic. Landsat-derived lineament maps were examined for the area between 47/degrees/ and 48/degrees/ north lat. and 103/degrees/ and 104/degrees/ west long. (northern Billings and Golden Valley Counties, and western McKenzie County, North Dakota) in an attempt to identify large-scale fracture trends. In the absence of major tectonic deformation in the craton, a subtle pattern of fracturing has propagated upward through the sedimentary cover and emerged as linear topographic features visible on these large-scale, remote-sensed images.

Freisatz, W.B.

1988-07-01T23:59:59.000Z

20

Minimizing casing corrosion in Kuwait oil fields  

SciTech Connect (OSTI)

Corrosion in production strings is a well known problem in Kuwait oil fields. Failure to remedy the affected wells results mainly in undesirable dump flooding of the oil reservoirs, or in oil seepage and hydrocarbon contamination in shallow water bearing strata. Any of these situations (unless properly handled) leads to a disastrous waste of oil resources. This study discusses casing leaks in Kuwait oil fields, the nature of the formations opposite the leaks and their contained fluids, and the field measures that can be adopted in order to avoid casing leak problems.

Agiza, M.N.; Awar, S.A.

1983-03-01T23:59:59.000Z

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


21

Thermal history of Bakken shale in Williston basin  

SciTech Connect (OSTI)

Stratigraphic and thermal conductivity data were combined to analyze the thermostratigraphy of the Williston basin. The present thermostratigraphy is characterized by geothermal gradients of the order of 60 mK/m in the Cenozoic and Mesozoic units, and 30 mK/m in the Paleozoic units. The differences in geothermal gradients are due to differences in thermal conductivities between the shale-dominated Mesozoic and Cenozoic units and the carbonate-dominated Paleozoic units. Subsidence and compaction rates were calculated for the basin and were used to determine models for time vs. depth and time vs. thermal conductivity relationships for the basin. The time/depth and time/conductivity relationships include factors accounting for thermal conductivity changes due to compaction, cementation, and temperature. The thermal history of the Bakken shale, a primary oil source rock in the Williston basin, was determined using four different models, and values for Lopatin's time-temperature index (TTI) were calculated for each model. The first model uses a geothermal gradient calculated from bottom-hole temperature data, the second uses present-day thermostratigraphy, the third uses the thermostratigraphic relationship determined in this analysis, and the fourth modifies the third by including assumed variations in continental heat flow. The thermal histories and the calculated TTI values differ markedly among the models with TTI values differing by a factor of about two between some models.

Gosnold, W.D. Jr.; Lefever, R.D.; Crashell, J.J. (Univ. of North Dakota, Grand Forks (USA))

1989-12-01T23:59:59.000Z

22

North Dakota and Texas help boost U.S. oil reserves to highest...  

U.S. Energy Information Administration (EIA) Indexed Site

in total U.S. oil reserves, driven by the continued development of North Dakota's Bakken shale formation. North Dakota's proved oil reserves now exceeds the oil reserves in the...

23

Azerbaijan field to step up oil flow  

SciTech Connect (OSTI)

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

Not Available

1992-10-19T23:59:59.000Z

24

NETL: Oil & Natural Gas Projects  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

Geomechanical Study of Bakken Formation for Improved Oil Recovery Last Reviewed 12/12/2013 Geomechanical Study of Bakken Formation for Improved Oil Recovery Last Reviewed 12/12/2013 DE-08NT0005643 Goal The goal of this project is to determine the geomechanical properties of the Bakken Formation in North Dakota, and use these results to increase the success rate of horizontal drilling and hydraulic fracturing in order to improve the ultimate recovery of this vast oil resource. Performer University of North Dakota, Grand Forks, ND 58202-7134 Background Compared to the success of producing crude oil from the Bakken Formation in eastern Montana, the horizontal drilling and hydraulic fracture stimulation technology applied in western North Dakota has been less successful, thus requiring the development of new completion and fracturing technologies.

25

A field laboratory for improved oil recovery  

SciTech Connect (OSTI)

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.

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

1992-09-01T23:59:59.000Z

26

Baker likes its oil field prospects  

SciTech Connect (OSTI)

The oil field chemicals business is in the middle of a shakeout, and Baker Performance Chemicals (Houston) is working hard to be one of the survivors. In June, Baker acquired Canadian firm Suramco Chemical Research (Lloydminster, AB), and in late August is signed a deal with BASF to take over the German firm`s business in the oil field chemicals market, which will enhance Baker`s position in Europe. According to Baker president Glen Bassett, first among the factors at work in the industry is the decline in oil production in the US. Second is that, although sales and service expenses are the biggest cost in this service-intensive business, the substantial increase in prices of key raw material products such as ethylene oxide and methanol during the past few years has hurt oil field chemical makers` margins. Third, against the background of overcapacity in the industry, the big oil company customers {open_quotes}have been reluctant to talk price increases,{close_quotes} Bassett says.

Hunter, D.

1996-10-23T23:59:59.000Z

27

U.S. crude oil production expected to top 9 million barrels per...  

U.S. Energy Information Administration (EIA) Indexed Site

oil prices should be strong enough to support most drilling in North Dakota's Bakken shale formation and in the tight oil basins of Texas which account for the majority of the...

28

Biobjective optimization for general oil field development  

Science Journals Connector (OSTI)

Abstract The optimization of oil field development and production planning typically requires the consideration of multiple, possibly conflicting, objectives. For example, in a waterflooding project, we might seek to maximize oil recovery and minimize water injection. It is therefore important to devise and test optimization procedures that consider two or more objectives in the determination of optimal development and production plans. In this work we present an approach for field development optimization with two objectives. A single-objective product formulation, which systematically combines the two objectives in a sequence of single-objective optimization problems, is applied. The method, called BiPSOMADS, utilizes at its core our recently developed PSO–MADS (Particle Swarm Optimization–Mesh Adaptive Direct Search) hybrid optimization algorithm. This derivative-free procedure has been shown to be effective for the solution of generalized field development and well control problems that include categorical, discrete and continuous variables along with general (nonlinear) constraints. Four biobjective field development and well control examples are solved using BiPSOMADS. These examples include problems that consider the maximization of both net present value and cumulative oil production, and the maximization of both long-term and short-term reservoir performance. An example that highlights the applicability of biobjective optimization for field development under geological uncertainty is also presented. This usage of BiPSOMADS enables us to maximize expected reservoir performance while reducing the risk associated with the worst-case scenario.

Obiajulu J. Isebor; Louis J. Durlofsky

2014-01-01T23:59:59.000Z

29

A reservoir management study of a mature oil field  

E-Print Network [OSTI]

to other mature oil fields to make sound engineering and business decisions. I interpreted the geological structure and stratigaphy of the salt dome oil field. Structure, isopach and cross-sectional maps were constructed. Depositional environments...

Peruzzi, Tave

2012-06-07T23:59:59.000Z

30

Subsurface horizontal microfracture propagation within the middle member of the Bakken Formation, Williston Basin, North Dakota.  

E-Print Network [OSTI]

??The Devonian-Mississippian Bakken Formation of the Williston basin does not outcrop. All rock samples are obtained by coring. Open, uncemented, horizontal mode I (joints, with… (more)

Warner, Travis Blackburn.

2011-01-01T23:59:59.000Z

31

Abandoned oil fields in Arkansas, Louisiana, Mississippi and New Mexico  

SciTech Connect (OSTI)

Data were obtained from the Petroleum Data System at the University of Oklahoma and validated by visits to the following state agencies: Arkansas Oil and Gas Commission; Louisiana Office of Conservation; Mississippi State Oil and Gas Board; and New Mexico Oil and Gas Conservation Division. For this report, abandoned oil fields are defined as those fields listed by state agencies as officially abandoned and that produced at least 10,000 barrels of oil.

Not Available

1982-07-01T23:59:59.000Z

32

Horizontal drilling the Bakken Formation, Williston basin: A new approach  

SciTech Connect (OSTI)

Horizontal drilling is an attractive new approach to exploration and development of the Mississippian/Devonian Bakken Formation in the southwestern part of North Dakota. This drilling technique increases the probability of success, the profit potential, the effective drainage area maximizing recoverable reserves, and the productivity by encountering more natural occurring fractures. The target formation, the Mississippian/Devonian Bakken, consists of three members in an overlapping relationship, a lower organic-rich black shale, a middle siltstone/limestone, and an upper organic-rich black shale. It attains a maximum thickness of 145 ft and thins to a feather edge along its depositional limit. Considered to be a major source rock for the Williston basin, the Bakken is usually overpressured where productive. Overpressuring is attributed to intense hydrocarbon generation. Reservoir properties are poor with core fluid porosities being generally 5% or less and permeabilities ranging from 0.1 to 0.2 md. The presence of natural fractures in the shale are necessary for production. Two types of fractures are associated with Bakken reservoirs: large vertical fractures (of tectonic origin) and microfractures (probably related to hydrocarbon generation). An economic comparison between horizontal and vertical wells show that well completion costs are approximately two times higher (average costs; $1,500,000 for a horizontal to $850,000 for a vertical) with average payout for horizontal wells projected to occur in half the time (1.5 yr instead of 3.4 yr). Projected production and reserves are considered to be 2 to 4 times greater from a horizontal well.

Lefever, J.A. (North Dakota Geological Survey, Grand Forks (USA))

1990-05-01T23:59:59.000Z

33

A model of peak production in oil fields  

Science Journals Connector (OSTI)

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.

Daniel M. Abrams; Richard J. Wiener

2010-01-01T23:59:59.000Z

34

Website Provides Data for Key Oil Play in North Dakota, Eastern Montana |  

Broader source: Energy.gov (indexed) [DOE]

Website Provides Data for Key Oil Play in North Dakota, Eastern Website Provides Data for Key Oil Play in North Dakota, Eastern Montana Website Provides Data for Key Oil Play in North Dakota, Eastern Montana July 19, 2011 - 1:00pm Addthis Washington, DC - A new web-based geographic information system designed to improve oil production in North Dakota and eastern Montana has been launched with support from the U.S. Department of Energy. The Bakken Decision Support System (BDSS) assembles data for the Bakken and Three Forks Formations into an application that enables a user to visualize geologic and oil production information.The online tool, called the Bakken Decision Support System (BDSS), assembles data for the Bakken and Three Forks Formations into an application that enables a user to visualize geologic and oil production information. The system was developed by the

35

OPTIMAL DEVELOPMENT PLANNING OF OFFSHORE OIL AND GAS FIELD  

E-Print Network [OSTI]

OPTIMAL DEVELOPMENT PLANNING OF OFFSHORE OIL AND GAS FIELD INFRASTRUCTURE UNDER COMPLEX FISCAL Pittsburgh, PA 15213 Abstract The optimal development planning of offshore oil and gas fields has received development planning. Keywords Multiperiod Optimization, Planning, Offshore Oil and Gas, MINLP, MILP, FPSO

Grossmann, Ignacio E.

36

Seismic Attribute Analysis of the Upper Cretaceous below the Tambaredjo oil field, Suriname:.  

E-Print Network [OSTI]

??The Tambaredjo field is the largest oil field in Suriname. Since 1982 the state oil company, Staatsolie Maatschappij Suriname N.V., has been extracting oil from… (more)

Roepnarain, R.

2013-01-01T23:59:59.000Z

37

The Evolution of Giant Oil Field Production Behavior  

Science Journals Connector (OSTI)

The data for this study have been taken from the giant oil field database compiled by Robelius (2007...). AAPG was the main source for information about discovery year, year of first oil production, URR and cumulative

Mikael Höök; Bengt Söderbergh; Kristofer Jakobsson…

2009-03-01T23:59:59.000Z

38

Salt caverns for oil field waste disposal.  

SciTech Connect (OSTI)

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.

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

2000-07-01T23:59:59.000Z

39

Drop in drilling hurts oil-field chemicals market  

Science Journals Connector (OSTI)

Drop in drilling hurts oil-field chemicals market ... But events in the past few years have proven that notion faulty, and oil-field chemicals have fallen on hard times as drilling activity declines. ... The consumption of oil-field chemicals is directly related to drilling activity, and two new studies point out how far that market has declined and where opportunities still exist. ...

1985-11-18T23:59:59.000Z

40

Remote control of off-shore oil field production equipment  

E-Print Network [OSTI]

REMOTE CONTROL OF OFF-SHORE OIL FIELD PRODUCTION EQUIPMENT A Thesis Alton W. Sissom 1949 Approve as to style and on n by Cha1rman of omm1ttee REMOTE CONTROL OF OFFSHORE OIL FIELD PRODUCTION EQUIPMENT A Thesis Alton W. Oissom 1949 REMOTE...-Carrier Channel 26 PZNOTE CONTROL OF OFF-SHORE OIL FIELD PRODUCTION K, 'UIPMENT I GENERAL IiPOPPUi TION Since the beginning of the exploitation of the under-sea oil deposits in the Gulf' of qexico, most, of the territory off the shores of Texas and Louisiana...

Sissom, Alton Wayne

2012-06-07T23:59:59.000Z

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


41

Method of determining interwell oil field fluid saturation distribution  

DOE Patents [OSTI]

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.

Donaldson, Erle C. (Bartlesville, OK); Sutterfield, F. Dexter (Bartlesville, OK)

1981-01-01T23:59:59.000Z

42

Oil and Gas Field Code Master List - Energy Information Administration  

U.S. Energy Information Administration (EIA) Indexed Site

Oil and Gas Field Code Master List Oil and Gas Field Code Master List With Data for 2012 | Release Date: May 8, 2013 | Next Release Date: April 2014 Previous Issues Year: 2011 2010 2009 2008 2007 2006 2005 2004 2003 2002 2001 2000 1998 1997 1996 1995 Go Comprehensive listing of U.S. oil and gas field names. Oil and Gas Field Code Master List 2012 Definition of a Field Afield is defined as "an area consisting of a single reservoir ormultiple reservoirs all grouped on, or related to, the same individual geological structural feature and/or stratigraphic condition. There may be two or more reservoirs in a field which are separated vertically by intervening impervious strata, or laterally by local geologic barriers, or by both." More › About the Field Code Master List Related Links

43

Saving diesel fuel in the oil field  

SciTech Connect (OSTI)

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

Elder, B.

1982-11-01T23:59:59.000Z

44

An EOR Application @ Liaohe Oil Field in China  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

AN EOR APPLICATION @ LIAOHE OIL AN EOR APPLICATION @ LIAOHE OIL FIELD IN CHINA Tests of Pumping Boiler Flue Gas into Oil Wells Chenglin Zhu (huafugs@sohu.com 011-86-427-7809254 ) Huafu Electrical Appliance Co., Ltd. Xing long Tai District City of Pan Jing, Lioning Province, PRC 124013 Zhang, Fengshan ( huafugs@sohu.com 011-86-427-7809254 ) Liaohe Petroleum Exploration Bureau Xing Long Tai District City of Pan Jing, Lioning Province, PRC 124013

45

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

Science Journals Connector (OSTI)

If observed oil and gas field size distributions are obtained ... should approximate that of the parent population of oil and gas fields. However, empirical evidence ... the observable size distributions change w...

Lawrence J. Drew; Emil D. Attanasi; John H. Schuenemeyer

1988-11-01T23:59:59.000Z

46

Perspectives on the Design and Planning of Oil Field Infrastructure  

Science Journals Connector (OSTI)

Abstract Drilling for oil and gas is a costly and risky endeavor. Existing literature has already recognized the role of modeling and simulation in aiding the development and management of an oil field and its infrastructure. The optimal design and planning of oil field infrastructure is a highly complex and challenging noncontinuous process design problem involving many continuous and discrete decisions over time. In this article, we describe its challenges and complexity, and review various contributions from the process systems and petroleum engineering communities. We classify the various design and planning issues based on the planning horizon, discuss progress trends, and highlight possible future work.

M. Sadegh Tavallali; Iftekhar A. Karimi

2014-01-01T23:59:59.000Z

47

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

E-Print Network [OSTI]

Mar Lett (2010) 30:331–338 Fig. 3 Coal Oil Point seep field,hydrocarbon seeps near Coal Oil Point, California. Marhydrocarbon seep emissions, Coal Oil Point seep field,

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

2010-01-01T23:59:59.000Z

48

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

E-Print Network [OSTI]

hydrocarbon seeps near Coal Oil Point, California. Marof seep bubble plumes in the Coal Oil Point seep field Irameasurement system in the Coal Oil Point seep field in the

Leifer, Ira; Culling, Daniel

2010-01-01T23:59:59.000Z

49

Abandoned oil fields in Alaska, California, Colorado, Montana, North Dakota, Utah and Wyoming  

SciTech Connect (OSTI)

This publication lists approximately 250 abandoned oil fields in Alaska, California, Colorado, Montana, North Dakota, Utah and Wyoming that have produced 10,000 or more barrels of oil before abandonment. The following information is provided for each field: county; DOE field code; field name; AAPG geologic province code; discovery data of field; year of last production; discovery well operator; proven acreage; formation thickness; depth of field; gravity of oil production; calendar year; yearly field oil production; yearly field gas production; cumulative oil production; cumulative gas production; number abandoned fields in county; cumulative production of oil from fields; cumulative production of gas from fields. (ATT)

Not Available

1983-04-01T23:59:59.000Z

50

Relationships among oil density, gross composition, and thermal maturity indicators in northeastern Williston basin oils and their significance for expulsion thresholds and migration pathways  

SciTech Connect (OSTI)

Oil density ({degree}API), gross composition, and biological market thermal maturity variations in northeastern Williston basin have stratigraphic and geographic significance controlled by migration pathways and source rock composition as it affects hydrocarbon generation and expulsion characteristics. When the depth and density of oil pools is compared to relationships predicted using the correlation between source rock thermal maturity and oil density, several different migration pathways can be inferred. Winnipegosis source oils indicate four paths. Most small pinnacle reef pools are sourced locally, but larger coalesced reefs contain oils migrated long distances through the Lower Member Winnipegosis Formation. Among oils that have migrated past Prairie salts, both locally sourced oils, like those on the flank of the Hummingbird Trough, and more mature, longer migrated oils in Saskatchewan Group reservoirs can be identified. Bakken oils have the longest migration pathways, controlled primarily by a lowstand shoreline sandstone on the eastern side of the basin. Lodgepole-sourced oils dominate Madison Group plays. Northwest of Steelman field, oil density increases primarily due to thermal maturity differences but also because of increasing biodegradation and water-washing that affect the western edge of the play trend. Along the margin of the Hummingbird Trough are a number of deep, medium-gravity pools whose oil compositions are entirely attributable to low thermal maturity and local migration pathways.

Osadetz, K.G.; Snowdon, L.R.; Brooks, P.W. (Geological Survey of Canada, Calgary, Alberta (Canada))

1991-06-01T23:59:59.000Z

51

Thermal modeling of Bakken Formation of Williston basin  

SciTech Connect (OSTI)

Organic geochemical analyses provide a quantitative basis on which conceptual models of thermal maturation may be built. Contour maps of maturation indices of the Mississippian-Devonian Bakken Formation of the Williston basin show anomalous patterns that are not dependent on burial depth. One such area is on the western side of the Nesson anticline. One-dimensional modeling incorporating a uniform, constant heat flow, lithology-dependent thermal conductivities, and decompaction factors indicates that these areas are less mature than surrounding regions. This is due primarily to decreasing burial depth and thinning of low-thermal-conductivity Tertiary and Cretaceous shales. Additional heat transfer to these regions may be due in part to heat transfer by fluid movement through aquifers or vertical fractures. The influence of these fluid systems is simulated through the use of a two-dimensional finite difference program. Basic assumptions are made concerning heat flow, thermal properties, and ground-water flow rates through time. Modeling of the time-temperature history is simplified by restricting the study to the time of greatest maturation, the post-Jurassic.

Anderson, D.

1986-08-01T23:59:59.000Z

52

Oil composition variation and reservoir continuity: Unity field, Sudan  

Science Journals Connector (OSTI)

A suite of oils from stacked reservoirs in the Unity Field in Sudan has been analyzed by various geochemical techniques for molecular information to elucidate the geological processes which cause variations in oil composition and their resulting oil fingerprints in different reservoir units. Analyses of these highly paraffinic oils indicate that the chromatographic fingerprint variations are due to differences in the abundances of saturated compounds, including branched and cyclic alkanes. Neither aromatics nor NSO compounds have any significant effect on the observed fingerprint variations. This association of saturates, instead of aromatics and NSO compounds, with the fingerprint variations precludes rock-fluid interactions as a cause of the variations. Biomarker analyses show that variations in thermal maturity and organic facies of the source rock are responsible for the fingerprint variations. Thermal maturity increases with the depth of the reservoir, suggesting a multiple-charge process for the oils to fill these reservoirs over an extended period of time. Apparently the source rock generated and expelled progressively more mature oils and little mixing occurred during migration. Thus, knowledge of oil compositional variations from one reservoir to another, organic facies variation and source rock maturity combined with tectonic history may help explain charging and timing of oil emplacement.

R.J. Hwang; A.S. Ahmed; J.M. Moldowan

1994-01-01T23:59:59.000Z

53

Verifying a Simplified Fuel Oil Flow Field Measurement Protocol  

SciTech Connect (OSTI)

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.

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

2013-07-01T23:59:59.000Z

54

A field laboratory for improved oil recovery. Final report  

SciTech Connect (OSTI)

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.

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

1992-09-01T23:59:59.000Z

55

Scientific research and field applications of polymer flooding in heavy oil recovery  

Science Journals Connector (OSTI)

The heavy oil resources worldwide are estimated at 3,396 billion barrels. With depletion of light oil, we have to face the technical and economical challenges of developing heavy oil fields. Due to severe visc...

Chang Hong Gao

2011-12-01T23:59:59.000Z

56

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology  

SciTech Connect (OSTI)

Objectives are listed and technical progress is summarized for contracts for field projects and supporting research on: chemical flooding, carbon dioxide injection, thermal/heavy oil, extraction technology, improved drilling technology, residual oil, and microbial enhanced oil recovery. (DLC)

Linville, B. (ed.)

1980-10-01T23:59:59.000Z

57

SMOOTH OIL & GAS FIELD OUTLINES MADE FROM BUFFERED WELLS  

U.S. Energy Information Administration (EIA) Indexed Site

The VBA code provided at the bottom of this document is an updated version The VBA code provided at the bottom of this document is an updated version (from ArcGIS 9.0 to ArcGIS 9.2) of the polygon smoothing algorithm described below. A bug that occurred when multiple wells had the same location was also fixed. SMOOTH OIL & GAS FIELD OUTLINE POLYGONS MADE FROM BUFFERED WELLS Why smooth buffered field outlines? See the issues in the figure below: [pic] The smoothing application provided as VBA code below does the following: Adds area to the concave portions; doesn't add area to convex portions to maintain buffer spacing Fills in non-field "islands" smaller than buffer size Joins separate polygon rings with a "bridge" if sufficiently close Minimizes increase in total field area Methodology: creates trapezoids between neighboring wells within an oil/gas

58

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

SciTech Connect (OSTI)

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.

Kaufman, R.L.; Noguera, V.H.; Bantz, D.M. [Chevron Overseas Petroleum, San Ramon, CA (United States); Rodriguez, R. [Maraven, S.A., Caracas (Venezuela)

1996-08-01T23:59:59.000Z

59

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

E-Print Network [OSTI]

. Infill predictions on a single-phase synthetic case showed greater accuracy than results from statistical techniques. The methodology successfully identified infill well locations iv on a synthetic case derived from Cut Bank field, a water-flooded oil... OF METHODOLOGY ON SYNTHETIC CASES????????... 11 Single Phase Synthetic Gas Reservoir Case????????..??... 11 Cut Bank Field Overview?????????..??????..??. 17 Multiphase Synthetic Oil Reservoir case????????.??.?... 24 TEST OF METHODOLOGY ON ACTUAL CASE...

Chavez Ballesteros, Luis Eladio

2005-02-17T23:59:59.000Z

60

Reverse osmosis process successfully converts oil field brine into freshwater  

SciTech Connect (OSTI)

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

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

1993-09-20T23:59:59.000Z

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


61

Electric Power Generation from Co-Produced and Other Oil Field...  

Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

Electric Power Generation from Co-Produced and Other Oil Field Fluids Electric Power Generation from Co-Produced and Other Oil Field Fluids Co-produced and low-temperature...

62

Chemostratigraphy And Geochemical Constraints On The Deposition Of The Bakken Formation, Williston Basin, Eastern Montana And Western North Dakota.  

E-Print Network [OSTI]

??Rowe, Harold The late Devonian-early Mississippian Bakken Formation was deposited in a structural-sedimentary intracratonic basin that extends across a large part of modern day North… (more)

Maldonado, David Nyrup

2013-01-01T23:59:59.000Z

63

Chemostratigraphy And Geochemical Constraints On The Deposition Of The Bakken Formation, Williston Basin, Eastern Montana And Western North Dakota.  

E-Print Network [OSTI]

??Rowe, Harold The late Devonian-early Mississippian Bakken Formation was deposited in a structural-sedimentary intracratonic basin that extends across a large part of modern day North… (more)

Maldonado, David Nyrup

2014-01-01T23:59:59.000Z

64

Optimal Planning and Scheduling of Offshore Oil Field Infrastructure Investment and Operations  

Science Journals Connector (OSTI)

Optimal Planning and Scheduling of Offshore Oil Field Infrastructure Investment and Operations ... A multiperiod mixed-integer linear programming (MILP) model formulation is presented for the planning and scheduling of investment and operation in offshore oil field facilities. ... An Efficient Multiperiod MINLP Model for Optimal Planning of Offshore Oil and Gas Field Infrastructure ...

R. R. Iyer; I. E. Grossmann; S. Vasantharajan; A. S. Cullick

1998-03-13T23:59:59.000Z

65

Clay-Oil Droplet Suspensions in Electric Field.  

E-Print Network [OSTI]

?? Silicone oil droplets containing synthetic smectite clay submerged in another immiscible organic oil have been studied by observing clay particle movement, oil circulation and… (more)

Kjerstad, Knut Brøndbo

2012-01-01T23:59:59.000Z

66

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

SciTech Connect (OSTI)

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.

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

2002-09-30T23:59:59.000Z

67

Surface reclamation of the Big Lake oil field  

SciTech Connect (OSTI)

Since the discovery of 1 Santa Rita in 1923, millions of barrels of salt water have been produced along with 135 million bbl of oil from the Big Lake oil field in Reagan County, Texas. Until the early 1960s, the accepted disposal method for the produced water was surface discharge to a large evaporation pond north of the field. Produced water was allowed to flow from wells to the pond via natural topographic drainage. This practice resulted in 2000 ac of eroded, barren landscape, characterized by highly saline soils incapable of supporting vegetation. In 1989, the University of Texas System, the U.S. Soil Conservation Service, and Marathon Oil Company, which acquired Big Lake field in 1962, initiated an experimental project to reclaim the affected land and restore rangeland productivity. An underground drainage system, consisting of 125,000 ft of buried drainage conduit and eight collection sumps, was installed over 205 ac of the affected area. Earthen terraces were constructed to capture and hold rain water to facilitate downward percolation and leaching of salts from the soil profile. Salts leached from the soil are captured by the drainage system and pumped to injection wells for disposal. The excellent revegetation that has occurred over the test area after three years of operations is encouraging and has shown the need for expanding and enhancing the existing system with supplemental water from fresh water wells, application of soil-amending agents, additional terracing, and selective planting with salt-tolerant species.

Weathers, M.L. (Univ. of Texas Lands, Midland, TX (United States)); Moore, K.R. (Univ. of Texas Lands, Big Lake, TX (United States)); Ford, D.L. (U.S.D.A. Soil Conservation Service, San Angelo, TX (United States)); Curlee, C.K. (Marathon Oil Company, Midland, TX (United States))

1994-03-01T23:59:59.000Z

68

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

SciTech Connect (OSTI)

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.

Youash, Y.Y.

1989-03-01T23:59:59.000Z

69

Recognition of hydrocarbon expulsion using well logs: Bakken Formation, Williston Basin  

SciTech Connect (OSTI)

The Upper Mississippian-Lower Devonian Bakken Formation forms a source/carrier/reservoir system in the Williston basin. Hydrocarbon expulsion within the Bakken has been identified by overlaying sonic and resistivity logs. Typically, these curves track in organically lean, water-saturated mudrocks because both respond mainly to porosity; however, in thermally mature organic-rich rocks and hydrocarbon reservoirs or carrier beds, the curves separate due to the anomalously high resistivity associated with replacement of pore water by hydrocarbons. Sonic/resistivity-log overlays for wells throughout the Montana and North Dakota parts of the Williston basin reveal significant increases and maximum in-curve separation within the middle siltstone member of the Bakken at subsurface temperatures of about 170 and 200{degree}F, respectively. Sequence-stratigraphic characteristics of the Bakken define the framework within which the expulsion process operates. The organic-rich upper and lower shale members represent the transgressive and early highstand systems tracts of two adjacent depositional sequences. A sequence boundary within the intervening middle siltstone member separates nearshore siltstone and sandstone of the late highstand systems tract in the lower sequence from cross-bedded subtidal to intertidal sandstones of the lowstand systems tract in the upper sequence. Reservoir properties vary across this sequence boundary. The authors attribute the log separation in the siltstone member to hydrocarbons expelled from the adjacent shales. Abrupt shifts in several geochemical properties of the shale members, indicative of hydrocarbon generation occur over the same subsurface temperature range as the rapid increase in log separation in the middle siltstone, thus indicating the contemporaneity of generation and expulsion.

Cunningham, R.; Zelt, F.B.; Morgan, S.R.; Passey, Q.R. (Exxon Production Research Co., Houston, TX (USA)); Snavely, P.D. III; Webster, R.L. (Exxon Co., U.S.A., Houston, TX (USA))

1990-05-01T23:59:59.000Z

70

Crude oil from the Zaburun'e field  

SciTech Connect (OSTI)

In order to work up recommendations for the directions to be taken in processing oil from the new Zaburun'e field in the Ural-Volga interfluvial district, a complete, unified program was used to investigate oil samples taken from depths of 905-913 and 895-903 meters from the Lower Cretaceous deposits. Density, viscosity, medium-resin content, flash point, and other processing-relevant properties were derived. The hydrocarbon group composition was assessed. Fractions distilling below 350/sup 0/C consisted mainly of high-energy isoparaffinic and naphthenic hydrocarbons. Characteristics of the diesel fuel cuts were derived. All cuts had low-temperature properties and cloud points below minus 60/sup 0/C. Lube stocks were analyzed and showed high viscosity indices, low solid points, and low sulfur contents. Straight-run resids were also evaluated.

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

1988-03-01T23:59:59.000Z

71

Plateau Field Test of Diesel Engine Oils with Different Viscosity Grades  

Science Journals Connector (OSTI)

The degradation of SF/CD 0W/30, CD5W/30 and SF/CD 15W/40 general engine oils has been investigated by Plateau field test with STYER 91 trucks. The experimental results have shown that on the Plateau viscosity grade of the oil hardly impacts on its service ... Keywords: Plateau, field test, viscosity grade, oil, diesel engine

Su Bin; Shi Yonggang; Gong Haifeng; Xu Jinlong; Wei Wei; Mei Lin

2011-01-01T23:59:59.000Z

72

A Multistage Stochastic Programming Approach for the Planning of Offshore Oil or Gas Field Infrastructure  

E-Print Network [OSTI]

1 A Multistage Stochastic Programming Approach for the Planning of Offshore Oil or Gas Field, Houston, TX 77098 Abstract The planning of offshore oil or gas field infrastructure under uncertainty is addressed in this paper. The main uncertainties considered are in the initial maximum oil or gas flowrate

Grossmann, Ignacio E.

73

Understanding Sectoral Labor Market Dynamics: An Equilibrium Analysis of the Oil and Gas Field Services  

E-Print Network [OSTI]

Understanding Sectoral Labor Market Dynamics: An Equilibrium Analysis of the Oil and Gas Field examines the response of employment and wages in the US oil and gas ...eld services industry to changes the dynamic response of wages and employment in the U.S. Oil and Gas Field Services (OGFS) industry to changes

Sadoulet, Elisabeth

74

Floating oil production unit slated in small field off Gabon  

SciTech Connect (OSTI)

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.

Not Available

1991-10-14T23:59:59.000Z

75

Multi-level analysis of field synergy in the displacement mechanisms of heavy oil thermal recovery  

Science Journals Connector (OSTI)

One of the major problems of heavy oil thermal recovery is the inadequacy of understanding the multi-field coupling displacement mechanisms to improve the oil production and extraction ratio. From the perspect...

Yang Liu; Qinglin Cheng; Xuxu Wang; Xinyao Xiang

2014-02-01T23:59:59.000Z

76

Promising Aspects of Heavy Oil and Native Asphalt Conversion Under Field Conditions  

Science Journals Connector (OSTI)

Heavy oils and native asphalt commercial field development is concerned with research on different issues, refer to production, transportation and processing. Investigation on the possibility of heavy oils and...

B. P. Tumanyan; G. V. Romanov…

2014-07-01T23:59:59.000Z

77

A Study of Decline Curve Analysis in the Elm Coulee Field  

E-Print Network [OSTI]

In the last two years, due in part to the collapse of natural gas prices, the oil industry has turned its focus from shale gas exploration to shale oil/tight oil. Some of the important plays under development include the Bakken, Eagle Ford...

Harris, Seth C

2013-08-22T23:59:59.000Z

78

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

SciTech Connect (OSTI)

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.

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

2002-09-30T23:59:59.000Z

79

Archaeoglobus fulgidus Isolated from Hot North Sea Oil Field Waters  

Science Journals Connector (OSTI)

...hydrothermal systems near Mexico (6). The sulfate-reducing...generation of H2S in geothermal heated oil wells when suitable substrates...and steel alloys in oil wells and in the oil-processing...in the production well head or in the oil-water...

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

1994-04-01T23:59:59.000Z

80

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

Science Journals Connector (OSTI)

An Efficient Multiperiod MINLP Model for Optimal Planning of Offshore Oil and Gas Field Infrastructure ... Offshore oil and gas field development represents a very complex problem and involves multibillion dollar investments and profits (Babusiaux et al.(1)). ... This paper focuses on a nonconvex MINLP model for the strategic/tactical planning of the offshore oil and gas fields, which includes sufficient details to make it useful for realistic oilfield development projects, as well as for extensions to include fiscal and uncertainty considerations. ...

Vijay Gupta; Ignacio E. Grossmann

2012-04-07T23:59:59.000Z

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


81

Uncertainty of Oil Field GHG Emissions Resulting from Information Gaps: A Monte Carlo Approach  

Science Journals Connector (OSTI)

Uncertainty of Oil Field GHG Emissions Resulting from Information Gaps: A Monte Carlo Approach ... 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. ...

Kourosh Vafi; Adam R. Brandt

2014-08-10T23:59:59.000Z

82

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

E-Print Network [OSTI]

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

Wang, Jianwei

2010-01-14T23:59:59.000Z

83

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

SciTech Connect (OSTI)

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

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

1985-02-01T23:59:59.000Z

84

Oil field waste disposal in salt caverns: An information website  

SciTech Connect (OSTI)

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.

Tomasko, D.; Veil, J. A.

1999-12-10T23:59:59.000Z

85

Chemically bonded phosphate ceramic sealant formulations for oil field applications  

DOE Patents [OSTI]

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.

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

2008-10-21T23:59:59.000Z

86

Indexes of pumps for oil field pumping units  

SciTech Connect (OSTI)

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.

Ibragimov, E.S.

1995-07-01T23:59:59.000Z

87

A turbine oil-degrading bacterial consortium from soils of oil fields and its characteristics  

Science Journals Connector (OSTI)

A microbial consortium capable of degrading turbine oil (TuO), which consisted mainly of recalcitrant cycloalkanes and isoalkanes, was obtained from a soil sample collected from oil fields using repeated enrichment. When this consortium, named Atsuta A, was cultured in minimal salts medium containing 0.5% (w/v) TuO, it degraded 90% of TuO at 30 °C and pH 7 over 5 days. Although nine bacterial strains were isolated from the Atsuta A consortium, TuO degradation by the individual isolates and by a mixture of them was negligible. The community structure of the consortium, which was investigated by PCR–denaturing gradient gel electrophoresis (DGGE) targeting 16S rRNA genes, changed significantly during the degradation of TuO. Four major bands (F, K, N and T) out of at least 23 DGGE bands significantly increased in intensity over time during incubation. The DGGE bands F, K and N corresponded to those of previously isolated species. However, DGGE band T did not correspond to any isolated strain. The 16S rRNA gene sequence collected from band T was 98% homologous to that of an unculturable strain belonging to the ?-Proteobacteria. The degradation of TuO in the consortium may occur by cooperation between the unculturable species corresponding to band T and other strains in the consortium, including species corresponding to bands F, K and N.

Hitoshi Ito; Reia Hosokawa; Masaaki Morikawa; Hidetoshi Okuyama

2008-01-01T23:59:59.000Z

88

Tax effects upon oil field development in Venezuela  

E-Print Network [OSTI]

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

Manzano, Osmel

2000-01-01T23:59:59.000Z

89

The Oil Waste History of Smackover Field, Arkansas  

Science Journals Connector (OSTI)

...emulsions resulted in low recovery amounts of pipeline oil, about 30 of the total amount of...Becker, J.-R. (1997). Crude oil waxes, emulsions, and asphaltenes. Tulsa...on stream - a history of Interstate Oil Pipeline Company 1909-1959. Baton Rouge, LA...

Mary L. Barrett

90

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

E-Print Network [OSTI]

geology and gas-phase (methane) seepage for the Coal Oil Point (COP) seep field, one of the worldORIGINAL Geologic control of natural marine hydrocarbon seep emissions, Coal Oil Point seep field constructed from 3D seismic and well data allowed investigation of the relationship between the subsurface

Luyendyk, Bruce

91

A Bayesian Network to Manage Risks of Maritime Piracy against Offshore Oil Fields  

E-Print Network [OSTI]

A Bayesian Network to Manage Risks of Maritime Piracy against Offshore Oil Fields Amal Bouejla1 an innovative solution to the problem of offshore piracy from the perspective of the entire processing chain, offshore oil fields, pirate attacks, Bayesian networks, quantitative and qualitative knowledge

92

NETL: News Release - DOE Project Revives Oil Production in Abandoned Fields  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

4 , 2006 4 , 2006 DOE Project Revives Oil Production in Abandoned Fields on Osage Tribal Lands Novel Oil Recovery Technique Developed Under DOE's Native American Initiative WASHINGTON, DC - A technology developed with U.S. Department of Energy funding has revived oil production in two abandoned oilfields on Osage Indian tribal lands in northeastern Oklahoma, and demonstrated a technology that could add billions of barrels of additional domestic oil production in declining fields. Production has jumped from zero to more than 100 barrels of oil per day in the two Osage County, Okla., fields, one of which is more than 100 years old. The technology was successfully pilot-tested in the century-old field, and using the knowledge gained, the technology was applied to a neighboring field with comparable success. This suggests that such approaches could revitalize thousands of other seemingly depleted oilfields across America's Midcontinent region.

93

Rosedale Ranch oil field, new shallow pay in an old field  

SciTech Connect (OSTI)

The Rosedale Ranch oil field, located on Sec. 1,2, T29S, R26E, in Kern County, California, was discovered by Chevron in 1959. The main pay zone was the Miocene Lerdo sandstone at 4,400 ft depth. Sixty-four wells have been drilled to date by Chevron to develop the lower zone. Five wells were completed in the shallower Pliocene Etchegoin Formation. Nahama and Weagant Energy Company in 1985 drilled 3,800 ft well based on a prospect by consultant Ernie Rennie to test the Etchegoin, resulting in a discovery. a total of 13 wells have been drilled to date producing approximately 500 BOPD from the Etchegoin with additional development potential present. The completion technique proved to be critical to good initial production. Nahama and Weagant Energy Company tried slotted lines against the formation with poor results. Subsequent recompletions with undereaming, gravelpacking, and larger slotted lines have resulted in commercial rates out of the Etchegoin. The Rosedale Ranch oil field is located on a faulted anticlinal structure. The main fault is north-trending down to the basin normal fault. Oil produced from the Etchegoin is 13{degree} gravity.

Nahama, R.; Sterling, R. (Nahama and Weagant Energy Co., Bakersfield, CA (United States))

1991-02-01T23:59:59.000Z

94

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

SciTech Connect (OSTI)

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.

Scott Hara

2001-06-27T23:59:59.000Z

95

INCREASED OIL RECOVERY FROM MATURE OIL FIELDS USING GELLED POLYMER TREATMENTS  

SciTech Connect (OSTI)

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

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

2003-05-01T23:59:59.000Z

96

Bayesian Networks in the Management of Oil Field Piracy Risk  

E-Print Network [OSTI]

for the extraction, processing and temporary storage of crude oil and on the other hand, shipping capable production. This energy resource, despite its scarcity, is being explored in many areas, some of which in the offshore oil and gas industry find themselves helpless. The attacks carried out against them generate

Paris-Sud XI, Université de

97

Stochastic Programming Approach for the Planning of Offshore Oil or Gas Field Infrastructure under Decision-Dependent Uncertainty  

Science Journals Connector (OSTI)

Stochastic Programming Approach for the Planning of Offshore Oil or Gas Field Infrastructure under Decision-Dependent Uncertainty ... The planning of offshore oil or gas field infrastructure under uncertainty is addressed in this article. ... An Efficient Multiperiod MINLP Model for Optimal Planning of Offshore Oil and Gas Field Infrastructure ...

Bora Tarhan; Ignacio E. Grossmann; Vikas Goel

2009-02-23T23:59:59.000Z

98

CO2 Enhanced Oil Recovery Feasibility Evaluation for East Texas Oil Field  

E-Print Network [OSTI]

Carbon dioxide enhanced oil recovery (CO2-EOR) has been undergoing for four decades and is now a proven technology. CO2-EOR increases oil recovery, and in the meantime reduces the greenhouse gas emissions by capture CO2 underground. The objectives...

Lu, Ping

2012-08-31T23:59:59.000Z

99

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

E-Print Network [OSTI]

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

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

100

Dobson Butte field, Williston basin, Stark County, North Dakota: nontypical oil production  

SciTech Connect (OSTI)

The Dobson Butte field (T139N, R96W), Stark County, North Dakota, was discovered in 1982 following a detailed seismic program. Production is primarily from a structural trap in the Interlake Formation of Silurian age. Three oil wells are presently producing from a dolomite reservoir at about 11,000 ft in depth. Primary recoverable reserves of these three producing wells is calculated to be about 2 million bbl of oil. Additional reserves will come from further development of the Interlake reservoir as well as from the deeper Red River (Ordovician) Formation. The Dobson Butte field is a nontypical oil field within the Williston basin as to its high pour point oil (90/sup 0/F), high production water cuts (85-95%), lack of good oil shows in samples, unpredictable noncontinuous oil-producing reservoirs throughout the entire 600-ft Interlake Formation, difficulty in log interpretations, and difficulty in determining the source bed. The interpretation of these nontypical characteristics of Interlake oil production in the Dobson Butte field compared to other Interlake oil production within the Williston basin will have a profound effect upon future Interlake exploration.

Guy, W.J.

1987-05-01T23:59:59.000Z

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


101

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

E-Print Network [OSTI]

UK Oil and Gas Collaborative Doctoral Training Centre (2014 start) Project Title: Environmental assessment of deep-water sponge fields in relation to oil and gas activity: a west of Shetland case study industry and government identified sponge grounds in areas of interest to the oil and gas sector

Henderson, Gideon

102

Survey of tar sand deposits, heavy oil fields, and shallow light oil fields of the United States for underground coal gasification applications  

SciTech Connect (OSTI)

A literature survey was conducted to identify areas of the United States where tar sand deposits, heavy oil fields, or shallow light oil fields might be suitably associated with coal deposits for production of oil by in situ thermal recovery methods using heat derived from underground coal gasification (UCG) processes. The survey is part of a Department of Energy-sponsored program to develop new applications for UCG technology in utilizing coal resources that are unattractive for mining. Results from the survey indicate tar sand deposits, heavy oil fields, or light oil fields are probably or possibly located within 5 miles of suitable coal in 17 states (Table 1). Especially promising areas are in the Uinta Basin of Utah; the North Slope of Alaska; the San Miguel deposit in southwest Texas; the Illinois-Eastern Interior Basin area of western Kentucky, southwestern Indiana and Illinois; the tri-state area of Missouri, Kansas and Oklahoma; and the northern Appalachian Basin in eastern Ohio and northwestern Pennsylvania. The deposits in these areas warrant further evaluation. 30 refs., 4 figs., 1 tab.

Trudell, L.G.

1986-06-01T23:59:59.000Z

103

Neutron scattering studies of crude oil viscosity reduction with electric field  

Science Journals Connector (OSTI)

Abstract 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.

R. Tao; E. Du; H. Tang; X. Xu

2014-01-01T23:59:59.000Z

104

Magnetic signature of hydrocarbon-contaminated soils and sediments at the former oil field Hänigsen, Germany  

Science Journals Connector (OSTI)

Magnetic properties of hydrocarbon (HC) containing soils and sediments from two sites (Site A and B) of the former oil-field Hänigsen were analyzed in order to determine whether magnetic methods can be employe...

Moti L. Rijal; Katharina Porsch; Erwin Appel…

2012-07-01T23:59:59.000Z

105

Abandoned oil fields in Alabama, Florida, Illinois, Indiana, Kentucky, Michigan, Missouri, New York, Tennessee and West Virginia  

SciTech Connect (OSTI)

Data are presented for approximately 240 abandoned oil fields in Alabama, Florida, Illinois, Indiana, Kentucky, Michigan, Missouri, New York, Tennessee, and West Virginia. Production data were not available on a majority of abandoned fields in New York, Missouri, and Kentucky. Consequently, some fields with less than 10,000 barrels cumulative production are included. The following information is presented for each field: county; DOE field code; field name; AAPG geologic province code; discovery date of field; year of last production; discovery well operator; proven acreage; formation thickness; depth of field; gravity of oil production; calendar year; yearly field oil production; yearly field gas production; cumulative oil production; cumulative gas production; number abandoned fields in county; cumulative production of oil from fields; cumulative production of gas from fields. (ATT)

Not Available

1983-04-01T23:59:59.000Z

106

Optimization of offshore oil and gas field development using mathematical programming  

E-Print Network [OSTI]

OPTIMIZATION OF OFFSHORE OIL AND GAS FIELD DEVELOPMENT USING MATHEMATICAL PROGRAMMING A Thesis by TODD THATCHER GRIMMETT Submitted to the Graduate College of Texas A6M University in partial fulfillment of the requirements for the degree... of MASTER OF SCIENCE August 1986 Major Subject: Petroleum Engineering OPTIMIZATION OF OFFSHORE OIL AND GAS FIELD DEVELOPMENT VSING MATHEMATICAL PROGRAMMING A Thesis by TODD THATCHER GRIMMETT Approved as to style and content by: R. A. Startzma...

Grimmett, Todd Thatcher

2012-06-07T23:59:59.000Z

107

Sequence stratigraphy, depositional environments, and regional mapping of the late Devonian interval, upper Three Forks Formation, Sanish Member, and lower Bakken Shale, U.S. portion of the Williston Basin.  

E-Print Network [OSTI]

??Cores of the Late Devonian upper Three Forks, Sanish, and lower Bakken units from eight wells were examined and described at the North Dakota core… (more)

Sesack, Steven A.

2011-01-01T23:59:59.000Z

108

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

SciTech Connect (OSTI)

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

Unknown

2001-08-08T23:59:59.000Z

109

Preliminary Study of In-situ Combustion in Heavy Oil Field in the North of Thailand  

Science Journals Connector (OSTI)

A small oil field in the north of Thailand has medium viscous and low gas-content heavy oil. Since conventional production methods are ineffective, thermal recovery is potentially suitable to enhance oil recovery for this reservoir. In -situ combustion is a complex EOR process used for medium to heavy crude oils. The process involves the multi-phase fluid flow through porous media with chemical and physical transition of the crude oil components under high temperature and pressure conditions. The simulation results with STARS were investigated by conducting a number of sensitivity studies with varying the parameters like gridblock sizes, air-injection rates, oxygen concentrations, and injected air temperature. The 0.5m-block size was chosen due to the optimum running time with acceptable accuracy. From the results, it can be concluded that changing injection rate from 100 Mscf/d to 400 Mscf/d does not significantly affect cumulative oil production – less than 6% incremental recovery. Increase oxygen concentration from 29% to 100% shows an increase in 40.67% oil production. Moreover, if the injected fluid temperature is increased from 80?F to 500?F, total oil production increases 97.14%. Furthermore, optimal operating conditions to enhance recovery of oil were also studied.

Kreangkrai Maneeintr et al

2013-01-01T23:59:59.000Z

110

Statistical model for source rock maturity and organic richness using well-log data, Bakken Formation, Williston basin, United States  

SciTech Connect (OSTI)

A study of the Bakken Formation, the proposed source rock for much of the hydrocarbons generated in the Williston basin, was done using bulk density, neutron porosity, and resistivity logs, and formation temperatures. Principal components, cluster, and discriminant analyses indicate that the present-day distribution of organic matter controls much of the variability in the log values. Present-day total organic carbon values are high in the central part of the basin near northeastern Montana and along the east edge of the basin, and low in the area of the Nesson anticline and along the southwest edge of the basin. Using a regression of density on temperature and the analysis of residuals from this regression, hydrocarbon maturity effects were partially separated from depositional effects. These analyses suggest that original concentrations of organic matter were low near the limits of the Bakken and increased to a high in northeastern Montana. The pre-maturation distribution of total organic carbon and the present-day total organic carbon distribution, as determined by statistical analyses of well-log data, agree with the results of geochemical analyses. The distributions can be explained by a relatively simple depositional pattern and thermal history for the Bakken. 6 figures, 3 tables.

Krystinik, K.B.; Charpentier, R.R.

1987-01-01T23:59:59.000Z

111

NETL: Oil & Natural Gas Projects 00516 North Dakota Refining Capacity Study  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

North Dakota Refining Capacity Study North Dakota Refining Capacity Study DE-FE0000516 Goal The objective of the North Dakota Refining Capacity study is to assess the feasibility of increasing the oil refinery capacity in North Dakota, and, if possible, determine the scale of such an expansion, the slate of refined product(s) that would produce the most economic benefit, and the preferred ownership model, i.e., private, public or private-public. Performer North Dakota Association of Rural Electric Cooperatives (NDAREC) Corval Group, partnered with Purvin & Gertz and Mustang Engineering Background The genesis of this study came from an April 2008 report issued by the U.S. Geological Survey (USGS) asserting that North Dakota and Montana have an estimated 3.0 to 4.3 billion barrels of undiscovered, technically recoverable oil in an area known as the Bakken Formation. This assessment shows a 25-fold increase in the amount of recoverable oil compared to the USGS 1995 estimate of 151 million barrels of oil. The Bakken Formation estimate is larger than all other current USGS oil assessments of the lower 48 states and is the largest "continuous" oil accumulation ever assessed by the USGS. The new report points out that the new geologic models applied to the Bakken Formation, advances in drilling and production technologies, and recent oil discoveries have resulted in these substantially larger technically recoverable oil volumes. About 105 million barrels of oil were produced from the Bakken Formation by the end of 2007. In 2008, the formation produced another 27.2 million barrels of oil, which represented 43% of the stateÂ’s annual oil production of some 62.3 million barrels. Even though oil prices have dropped significantly in recent months, it appears that oil production from this formation will continue strong for decades to come. Most recently, a major production find has occurred in the Three Forks formation underlying the Bakken. This find is still undergoing significant testing, but early evidence suggests it represents another significant recoverable pool of oil in western North Dakota.

112

Play analysis and stratigraphic position of Uinta Basin tertiary - age oil and gas fields  

SciTech Connect (OSTI)

Tertiary-age sediments in the Uinta basin produce hydrocarbons from five types of plays. These play types were determined by hydrocarbon type, formation, depositional environment, rock type, porosity, permeability, source, and per-well recovery. Each well was reviewed to determine the stratigraphic position and producing characteristics of each producing interval. The five types of plays are as follows: (1) naturally fractured oil reservoirs, (2) low-permeability oil reservoirs, (3) high-permeability of oil reservoirs, (4) low-permeability gas reservoirs, and (5) tight gas sands. Several fields produce from multiple plays, which made it necessary to segregate the hydrocarbon production into several plays. The stratigraphic position of the main producing intervals is shown on a basin-wide cross section, which is color-coded by play type. This 61-well cross section has several wells from each significant Tertiary oil and gas field in the Uinta basin.

Williams, R.A. (Pennzoil Exploration and Production Co., Houston, TX (United States))

1993-08-01T23:59:59.000Z

113

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

Science Journals Connector (OSTI)

Weathered crude oil contaminated soils (COCSs), which are much more difficult to remediate than those freshly contaminated, are widespread especially at the sites of oil fields and industries. Surfactant enhanced ex situ soil washing could be used to remediate COCSs, but surfactant toxicity becomes one of the major concerns. In this study, a class of green surfactants, alkyl polyglucosides (APGs), were tested in washing the field weathered COCS with relatively high oil concentration (123 mg g?1 dry soil) from Jilin Oilfield, Northeastern China. APG1214, characterized with longer alkyl chain, was more effective than APG0810 in crude oil removal. Adding inorganic sodium salts into APG1214 solution further improved the crude oil removal efficiency (CORE). Washing parameters (temperature, washing time, agitation speed and solution/soil ratio) were investigated and further optimized integratedly with an orthogonal design. At the optimum conditions, the CORE reached 97%. GC/MS analysis showed that the proportion of small n-alkanes (C16–C23) in residual crude oil gradually increased, which was helpful to interpret the oil removal mechanism. Moreover, eminent effect on removal of large n-alkanes was achieved from the synergy between APG1214 and inorganic salts, which was opposite to the effect when they were added separately. This study demonstrated a promising way to remediate COCS with ecologically compatible surfactant and provided guidelines for its practical application.

Mei Han; Guodong Ji; Jinren Ni

2009-01-01T23:59:59.000Z

114

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

SciTech Connect (OSTI)

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.

Thorsness, C. B., LLNL

1997-01-21T23:59:59.000Z

115

Increased oil recovery from mature oil fields using gelled polymer treatments  

SciTech Connect (OSTI)

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.

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

2000-02-23T23:59:59.000Z

116

New information on disposal of oil field wastes in salt caverns  

SciTech Connect (OSTI)

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.

Veil, J.A.

1996-10-01T23:59:59.000Z

117

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

SciTech Connect (OSTI)

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.

Veil, J.A.

1996-10-01T23:59:59.000Z

118

Open-Source LCA Tool for Estimating Greenhouse Gas Emissions from Crude Oil Production Using Field Characteristics  

Science Journals Connector (OSTI)

Open-Source LCA Tool for Estimating Greenhouse Gas Emissions from Crude Oil Production Using Field Characteristics ... OPGEE models oil production emissions in more detail than previous transport LCA models. ... El-Houjeiri, H. and Brandt, A.Exploring the variation of GHG emissions from conventional oil production using an engineering-based LCA model. ...

Hassan M. El-Houjeiri; Adam R. Brandt; James E. Duffy

2013-05-01T23:59:59.000Z

119

Simulation Study of Enhanced Oil Recovery by ASP (Alkaline, Surfactant and Polymer) Flooding for Norne Field C-segment.  

E-Print Network [OSTI]

?? This research is a simulation study to improve total oil production using ASP flooding method based on simulation model of Norne field C-segment. The… (more)

Abadli, Farid

2012-01-01T23:59:59.000Z

120

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

SciTech Connect (OSTI)

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.

Veil, J.A. [Argonne National Lab., Washington, DC (United States). Water Policy Program

1997-10-01T23:59:59.000Z

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121

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

SciTech Connect (OSTI)

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 that if caverns are sited and designed well, operated carefully, closed properly, and monitored routinely, they could, from technical and legal perspectives, be suitable for disposing of oil-field wastes. On the basis of these findings, ANL subsequently conducted a preliminary risk assessment on the possibility that adverse human health effects (carcinogenic and noncarcinogenic) could result from exposure to contaminants released from the NOW disposed of in salt caverns. The methodology for the risk assessment included the following steps: identifying potential contaminants of concern; determining how humans could be exposed to these contaminants; assessing contaminant toxicities; estimating contaminant intakes; and estimating human cancer and noncancer risks. To estimate exposure routes and pathways, four 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 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 (for noncancer health effects) estimates that were well within the EPA target range for acceptable exposure risk levels. These results lead to the preliminary conclusion that from a human health perspective, salt caverns can provide an acceptable disposal method for nonhazardous oil-field wastes.

Elcock, D.

1998-03-10T23:59:59.000Z

122

Tertiary development of heavy oil sands through thermal stimulation in the Wilmington Oil Field, California: A geological perspective  

SciTech Connect (OSTI)

In 1995, a DOE cost share project was initiated to extend thermal recovery in the Tar Zone, Fault Block 11 of the West Wilmington Oil Field, California. The project involved the collection of old oil well data and the construction of a modern digital data base in order to develop a deterministic geological model. The plan was to rigorously define the geology such that horizontal wells could be accurately placed within the sands containing heavy oil to facilitate gravity drainage. A detailed deterministic geological model was constructed using a state of the art 3D mapping and modeling package. Beginning in July, 1995, five observation wells were drilled. Data inconsistencies were revealed when core hole OB2-003 was drilled. It was discovered that the data used to make the maps was corrupted; as a result, the predicted coring point was missed by more than 20'. Significant modifications to the data base were required due to inaccurate subsidence corrections in the original data set. Horizontal wells were then laid out based on the revised data and the geological model was completely reconstructed. Detailed cross sections extracted from the model were use for geosteering. These cross sections proved to be highly accurate and five more wells are now planned for the target sands. This detailed deterministic model will be further refined and combined with our geostatistical mode for geological control in an advanced reservoir simulator. If successful, the thermal stimulation project will be expanded to other fault blocks.

Clarke, D.D. (Department of Oil Properties, Long Beach, CA (United States)); Henry, M.J.; Strehle, R.W. (Dept. of Oil Properties, Long Beach, CA (United States))

1996-01-01T23:59:59.000Z

123

Tertiary development of heavy oil sands through thermal stimulation in the Wilmington Oil Field, California: A geological perspective  

SciTech Connect (OSTI)

In 1995, a DOE cost share project was initiated to extend thermal recovery in the Tar Zone, Fault Block 11 of the West Wilmington Oil Field, California. The project involved the collection of old oil well data and the construction of a modern digital data base in order to develop a deterministic geological model. The plan was to rigorously define the geology such that horizontal wells could be accurately placed within the sands containing heavy oil to facilitate gravity drainage. A detailed deterministic geological model was constructed using a state of the art 3D mapping and modeling package. Beginning in July, 1995, five observation wells were drilled. Data inconsistencies were revealed when core hole OB2-003 was drilled. It was discovered that the data used to make the maps was corrupted; as a result, the predicted coring point was missed by more than 20`. Significant modifications to the data base were required due to inaccurate subsidence corrections in the original data set. Horizontal wells were then laid out based on the revised data and the geological model was completely reconstructed. Detailed cross sections extracted from the model were use for geosteering. These cross sections proved to be highly accurate and five more wells are now planned for the target sands. This detailed deterministic model will be further refined and combined with our geostatistical mode for geological control in an advanced reservoir simulator. If successful, the thermal stimulation project will be expanded to other fault blocks.

Clarke, D.D. [Department of Oil Properties, Long Beach, CA (United States); Henry, M.J.; Strehle, R.W. [Dept. of Oil Properties, Long Beach, CA (United States)

1996-12-31T23:59:59.000Z

124

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

SciTech Connect (OSTI)

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

Scott Hara

2004-03-05T23:59:59.000Z

125

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

SciTech Connect (OSTI)

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

Scott Hara

2003-09-04T23:59:59.000Z

126

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

SciTech Connect (OSTI)

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

Scott Hara

2003-06-04T23:59:59.000Z

127

Little Knife field - US Williston basin  

SciTech Connect (OSTI)

Little Knife field is a combination structural and stratigraphic trap located near the structural center of the Williston basin, North Dakota. The field is approximately 12 mi (19.3 km) long and 2.5 to 5.5 mi (4 to 8.9 km) wide. Little Knife was discovered by Gulf Oil in 1976 as part of a regional exploration play involving a transition from impermeable to porous carbonate rocks. In 1987, ultimate recovery from the Mission Canyon (Mississippian) reservoir was estimated to be 97.5 MMBO. This included 57.5 MMBO primary, 27 MMBO secondary, and 13 MMBO tertiary (CO{sub 2}) oil. At present the field is still under primary recovery, since utilization efforts have not been successful. Approximately one-third of Little Knife's 130 ft (39.6 m) oil column is trapped by structural closure beneath a regional anhydrite seal in a north-south-trending anticline. The remaining two-thirds of the oil column is trapped where the reservoir beds change facies from porous dolostones and dolomitic limestones to nonporous limestones. Structural entrapment accounts for approximately 50% (127 MMBO) of the OOIP, but covers only 30% of the producing area. Production is from the upper portions of the Mission Canyon Formation, a regressive, shoaling-upward carbonate-anhydrite sequence deposited in a slowly shrinking epeiric sea. The Mission Canyon in the Little Knife area is divided into six zones that record predominantly cyclic, subtidal deposition. These are overlain by prograding lagoonal, tidal flat, and sabkha beds. The source of Mission Canyon oil is thought to be the Bakken Formation, an organic-rich shale at the base of the Mississippian.

Wittstrom, M.D.; Lindsay, R.F. (Chevron USA, Inc., Midland, TX (United States))

1991-03-01T23:59:59.000Z

128

Citronelle Oil Field north of Mobile, Alabama. The project will capture  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

Citronelle Oil Field north of Mobile, Alabama. The project will capture Citronelle Oil Field north of Mobile, Alabama. The project will capture approximately 150,000 tons of CO 2 per year from Alabama Power's Plant Barry (a total equivalent to the emissions from 25 megawatts of the plant's generating capacity) and inject the CO 2 into a deep saline reservoir 9,000 feet beneath the surface. Under the plan, the CO 2 will be transported by pipeline and injected into the saline formation, which has oil-bearing formations both above and below its location. A monitoring, verification, and accounting (MVA) program will be conducted to track the movement of the injected CO 2 and ensure that it is safely and permanently stored. The project will commence in 2011 and is expected to last up to four years. This test site was selected by

129

Analysis of horizontal and vertical in-situ oil-shale retorting: comparison of field experiments  

SciTech Connect (OSTI)

Currently two different processing techniques are utilized for in situ oil shale retorting. Horizontal In Situ (HIS), in which the retort front moves parallel to the shale bedding planes, is being utilized on relatively thin, near-surface oil shale. Vertical Modified In Situ (VMIS), in which the retort front moves perpendicular to the shale bedding planes, is being utilized for thicker deposits of shale at greater depths. While chemical effects in the two processes should be similar, physical phenomena (such as fluid product flow and heat transfer) can be substantially different due to gravity and anisotropic shale properties associated with the shale bedding planes. To illustrate both similarities between the processes and some striking differences, we present thermal data (detailing movement of the steam and retorting fronts) and offgas and oil analysis data (allowing material and energy balance closures) from two recent field experiments, Sandia/Geokinetics Retort 23 (HIS) and Occidental Retort 8 (VMIS). These data show, for example, a broader combustion front in the horizontal process, resulting in a lower thermal efficiency. However, because of a lower shale grade in the VMIS experiment, local oil yield (50 to 60% of Fischer Assay) was similar in the two experiments, with roughly two-thirds of the loss to oil combustion and one-third to oil coking and cracking reactions.

Tyner, C.E.; Bickel, T.C.; Stevens, A.L.; Lekas, J.M.

1983-01-01T23:59:59.000Z

130

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

SciTech Connect (OSTI)

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

NONE

1998-03-01T23:59:59.000Z

131

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

SciTech Connect (OSTI)

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

Not Available

1994-07-08T23:59:59.000Z

132

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

E-Print Network [OSTI]

The main objectives of this study are to determine the most suitable type of gas for a water-alternating-gas (WAG) injection scheme, the WAG cycle time, and gas injection rate to increase oil production rate and recovery from the San Francisco field...

Rueda Silva, Carlos Fernando

2012-06-07T23:59:59.000Z

133

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

E-Print Network [OSTI]

million gallons of South Louisiana crude into the northern Gulf of Mexico (nGOM) [1,2]. Several field Science Foundation (www.NSF.gov) (DEB-1120512 and DEB-1048206 to A.W.) and the Gulf of Mexico Research studies to date have investigated the direct impacts of crude oil on native wildlife species

Whitehead, Andrew

134

Prediction for wax deposition in oil pipelines validated by field pigging  

Science Journals Connector (OSTI)

Abstract The deposition of wax in oil pipelines presents a costly production and transportation problem. The deposited wax is removed periodically by pigging operation in field. In this study, in order to understand this problem and address it, a series of wax deposition experiments involved the sloughing effect was performed in the laboratory flow loop, and a model was established to predict the wax deposition distribution along the pipeline. These results were used to implement a pigging program. In addition, a practical experimental method by testing the viscosity of deposit-in-oil slurry ahead of the pig was specially designed to measure the volume of deposit during pigging in actual field. The model predictions agreed with the field measured results excellently with a relative error being ?10.9%. Of more importance, some pigging issues are discussed in combination with the data from the laboratory simulations and field pigging operation.

Wenda Wang; Qiyu Huang

2014-01-01T23:59:59.000Z

135

Diversity analyses of microbial communities in petroleum samples from Brazilian oil fields  

Science Journals Connector (OSTI)

Recent studies of oil fields have shown that the microbial diversity is represented by bacteria and archaea of wide distribution, and that many of these organisms have potential to metabolize organic and inorganic compounds. Biodegradation processes in oil industry are of great relevance, since it may be related with the loss of petroleum quality and can bring problems during production. The aim of this study was to compare the microbial communities present in biodegraded (GMR75) and non-biodegraded (PTS1) terrestrial oils from the Potiguar Basin (RN, Brazil) by using cultivation (microbial enrichments and isolation) and molecular approaches (16S rRNA gene libraries). The cultivated microorganisms recovered were affiliated with the phyla Actinobacteria, Firmicutes and Proteobacteria. Both bacterial 16S rRNA gene libraries revealed a great diversity, encompassing representatives from 8 different phyla (Actinobacteria, Bacteroidetes, Deferribacteres, Spirochaetes, Firmicutes, Proteobacteria, Thermotogae and Synergistetes) for the GMR75 sample, and from 5 different phyla (Actinobacteria, Chloroflexi, Firmicutes, Proteobacteria and Thermotoga) for the PTS1 sample. The archaeal 16S rRNA gene library was obtained only for GMR75 oil and all phylotypes were affiliated with the family Methanomicrobiaceae. Diversity results suggest that methanogenesis is the dominant terminal process for hydrocarbon degradation in GMR oil field, driven by anaerobic biodegradation.

T.R. Silva; L.C.L. Verde; E.V. Santos Neto; V.M. Oliveira

2013-01-01T23:59:59.000Z

136

Development of Improved Oil Field Waste Injection Disposal Techniques  

SciTech Connect (OSTI)

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.

Terralog Technologies

2002-11-25T23:59:59.000Z

137

A chemical kinetic model of hydrocarbon generation from the Bakken Formation, Williston Basin, North Dakota  

SciTech Connect (OSTI)

This report describes a model of hydrocarbon generation and expulsion in the North Dakota portion of the Williston Basin. The modeling incorporates kinetic methods to simulate chemical reactions and 1-dimensional conductive heat flow models to simulate thermal histories of the Mississippian-Devonian Bakken Formation source rock. We developed thermal histories of the source rock for 53 wells in the basin using stratigraphic and heat flow data obtained by the University of North Dakota. Chemical kinetics for hydrocarbon generation, determined from Pyromat pyrolysis, were, then used with the diennal histories to calculate the present day value of the Rock-Eval T{sub max} for each well. The calculated Rock-Eval T{sub max} values agreed with measured values within amounts attributable to uncertainties in the chemical kinetics and the heat flow. These optimized thermal histories were then used with a more detailed chemical kinetic model of hydrocarbon generation and expulsion, modified from a model developed for the Cretaceous La Luna shale, to simulate pore pressure development and detailed aspects of the hydrocarbon chemistry. When compared to values estimated from sonic logs, the pore pressure calculation underestimates the role of hydrocarbon generation and overestimates the role of compaction disequilibrium, but it matches well the general areal extent of pore pressures of 0.7 times lithostatic and higher. The simulated chemistry agrees very well with measured values of HI, PI, H/C atomic ratio of the kerogen, and Rock-Eval S1. The model is not as successful in simulating the amount of extracted bitumen and its saturate content, suggesting that detailed hydrous pyrolysis experiments will probably be needed to further refine the chemical model.

Sweeney, J.J.; Braun, R.L.; Burnham, A.K. [Lawrence Livermore National Lab., CA (United States); Gosnold, W.D. [North Dakota Univ., Grand Forks, ND (United States)

1992-10-01T23:59:59.000Z

138

Short-Term Energy Outlook Supplement: Status of Libyan Loading Ports and Oil and Natural Gas Fields  

Gasoline and Diesel Fuel Update (EIA)

Short-Term Energy Outlook Supplement: Short-Term Energy Outlook Supplement: Status of Libyan Loading Ports and Oil and Natural Gas Fields Tuesday, September 10, 2013, 10:00AM EST Overview During July and August 2013, protests at major oil loading ports in the central-eastern region of Libya forced the complete or partial shut-in of oil fields linked to the ports. As a result of protests at ports and at some oil fields, crude oil production fell to 1.0 million barrels per day (bbl/d) in July and 600,000 bbl/d in August, although the production level at the end of August was far lower. At the end of August, an armed group blocked pipelines that connect the El Sharara and El Feel (Elephant) fields to the Zawiya and Mellitah export terminals, respectively, forcing the shutdown of those fields. El Sharara had been

139

Pore-Level Modeling of Carbon Dioxide Sequestration in Oil Fields: A study of viscous and buoyancy forces  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

Sequestration in Oil Fields: A Sequestration in Oil Fields: A study of viscous and buoyancy forces Grant S. Bromhal, U.S. Department of Energy, National Energy Technology Laboratory, Morgantown, WV 26507-0880, gbromhal@netl.doe.gov, M. Ferer, Department of Physics, West Virginia University, and Duane H. Smith, U.S. Department of Energy, National Energy Technology Laboratory, Morgantown, WV 26507-0880 Underground injection of carbon dioxide for enhanced oil recovery (EOR) is a common practice in the oil and gas industry and has often been cited as a proven method of sequestering CO 2 (US DOE, 1999). Of all sequestration methods, this is probably the best understood, as carbon dioxide has been used in the oil industry for many years. Additionally, most oil fields have been relatively well characterized geologically, and

140

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

SciTech Connect (OSTI)

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.

Eric P. Robertson

2007-11-01T23:59:59.000Z

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


141

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

SciTech Connect (OSTI)

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.

Scott Hara

2001-05-07T23:59:59.000Z

142

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

SciTech Connect (OSTI)

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

Scott Hara

1997-08-08T23:59:59.000Z

143

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

SciTech Connect (OSTI)

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

Scott Hara

1998-03-03T23:59:59.000Z

144

Increasing Heavy Oil Reservers in the Wilmington Oil field Through Advanced Reservoir Characterization and Thermal Production Technologies  

SciTech Connect (OSTI)

The project involves improving thermal recovery techniques in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., Calif. using advanced reservoir characterization and thermal production technologies. The existing steamflood in the Tar zone of Fault Block (FB) 11-A has been relatively inefficient because of several producibility problems which are common in SBC reservoirs. Inadequate characterization of the heterogeneous turbidite sands, high permeability thief zones, low gravity oil, and nonuniform distribution of remaining oil have all contributed to poor sweep efficiency, high steam-oil ratios, and early steam breakthrough. Operational problems related to steam breakthrough, high reservoir pressure, and unconsolidated formation sands have caused premature well and downhole equipment failures. In aggregate, these reservoir and operational constraints have resulted in increased operating costs and decreased recoverable reserves. The advanced technologies to be applied include: (1) Develop three-dimensional (3-D) deterministic and stochastic geologic models. (2) Develop 3-D deterministic and stochastic thermal reservoir simulation models to aid in reservoir management and subsequent development work. (3) Develop computerized 3-D visualizations of the geologic and reservoir simulation models to aid in analysis. (4) Perform detailed study on the geochemical interactions between the steam and the formation rock and fluids. (5) Pilot steam injection and production via four new horizontal wells (2 producers and 2 injectors). (6) Hot water alternating steam (WAS) drive pilot in the existing steam drive area to improve thermal efficiency. (7) Installing a 2100 foot insulated, subsurface harbor channel crossing to supply steam to an island location. (8) Test a novel alkaline steam completion technique to control well sanding problems and fluid entry profiles. (9) Advanced reservoir management through computer-aided access to production and geologic data to integrate reservoir characterization, engineering, monitoring, and evaluation.

Hara, Scott [Tidelands Oil Production Co., Long Beach, CA (United States)

1997-05-05T23:59:59.000Z

145

Oil-field disposal practices in hydrogeologic setting of Midway Sunset and Buena Vista oil fields; review of past effects, current activities, and future scenarios  

SciTech Connect (OSTI)

Class 2 water disposal in the Midway Sunset and Buena Vista oil fields of Kern County, California, has been by injection and infiltration from spreading ponds into the unsaturated zone, which is typically hundreds of feet thick. Water collection is mostly through an extensive tributary network of collection ditches radiating from several disposal facility locations. The purpose of this study was to evaluate the subsurface movement of fluid in the hydrogeological environment and to determine the fate of the disposed water and its long-term impact on the area.

Sengebush, R.M.; Kiser, S.C.; Greenwood, E.J.; Crozier, R.N.; Crewdson, R.A.; Wilson, M.J.; Rycerski, B.A.

1988-03-01T23:59:59.000Z

146

Williston basin oil exploration: Past, present, and future  

SciTech Connect (OSTI)

Past: In 1951, modern oil exploration came to the Williston basin with the discovery of Paleozoic oil on the large Nesson anticline. This was quickly followed by similar discoveries on Cedar Creek and Poplar anticlines. To the north, the Canadians, lacking large structures, concentrated on Paleozoic stratigraphic traps and were highly successful. US explorationists quickly followed, finding similar traps on the basin's northeastern flank and center. The 1960s saw multiple Devonian salt dissolution structures produce on the western flank. To the northwest, shallow Mississippian and deeper Ordovician pays were found on small structural closures. These later were combined with pays in the Devonian and Silurian to give multiple pay potential. In the basin center large buried structures, visible only to seismic, were located. The 1970s revealed an Ordovician subcrop trap on the southeast flank. Centrally, a Jurassic astrobleme with Mississippian oil caused a flurry of leasing and deep drilling. The 1982 collapse of oil prices essentially halted exploration. 1987 saw a revival when horizontal drilling for the Mississippian Bakken fractured shale promised viable economics. Present: Today, emphasis is on Bakken horizontal drilling in the deeper portion of the basin. Next in importance is shallow drilling such as on the northeastern flank. Future: An estimated on billion barrels of new oil awaits discovery in the Williston basin. Additional exploration in already established production trends will find some of this oil. Most of this oil, however, will almost certainly be found by following up the numerous geological leads hinted at by past drilling.

Jennings, A.H.

1991-06-01T23:59:59.000Z

147

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

E-Print Network [OSTI]

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

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

2014-12-11T23:59:59.000Z

148

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

E-Print Network [OSTI]

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

Varshney, Atul; Ghosh, Shankar; Yethiraj, Anand; Bhattacharya, S; Joshi, J B

2014-01-01T23:59:59.000Z

149

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

SciTech Connect (OSTI)

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.

Baroni, M. [American Oil Recovery, Inc., Decatur, IL (United States)

1995-09-01T23:59:59.000Z

150

Improved reservoir management of heavy oil assets using biomarker variability in sidewall cores and produced oils: An example from the Cymric Field, Kern County, California  

SciTech Connect (OSTI)

Development of biodegraded oil accumulations can be optimized by using geochemical indicators of variations in the extent of biodegradation. Biodegradation typically reduces oil producibility by increasing oil viscosity. Using the Cymric Field (Kern County, California), we show that the extent of oil biodegradation can change substantially over extremely short vertical distances (feet) in shallow, low-permeability reservoirs. These variations can be mapped laterally for more than a mile using reservoir sidewall core extract compositions. The relationship between oil viscosity and biomarker biodegradation parameters can be calibrated from analyses of produced oils. These relationships can then be used to convert sidewall core biomarker parameters into quantitative predictions of lateral and vertical changes in oil viscosity and gravity. These compositional variations can be used to optimize the placement of new wells and well completion intervals, as well as to assess the relative production from discrete zones. We discuss how this new technique can be used to optimize field development, including parameters such as (1) the placement of completion intervals, (2) the thickness of steam injection intervals, and (3) the spacing between injection intervals in the same well.

Legarre, H.A.; Johnson, S.J. (Chevron Production Co., Bakersfield, CA (United States)); McCaffrey, M.A. (Chevron Petroleum Technology, Co., La Habra, CA (United States))

1996-01-01T23:59:59.000Z

151

Improved reservoir management of heavy oil assets using biomarker variability in sidewall cores and produced oils: An example from the Cymric Field, Kern County, California  

SciTech Connect (OSTI)

Development of biodegraded oil accumulations can be optimized by using geochemical indicators of variations in the extent of biodegradation. Biodegradation typically reduces oil producibility by increasing oil viscosity. Using the Cymric Field (Kern County, California), we show that the extent of oil biodegradation can change substantially over extremely short vertical distances (feet) in shallow, low-permeability reservoirs. These variations can be mapped laterally for more than a mile using reservoir sidewall core extract compositions. The relationship between oil viscosity and biomarker biodegradation parameters can be calibrated from analyses of produced oils. These relationships can then be used to convert sidewall core biomarker parameters into quantitative predictions of lateral and vertical changes in oil viscosity and gravity. These compositional variations can be used to optimize the placement of new wells and well completion intervals, as well as to assess the relative production from discrete zones. We discuss how this new technique can be used to optimize field development, including parameters such as (1) the placement of completion intervals, (2) the thickness of steam injection intervals, and (3) the spacing between injection intervals in the same well.

Legarre, H.A.; Johnson, S.J. [Chevron Production Co., Bakersfield, CA (United States); McCaffrey, M.A. [Chevron Petroleum Technology, Co., La Habra, CA (United States)

1996-12-31T23:59:59.000Z

152

Charging of the Penglai 9-1 oil field, Bohai Bay basin, China: Functions of the delta on accumulating petroleum  

Science Journals Connector (OSTI)

Abstract The Penglai 9-1 (PL9-1) oil field, which contains China's third largest offshore oil accumulation (in-place reserves greater than 2.28 × 108 ton or 1.49 × 109 bbl), was found in shallow reservoirs (700–1700 m, 2297–5577 ft) within the most active fault zone in east China. The PL9-1 field contains two oil-bearing series, the granite intrusions in Mesozoic (Mz) and both the sandstone reservoirs in Neogene Guantao (Ng) and Neogene Minghuazhen (Nm) Formation. The origins of the PL9-1 field, both in terms of source rock intervals and generative kitchens, were determined by analyzing biomarker distributions for 61 source rock samples and 33 oil samples. The Mesozoic granite intrusions, which hold more than 80% of the oil reserves in the field, were charged in the west by oil generated from the third member (Es3) of the Shahejie Formation in the Bodong depression. The Neogene reservoirs of the PL9-1 field were charged in the west by oil generated from the third member (Es3) of the Shahejie Formation in the Bodong depression and in the south by oil generated from the first member (Es1) of the Shahejie Formation in the Miaoxibei depression. Interactive contact between the large fan delta and the mature source rocks residing in the Es3 Formation of the Bodong depression resulted in a high expulsion efficiency from the source rocks and rapid oil accumulation in the PL9-1 field, which probably explains how can this large oil field accumulate and preserve within the largest and most active fault zone in east China.

Jinqiang Tian; Fang Hao; Xinhuai Zhou; Huayao Zou; Lei Lan

2014-01-01T23:59:59.000Z

153

Offshore oil: Investigating production parameters of fields of varying size, location and water depth  

Science Journals Connector (OSTI)

Abstract This paper derives empirical estimates of field depletion level, depletion rate, decline rate and characteristic time intervals in offshore oil production based on a global field-by-field database containing 603 offshore oil fields. Statistical distributions as well as arithmetic and weighted averages of production parameters are derived for different categories of fields specified by size, location and water depth. A significant tendency of small fields having higher depletion and decline rates is found. Similarly, OECD countries generally have higher rates compared to non-OECD countries. Trends related to water depth are not clearly distinguishable and require additional investigation of time related aspects. Resulting spreads in derived parameter estimates are found to be well described by positively skewed probability distributions. Also, in line with theory, a strong correlation between depletion and decline rate is found. According to the study, the net share of global offshore production from smaller and deeper fields is increasing. A continuation of these trends would likely have implications for future aggregate offshore production behaviour, most notably, increasing global aggregate decline rates.

David Sällh; Henrik Wachtmeister; Xu Tang; Mikael Höök

2015-01-01T23:59:59.000Z

154

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

SciTech Connect (OSTI)

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.

Elcock, D.

1998-03-05T23:59:59.000Z

155

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

SciTech Connect (OSTI)

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.

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

1997-09-01T23:59:59.000Z

156

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

SciTech Connect (OSTI)

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.

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

2002-02-28T23:59:59.000Z

157

Oil and gas developments in western Canada in 1987  

SciTech Connect (OSTI)

Exploratory drilling in western Canada increased by 21% in 1987 whereas total drilling increased by 32%. The seismic crew count increased 4% to 671 crew-months, and land expenditures increased 166% to $793 million. No major plays broke during 1987 in western Canada. The 2 major plays resulting from 1986 activity - Caroline, Alberta, and Tableland, Saskatchewan - continued to expand in 1987. By year end at Caroline, industry drilled 14 wells, which included 6 Swan Hills gas wells, 3 uphole gas wells, 3 wells standing or suspended, and 2 dry holes. The reserves for this field now are 17 billion m/sup 3/ of sales gas, 32 million m/sup 3/ of condensate, and 20 million MT of sulfur. At Tableland and surrounding areas, industry has drilled 11 oil wells and 16 dry holes. No overall reserve figures have been published for this play. In Alberta, operators had their best exploratory oil success in the Cretaceous Second White Specks and in the Devonian Nisku, Leduc, Gilwood, and Keg River; the best exploratory gas success was in the Cretaceous Viking and Paddy, and Devonian Nisku and Leduc. In British Columbia, gas drilling was successful in the Cretaceous of the Deep Basin, as well as in the Mississippian Kiskatinaw and the Triassic Halfway. In Saskatchewan, both the shallow Cretaceous gas play and the deep Devonian Winnipegosis oil play continued to expand, whereas in Manitoba the main exploration target was the Mississippian carbonates and Bakken Formation. The Northwest Territories, Beaufort Sea, and Arctic Islands had a poor year, with only 4 exploratory wells drilled - all dry holes. 7 figs., 10 tabs.

Portigal, M.H.; Creed, R.M.; Hogg, J.R.; Hewitt, M.D.

1988-10-01T23:59:59.000Z

158

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

SciTech Connect (OSTI)

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

Scott Hara

2002-01-31T23:59:59.000Z

159

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

SciTech Connect (OSTI)

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

Scott Hara

2001-11-01T23:59:59.000Z

160

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

SciTech Connect (OSTI)

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

Scott Hara

2001-05-08T23:59:59.000Z

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


161

The Esso Energy Award Lecture, 1998. Boosting production from low-pressure oil and gas fields: a revolution in hydrocarbon production  

Science Journals Connector (OSTI)

...Boosting production from low-pressure oil and gas fields: a revolution in hydrocarbon...major part of the future source of oil and gas supply. Full development...Caledonia Ltd (Wood Group Engineering), Marathon Oil UK Ltd, Mobil North Sea Ltd, Oil...

1999-01-01T23:59:59.000Z

162

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

E-Print Network [OSTI]

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

Li, Junlun

163

Crosswell seismic waveguide phenomenology of reservoir sands & shales at offsets >600 m, Liaohe Oil Field, NE China  

Science Journals Connector (OSTI)

......employed to lower the cost of hydrocarbon production monitoring (de Waal...2001. Development Production (Special Section...continuity logging for oil and gas field applications...from the Antrim Shale gas play, Michigan Basin......

P. C. Leary; W. Ayres; W. J. Yang; X. F. Chang

2005-10-01T23:59:59.000Z

164

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

SciTech Connect (OSTI)

For biodegraded oil accumulations, field development can be optimized by using geochemical indicators of variations in the extent of bacterial alteration. Biodegradation typically reduces oil producibility by increasing oil viscosity. In the Cymric field (Kern County, California), sidewall core extracts reveal that the extent of oil biodegradation changes substantially over extremely short vertical distances in a shallow, low-permeability reservoir. Zones of more degraded oil can extend laterally for more than a mile. The relationships between oil viscosity and biomarker biodegradation parameters in this field were calibrated from analyses of produced oils, and these relationships were used to convert sidewall core biomarker analyses into quantitative predictions of lateral and vertical changes in oil viscosity and gravity. Compositional variations were also used to allocate production to discrete zones. Viscosity prediction and production allocation can be used to optimize (1) the placement of new wells, (2) the placement of completion intervals, (3) the thickness of steam injection intervals, and (4) the spacing between injection intervals in the same well.

McCaffrey, M.A. [Chevron Petroleum Technology Co., La Habra, CA (United States); Legarre, H.A.; Johnson, S.J. [Chevron U.S.A. Production Co., Bakersfield, CA (United States)

1996-06-01T23:59:59.000Z

165

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

SciTech Connect (OSTI)

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

Scott Hara

2002-11-08T23:59:59.000Z

166

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

E-Print Network [OSTI]

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

Putt, Russell Eugene

2012-06-07T23:59:59.000Z

167

Optimization of Miscible CO2 Water-Alternating-Gas Injection in the Bakken Formation  

Science Journals Connector (OSTI)

The sandstone reservoir core plugs were found to be completely blocked by the fine solids in the reservoir brine after it was tested and used in the coreflood tests. ... From 0.30 to 0.50 PV, the oil RF of test 3 did not increase at all, while the oil RFs of the other two tests were increased continuously. ...

Longyu Han; Yongan Gu

2014-09-30T23:59:59.000Z

168

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

SciTech Connect (OSTI)

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

NONE

1996-08-01T23:59:59.000Z

169

Evidences for secondary cracking of oil in South Pars field, Persian Gulf, Iran  

Science Journals Connector (OSTI)

Condensates and natural gases in South Pars, world's largest gas field in Persian Gulf were studied for their geochemical characteristics and possibility of secondary cracking as a major gas producing mechanism. Carbon isotopic analysis of gas components proposes thermogenic origin for South Pars gas field. However, ?13C values of Methane and Ethane are slightly depleted in comparison with generated gas from primary thermogenic gas whereas gases from secondary cracking of oils are systematically depleted in 13C in Methane and Ethane compared to gases from primary cracking. Gas composition of Head-Space gas samples were plotted in Ln(C1/C2) vs. Ln(C2/C3) diagram that all the data points indicate a noticeable shift toward trend of secondary cracking, indicating frequency of higher components i.e. C2+. Silurian black shales are recognized as most important source rock for the South Pars field. Biomarker analysis of hydrocarbon liquid samples indicates Pristane to Phytane ratio is > 1 that could confirm mentioned shaly source rock which is deposited in suboxic to oxic marine environment. Considering of ?13C of Silurian shales the “?13C Methane-?13C Source” was calculated and plotted against C1/?C1–5 indicating effect of secondary cracking of oil as producing mechanism for South Pars gas field. Moreover, pyro-bitumen as product of the secondary cracking was found filling secondary porosities in bottom part of the reservoir.

Jafar Aali; Omeid Rahmani

2011-01-01T23:59:59.000Z

170

Laboratory Toxicity and Field Effects of a Complex Mixture: Oil-field Produced Water.  

E-Print Network [OSTI]

??This dissertation investigated how organisms in the field and the laboratory responded to complex mixtures or combinations of stressors. Organisms are continually exposed to natural… (more)

Fisher, Jonathan C.

2010-01-01T23:59:59.000Z

171

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

SciTech Connect (OSTI)

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

Scott Hara

2002-04-30T23:59:59.000Z

172

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 26, quarter ending March 31, 1981  

SciTech Connect (OSTI)

Objectives and technical progress are summarized for field projects and supporting research in chemical flooding, CO/sub 2/ injection, thermal/heavy oil recovery, resource assessment, extraction technology, microbial enhanced oil recovery, and improved drilling technology. (DLC)

Linville, B. (ed.)

1981-07-01T23:59:59.000Z

173

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 21, quarter ending December 31, 1979  

SciTech Connect (OSTI)

Individual report are presented of contracts for field projects and supporting research on chemical flooding, CO/sub 2/ injection, thermal/heavy oil, resource assessment technology, improved drilling technology, residual oil, environment, and petroleum technology. (DLC)

Linville, B. (ed.)

1980-04-01T23:59:59.000Z

174

For the first 15 years of my life, I lived in the shadow of the oil and gas fields of South Louisiana and became accustomed to the oil indus-  

E-Print Network [OSTI]

For the first 15 years of my life, I lived in the shadow of the oil and gas fields of South jobs and how they worked together to drill and explore for oil and gas. It was no wonder then that I in building the oil and gas assets in Enerfin Resources over a 20 year period to over $250 million. After

Stephens, Jacqueline

175

Electric field induced structuring in clay–oil suspensions: new insights from WAXS, SEM,  

Science Journals Connector (OSTI)

The electric field induced structuring in clay–oil suspensions has been studied by means of wide angle x-ray scattering (WAXS), rheometry, scanning electron microscopy (SEM), as well as leak current density and dielectric constant measurements. The clay particles' orientation distribution was inferred from the azimuthal changes of the clay diffraction peak intensity. The angular width of that distribution was quantified through an orientational order parameter. Chain and column formation processes were distinguished by comparison of the time evolution of the diffraction peak amplitude with that of the current density. Leak current density was measured for different electric field strengths E and clay particle concentrations ?. The following scaling relation was found: . In addition, the dependence of the yield stress on the electric field and on the particle concentration was measured and shown to scale as: .

Z Rozynek; K D Knudsen; J O Fossum; Y Méheust; B Wang; M Zhou

2010-01-01T23:59:59.000Z

176

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 28  

SciTech Connect (OSTI)

Highlights of progress during the quarter ending September 30, 1981 are summarized. Field projects and supporting research in the following areas are reported: chemical flooding; carbon dioxide injection; thermal processes/heavy oil (steam and in-situ combustion); resource assessment technology; extraction technology; environmental; petroleum technology; microbial enhanced oil recovery; and improved drilling technology. A list of BETC publications with abstracts, published during the quarter is included. (DMC)

Linville, B.

1982-01-01T23:59:59.000Z

177

Probabilistic Performance Forecasting for Unconventional Reservoirs With Stretched-Exponential Model  

E-Print Network [OSTI]

and Montana's Elm Coulee field producing from the Bakken oil shale (400 wells). This section aims to present the utility of proposed methodology for assessing reserves in tight gas and oil reservoirs. The overall results are presented in Table 4...

Can, Bunyamin

2011-08-08T23:59:59.000Z

178

A statistical analysis of well production rates from UK oil and gas fields – Implications for carbon capture and storage  

Science Journals Connector (OSTI)

Abstract The number of wells required to dispose of global CO2 emissions by injection into geological formations is of interest as a key indicator of feasible deployment rate, scale and cost. Estimates have largely been driven by forecasts of sustainable injection rate from mathematical modelling of the CO2 injection process. Recorded fluid production rates from oil and gas fields can be considered an observable analogue in this respect. The article presents statistics concerning Cumulative average Bulk fluid Production (CBP) rates per well for 104 oil and gas fields from the UK offshore region. The term bulk fluid production is used here to describe the composite volume of oil, gas and water produced at reservoir conditions. Overall, the following key findings are asserted: (1) CBP statistics for UK offshore oil and gas fields are similar to those observed for CO2 injection projects worldwide. (2) 50% probability of non-exceedance (PNE) for CBP for oil and gas fields without water flood is around 0.35 Mt/yr/well of CO2 equivalent. (3) There is negligible correlation between reservoir transmissivity and CBP. (4) Study of net and gross CBP for water flood fields suggest a 50% PNE that brine co-production during CO2 injection could lead to a 20% reduction in the number of wells required.

Simon A. Mathias; Jon G. Gluyas; Eric J. Mackay; Ward H. Goldthorpe

2013-01-01T23:59:59.000Z

179

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

SciTech Connect (OSTI)

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.

James Spillane

2005-10-01T23:59:59.000Z

180

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 32, quarter ending September 30, 1982  

SciTech Connect (OSTI)

Progress reports are presented of contracts for field projects and supporting research on chemical flooding, carbon dioxide injection, thermal/heavy oil, resource assessment technology, extraction technology, environmental and safety, microbial enhanced oil recovery, oil recovery by gravity mining, improved drilling technology, and general supporting research.

Linville, B. (ed.)

1983-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


181

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 33, quarter ending December 31, 1982  

SciTech Connect (OSTI)

Progress reports are presented of contracts for field projects and supporting research on chemical flooding, carbon dioxide injection, thermal/heavy oil, resource assessment technology, extraction technology, environmental and safety, microbial enhanced oil recovery, oil recovery by gravity mining, improved drilling technology, and general supporting research.

Linville, B. (ed.)

1983-04-01T23:59:59.000Z

182

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 36 for quarter ending September 30, 1983  

SciTech Connect (OSTI)

Progress reports for the quarter ending September 30, 1983, are presented for field projects and supported research for the following: chemical flooding; carbon dioxide injection; thermal/heavy oil; resource assessment technology; extraction technology; environmental and safety; microbial enhanced oil recovery; oil recovery by gravity mining; improved drilling technology; and general supporting research.

Linville, B. (ed.)

1984-03-01T23:59:59.000Z

183

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress Review No. 31, quarter ending June 30, 1982  

SciTech Connect (OSTI)

Progress reports are presented of contracts for field projects and supporting research on chemical flooding, carbon dioxide injection, thermal/heavy oil, resource assessment technology, extraction technology, environmental, petroleum technology, microbial enhanced oil recovery, oil recovery by gravity mining, improved drilling technology, and general supporting research.

Linville, B. (ed.)

1982-10-01T23:59:59.000Z

184

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 (OSTI)

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)

Linville, B. (ed.) [ed.

1983-07-01T23:59:59.000Z

185

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

SciTech Connect (OSTI)

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 and net oil production rates of 7,700 BPD and 750 BOPD (injection to production ratio of 4) will occur in October 1999. At that time, the reservoir should act more like a waterflood and production and cold water injection can be operated at lower net injection rates to be determined. Modeling runs developed this quarter found that varying individual well injection rates to meet added production and local pressure problems by sub-zone could reduce steam chest fill-up by up to one month.

Scott Hara

2000-02-18T23:59:59.000Z

186

Stratigraphic and structural analysis of Shannon Sandstone, Teapot Dome field: implications for secondary and tertiary oil recovery  

SciTech Connect (OSTI)

The Department of Energy and Lawrence-Allison Associates have initiated three enhanced oil recovery (EOR) pilot projects in the last 4 years in the Shannon Sandstone at the Teapot Dome field. Performance of these pilot projects has generally been poor. As a result, a reevaluation of the geology for the entire field and for the pilot areas was conducted in an attempt to explain the pilots' performances. Based on core descriptions, conceptual reservoir flow patterns, and post-fireflood coring, only the bar-margin facies was found amenable to fluid displacement processes for oil recovery. This results in 25 million bbl of oil originally in place vs 180 million bbl of oil originally in place as a target for EOR. Stratigraphy alone does not explain the observed production patterns and simulation of the reservoir. Faulting and fracturing are extensive. Based on faults mapped in the in-situ pilot area, 12 to 16 northeast-trending normal faults per mile can be projected. Fracture orientations were obtained by mapping calcareous streaks in the upper and lower Shannon. These orientations confirm directions of premature fluid breakthroughs observed in the pilot projects and in the old East Teapot waterflood. Water resistivities and total dissolved solids measurements, water-cut maps, and daily oil production maps suggest that some faults are partial to total barriers to fluid flow across the field.

Chappelle, H.; Emsurak, G.; Obernyer, S.

1986-08-01T23:59:59.000Z

187

of oil yields from enhanced oil recovery  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

oil yields from enhanced oil recovery (EOR) and CO oil yields from enhanced oil recovery (EOR) and CO 2 storage capacity in depleted oil reservoirs. The primary goal of the project is to demonstrate that remaining oil can be economically produced using CO 2 -EOR technology in untested areas of the United States. The Citronelle Field appears to be an ideal site for concurrent CO 2 storage and EOR because the field is composed of sandstone reservoirs

188

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

SciTech Connect (OSTI)

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.

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

1997-12-31T23:59:59.000Z

189

Simulation studies of steam-propane injection for the Hamaca heavy oil field.  

E-Print Network [OSTI]

??Simulation studies were performed to evaluate a novel technology, steam-propane injection, for the heavy Hamaca crude oil. The oil has a gravity of 9.3?API and… (more)

Venturini, Gilberto Jose

2012-01-01T23:59:59.000Z

190

Selected Abstracts & Bibliography of International Oil Spill Research, through 1998  

E-Print Network [OSTI]

Kuwait, Middle East, oil and gas fields, oil refinery, oil waste, oil well,Equipment Kuwait Oil Co. 1991. Mideast well fire, oil spillKuwait, Persian Gulf, Saudia Arabia, Oil spill, cleanup, oil spills, crude, oil spill incidents, oil spills-pipeline, warfare, oil skimmers, oil wells,

Louisiana Applied Oil Spill Research & Development Program Electronic Bibliography

1998-01-01T23:59:59.000Z

191

Competitive Oxidation of Volatile Fatty Acids by Sulfate- and Nitrate-Reducing Bacteria from an Oil Field in Argentina  

Science Journals Connector (OSTI)

...Neuquen Basin, western Argentina, had significant activity...SRB). SRB derive energy for growth by coupling...11). Oil fields in Argentina conform to this worldwide...the same carbon and energy source. VFA consists...Neuquen Basin, western Argentina (see Fig. S1 in the...

Aleksandr A. Grigoryan; Sabrina L. Cornish; Brenton Buziak; Shiping Lin; Adriana Cavallaro; Joseph J. Arensdorf; Gerrit Voordouw

2008-05-23T23:59:59.000Z

192

Isolation and Characterization of Methanothermobacter crinale sp. nov., a Novel Hydrogenotrophic Methanogen from the Shengli Oil Field  

Science Journals Connector (OSTI)

...17393T) was isolated from oil sands in the Haoxian central facility...sediments that contain methane hydrates, and description of Methanoculleus...in a high temperature natural gas field in Japan. Extremophiles...G. E . 1983. Interpreting gas kinetics of batch cultures...

Lei Cheng; Lirong Dai; Xia Li; Hui Zhang; Yahai Lu

2011-06-24T23:59:59.000Z

193

Class III Mid-Term Project, "Increasing Heavy Oil Reserves in the Wilmington Oil Field Through Advanced Reservoir Characterization and Thermal Production Technologies"  

SciTech Connect (OSTI)

The overall objective of this project was to increase heavy oil reserves in slope and basin clastic (SBC) reservoirs through the application of advanced reservoir characterization and thermal production technologies. The project involved improving thermal recovery techniques in the Tar Zone of Fault Blocks II-A and V (Tar II-A and Tar V) of the Wilmington Field in Los Angeles County, near Long Beach, California. A primary objective has been to transfer technology that can be applied in other heavy oil formations of the Wilmington Field and other SBC reservoirs, including those under waterflood. The first budget period addressed several producibility problems in the Tar II-A and Tar V thermal recovery operations that are common in SBC reservoirs. A few of the advanced technologies developed include a three-dimensional (3-D) deterministic geologic model, a 3-D deterministic thermal reservoir simulation model to aid in reservoir management and subsequent post-steamflood development work, and a detailed study on the geochemical interactions between the steam and the formation rocks and fluids. State of the art operational work included drilling and performing a pilot steam injection and production project via four new horizontal wells (2 producers and 2 injectors), implementing a hot water alternating steam (WAS) drive pilot in the existing steamflood area to improve thermal efficiency, installing a 2400-foot insulated, subsurface harbor channel crossing to supply steam to an island location, testing a novel alkaline steam completion technique to control well sanding problems, and starting on an advanced reservoir management system through computer-aided access to production and geologic data to integrate reservoir characterization, engineering, monitoring, and evaluation. The second budget period phase (BP2) continued to implement state-of-the-art operational work to optimize thermal recovery processes, improve well drilling and completion practices, and evaluate the geomechanical characteristics of the producing formations. The objectives were to further improve reservoir characterization of the heterogeneous turbidite sands, test the proficiency of the three-dimensional geologic and thermal reservoir simulation models, identify the high permeability thief zones to reduce water breakthrough and cycling, and analyze the nonuniform distribution of the remaining oil in place. This work resulted in the redevelopment of the Tar II-A and Tar V post-steamflood projects by drilling several new wells and converting idle wells to improve injection sweep efficiency and more effectively drain the remaining oil reserves. Reservoir management work included reducing water cuts, maintaining or increasing oil production, and evaluating and minimizing further thermal-related formation compaction. The BP2 project utilized all the tools and knowledge gained throughout the DOE project to maximize recovery of the oil in place.

Scott Hara

2007-03-31T23:59:59.000Z

194

Horizontal oil well applications and oil recovery assessment. Volume 2: Applications overview, Final report  

SciTech Connect (OSTI)

Horizontal technology has been applied in over 110 formations in the USA. Volume 1 of this study addresses the overall success of horizontal technology, especially in less-publicized formations, i.e., other than the Austin Chalk, Bakken, and Niobrara. Operators in the USA and Canada were surveyed on a formation-by-formation basis by means of a questionnaire. Response data were received describing horizontal well projects in 58 formations in the USA and 88 in Canada. Operators` responses were analyzed for trends in technical and economic success based on lithology (clastics and carbonates) and resource type (light oil, heavy oil, and gas). The potential impact of horizontal technology on reserves was also estimated. A forecast of horizontal drilling activity over the next decade was developed.

Deskins, W.G.; McDonald, W.J.; Knoll, R.G.; Springer, S.J.

1995-03-01T23:59:59.000Z

195

Bakken and other Devonian-Mississippian petroleum source rocks, northern Rocky Mtns.-Williston basin: Depositional and burial history and maturity estimations  

SciTech Connect (OSTI)

The three-member Devonian-Mississippian Bakken-Exshaw organic-rich shaly facies is widely distributed in the northern U.S. and southern Canadian Cordillera. Equivalent facies are also present as far south as Utah and Nevada. Paleogeographically, these rocks thin markedly or pinchout to the west approximately along the Devonian-Mississippian carbonate reef-mound belt of the Cordilleran shelf margin. Although these rocks reach maximum organic richness approximately at the Devonian-Carboniferous transition, similar but somewhat less organic-rich Bakken-like beds are also present in underlying Upper Devonian and overlying Lower Carboniferous carbonate depositional cycles. At least ten cycles are identified in the underlying Duperow and Jefferson Formations, characterized by basal organic-rich Bakken-like shale or shaly carbonate that grades upward into carbonate mound or reefal beds, overlain by evaporite or solution breccia. Cycles in the overlying Lodgepole and Mission Canyon Formations, as many as 10-12 in number, are similar except that the carbonates are composed of algal-oolith, crinoid, or mixed skeletal beds, and end-cycle evaporitic units are less prevalent in the lower cycles. These dark shaly beds are the most important source of hydrocarbon reserves in Montana and the Williston basin. Maximum net thickness of the Devonian-Mississippian organic-rich facies is in the Williston basin. However, variable thicknesses of these potential source rocks is present in parts of Montana as far west as the thrust belt. Burial history studies suggest that in some areas these rocks are probably thermally immature. However, in much of the area original burial depths are sufficient for them to reach the thermally mature stage, and therefore are of importance to further exploration efforts in the Devonian-Mississippian Madison-Duperow-Jefferson Formations.

Peterson, J.A. [Univ. of Montana, Missoula, MT (United States)

1996-06-01T23:59:59.000Z

196

Dynamics of cementation in response to oil charge: Evidence from a Cretaceous carbonate field, U.A.E.  

Science Journals Connector (OSTI)

Oil charge is thought to inhibit the growth of cements within subsurface pore systems. We explore this phenomenon in a giant Cretaceous carbonate field from U.A.E., where the oil-filled crest porosity ranges from 10 to 50% and permeability from 0.08 to 830 mD but coeval water leg porosity is reduced to 10 to 23% and permeability to 0.1 to 4 mD. Only 5% of primary interparticle pores (> 30 ?m diameter) in the crest are fully cemented, compared to 99% of pores in the water leg. Syntaxial calcite burial cements (> 10 ?m diameter) in the oil leg show 12 cathodoluminescence zones with oil inclusions (n = 27) occurring in four of the five final zones. Mean in-situ ion microprobe ?18OVPDB data from the oil leg cements range from ?1.2‰ in the oldest zone decreasing to ?10.3‰ in zone 11, returning to ?7.7‰ in the final zone. The oldest distinguishable cement zone in the water leg shows highly variable ?18O from ?3.6‰ to ?9.3‰ with a mean of ?7.3‰, and with subsequent zones decreasing to a mean value of ?9.4‰ for the youngest cement zone. Decreasing ?18O values are interpreted as indicating increasing temperature reflecting burial and the evolution of pore water composition: broadly similar trends in the oil and water legs suggest precipitation under the same general conditions. Unlike the oil leg cements, the final zone in the water leg occludes nearly all remaining pore space. The ?18OVPDB of bulk micrite from the water leg shows an average of ?7.4‰ (n = 9) compared to ?6.2‰ (n = 10) from the oil leg, suggesting the precipitation of further micrite cement at greater burial depths. We infer that burial cementation slowed in the presence of oil due to a reduction of potential nucleation sites as well as porewater and solute movement within weakly oil-wet pores, whereas continued flow and solute movement through all pores including the micropores (< 10 ?m diameter) enabled extensive cementation in the water leg.

P.A. Cox; R.A. Wood; J.A.D. Dickson; H.B. Al Rougha; H. Shebl; P.W.M. Corbett

2010-01-01T23:59:59.000Z

197

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 (OSTI)

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.

Ernest A. Mancini

2003-05-20T23:59:59.000Z

198

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

SciTech Connect (OSTI)

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.

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

1997-09-01T23:59:59.000Z

199

Heavy metals in water base drilling muds used in several locations of oil fields in Indonesia  

SciTech Connect (OSTI)

Heavy metals are parameters to be considered among other parameters such as pH, salts, hydrocarbons, cutting and fluids when water base muds are to be disposed. In most cases reducing or eliminating heavy metals, either as additives or contaminants, will reduce the problems associated with disposal. Even if all heavy metals are eliminated from the additives placed in a mud system, however, these contaminants can still become incorporated into the mud from the formation that is being drilled. In Indonesia, drilling muds are classified as hazardous material according to the Governmental Regulation PP 19/1994. This paper try to investigate the concentration of some of heavy metals in drilling muds used in several locations of oil fields in Indonesia using Toxicity Characteristic Leaching Procedure (TCLP) extracted with several acids and other extracting agents. {open_quotes}Total heavy metals{close_quotes} content as released through refluxing in strong acids are also determined to correlate between Total Heavy Metals and Extractable Heavy Metals, in order to examine the type of compounds which could be considered as potential pollutants.

Mulyono, M.; Desrina, R.; Priatna, R. [and others

1996-12-31T23:59:59.000Z

200

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 29, quarter ending December 31, 1981  

SciTech Connect (OSTI)

Highlights of progress accomplished during the quarter ending December, 1981, are summarized in this report. Discussion is presented under the following headings: chemical flooding - field projects; chemical flooding - supporting research; carbon dioxide injection - field projects; carbon dioxide injection - supporting research; thermal/heavy oil - field projects and supporting research; resource assessment technology; extraction technology; environmental aspects; petroleum processing technology; microbial enhanced oil recovery; and improved drilling technology. (DMC)

Linville, B. (ed.)

1982-05-01T23:59:59.000Z

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


201

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

SciTech Connect (OSTI)

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.

NONE

1997-05-01T23:59:59.000Z

202

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 35, quarter ending June 30, 1983  

SciTech Connect (OSTI)

Progress reports are presented for field projects and supporting research for the following: chemical flooding; carbon dioxide injection; thermal/heavy oil; resource assessment technology; extraction technology; environmental and safety; microbial enhanced oil recovery; improved drilling technology; and general supporting research.

Linville, B. (ed.)

1983-10-01T23:59:59.000Z

203

Progress review No. 24: contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress report, quarter ending September 30, 1980  

SciTech Connect (OSTI)

Reports are presented of contracts for field projects and supporting research on chemical flooding, carbon dioxide injection and thermal/heavy oil, as well as for the following areas of research: extraction technology; resource assessment technology; environmental; petroleum technology; microbial enhanced oil recovery; improved drilling technology; and general supporting research.

Linville, B. (ed.)

1981-02-01T23:59:59.000Z

204

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 30, quarter ending March 31, 1982  

SciTech Connect (OSTI)

Reports are presented of contracts for field projects and supporting research on chemical flooding, carbon dioxide injection, thermal/heavy oil, as well as for the following areas of research: resource assessment technology; extraction technology; microbial enhanced oil recovery; improved drilling technology, and general supporting research.

Linville, B. (ed.)

1982-07-01T23:59:59.000Z

205

Progress review No. 25: contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress report, quarter ending December 31, 1980  

SciTech Connect (OSTI)

Reports are presented of contracts for field projects and supporting research on chemical flooding, carbon dioxide injection, thermal/heavy oil, as well as for the following areas of research: resource assessment technology; extraction technology; environmental; microbial enhanced oil recovery; improving drilling technology; and general supporting research.

Linville, B. (ed.)

1981-05-01T23:59:59.000Z

206

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 27, for quarter ending June 30, 1981  

SciTech Connect (OSTI)

Reports are presented of contracts for field projects and supporting research on chemical flooding, carbon dioxide injection, thermal/heavy oil, as well as for the following areas of research: resource assessment technology; extraction technology; environmental; microbial enhanced oil recovery; improved drilling technology; and general supporting research.

Linville, B. (ed.)

1981-09-01T23:59:59.000Z

207

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 (OSTI)

The project involves improving thermal recovery techniques in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., Calif. using advanced reservoir characterization and thermal production technologies. The existing steamflood in the Tar zone of Fault Block (FB) 11-A has been relatively inefficient because of several producibility problems which are common in SBC reservoirs. Inadequate characterization of the heterogeneous turbidite sands, high permeability thief zones, low gravity oil, and nonuniform distribution of remaining oil have all contributed to poor sweep efficiency, high steam-oil ratios, and early steam breakthrough. Operational problems related to steam breakthrough, high reservoir pressure, and unconsolidated formation sands have caused premature well and downhole equipment failures. In aggregate, these reservoir and operational constraints have resulted in increased operating costs and decreased recoverable reserves. The advanced technologies to be applied include: (1) Develop three-dimensional (3-D) deterministic and stochastic geologic models. (2) Develop 3-D deterministic and stochastic thermal reservoir simulation models to aid in reservoir management and subsequent development work. (3) Develop computerized 3-D visualizations of the geologic and reservoir simulation models to aid in analysis. (4) Perform detailed study on the geochemical interactions between the steam and the formation rock and fluids. (5) Pilot steam injection and production via four new horizontal wells (2 producers and 2 injectors). (6) Hot water alternating steam (WAS) drive pilot in the existing steam drive area to improve thermal efficiency. (7) Installing a 2100 foot insulated, subsurface harbor channel crossing to supply steam to an island location. (8) Test a novel alkaline steam completion technique to control well sanding problems and fluid entry profiles. (9) Advanced reservoir management through computer-aided access to production and geologic data to integrate reservoir characterization, engineering, monitoring, and evaluation.

Hara, S. [Tidelands Oil Production Co., Long Beach, CA (United States)], Casteel, J. [USDOE Bartlesville Project Office, OK (United States)

1997-05-11T23:59:59.000Z

208

Increasing heavy oil reserves in the Wilmington Oil field through advanced reservoir characterization and thermal production technologies. Quarterly report, April 1, 1996--June 30, 1996  

SciTech Connect (OSTI)

The project involves improving thermal recovery techniques in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., California using advanced reservoir characterization and thermal production technologies. Inadequate characterization of the heterogeneous turbidite sands, high permeability thief zones, low gravity oil, and nonuniform distribution of remaining oil have all contributed to poor sweep efficiency, high steam-oil ratios, and early steam breakthrough. Operational problems related to steam breakthrough, high reservoir pressure, and unconsolidated formation sands have caused premature well and downhole equipment failures. In aggregate, these reservoir and operational constraints have resulted in increased operating costs and decreased recoverable reserves. The technologies include: (1) Develop three-dimensional (3-D) deterministic and stochastic geologic models. (2) Develop 3-D deterministic and stochastic thermal reservoir simulation models to aid in reservoir management and subsequent development work. (3) Develop computerized 3-D visualizations of the geologic and reservoir simulation models to aid in analysis. (4) Perform detailed study on the geochemical interactions between the steam and the formation rock and fluids. (5) Pilot steam injection and production via four new horizontal wells (2 producers and 2 injectors). (6) Hot water alternating steam (WAS) drive pilot in the existing steam drive area to improve thermal efficiency. (7) Installing an 2400 foot insulated, subsurface harbor channel crossing to supply steam to an island location. (8) Test a novel alkaline steam completion technique to control well sanding problems and fluid entry profiles. (9) Advanced reservoir management through computer-aided access to production and geologic data to integrate reservoir characterization, engineering, monitoring, and evaluation.

Hara, S.

1996-08-05T23:59:59.000Z

209

Field Instruments for Real Time In-Situ Crude Oil Concentration Measurements  

E-Print Network [OSTI]

The Texas Water Resources Institute awarded a Mill Scholarship to M.C. Sterling, Jr in 2002. This project describes five sensors for rapid monitoring of crude oil concentrations in an aquatic system. These measurements are critical for monitoring...

Fuller, C. B.; Bonner, J. S.; Page, C. A.; Arrambide, G.; Sterling Jr., M. C.; Ojo, T.

210

Increasing Waterflooding Reservoirs in the Wilmington Oil Field through Improved Reservoir Characterization and Reservoir Management, Class III  

SciTech Connect (OSTI)

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.

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

2001-08-07T23:59:59.000Z

211

Ground level concentration of sulfur dioxide at Kuwait`s major population centers during the oil-field fires  

SciTech Connect (OSTI)

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.

Al-Ajmi, D.N.; Marmoush, Y.R. [Kuwait Institute for Scientific Research (Kuwait)] [Kuwait Institute for Scientific Research (Kuwait)

1996-08-01T23:59:59.000Z

212

Productivity evaluation and influential factor analysis for Sarvak reservoir in South Azadegan oil field, Iran  

Science Journals Connector (OSTI)

Abstract Production pattern of oil wells and influential factors on productivity for the massive carbonate reservoir in the Middle East were researched by productivity evaluation on Sarvak and analysis of properties impact on production. Based on dynamic performance of Sarvak production test, the relationship between daily oil production, tubing pressure, cumulative oil production and choke size was analyzed and reasonable productivity prediction model was established by applying Poettman model, and the effect of physical properties and fluid parameters on productivity were analyzed further by numerical simulation. The study shows that daily oil production is linearly correlated with oil pressure under certain working regime, and daily oil production is power law correlated with choke sizes before and after working regime adjustment. The average designed single well productivity should be about 270 m3/d by depletion to ensure a three-year plateau period. Sarvak is a blocky carbonate reservoir, when developed with horizontal wells, interbeds distributed between layers and permeability property have the strongest impact on production of horizontal wells. So, highly deviated wells should be used to reduce the effect of interbeds and acidizing should be considered to improve the reservoir physical properties.

Hui LIU; Rui GUO; Junchang DONG; Li LIU; Yang LIU; Yingjie YI

2013-01-01T23:59:59.000Z

213

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 (OSTI)

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.

Hara, S. [Tidelands Oil Production Co., Long Beach, CA (United States)

1996-12-01T23:59:59.000Z

214

Integrated, multidisciplinary reservoir characterization, modeling and engineering leading to enhanced oil recovery from the Midway-Sunset field, California  

SciTech Connect (OSTI)

The Pru Fee property is developed in a heavy oil, Class III (slope and basin clastic sand), reservoir of the Midway-Sunset field, San Joaquin Basin, California. Wells on the property were shut-in with an estimated 85% of the original oil remaining in place because the reservoir failed to respond to conventional cyclic steaming. Producibility problems are attributed to the close proximity of the property to the margin of the field. Specific problems include complex reservoir geometry, thinning pay, bottom water, and dipping beds. These problems are likely common at the margins of the Midway-Sunset and other Class III reservoirs. This project forms the first step in returning the property to production and explores strategies that might be applied elsewhere. Reservoir characterization, modeling, and engineering methods are integrated to design, simulate, and implement a pilot steam flood. A new drillhole provides good quality, core through the pay zone and a full suite of geophysical logs. Correlations between geological and petrophysical data are used to extrapolate reservoir conditions from older logs and yield a 3-dimensional petrophysical model. Numerical results illustrate how each producibility problem might influence production and provide a framework for designing the pilot steam flood. This first phase illustrates how a multidisciplinary team can use established technologies in developing the detailed petrophysical, geological, and numerical models needed to enhance oil recovery from marginal areas of Class III reservoirs.

Schamel, S.; Forster, C.; Deo, M. (Univ. of Utah, Salt Lake City, UT (United States)) (and others)

1996-01-01T23:59:59.000Z

215

Integrated, multidisciplinary reservoir characterization, modeling and engineering leading to enhanced oil recovery from the Midway-Sunset field, California  

SciTech Connect (OSTI)

The Pru Fee property is developed in a heavy oil, Class III (slope and basin clastic sand), reservoir of the Midway-Sunset field, San Joaquin Basin, California. Wells on the property were shut-in with an estimated 85% of the original oil remaining in place because the reservoir failed to respond to conventional cyclic steaming. Producibility problems are attributed to the close proximity of the property to the margin of the field. Specific problems include complex reservoir geometry, thinning pay, bottom water, and dipping beds. These problems are likely common at the margins of the Midway-Sunset and other Class III reservoirs. This project forms the first step in returning the property to production and explores strategies that might be applied elsewhere. Reservoir characterization, modeling, and engineering methods are integrated to design, simulate, and implement a pilot steam flood. A new drillhole provides good quality, core through the pay zone and a full suite of geophysical logs. Correlations between geological and petrophysical data are used to extrapolate reservoir conditions from older logs and yield a 3-dimensional petrophysical model. Numerical results illustrate how each producibility problem might influence production and provide a framework for designing the pilot steam flood. This first phase illustrates how a multidisciplinary team can use established technologies in developing the detailed petrophysical, geological, and numerical models needed to enhance oil recovery from marginal areas of Class III reservoirs.

Schamel, S.; Forster, C.; Deo, M. [Univ. of Utah, Salt Lake City, UT (United States)] [and others

1996-12-31T23:59:59.000Z

216

Field testing of paper/polymerized vegetable oil mulches for enhancing growth of eastern cottonwood trees for pulp  

Science Journals Connector (OSTI)

Field studies of biodegradable polymerized vegetable oil-coated paper mulches were conducted to determine if these could replace non-degradable polyethylene mulches for stopping weeds and promoting growth of cottonwood trees. Tests were conducted over two growing seasons in two adjacent field sites in southeastern Missouri. At the end of the 2001 season, eastern cottonwood trees grown on the coated paper mulches had average heights (4.57–4.66 m, 15.0–15.3 ft), which were not significantly different from the control black polyethylene mulch (4.75 m, 15.6 ft). Tree heights were significantly less for uncoated paper mulch (4.45 m, 14.6 ft) or no mulch (3.90 m, 12.8 ft), presumably due to heavy weed growth around the trees. Uncoated paper mulch was extensively degraded after only about 4 weeks, while the coated paper persisted until the fall. Addition of ZnO to the oil coating delayed the onset of visible degradation, such as the formation of holes and tears, especially near the buried edge and above the drip tube. Similar results were seen for the 2002 study except that weed growth was not extensive so that tree heights for the mulched and bare plots were not significantly different. These results suggest that polymerized vegetable oil-coated paper mulches can function as effective mulches during the first year of tree growth, and thus, eliminate the need to use non-degradable polyethylene mulches.

Randal L. Shogren; Randall J. Rousseau

2005-01-01T23:59:59.000Z

217

Horizontal oil well applications and oil recovery assessment. Volume 1: Success of horizontal well technology, Final report  

SciTech Connect (OSTI)

Horizontal technology has been applied in over 110 formations in the USA. Volume I of this study addresses the overall success of horizontal technology, especially in less-publicized formations, i.e., other than the Austin Chalk, Bakken, and Niobrara. Operators in the USA. and Canada were surveyed on a formation-by-formation basis by means of a questionnaire. Response data were received describing horizontal well projects in 58 formations in the USA. and 88 in Canada. Operators responses were analyzed for trends in technical and economic success based on lithology (clastics and carbonates) and resource type (light oil, heavy oil, and gas). The potential impact of horizontal technology on reserves was also estimated. A forecast of horizontal drilling activity over the next decade was developed.

Deskins, W.G.; McDonald, W.J.; Knoll, R.G.; Springer, S.J.

1995-03-01T23:59:59.000Z

218

Predicted and actual productions of horizontal wells in heavy-oil fields  

Science Journals Connector (OSTI)

This paper discusses the comparison of predicted and actual cumulative and daily oil production. The predicted results were obtained from the use of Joshi's equation, wherein, the effects of anisotropy and eccentricity were included. The cumulative production obtained from the use of equations developed by Borisov, Giger, Renard and Dupuy resulted in errors in excess of 100%, thus, they were not considered applicable for predicting cumulative and daily flows of heavy oils in horizontal wells. The wells considered in this analysis varied from 537 to 1201 metres with corresponding well bores of 0.089 to. 0.110 m. Using Joshi's equation, the predicted cumulative oil-production was within a 20% difference for up to 12 months of production for long wells and up to 24 months for short wells. Short wells were defined as those being under 1000 m.

Peter Catania

2000-01-01T23:59:59.000Z

219

Increasing heavy oil reserves in the Wilmington oil field through advanced reservoir characterization and thermal production technologies. Technical progress report  

SciTech Connect (OSTI)

The project involves improving thermal recovery techniques in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., California using advanced reservoir characterization and thermal production technologies. This is the third quarterly technical progress report for the project. Significant technical achievements accomplished include the drilling of four horizontal wells (two producers and two steam injectors) utilizing a new and lower cost drilling program, the drilling of five observation wells to monitor the horizontal steamflood pilot, the installation of a subsurface harbor channel crossing for delivering steam to an island location, and a geochemical study of the scale minerals being created in the wellbore. Cyclic steam injection into the two horizontal injection wells began in mid-December 1995 utilizing the new 2400 ft steam line under the Cerritos channel and the wells will be placed on production in May. Cyclic steam injection into the two horizontal producers will start in May. Work on the basic reservoir engineering is expected to be completed in March 1996. The deterministic geologic model was improved to add eight layers to the previous ten.

Hara, S.

1996-05-06T23:59:59.000Z

220

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 (OSTI)

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)

Tiedemann, H.A. (ed.) (USDOE Bartlesville Project Office, OK (USA))

1991-03-01T23:59:59.000Z

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


221

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

SciTech Connect (OSTI)

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.

NONE

1997-10-01T23:59:59.000Z

222

Adaptive Management and Planning Models for Cultural Resources in Oil and Gas Fields in New Mexico and Wyoming  

SciTech Connect (OSTI)

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.

Eckerle, William; Hall, Stephen

2005-12-30T23:59:59.000Z

223

Hydrogeologic aspects of brine disposal in the East Poplar oil field, Fort Peck Indian Reservation, northeastern Montana  

SciTech Connect (OSTI)

The East Poplar Oil Field encompasses about 70 square miles in the south-central part of the Fort Peck Indian Reservation. Oil production began in 1952 from the Mississippian Madison Group. Production depths range from about 5,500 to 6,000 feet below land surface. Large quantities of brine (water having a dissolved-solids concentration greater than 35,000 milligrams per liter) have been produced with the oil. The brine has a dissolved-solids concentration of as much as 160,000 milligrams per liter. Most of the brine has been disposed of by injection into shallower subsurface formations (mainly the Lower Cretaceous Dakota Sandstone at depths of about 3,300 feet and the Upper Cretaceous Judith River Formation at depths of about 1,000 feet). Smaller quantities of brine have been directed to storage and evaporation pits. Handling, transport, and disposal of the brine have resulted in its movement into and migration through shallow Quaternary alluvial and glacial deposits along the Poplar River valley. Locally, domestic water supplies are obtained from these deposits. The major point, sources of shallow ground-water contamination probably is leakage of brine from corroded disposal-well casing and pipelines. Using electromagnetic geophysical techniques and auger drilling, three saline-water plumes in alluvial deposits and one plum in glacial deposits have been delineated. Dominant constituents in plume areas are sodium and chloride, whereas those in nonplume areas are sodium and bicarbonate.

Craigg, S.D.; Thamke, J.N. (Geological Survey, Helena, MT (United States))

1993-04-01T23:59:59.000Z

224

Experimental study of enhancement of injectivity and in-situ oil upgrading by steam-propane injection for the Hamaca heavy oil field.  

E-Print Network [OSTI]

??Experiments were conducted to study the feasibility of using propane as a steam additive to accelerate oil production and improve steam injectivity in the Hamaca… (more)

Rivero Diaz, Jose Antonio

2012-01-01T23:59:59.000Z

225

An integrated approach to seismic stimulation of oil reservoirs: laboratory, field and theoretical results from DOE/industry collaborations.  

SciTech Connect (OSTI)

It has been observed repeatedly that low-frequency (10-500 Hz) seismic stress waves can enhance oil production from depleted reservoirs . Until recently, the majority of these observations have been anecdotal or at the proof-of-concept level. The physics coupling stress waves to multiphase fluid flow behavior in porous media is still poorly understood, even though numerous underlying physical mechanisms have been proposed to explain the observations . Basic research on the phenomenon is being conducted through a U .S. Department of Energy funded collaboration between Lawrence Berkeley National Laboratory, the University of California at Berkeley, Los Alamos National Laboratory and the U .S . oil and gas industry . The project has focused on three main areas of research: (1) laboratory core flow experiments, (2) field seismic monitoring of downhole stimulation tests, and (3) theoretical modeling of the coupled stress/flow phenomenon . The major goal is to obtain a comprehensive scientific understanding of the seismic stimulation phenomenon so that field application technologies can be improved. Initial developments and experimental results in all three research focus areas confirm historic observations that the stimulated flow phenomenon is real and that a fundamental scientific understanding can be obtained through continued research . Examples of project results and developments are presented here.

Roberts, P. M. (Peter M.); Majer, Ernest Luther; Lo, W. C. (Wei-Cheng); Sposito, Garrison,; Daley, T. M. (Thomas M.)

2003-01-01T23:59:59.000Z

226

Establishment of an oil and gas database for increased recovery and characterization of oil and gas carbonate reservoir heterogeneity. [Jurassic Smackover Formation  

SciTech Connect (OSTI)

This volume contains maps, well logging correlated to porosity and permeability, structural cross section, graph of production history, porosity vs. natural log permeability plot, detailed core log, paragenetic sequence and reservoir characterization sheet of the following fields in southwest Alabama: Appleton oil field; Barnett oil field; Barrytown oil field; Big Escambia Creek gas and condensate field; Blacksher oil field; Broken Leg Creed oil field; Bucatunna Creed oil field; Chappell Hill oil field; Chatom gas and condensate field; Choctaw Ridge oil field; Chunchula gas and condensate field; Cold Creek oil field; Copeland gas and condensate field; Crosbys Creed gas and condensate field; and East Barnett oil field. (AT)

Kopaska-Merkel, D.C.; Moore, H.E. Jr.; Mann, S.D.; Hall, D.R.

1992-06-01T23:59:59.000Z

227

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

SciTech Connect (OSTI)

This volume contains maps, well logging correlated to porosity and permeability, structural cross section, graph of production history, porosity vs. natural log permeability plot, detailed core log, paragenetic sequence and reservoir characterization sheet of the following fields in southwest Alabama: Appleton oil field; Barnett oil field; Barrytown oil field; Big Escambia Creek gas and condensate field; Blacksher oil field; Broken Leg Creed oil field; Bucatunna Creed oil field; Chappell Hill oil field; Chatom gas and condensate field; Choctaw Ridge oil field; Chunchula gas and condensate field; Cold Creek oil field; Copeland gas and condensate field; Crosbys Creed gas and condensate field; and East Barnett oil field. (AT)

Kopaska-Merkel, D.C.; Moore, H.E. Jr.; Mann, S.D.; Hall, D.R.

1992-06-01T23:59:59.000Z

228

Reservoir simulation of co2 sequestration and enhanced oil recovery in Tensleep Formation, Teapot Dome field  

E-Print Network [OSTI]

Teapot Dome field is located 35 miles north of Casper, Wyoming in Natrona County. This field has been selected by the U.S. Department of Energy to implement a field-size CO2 storage project. With a projected storage of 2.6 million tons of carbon...

Gaviria Garcia, Ricardo

2006-04-12T23:59:59.000Z

229

Let’s Try That Again: Selling the Teapot Dome Oil Field  

Broader source: Energy.gov [DOE]

The first time the Teapot Dome Oilfield was sold, it threw the Harding administration into scandal. Now -- 93 years later -- we're selling the field legally.

230

ADAPTIVE MANAGEMENT AND PLANNING MODELS FOR CULTURAL RESOURCES IN OIL & GAS FIELDS IN NEW MEXICO AND WYOMING  

SciTech Connect (OSTI)

This report summarizes activities that have taken place in the last six (6) months (January 2005-June 2005) under the DOE-NETL cooperative agreement ''Adaptive Management and Planning Models for Cultural Resources in Oil and Gas Fields, New Mexico and Wyoming'' DE-FC26-02NT15445. This project examines the practices and results of cultural resource investigation and management in two different oil and gas producing areas of the United States: southeastern New Mexico and the Powder River Basin of Wyoming. The project evaluates how cultural resource investigations have been conducted in the past and considers how investigation and management could be pursued differently in the future. The study relies upon full database population for cultural resource inventories and resources and geomorphological studies. These are the basis for analysis of cultural resource occurrence, strategies for finding and evaluating cultural resources, and recommendations for future management practices. Activities can be summarized as occurring in either Wyoming or New Mexico. Gnomon as project lead, worked in both areas.

Peggy Robinson

2005-07-01T23:59:59.000Z

231

Experimental and Computational Studies of Fluid Flow Phenomena in Carbon Dioxide Sequestration in Brine and Oil Fields  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

EXPERIMENTAL AND COMPUTATIONAL STUDIES OF FLUID EXPERIMENTAL AND COMPUTATIONAL STUDIES OF FLUID FLOW PHENOMENA IN CARBON DIOXIDE SEQUESTRATION IN BRINE AND OIL FIELDS Chuang Ji ( chuang.ji@netl.doe.gov ) National Energy Technology Laboratory Department of Energy, Morgantown, WV 26507-0880 BOX 5725 Clarkson University Potsdam, NY 13699 Goodarz Ahmadi ( ahmadi@clarkson.edu ) BOX 5725 Clarkson University Potsdam, NY 13699 Duane H. Smith ( duane.smith@netl.doe.gov ) National Energy Technology Laboratory Department of Energy, Morgantown, WV 26507-0880 2 INTRODUCTION Sequestration of CO 2 by injection into deep geological formations is a method to reduce CO 2 emissions into the atmosphere. However, when CO 2 is injected underground, it forms fingers extending into the rock pores saturated with brine or petroleum. This flow

232

ADAPTIVE MANAGEMENT AND PLANNING MODELS FOR CULTURAL RESOURCES IN OIL & GAS FIELDS IN NEW MEXICO AND WYOMING  

SciTech Connect (OSTI)

This report contains a summary of activities of Gnomon, Inc. and five subcontractors that have taken place during the first six months of 2004 (January 1, 2004-June 30, 2004) under the DOE-NETL cooperative agreement: ''Adaptive Management and Planning Models for Cultural Resources in Oil & Gas Fields in New Mexico and Wyoming'', DE-FC26-02NT15445. Although Gnomon and all five subcontractors completed tasks during these six months, most of the technical experimental work was conducted by the subcontractor, SRI Foundation (SRIF). SRIF created a sensitivity model for the Azotea Mesa area of southeastern New Mexico that rates areas as having a very good chance, a good chance, or a very poor chance of containing cultural resource sites. SRIF suggested that the results of the sensitivity model might influence possible changes in cultural resource management (CRM) practices in the Azote Mesa area of southeastern New Mexico.

Peggy Robinson

2004-07-01T23:59:59.000Z

233

ADAPTIVE MANAGEMENT AND PLANNING MODELS FOR CULTURAL RESOURCES IN OIL & GAS FIELDS IN NEW MEXICO AND WYOMING  

SciTech Connect (OSTI)

This report contains a summary of activities of Gnomon, Inc. and five subcontractors that have taken place during the second six months (July 1, 2003-December 31, 2003) under the DOE-NETL cooperative agreement: ''Adaptive Management and Planning Models for Cultural Resources in Oil & Gas Fields in New Mexico and Wyoming'', DE-FC26-02NT15445. Although Gnomon and all five subcontractors completed tasks during these six months, most of the technical experimental work was conducted by the subcontractor, SRI Foundation (SRIF). SRIF created a sensitivity model for the Loco Hills area of southeastern New Mexico that rates areas as having a very good chance, a good chance, or a very poor chance of containing cultural resource sites. SRIF suggested that the results of the sensitivity model might influence possible changes in cultural resource management (CRM) practices in the Loco Hills area of southeastern New Mexico.

Peggy Robinson

2004-01-01T23:59:59.000Z

234

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

E-Print Network [OSTI]

amount of capital required for offshore field and environmental restricted on-shore field development (swamp, farming land etc. ), reducing even a, small fraction of the total investment could mean large capital savings. Therefore, the minimization... for this research. In this research, four problems are addressed. First, a general model for both on-shore and off-shore facility location and well location problems is developed. Second, a preprocessing stage is added to the revised 0-1 Balas algorithm...

Ding, Zixuan

2012-06-07T23:59:59.000Z

235

Study on detailed geological modelling for fluvial sandstone reservoir in Daqing oil field  

SciTech Connect (OSTI)

Guided by the sedimentation theory and knowledge of modern and ancient fluvial deposition and utilizing the abundant information of sedimentary series, microfacies type and petrophysical parameters from well logging curves of close spaced thousands of wells located in a large area. A new method for establishing detailed sedimentation and permeability distribution models for fluvial reservoirs have been developed successfully. This study aimed at the geometry and internal architecture of sandbodies, in accordance to their hierarchical levels of heterogeneity and building up sedimentation and permeability distribution models of fluvial reservoirs, describing the reservoir heterogeneity on the light of the river sedimentary rules. The results and methods obtained in outcrop and modem sedimentation studies have successfully supported the study. Taking advantage of this method, the major producing layers (PI{sub 1-2}), which have been considered as heterogeneous and thick fluvial reservoirs extending widely in lateral are researched in detail. These layers are subdivided into single sedimentary units vertically and the microfacies are identified horizontally. Furthermore, a complex system is recognized according to their hierarchical levels from large to small, meander belt, single channel sandbody, meander scroll, point bar, and lateral accretion bodies of point bar. The achieved results improved the description of areal distribution of point bar sandbodies, provide an accurate and detailed framework model for establishing high resolution predicting model. By using geostatistic technique, it also plays an important role in searching for enriched zone of residual oil distribution.

Zhao Hanqing; Fu Zhiguo; Lu Xiaoguang [Institute of Petroleum Exploration and Development, Daqing (China)

1997-08-01T23:59:59.000Z

236

Low-frequency anomalies in spectral ratios of single station microtremor measurements: Observations across an oil and gas field in Austria  

E-Print Network [OSTI]

Low-frequency anomalies in spectral ratios of single station microtremor measurements: Observations across an oil and gas field in Austria Marc Lambert and Stefan M. Schmalholz, Geological Institute, ETH are calculated from the different components of ground motion measured at single stations. An example

Podladchikov, Yuri

237

Ammonium Concentrations in Produced Waters from a Mesothermic Oil Field Subjected to Nitrate Injection Decrease through Formation of Denitrifying Biomass and Anammox Activity  

Science Journals Connector (OSTI)

...sulfate- and nitrate-reducing bacteria from an oil field in Argentina. Appl. Environ. Microbiol. 74: 4324-4335. 12 Haveman...injection, p. 370-388. In J. D. Wall et al. (ed.), Bioenergy. ASM Press, Washington, DC. 39 Voordouw, G., A. A...

Sabrina L. Cornish Shartau; Marcy Yurkiw; Shiping Lin; Aleksandr A. Grigoryan; Adewale Lambo; Hyung-Soo Park; Bart P. Lomans; Erwin van der Biezen; Mike S. M. Jetten; Gerrit Voordouw

2010-06-18T23:59:59.000Z

238

Contracts for field projects and supporting research on enhanced oil recovery. Progress review No. 89  

SciTech Connect (OSTI)

Summaries are presented for the DOE contracts related to supported research for thermal recovery of petroleum, geoscience technology, and field demonstrations in high-priority reservoir classes. Data included for each project are: title, contract number, principal investigator, research organization, beginning date, expected completion date, amount of award, objectives of the research, and summary of technical progress.

NONE

1998-04-01T23:59:59.000Z

239

Activities of the Oil Implementation Task Force; Contracts for field projects and supporting research on enhanced oil recovery, July--September 1990  

SciTech Connect (OSTI)

The report contains a general introduction and background to DOE's revised National Energy Strategy Advanced Oil Recovery Program and activities of the Oil Implementation Task Force; a detailed synopsis of the symposium, including technical presentations, comments and suggestions; a section of technical information on deltaic reservoirs; and appendices containing a comprehensive listing of references keyed to general deltaic and geological aspects of reservoirs and those relevant to six selected deltaic plays. Enhanced recovery processes include chemical floodings, gas displacement, thermal recovery, geoscience, and microbial recovery.

Tiedemann, H.A. (ed.) (USDOE Bartlesville Project Office, OK (USA))

1991-05-01T23:59:59.000Z

240

Disposal of NORM-Contaminated Oil Field Wastes in Salt Caverns  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

Prepared for: U.S. Department of Energy U.S. Department of Energy Office of Fossil Energy Office of Fossil Energy National Petroleum Technology Office National Petroleum Technology Office under Contract W -31-109- under Contract W -31-109- Eng Eng -38 -38 Prepared by: Prepared by: John A. Veil, Karen P. Smith, David John A. Veil, Karen P. Smith, David Tomasko Tomasko , , Deborah Deborah Elcock Elcock , Deborah L. Blunt, and , Deborah L. Blunt, and Gustavious Gustavious P. W illiams P. W illiams Argonne National Laboratory August 1998 August 1998 Disposal of NORM - Disposal of NORM - Contam inated O il Contam inated O il Field Wastes in Salt Field Wastes in Salt Caverns Caverns Disposal of NORM in Salt Caverns Page i Table of Contents Acronyms and Abbreviations . . . . . . . . . . . . . . . . . . . . . . . . . .

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


241

Seismic attribute studies, Mississippian Frobisher-Alida oil fields, northeast Williston basin  

SciTech Connect (OSTI)

Subtle Mississippian stratigraphic traps of the Wiley and Glenburn fields of North Dakota and the Creelman field of southeast Saskatchewan illustrate similar seismic response to distinctly different geologic settings. Shoreline facies change, thick supratidal salt pans, carbonate porosity zones, buried hills, and structure on the top of the Mississippian unconformity can all cause similar seismic response (seismic facies). In each instance, vertical and lateral thickness and lithologic changes are the dominant influence on the seismic response. In addition, pitfalls due to tuning, multiples, and other causes can make it difficult, if not impossible, to differentiate these anomalies based on seismic response alone. Careful attribute studies must be coordinated with sound geologic control and models to explore effectively for these subtle stratigraphic traps.

Davis, T.L.

1988-07-01T23:59:59.000Z

242

Geology of oil fields and future exploration potential in west African Aptian Salt basin  

SciTech Connect (OSTI)

The Aptian Salt basin of west Africa, extends from Equatorial Guinea southward to Angola, contains recoverable reserves estimated at nearly 4 billion BOE, and is current producing 600,000 BOPD. The basin developed as a result of tensional forces between west Africa and South America initiated at the end of the Jurassic. The prospective sedimentary sequences ranged in age from Early Cretaceous (uppermost Jurassic in places) to Holocene and is divided by the Aptian transgressive sand and salt into a pre-salt, nonmarine, syn-rift sequence and a post-salt, marine, post-rift sequence. Both the pre- and post-salt sequences contain several successful exploration plays, the most prolific of which are the Early Cretaceous nonmarine sandstone fields in tilted fault blocks of Gabon and Cabinda; Early Cretaceous carbonate buildups on the margins of basement highs in Cabinda; Early Cretaceous transgressive marine sandstone fields in anticlines draped over basement highs in Gabon; Late Cretaceous shallow marine sandstone and carbonate fields in salt-related structures in the Congo, Zaire, Cabinda, and Angola; Late Cretaceous dolomites in structural/stratigraphic traps in Angola; Late Cretaceous/early Tertiary deltaic/estuarine sandstone traps formed by salt movement in Gabon, Cabinda, and angola; and Tertiary marine turbidite fields in Cabinda and Angola. Despite the exploration success in these trends, much of the basin is under or poorly explored. The major problems for exploration are the poor quality of seismic definition beneath the salt, which makes it difficult to predict pre-salt structure and stratigraphy, and the importance of a stratigraphic element in many of the post-salt traps, also difficult to detect on seismic.

Bignell, R.D.; Edwards, A.D.

1987-05-01T23:59:59.000Z

243

Area balance and strain in an extensional fault system: Strategies for improved oil recovery in fractured chalk, Gilbertown Field, southwestern Alabama. Final report, March 1996--September 1998  

SciTech Connect (OSTI)

This project was designed to analyze the structure of Mesozoic and Tertiary strata in Gilbertown Field and adjacent areas to suggest ways in which oil recovery can be improved. The Eutaw Formation comprises 7 major flow units and is dominated by low-resistivity, low-contrast play that is difficult to characterize quantitatively. Selma chalk produces strictly from fault-related fractures that were mineralized as warm fluid migrated from deep sources. Resistivity, dipmeter, and fracture identification logs corroborate that deformation is concentrated in the hanging-wall drag zones. New area balancing techniques were developed to characterize growth strata and confirm that strain is concentrated in hanging-wall drag zones. Curvature analysis indicates that the faults contain numerous fault bends that influence fracture distribution. Eutaw oil is produced strictly from footwall uplifts, whereas Selma oil is produced from fault-related fractures. Clay smear and mineralization may be significant trapping mechanisms in the Eutaw Formation. The critical seal for Selma reservoirs, by contrast, is where Tertiary clay in the hanging wall is juxtaposed with poorly fractured Selma chalk in the footwall. Gilbertown Field can be revitalized by infill drilling and recompletion of existing wells. Directional drilling may be a viable technique for recovering untapped oil from Selma chalk. Revitalization is now underway, and the first new production wells since 1985 are being drilled in the western part of the field.

Pashin, J.C.; Raymond, D.E.; Rindsberg, A.K.; Alabi, G.G.; Carroll, R.E.; Groshong, R.H.; Jin, G.

1998-12-01T23:59:59.000Z

244

Oil Field Electrical Energy Savings Through Energy-Efficient Motor Retrofits  

E-Print Network [OSTI]

. ____ Lobod. Mhd. 40.l... N N "' .. Motor Load % As shown in Figure I, the slip method is very inaccurate, while both Lobodovsky's method and the WEMTTC method are reasonably accurate. However, testing using the WEMTTC method is much easier than... and calculations. Figure 3 shows a block diagram of the system developed at WEMTTC to accomplish this task. To use the motor efficiency meter in the field, the clamps used to facilitate measuring the three-phase power input to the motor must be connected...

Ula, S.; Bershinsky, V.; Cain, W.

245

Investigating Sequestration Potential of Carbonate Rocks during Tertiary Recovery from a Billion Barrel Oil Field, Weyburn, Saskatchewan: the Geoscience Framework (IEA Weyburn CO2 Monitoring Project)  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

Sequestration Potential of Carbonate Rocks during Tertiary Sequestration Potential of Carbonate Rocks during Tertiary Recovery from a Billion Barrel Oil Field, Weyburn, Saskatchewan: the Geoscience Framework (IEA Weyburn CO 2 Monitoring and Storage Project) G. Burrowes (Geoffrey_Burrowes@pancanadian.ca; 403-290-2796) PanCanadian Resources 150 - 9 th Avenue S.W., P.O. Box 2850 Calgary, Alberta, Canada T2P 2S5 C. Gilboy (cgilboy@sem.gov.sk.ca; 306-787-2573) Petroleum Geology Branch, Saskatchewan Energy and Mines 201 Dewdney Avenue East Regina, Saskatchewan, Canada S4N 4G3 Introduction In Western Canada the application of CO 2 injection for enhanced, 'tertiary' oil recovery is a relatively recent addition to the arsenal available to reservoir engineers. The first successful application of CO 2 as a miscible fluid in Western Canada began in 1984 at Joffre Field, a

246

Area balance and strain in an extensional fault system: Strategies for improved oil recovery in fractured chalk, Gilbertown Field, southwestern Alabama -- Year 2. Annual report, March 1997--March 1998  

SciTech Connect (OSTI)

Gilbertown Field is the oldest oil field in Alabama and has produced oil from fractured chalk of the Cretaceous Selma Group and glauconitic sandstone of the Eutaw Formation. Nearly all of Gilbertown Field is still in primary recovery, although waterflooding has been attempted locally. The objective of this project is to analyze the geologic structure and burial history of Mesozoic and Tertiary strata in Gilbertown Field and adjacent areas in order to suggest ways in which oil recovery can be improved. Indeed, the decline of oil production to marginally economic levels in recent years has made this type of analysis timely and practical. Key technical advancements being sought include understanding the relationship of requisite strain to production in Gilbertown reservoirs, incorporation of synsedimentary growth factors into models of area balance, quantification of the relationship between requisite strain and bed curvature, determination of the timing of hydrocarbon generation, and identification of the avenues and mechanisms of fluid transport.

Pashin, J.C.; Raymond, D.E.; Rindsberg, A.K.; Alabi, G.G.; Carroll, R.E.

1998-09-01T23:59:59.000Z

247

OpenEI - oil  

Open Energy Info (EERE)

/0 en AEO2011: Oil and Gas /0 en AEO2011: Oil and Gas End-of-Year Reserves and Annual Reserve Additions http://en.openei.org/datasets/node/805 This dataset comes from the Energy Information Administration (EIA), and is part of the 2011 Annual Energy Outlook Report (AEO2011). This dataset is table 134, and contains only the reference case. The data is broken down into Crude oil, dry natural gas. 

License
field field-type-text field-field-license-type"> Type of License: 

248

Crude Oil Analysis Database  

DOE Data Explorer [Office of Scientific and Technical Information (OSTI)]

The composition and physical properties of crude oil vary widely from one reservoir to another within an oil field, as well as from one field or region to another. Although all oils consist of hydrocarbons and their derivatives, the proportions of various types of compounds differ greatly. This makes some oils more suitable than others for specific refining processes and uses. To take advantage of this diversity, one needs access to information in a large database of crude oil analyses. The Crude Oil Analysis Database (COADB) currently satisfies this need by offering 9,056 crude oil analyses. Of these, 8,500 are United States domestic oils. The database contains results of analysis of the general properties and chemical composition, as well as the field, formation, and geographic location of the crude oil sample. [Taken from the Introduction to COAMDATA_DESC.pdf, part of the zipped software and database file at http://www.netl.doe.gov/technologies/oil-gas/Software/database.html] Save the zipped file to your PC. When opened, it will contain PDF documents and a large Excel spreadsheet. It will also contain the database in Microsoft Access 2002.

Shay, Johanna Y.

249

Reactivation of an Idle Lease to Increase Heavy Oil Recovery Through Application of Conventional Steam Drive Technology in a Low Dip Slope and Basin Reservoir in the Midway-Sunset Field, San Jaoquin Basin, California  

SciTech Connect (OSTI)

A previously idle portion of the Midway-Sunset field, the ARCO Western Energy Pru Fee property, is being brought back into commercial production through tight integration of geologic characterization, geostatistical modeling, reservoir simulation, and petroleum engineering. This property, shut-in over a decade ago as economically marginal using conventional cyclic steaming methods, has a 200-300 foot thick oil column in the Monarch Sand. However, the sand lacks effective steam barriers and has a thick water-saturation zone above the oil-water contact. These factors require an innovative approach to steam flood production design that will balance optimal total oil production against economically viable steam-oil ratios and production rates. The methods used in the Class III demonstration are accessible to most operators in the Midway-Sunset field and could be used to revitalize properties with declining production of heavy oils throughout the region.

Steven Schamel

1998-03-20T23:59:59.000Z

250

Reactivation of an Idle Lease to Increase Heavy Oil Recovery Through Application of Conventional Steam Drive Technology in a Low Dip Slope and Basin Reservoir in the Midway-Sunset Field, San Jaoquin Basin, California  

SciTech Connect (OSTI)

A previously idle portion of the Midway-Sunset field, the ARCO Western Energy Pru Fee property, is being brought back into commercial production through tight integration of geologic characterization, geostatistical modeling, reservoir simulation, and petroleum engineering. This property, shut-in over a decade ago as economically marginal using conventional cyclic steaming methods, has a 200-300 foot thick oil column in the Monarch Sand. However, the sand lacks effective steam barriers and has a thick water-saturation zone above the oil-water contact. These factors require an innovative approach to steam flood production design that will balance optimal total oil production against economically viable steam-oil ratios and production rates. The methods used in the Class III demonstration are accessible to most operators in the Midway-Sunset field and could be used to revitalize properties with declining production of heavy oils throughout the region.

Steven Schamel

1998-08-31T23:59:59.000Z

251

Field Laboratory in the Osage Reservation -- Determination of the Status of Oil and Gas Operations: Task 1. Development of Survey Procedures and Protocols  

SciTech Connect (OSTI)

Procedures and protocols were developed for the determination of the status of oil, gas, and other mineral operations on the Osage Mineral Reservation Estate. The strategy for surveying Osage County, Oklahoma, was developed and then tested in the field. Two Osage Tribal Council members and two Native American college students (who are members of the Osage Tribe) were trained in the field as a test of the procedures and protocols developed in Task 1. Active and inactive surface mining operations, industrial sites, and hydrocarbon-producing fields were located on maps of the county, which was divided into four more or less equal areas for future investigation. Field testing of the procedures, protocols, and training was successful. No significant damage was found at petroleum production operations in a relatively new production operation and in a mature waterflood operation.

Carroll, Herbert B.; Johnson, William I.

1999-04-27T23:59:59.000Z

252

OIL SHALE  

E-Print Network [OSTI]

Seyitömer, Himmeto?lu and Hat?lda? oil shale deposits. The results demonstrate that these oil shales are

Fields (in-situ Combustion Approach; M. V. Kök; G. Guner; S. Bagci?

253

Support for Offshore Oil and Gas Drilling among the California Public  

E-Print Network [OSTI]

of support for offshore oil drilling that accompanied thein Support for Offshore Oil Drilling The earliest FieldPoll question about offshore oil drilling was asked in 1977.

Smith, Eric R.A.N.

2003-01-01T23:59:59.000Z

254

Effects of local microbial bioaugmentation and biostimulation on the bioremediation of total petroleum hydrocarbons (TPH) in crude oil contaminated soil based on laboratory and field observations  

Science Journals Connector (OSTI)

Abstract This study investigated factors enhancing the performance of the bioremediation of Total Petroleum Hydrocarbons (TPHs) in crude oil-contaminated soil in laboratory and field observations. The bioaugmentation process used local microbial consortia (MC1, MC2 and MC3) combined with the biostimulation processes of nutrient addition (mineral–salt medium, MSM and NPK) and enhanced air stimulation (air supply and Oxygen Releasing Compound (ORC™)). The microcosm tests were conducted in tank and soil column setups, whereas the field test was performed in test plots inside an oil and gas facility in Malaysia. In the microcosm tank experiment, the combination of bioaugmentation (10% inoculum size of MC3) and MSM biostimulation yielded the highest TPH degradation of 79% of the total. In the column experiments, the degradation of \\{TPHs\\} in the top soil was highest in columns combining bioaugmentation and nutrient addition, whereas in the bottom soil, the degradation of \\{TPHs\\} was highest in columns combining bioaugmentation with the addition of both nutrients and ORCs. In the field demonstration, 97% of the \\{TPHs\\} were degraded in the top soil (0–1 m) when bioaugmented with MC2. The kinetic analysis study of the microcosm tank showed that a combination of both biostimulation and bioaugmentation in the soil column achieved the fastest rate constant of 0.0390 day?1. The field test also demonstrated a comparable rate constant of 0.0339 day?1. The kinetic rate constants in both the laboratory and field indicated that the best treatment method for the contaminated site is a combination of MC3 bioaugmentation and nutrient biostimulation.

Fatihah Suja; Fazli Rahim; Mohd Raihan Taha; Nuraini Hambali; M. Rizal Razali; Alia Khalid; Ainon Hamzah

2014-01-01T23:59:59.000Z

255

India: Becoming well oiled  

Science Journals Connector (OSTI)

... been stirred into vigorous action and its redoubled efforts to find more oil onshore and offshore are beginning to yield results. From onshore fields in Assam and Gujarat, production this ... figure will go up to 11 million tonnes.

Correspondent

1976-04-01T23:59:59.000Z

256

Imbibition assisted oil recovery  

E-Print Network [OSTI]

analyzed in detail to investigate oil recovery during spontaneous imbibition with different types of boundary conditions. The results of these studies have been upscaled to the field dimensions. The validity of the new definition of characteristic length...

Pashayev, Orkhan H.

2004-11-15T23:59:59.000Z

257

Reactivation of an Idle Lease to Increase Heavy Oil Recovery through Application of Conventional Steam Drive Technology in a Low Dip Slope and Basin Reservoir in the Midway-Sunset Field, San Jaoquin Basin, California  

SciTech Connect (OSTI)

A previously idle portion of the Midway-Sunset field, the ARCO Western Energy Pru Fee property, is being brought back into commercial production through tight integration of geologic characterization, geostatistical modeling, reservoir simulation, and petroleum engineering. This property, shut-in over a decade ago as economically marginal using conventional cyclic steaming methods, has a 200-300 foot thick oil column in the Monarch Sand. However, the sand lacks effective steam barriers and has a thick water-saturation zone above the oil-water contact. These factors require an innovative approach to steam flood production design that will balance optimal total oil production against economically viable steam-oil ratios and production rates. The methods used in the Class III demonstration are accessible to most operators in the Midway-Sunset field and could be used to revitalize properties with declining production of heavy oils throughout the region. In January 1997 the project entered its second and main phase with the purpose of demonstrating whether steamflood can be a more effective mode of production of the heavy, viscous oils from the Monarch Sand reservoir than the more conventional cyclic steaming. The objective is not just to produce the pilot site within the Pru Fee property south of Taft, but to test which production parameters optimize total oil recovery at economically acceptable rates of production and production costs.

Steven Schamel

1998-02-27T23:59:59.000Z

258

„Peak Oil  

Science Journals Connector (OSTI)

Wissenschaftliche Voraussagen deuten auf „Peak Oil“, das Maximum globaler Erdölförderung, in unserer ... der demokratischen Systeme führen. Psychoanalytische Betrachtung darf „Peak Oil“ für die Zivilisation als e...

Dr. Manuel Haus; Dr. med. Christoph Biermann

2013-03-01T23:59:59.000Z

259

Increasing heavy oil reserves in the Wilmington oil field through advanced reservoir characterization and thermal production technologies. [Quarterly report], October 1, 1995--December 31, 1995  

SciTech Connect (OSTI)

The project involves improving thermal recovery techniques in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., California using advanced reservoir characterization and thermal production technologies. This is the third quarterly technical progress report for the project. Through December 1995, the project is on schedule and on budget. Several significant technical achievements have already been successfully accomplished including the drilling of four horizontal wells (two producers and two steam injectors) utilizing a new and lower cost drilling program, the drilling of five observation wells to monitor the horizontal steamflood pilot, the installation of a subsurface harbor channel crossing for delivering steam to an island location, and a geochemical study of the scale minerals being created in the wellbore. Steam injection into the two horizontal injection wells began in mid-December 1995 utilizing the new 2400 ft steam line under the Cerritos Channel. Work on the basic reservoir engineering is expected to be completed in March 1996. A working deterministic geologic model was completed which allowed work to commence on the stochastic geologic and reservoir simulation models.

Hara, S. [Tidelands Oil Production Co., Long Beach, CA (United States)

1996-01-31T23:59:59.000Z

260

This Week In Petroleum Printer-Friendly Version  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

crude oil reserves in 2007 came largely from the unconventional Bakken Formation. Oil Shale or Oil Produced from Shale? It is important to recognize the distinction between the...

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


261

Modeling of Energy Production Decisions: An Alaska Oil Case Study  

E-Print Network [OSTI]

Economics of Undiscovered Oil and Gas in the Central North1993) Mathematical theory of oil and gas recovery: withapplications to ex-USSR oil and gas fields, Boston: Kluwer

Leighty, Wayne

2008-01-01T23:59:59.000Z

262

field  

National Nuclear Security Administration (NNSA)

9%2A en Ten-Year Site Plans (TYSP) http:nnsa.energy.govaboutusouroperationsinfopsinfopstysp

field field-type-text field-field-page-name">

263

Contracts for field projects and supporting research on enhanced oil recovery. Progress review No. 78, quarter ending March 31, 1994  

SciTech Connect (OSTI)

This report presents descriptions of various research projects and field projects concerned with the enhanced recovery of petroleum. Contract numbers, principal investigators, company names, and project management information is included.

NONE

1995-05-01T23:59:59.000Z

264

Oil shale technology  

SciTech Connect (OSTI)

Oil shale is undoubtedly an excellent energy source that has great abundance and world-wide distribution. Oil shale industries have seen ups and downs over more than 100 years, depending on the availability and price of conventional petroleum crudes. Market forces as well as environmental factors will greatly affect the interest in development of oil shale. Besides competing with conventional crude oil and natural gas, shale oil will have to compete favorably with coal-derived fuels for similar markets. Crude shale oil is obtained from oil shale by a relatively simple process called retorting. However, the process economics are greatly affected by the thermal efficiencies, the richness of shale, the mass transfer effectiveness, the conversion efficiency, the design of retort, the environmental post-treatment, etc. A great many process ideas and patents related to the oil shale pyrolysis have been developed; however, relatively few field and engineering data have been published. Due to the vast heterogeneity of oil shale and to the complexities of physicochemical process mechanisms, scientific or technological generalization of oil shale retorting is difficult to achieve. Dwindling supplied of worldwide petroleum reserves, as well as the unprecedented appetite of mankind for clean liquid fuel, has made the public concern for future energy market grow rapidly. the clean coal technology and the alternate fuel technology are currently of great significance not only to policy makers, but also to process and chemical researchers. In this book, efforts have been made to make a comprehensive text for the science and technology of oil shale utilization. Therefore, subjects dealing with the terminological definitions, geology and petrology, chemistry, characterization, process engineering, mathematical modeling, chemical reaction engineering, experimental methods, and statistical experimental design, etc. are covered in detail.

Lee, S. (Akron Univ., OH (United States). Dept. of Chemical Engineering)

1991-01-01T23:59:59.000Z

265

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 22, quarter ending March 31, 1980  

SciTech Connect (OSTI)

This report contains statements of objectives and summaries of technical progress on all DOE contracts pertaining to enhanced oil recovery and improved drilling techniques. Subject categories include chemical flooding; carbon dioxide injection; thermal recovery of heavy oil; resource assessment; improved drilling technology; residual oil; environmental; petroleum technology; and microbial enhanced oil recovery. An index containing the names of the companies and institutions involved is included. Current publications resulting from the DOE contractual program are listed. (DMC)

Linville, B. (ed.)

1980-07-01T23:59:59.000Z

266

The recovery of oil from carbonate reservoirs by fluid injection  

E-Print Network [OSTI]

Hole 70 Neasured and Calculated Productivities Obtained on Wells Completed Through Perforations 39 Cumulative Oil Recovery Versus Total Water and Oil Throughf low for Stratified Reservoirs- lj. O Cumulative Oil Recovery Versus Total Water and Oil... for Field A 12, Cumulative Oil Recovery Versus Total Water and Oil Throughflow for Field B 13, -20, Permeability Distribution Plots $5-52 The object of this project was to study the extent of the variations of the permeability in carbonate reservoirs...

Coleman, Dwayne Marvin

2012-06-07T23:59:59.000Z

267

Fluorescence analysis can identify movable oil in self-sourcing reservoirs  

SciTech Connect (OSTI)

The recent surge of activity involving self-sourcing reservoirs and horizontal drilling recognizes a little tapped niche in the domestic energy mix. Such prolific pays as the Cretaceous Bakken and Austin Chalk have drawn research interest and large amounts of investment capital. Fluorescence analysis can discern movable oil--as opposed to exhausted source rock--in such reservoirs with an inexpensive test. Other potential targets are the Cretaceous Mesaverde in the Piceance basin, Devonian New Albany shale in Kentucky, Devonian Antrim shale in the Michigan basin, and the Cretaceous Niobrara, Mancos, and Pierre formations in Colorado and New Mexico. To insure success in this niche this key question must be answered positively: Is movable oil present in the reservoir? Even if tectonic studies verify a system of open fractures, sonic logs confirm overpressuring in the zone, and resistivity logs document the maturity of the source, the ultimate question remains: Is movable oil in the fractures available to flow to the borehole? The paper explains a technique that will answer these questions.

Calhoun, G.G. [Calhoun (Gerry G.), Midland, TX (United States)

1995-06-05T23:59:59.000Z

268

Water issues associated with heavy oil production.  

SciTech Connect (OSTI)

Crude oil occurs in many different forms throughout the world. An important characteristic of crude oil that affects the ease with which it can be produced is its density and viscosity. Lighter crude oil typically can be produced more easily and at lower cost than heavier crude oil. Historically, much of the nation's oil supply came from domestic or international light or medium crude oil sources. California's extensive heavy oil production for more than a century is a notable exception. Oil and gas companies are actively looking toward heavier crude oil sources to help meet demands and to take advantage of large heavy oil reserves located in North and South America. Heavy oil includes very viscous oil resources like those found in some fields in California and Venezuela, oil shale, and tar sands (called oil sands in Canada). These are described in more detail in the next chapter. Water is integrally associated with conventional oil production. Produced water is the largest byproduct associated with oil production. The cost of managing large volumes of produced water is an important component of the overall cost of producing oil. Most mature oil fields rely on injected water to maintain formation pressure during production. The processes involved with heavy oil production often require external water supplies for steam generation, washing, and other steps. While some heavy oil processes generate produced water, others generate different types of industrial wastewater. Management and disposition of the wastewater presents challenges and costs for the operators. This report describes water requirements relating to heavy oil production and potential sources for that water. The report also describes how water is used and the resulting water quality impacts associated with heavy oil production.

Veil, J. A.; Quinn, J. J.; Environmental Science Division

2008-11-28T23:59:59.000Z

269

RMOTC to Test Oil Viscosity Reduction Technology  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

to Test Oil Viscosity Reduction Technology to Test Oil Viscosity Reduction Technology The Rocky Mountain Oilfield Testing Center (RMOTC) announces that the "Teapot Dome" oil field in Wyoming is hosting a series of tests funded by STWA, Inc. ("STWA") to determine the performance of its Applied Oil Technology (AOT(tm)) in reducing crude oil's viscosity to lower transportation costs for pipeline operators. The testing is managed by RMOTC, and conducted at Naval Petroleum Reserve No. 3, also known as the Teapot Dome oil field. RMOTC is providing the infrastructure and technical expertise to support companies such as STWA in their efforts to validate new technologies and bring those products and

270

Peak Oil  

Science Journals Connector (OSTI)

At the start of the new millennium, the expression “Peak Oil” was unknown. Nevertheless, a discussion about when the world’s rate of oil production would reach its maximum had already ... . King Hubbert presented...

Kjell Aleklett

2012-01-01T23:59:59.000Z

271

Peak Oil  

Science Journals Connector (OSTI)

Between 2000 and 2010, world oil prices advanced from approximately $25 per barrel to more than $100 per barrel. The price appreciation of oil over the decade was around ten times the rate of inflation.

Robert Rapier

2012-01-01T23:59:59.000Z

272

Peak oil supply or oil not for sale?  

Science Journals Connector (OSTI)

Abstract The restrictions imposed by climate change are inevitable and will be exerted either via precautionary mitigation of (mainly energy-related) CO2 emissions or via irreversible impacts on ecosystems and on human habitats. Either way, oil markets are bound to incur drastic shrinking. Concern over peak oil supply will crumble when the irrevocable peak oil demand is created. Replacing oil in the world's energy economies requires redirected market forces, notably in the form of steadily increasing oil end-use prices. Yet, thus far, crude oil prices have obeyed the market fundamentals of expanding-contracting demand and oligopolistic supply. A hockey stick supply curve supports high sales prices, providing large rents to submarginal sources. Cutting oil demand and maintaining high prices implies reducing the supply hockey stick's length by curtailing some oil producers. In such a scenario, the alliances, goals, and tactics of oil geopolitics are set to change. We identify a distribution over friendly and hostile oil suppliers, with others drifting in between the two sides. Conflicts and warfare are less aimed at conquering oil fields for exploitation than at paralyzing production capabilities of opponents or of unreliable transient sources. Covert warfare and instigation of internal conflicts are likely tactics to exhaust hostile opponents.

Aviel Verbruggen; Thijs Van de Graaf

2013-01-01T23:59:59.000Z

273

by Patrick M. Barkey RecoveryWhat's on Track and What's Not  

E-Print Network [OSTI]

activity in the Elm Coulee oil fields in the Bakken, have continued at full pace throughout the year Domestic Product to less than 2 percent in the second quarter of 2012. Many countries in Europe by this measure (Figure 1). · Healing housing markets. After experiencing cumulative price declines of as much

Vonessen, Nikolaus

274

An application of Crosswell Tomography using a hydrophone receiver array and airgun source to monitor steam migration in an unconsolidated, heavy-oil sandstone, West Coalinga Field, California  

SciTech Connect (OSTI)

This crosswell tomography field trial demonstrates the viability and cost- reducing benefits of a hydrophone receiver array and airgun source for monitoring steam (heat) migration within an unconsolidated, heavy-oil sandstone. This project represents one of the first applications of hydrophone receivers in such an environment. Data quality from the hydrophone array proved more than adequate for P-wave tomography while costs were reduced dramatically from estimates using a clamped geophone array. Additionally, the resolution provided by the capture of travel-time data from interwell areas offered a distinct advantage over conventional monitoring techniques limited to observation wells. Two crosswell surveys were conducted in the vicinity of a new, infill steam injector. The purpose was to monitor steam migration within an 80-foot thick, sandstone interval by detecting the heat-induced velocity decrease between the first survey, conducted just before steam injection, and the second survey conducted approximately three months later. Difference plots of the two surveys clearly define regions of significant temperature change and contact temperature logs corroborate the zone of peak change. The crosswell tomography data and the inferred steam migration characteristics immediately altered an operational strategy for the drive and were later a factor in the abandonment of continuous steam injection.

Blevens, D.M. (Chevron USA Production Co., Bakersfield, CA (United States)); Fairborn, J.W. (Wellseismic Computing Services, Balboa, CA (United States))

1996-01-01T23:59:59.000Z

275

An application of Crosswell Tomography using a hydrophone receiver array and airgun source to monitor steam migration in an unconsolidated, heavy-oil sandstone, West Coalinga Field, California  

SciTech Connect (OSTI)

This crosswell tomography field trial demonstrates the viability and cost- reducing benefits of a hydrophone receiver array and airgun source for monitoring steam (heat) migration within an unconsolidated, heavy-oil sandstone. This project represents one of the first applications of hydrophone receivers in such an environment. Data quality from the hydrophone array proved more than adequate for P-wave tomography while costs were reduced dramatically from estimates using a clamped geophone array. Additionally, the resolution provided by the capture of travel-time data from interwell areas offered a distinct advantage over conventional monitoring techniques limited to observation wells. Two crosswell surveys were conducted in the vicinity of a new, infill steam injector. The purpose was to monitor steam migration within an 80-foot thick, sandstone interval by detecting the heat-induced velocity decrease between the first survey, conducted just before steam injection, and the second survey conducted approximately three months later. Difference plots of the two surveys clearly define regions of significant temperature change and contact temperature logs corroborate the zone of peak change. The crosswell tomography data and the inferred steam migration characteristics immediately altered an operational strategy for the drive and were later a factor in the abandonment of continuous steam injection.

Blevens, D.M. [Chevron USA Production Co., Bakersfield, CA (United States); Fairborn, J.W. [Wellseismic Computing Services, Balboa, CA (United States)

1996-12-31T23:59:59.000Z

276

Field evaluation of all-season tactical engine oil OE/HDO-15/40 at Ft. Knox, Kentucky and Ft. Bliss, Texas. Interim report, July 1984-December 1985  

SciTech Connect (OSTI)

Requirements for a multiviscosity grade 15W-40 engine oil were developed and the lubricant introduced for military consumption. The program efforts cover a demonstration and field-validation program of the newly introduced grade 15W-40 lubricant. The test involved a wide variety of combat, tactical, and support equipment operated by the 2D Squadron, 6th Cavalry at Fort Knox, KY, and the 3D Armored Cavalry Regiment at Fort Bliss, TX. During the test, vehicles accumulated in excess of 1,840,000 miles of operation under ambient conditions ranging from monthly low temperatures of -8 C (18 F) at Fort Knox to monthly high temperatures of 35 C (95 F) at Fort Bliss. Two-grade 15W-40, MIL-L-2104D qualified lubricants were employed in the test, one product at each of the test locations. The test lubricants were used in all equipment components, engines, transmissions, hydraulic systems, etc., that required MIL-L-2104 engine oil. Equipment within the test fleets were monitored in regard to wear performance, frequency of component replacement, and operational characteristics. Overall, the grade 15W-40 products demonstrated satisfactory and equivalent performance to single-graded oils. The oil was well received by both operators and maintenance personnel who noted that the grade 15W-40 products significantly reduced logistics burden by having only one grade product to requisition, store, and transport to the field.

Butler, W.E.; Alvarez, R.A.; Buckingham, J.P.; Owens, E.C.; Bowen, T.C.

1986-07-01T23:59:59.000Z

277

Enhanced oil recovery using hydrogen peroxide injection  

SciTech Connect (OSTI)

NOVATEC received an US Patent on a novel method to recovery viscous oil by hydrogen peroxide injection. The process appears to offer several significant improvements over existing thermal methods of oil recovery. Tejas joined NOVATEC to test the process in the laboratory and to develop oil field applications and procedures.

Moss, J.T. Jr.; Moss, J.T.

1995-02-01T23:59:59.000Z

278

OPEC Prices Make Heavy Oil Look Profitable  

Science Journals Connector (OSTI)

...barrels of heavy oil, a lighter...defined as any oil heavier than...flows into production lines at a profitable rate. Oil from the sands...strip-mine operations linked by...upgrading" equipment, in the industry...Ath-abaska field. Construction...summer. Its cost was $2...894 nerve gas ("Weteye...

ELIOT MARSHALL

1979-06-22T23:59:59.000Z

279

Modeling of Energy Production Decisions: An Alaska Oil Case Study  

E-Print Network [OSTI]

Oil Simulator, 1995) to simulate the effects of water injection rates, the cumulative production of the field,

Leighty, Wayne

2008-01-01T23:59:59.000Z

280

Understanding the Impact of Open-Framework Conglomerates on Water-Oil Displacements: Victor Interval of the Ivishak Reservoir, Prudhoe Bay Field, Alaska  

E-Print Network [OSTI]

The Victor Unit of the Ivishak Formation in the Prudhoe Bay Oilfield is characterized by high net-to-gross fluvial sandstones and conglomerates. The highest permeability is found within sets of cross-strata of open-framework conglomerate (OFC). They are preserved within unit bar deposits and assemblages of unit bar deposits within compound (braid) bar deposits. They are thief zones limiting enhanced oil recovery. We incorporate recent research that has quantified important attributes of their sedimentary architecture within preserved deposits. We use high-resolution models to demonstrate the fundamental aspects of their control on oil production rate, water breakthrough time, and spatial and temporal distribution of residual oil saturation. We found that when the pressure gradient is oriented perpendicular to the paleoflow direction, the total oil production and the water breakthrough time are larger, and remaining oil saturation is smaller, than when it is oriented parallel to paleoflow. The pressure differe...

Gershenzon, Naum I; Ritzi, Robert W; Dominic, David F

2014-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


281

Oil history, potential converge in Azerbaijan  

SciTech Connect (OSTI)

Azerbaijan, the oldest known oil producing region in the world, still holds great potential for new discoveries and increased production. A multi-billion dollar production sharing agreement was recently signed with a consortium of primarily western oil companies to develop three oil fields in the Caspian Sea. Soon, Azerbaijan will offer new exploration acreage both offshore and onshore. This paper describes the history of oil production in Azerbaijan, offshore developments, tectonics, stratigraphy, petroleum traps, mud volcanoes, and short summaries of several oil producing areas. Current production is about 9 million tons/yr of oil and 7 billion cu m/yr of natural gas.

Narimanov, A.A. [State Oil Co. of Azerbaijan, Baku (Azerbaijan); Palaz, I. [Amoco Production Co., Houston, TX (United States)

1995-05-22T23:59:59.000Z

282

Contamination of Soil by Crude Oil and Drilling Muds. Use of Wastes by Production of Road Construction Materials  

Science Journals Connector (OSTI)

A thermal method of separating wastes into organic and mineral parts is proposed for processing crude oil sludges and oil-contaminated soils accumulated in operation of oil fields and oil pipelines. After expo...

Z. A. Mansurov; E. K. Ongarbaev…

2001-11-01T23:59:59.000Z

283

Fracture characterization and fluid flow simulation with geomechanical constraints for a CO2–EOR and sequestration project Teapot Dome Oil Field, Wyoming, USA  

Science Journals Connector (OSTI)

Mature oil and gas reservoirs are attractive targets for geological sequestration of CO2 because of their potential storage capacities and the possible cost offsets from enhanced oil recovery (EOR). In this work, we analyze the fracture system of the Tensleep Formation to develop a geomechanically-constrained 3D reservoir fluid flow simulation at Teapot Dome Oil Field, WY, USA. Teapot Dome is the site of a proposed CO2-EOR and sequestration pilot project. The objective of this work is to model the migration of the injected CO2 in the fracture reservoir, as well as to obtain limits on the rates and volumes of CO2 that can be injected, without compromising seal integrity. Furthermore we want to establish the framework to design injection experiments that will provide insight into the fracture network of the reservoir, in particular of fracture permeability and connectivity. Teapot Dome is an elongated asymmetrical, basement-cored anticline with a north-northeast axis. The Tensleep Fm. in this area is highly fractured, and consists of an intercalation of eolian-dune sandstones and inter-dune deposits. The dune sandstones are permeable and porous intervals with different levels of cementation that affects their porosity, permeability, and fracture intensity. The inter-dune deposits consist of thin sabkha carbonates, minor evaporates, and thin but widespread extensive beds of very low-permeability dolomicrites. The average permeability is 30 mD, ranging from 10–100 mD. The average reservoir thickness is 50 ft. The caprock for the Tensleep Fm. consists of the Opeche Shale member, and the anhydrite of the Minnekhata member. The reservoir has strong aquifer drive. In the area under study, the Tensleep Fm. has its structural crest at 1675 m. It presents a 2-way closure trap against a NE-SW fault to the north and possibly the main thrust to the west. The CO2-EOR and sequestration project will consist of the injection of 1 million cubic feet of supercritical CO2 for six weeks. A previous geomechanical analysis suggested that the trapping faults do not appear to be at risk of reactivation and it was estimated that caprock integrity is not a risk by the buoyancy pressure of the maximum CO2 column height that the formation can hold. However, in the present study we established the presence of critically stressed minor faults and fractures in the reservoir and caprock, which if reactivated, could not only enhance the permeability of the reservoir, but potentially compromise the top seal capacity. The results of the preliminary fluid flow simulations indicate that the injected CO2 will rapidly rise to the top layers, above the main producing interval, and will accumulate in the fractures, where almost none will get into the matrix.

Laura Chiaramonte; Mark Zoback; Julio Friedmann; Vicki Stamp; Chris Zahm

2011-01-01T23:59:59.000Z

284

Development and field testing of a process for recovering heavy crude oil in the Carlyle pool-Allen County, Kansas using the Vapor Therm generator. Final report  

SciTech Connect (OSTI)

A Vapor Therm generator capable of producing steam and inert gases was built for conditions encountered in the Carlyle pool, and is capable of delivering heated gases at 900 psi and 700/sup 0/F. New wells were drilled in a five spot pattern with an inter-well distance of 208.7 ft. Logs and cores from these new wells were obtained and the subsurface reservoir was evaluated. Oil content of 1197 BSTO/Ac-Ft was encountered. This oil was 19.5/sup 0/ API with a viscosity of 1026 cps at 70/sup 0/F. The net pay thickness beneath the pattern exceeded thirty-five feet. Bartlesville sand porosity was 23.6% and absolute permeability was 695 md. Initial reservoir pressure was 235 psi. The oil reservoir is underlain by an extensive aquifer whose thickness exceeds one hundred feet. On January 31, 1977, the first of four stimulation cycles in the Bartleville sand was begun. The final cycle was concluded on March 5, 1978. During these months of cyclic stimulation-production, the wells produced at a sustained average rate of 7.82 BSTO/day and a water/oil ratio of 1.3. Over three barrels of oil per barrel of steam injected was recovered on the 4th cycle. Maximum production rate is 151 BSTO/well/week. Total oil production during the four cycles was 9034 barrels of stock tank oil, indicating an enhanced recovery of 6.04% of original oil in place or 71.2 BSTO/Ac-Ft.

Sperry, J.S.

1980-09-01T23:59:59.000Z

285

Gulf of Mexico Federal Offshore - Texas Crude Oil + Lease Condensate...  

U.S. Energy Information Administration (EIA) Indexed Site

New Field Discoveries (Million Barrels) Gulf of Mexico Federal Offshore - Texas Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1...

286

Gulf of Mexico Federal Offshore - Texas Crude Oil + Lease Condensate...  

U.S. Energy Information Administration (EIA) Indexed Site

New Reservoir Discoveries in Old Fields (Million Barrels) Gulf of Mexico Federal Offshore - Texas Crude Oil + Lease Condensate New Reservoir Discoveries in Old Fields (Million...

287

Louisiana State Offshore Crude Oil + Lease Condensate New Reservoir...  

U.S. Energy Information Administration (EIA) Indexed Site

New Reservoir Discoveries in Old Fields (Million Barrels) Louisiana State Offshore Crude Oil + Lease Condensate New Reservoir Discoveries in Old Fields (Million Barrels) Decade...

288

Essays on Macroeconomics and Oil  

E-Print Network [OSTI]

Oil Production . . . . . . . . . . . . . . . . . . . . . . . . . . .Oil Production in Venezuela and Mexico . . . . . . . . . .Oil Production and Productivity in Venezuela and

CAKIR, NIDA

2013-01-01T23:59:59.000Z

289

Essays on Macroeconomics and Oil  

E-Print Network [OSTI]

the Oil Industry . . . . . . . . . . . . . . . . . . . . . .in the Venezuelan Oil Industry . . . . . . . . . . . . .and Productivity: Evidence from the Oil Industry . .

CAKIR, NIDA

2013-01-01T23:59:59.000Z

290

Evaluation and application of highly alloyed materials for corrosive oil production  

Science Journals Connector (OSTI)

Selection of materials for production of oil from the Brae Field, operated by Marathon Oil Company, in the North Sea required extensive...

B. D. Craig

1983-06-01T23:59:59.000Z

291

Numerical Simulation of Low Salinity Water Flooding Assisted with Chemical Flooding for Enhanced Oil Recovery.  

E-Print Network [OSTI]

?? World proved oil reserve gradually decreases due to the increase production but decrease new field discovery. The focus on enhance oil recovery from the… (more)

Atthawutthisin, Natthaporn

2012-01-01T23:59:59.000Z

292

Recativation of an Idle Lease to Increase Heavy Oil Recovery Through Application of Conventional Steam Drive Technology in a Low Dip Slope and Basin Reservoir in the Midway-Sunset Field, San Jaoquin Basin, California  

SciTech Connect (OSTI)

This project reactivates ARCO`s idle Pru Fee lease in the Midway- Sunset field, California and conducts a continuous steamflood enhanced oil recovery demonstration aided by an integration of modem reservoir characterization and simulation methods. Cyclic steaming is being used to reestablish baseline production within the reservoir characterization phase of the project. During the demonstration phase scheduled to begin in January 1997, a continuous steamflood enhanced oil recovery will be initiated to test the incremental value of this method as an alternative to cyclic steaming. Other economically marginal Class III reservoirs having similar producibility problems will benefit from insight gained in this project. The objectives of the project are: (1) to return the shut-in portion of the reservoir to optimal commercial production; (2) to accurately describe the reservoir and recovery process; and (3) to convey the details of this activity to the domestic petroleum industry, especially to other producers in California, through an aggressive technology transfer program.

Schamel, Steven

1997-03-24T23:59:59.000Z

293

Reactivation of an Idle Lease to Increase Heavy Oil Recovery through Application of Conventional Steam Drive Technology in a Low Dip Slope and Reservoir in the Midway-Sunset Field, San Jaoquin Basin, California  

SciTech Connect (OSTI)

This project reactivates ARCO's idle Pru Fee lease in the Midway-Sunset field, California and conducts a continuous steamflood enhanced oil recovery demonstration aided by an integration of modern reservoir characterization and simulation methods. Cyclic steam was used to reestablish baseline production within the reservoir characterization phase of the project completed in December 1996. During the demonstration phase begun in January 1997, a continuous steamflood enhanced oil recovery is testing the incremental value of this method as an alternative to cyclic steaming. Other economically marginal Class III reservoirs having similar producibility problems will benefit from insight gained in this project. The objective of the project are: (1) to return the shut-in portion of the reservoir to optimal commercial production; (2) to accurately describe the reservoir and recovery process; and (3) to convey the details of this activity to the domestic petroleum industry, especially to other producers in California, through an aggressive technology transfer program.

Schamel, Steven

1999-07-08T23:59:59.000Z

294

Reactivation of an Idle Lease to Increase Heavy Oil Recovery Through Application of Conventional Steam Drive Technology in a Low Dip Slope and Basin Reservoir in the Midway-Sunset Field, San Jaoquin Basin, California  

SciTech Connect (OSTI)

This project reactivates ARCO?s idle Pru Fee property in the Midway-Sunset field, California and conducts a continuous steamflood enhanced oil recovery demonstration aided by an integration of modern reservoir characterization and simulation methods. Cyclic steaming was used to reestablish baseline production within the reservoir characterization phase of the project. During the demonstration phase begun in January 1997, a continuous steamflood enhanced oil recovery was initiated to test the incremental value of this method as an alternative to cyclic steaming. Other economically marginal Class III reservoirs having similar producibility problems will benefit from insight gained in this project. The objectives of the project are: (1) to return the shut-in portion of the reservoir to optimal commercial production; (2) to accurately describe the reservoir and the recovery process; and (3) to convey the details of this activity to the domestic petroleum industry, especially to other producers in California, through an aggressive technology transfer program.

Steven Schamel

1997-07-29T23:59:59.000Z

295

Reactivation of an Idle Lease to Increase Heavy Oil Recovery through Application of Conventional Steam Drive Technology in a Low Dip Slope and Basin Reservoir in the Midway-Sunset Field, San Jaoquin Basin, California  

SciTech Connect (OSTI)

This project reactivates ARCO's idle Pru Fee lease in the Midway-Sunset field, California and conducts a continuous steamflood enhanced oil recovery demonstration aided by an integration of modern reservoir characterization and simulation methods. Cyclic steaming was used to reestablish baseline production within the reservoir characterization phase of the project completed in December 1996. During the demonstration phase begun in January 1997, a continuous steamflood enhanced oil recovery is testing the incremental value of this method as an alternative to cyclic steaming. Other economically marginal Class III reservoirs having simular producibility problems will benefit from insight gained in this project. The objectives of the project are: (1) to return the shut-in portion of the reservoir to optimal commercial production; (2) to accurately describe the reservoir and recovery process; and (3) to convey the details of this activity to the domestic petroleum industry, especially t o other producers in California, through an aggressive technology transfer program.

Deo, M.; Forster, C.; Jenkins, C.; Schamel, S.; Sprinkel, D.; and Swain, R.

1999-02-01T23:59:59.000Z

296

Reactivation of an Idle Lease to Increase Heavy Oil Recovery Through Application of Conventional Steam Drive Technology in a Low Dip Slope and Basin Resrvoir in the Midway-Sunset Field, San Jaoquin Basin, California  

SciTech Connect (OSTI)

This project reactivates ARCO?s idle Pru Fee lease in the Midway-Sunset field, California and conducts a continuous steamflood enhanced oil recovery demonstration aided by an integration of modern reservoir characterization and simulation methods. Cyclic steaming is being used to reestablish baseline production within the reservoir characterization phase of the project. During the demonstration phase scheduled to begin in January 1997, a continuous steamflood enhanced oil recovery will be initiated to test the incremental value of this method as an alternative to cyclic steaming. Other economically marginal Class III reservoirs having similar producibility problems will benefit from insight gained in this project. The objectives of the project are: (1) to return the shut-in portion of the reservoir to optimal commercial production; (2) to accurately describe the reservoir and recovery process; and (3) to convey the details of this activity to the domestic petroleum industry, especially to other producers in California, through an aggressive technology transfer program.

Creties Jenkins; Doug Sprinkel; Milind Deo; Ray Wydrinski; Robert Swain

1997-10-21T23:59:59.000Z

297

OIL IMPORTS: For and Against  

Science Journals Connector (OSTI)

OIL IMPORTS: For and Against ... The eight—Ashland Oil, Atlantic Richfield, Cities Service, Marathon Oil, Mobil Oil, Standard Oil (Ind.), ...

1969-07-28T23:59:59.000Z

298

Waterflood and Enhanced Oil Recovery Studies using Saline Water and Dilute Surfactants in Carbonate Reservoirs  

E-Print Network [OSTI]

to decrease the residual oil saturation. In calcareous rocks, water from various resources (deep formation, seawater, shallow beds, lakes and rivers) is generally injected in different oil fields. The ions interactions between water molecules, salts ions, oil...

Alotaibi, Mohammed

2012-02-14T23:59:59.000Z

299

Fossil Energy Research Benefits Enhanced Oil Recovery  

Broader source: Energy.gov (indexed) [DOE]

Energy Research Benefits Energy Research Benefits Enhanced Oil Recovery EOR helps increase domestic oil supplies while also providing a way to safely and permanently store CO 2 underground. Enhanced Oil Recovery (EOR) is a way to squeeze out additional, hard- to-recover barrels of oil remaining in older fields following conventional production operations. It can also be used to permanently store carbon dioxide (CO 2 ) underground. Thanks in part to innovations supported by the Office of Fossil Energy's National Energy Technology Laboratory (NETL) over the past 30 years, the United States is a world leader in the number of EOR projects (200) and volume of oil production (over

300

Bioconversion of Heavy oil.  

E-Print Network [OSTI]

??70 % of world?s oil reservoirs consist of heavy oil, and as the supply of conventional oil decreases, researchers are searching for new technologies to… (more)

Steinbakk, Sandra

2011-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


301

The end of the age of oil David Goodstein  

E-Print Network [OSTI]

1986 1989 1992 1995 1998 2001 Non-OPEC OPEC bnbbls Source: BP Statistical Review of World Energy 2003 Tired Saudi Fields By JEFF GERTH The New York Times, February 24, 2004 ...the country's oil fields now (99 Quads) #12;Fossil Fuels Oil Natural gas Shale oil Methane hydrate Coal #12;Coal Hundreds, maybe

Bertini, Robert L.

302

5 World Oil Trends WORLD OIL TRENDS  

E-Print Network [OSTI]

5 World Oil Trends Chapter 1 WORLD OIL TRENDS INTRODUCTION In considering the outlook for California's petroleum supplies, it is important to give attention to expecta- tions of what the world oil market. Will world oil demand increase and, if so, by how much? How will world oil prices be affected

303

FIELD DEPLOYMENT EVALUATION OF THE FREEZE-THAW/EVAPORATION (FTE) PROCESS TO TREAT OIL AND GAS PRODUCED WATERS. Task 45. Final topical report  

SciTech Connect (OSTI)

TASK 45 FIELD DEPLOYMENT EVALUATION OF THE FREEZE-THAW/ EVAPORATION (FTE ) PROCESS TO TREAT OIL AND GAS PRODUCED WATERS coupling evaporation with freezing. This offers operators a year- round method for treating produced water. Treating water with the FTE process reduces the volume of water to be disposed of as well as purifying the water to a level acceptable for watering livestock and agricultural lands. This process is currently used at two evaporation facilities, one in the San Juan Basin in New Mexico and one in the Green River Basin in Wyoming. the freezing point below that of pure water. When such a solution is cooled below 32EF, relatively pure ice crystals form, along with an unfrozen brine solution that contains elevated concentrations of salts. Because of the brine's high concentration of these constituents, its density is greater than that of the ice, and the purified ice and brine are easily separated. Coupling the natural processes of freezing and evaporation makes the FTE process a more cost- effective and efficient method for the treatment and disposal of produced water and allows for year-round operation of an FTE facility. drops below 32 F, produced water is automatically pumped from a holding pond and sprayed onto a freezing pad. The freezing pad consists of an elevated framework of piping with regularly placed, upright, extendable spray heads similar to those used to irrigate lawns. As the spray freezes, an ice pile forms over the elevated framework of pipes, and the brine, with an elevated constituent concentration, drains from the ice pile. The high-salinity brine, identified by its high electrical conductivity, is separated using automatic valves and pumped to a pond where it can subsequently be disposed of by conventional methods. As the ice pile increases in height, the sprayers are extended. When the ice on the freezing pad melts, the relatively pure water is pumped from the freezing pad and discharged or stored for later use . No new wastes are generated by the FTE process. and the U. S. Department of Energy has been conducted since 1992 to develop a commercial FTE purification process for produced waters. Numeric process and economic modeling, as well as the laboratory-scale process simulation that confirmed the technical and economic feasibility of the process, was performed by B. C. Technologies, Ltd., and the University of North Dakota Energy & Environmental Research Center (EERC) from 1992 to 1995. They then conducted a field evaluation from 1995 to 1997 in New Mexico's San Juan Basin at a conventional evaporation facility operated by Amoco Production Company. The results of this evaluation confirmed that the FTE process has significant commercial economic potential. A new facility was designed in 1998, and its construction is expected to begin in 1999.

Ames A. Grisanti; James A. Sorensen

1999-05-01T23:59:59.000Z

304

Field-to-Fuel Performance Testing of Various Biomass Feedstocks: Production and Catalytic Upgrading of Bio-Oil to Refinery Blendstocks (Presentation)  

SciTech Connect (OSTI)

Large-scale, cost-competitive deployment of thermochemical technologies to replace petroleum oil with domestic biofuels will require inclusion of high volumes of low-cost, diverse biomass types into the supply chain. However, a comprehensive understanding of the impacts of feedstock thermo-physical and chemical variability, particularly inorganic matter (ash), on the yield and product distribution

Carpenter, D.; Westover, T.; Howe, D.; Evans, R.; French, R.; Kutnyakov, I.

2014-09-01T23:59:59.000Z

305

Increasing waterflood reserves in the Wilmington Oil Field through improved reservoir characterization and reservoir management. Annual report, March 21, 1995--March 20, 1996  

SciTech Connect (OSTI)

This project uses 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 saturation sands will be stimulated by recompleting existing production and injection wells in these sands using conventional means as well as short radius and ultra-short radius laterals. 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.

Sullivan, D.; Clarke, D.; Walker, S.; Phillips, C.; Nguyen, J.; Moos, D.; Tagbor, K.

1997-08-01T23:59:59.000Z

306

The Esso Energy Award Lecture, 1998. Boosting production from low-pressure oil and gas fields: a revolution in hydrocarbon production  

Science Journals Connector (OSTI)

...have developed a simple cost-effective system which...moving parts; low capital cost, with the payback achieved...14% coal oil gas hydro nuclear Figure 2. World primary...such as ASME, API, BS, Dnv stoomwezen (Dutch...The WELLCOM system is a cost-effective way to boost...

1999-01-01T23:59:59.000Z

307

Hydrotreating of oil from eastern oil shale  

SciTech Connect (OSTI)

Oil shale provides one of the major fossil energy reserves for the United States. The quantity of reserves in oil shale is less than the quantity in coal, but is much greater (by at least an order of magnitude) than the quantity of crude oil reserves. With so much oil potentially available from oil shale, efforts have been made to develop techniques for its utilization. In these efforts, hydrotreating has proved to be an acceptable technique for upgrading raw shale oil to make usuable products. The present work demonstrated the use of the hydrotreating technique for upgrading an oil from Indiana New Albany oil shale.

Scinta, J.; Garner, J.W.

1984-01-01T23:59:59.000Z

308

A geochemical assessment of petroleum from underground oil storage caverns in relation to petroleum from natural reservoirs offshore Norway.  

E-Print Network [OSTI]

??The aim of this study is to compare oils from known biodegraded fields offshore Norway to waxes and oils from an artificial cavern storage facility,… (more)

Østensen, Marie

2005-01-01T23:59:59.000Z

309

Near Shore Submerged Oil Assessment  

E-Print Network [OSTI]

) oil spill in the Gulf of Mexico, submerged oil refers to near shore oil which has picked up sediments You Should Know About Submerged Oil 1. Submerged oil is relatively uncommon: DWH oil is a light crude

310

Southwest Engineers participates in North Dakota fracking project  

Science Journals Connector (OSTI)

Southwest Engineers Inc is working with Earthwater Resources Inc on a major project in the Bakken Shale oil and gas zone in North Dakota, USA.

2013-01-01T23:59:59.000Z

311

Project Management Plan - Small Producers Program  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

RPSEA Final Report 09123.11.Final Enhanced Oil Recovery from the Bakken Shale using Surfactant Imbibition Coupled with Gravity Drainage 09123-09 Dongmei Wang Petroleum Engineering...

312

RMOTC - Testing - Enhanced Oil Recovery  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

Enhanced Oil Recovery Enhanced Oil Recovery Notice: As of July 15th 2013, the Department of Energy announced the intent to sell Naval Petroleum Reserve Number 3 (NPR3). The sale of NPR-3 will also include the sale of all equipment and materials onsite. A decision has been made by the Department of Energy to complete testing at RMOTC by July 1st, 2014. RMOTC will complete testing in the coming year with the currently scheduled testing partners. For more information on the sale of NPR-3 and sale of RMOTC equipment and materials please join our mailing list here. RMOTC will play a significant role in continued enhanced oil recovery (EOR) technology development and field demonstration. A scoping engineering study on Naval Petroleum Reserve No. 3's (NPR-3) enhanced oil recovery

313

Contracts for field projects and supporting research on enhanced oil recovery. Quarterly technical progress report, October 1994--December 1994. Progress review No. 81  

SciTech Connect (OSTI)

This document consists of a publications list for field projects and brief descriptions of research projects on enhanced petroleum recovery.

NONE

1996-03-01T23:59:59.000Z

314

OIl Speculation  

Gasoline and Diesel Fuel Update (EIA)

Investor Investor Flows and the 2008 Boom/Bust in Oil Prices Kenneth J. Singleton 1 August 10, 2011 1 Graduate School of Business, Stanford University, kenneths@stanford.edu. This research is the outgrowth of a survey paper I prepared for the Air Transport Association of America. I am grateful to Kristoffer Laursen for research assistance and to Kristoffer and Stefan Nagel for their comments. Abstract This paper explores the impact of investor flows and financial market conditions on returns in crude-oil futures markets. I begin by arguing that informational frictions and the associated speculative activity may induce prices to drift away from "fundamental" values and show increased volatility. This is followed by a discussion of the interplay between imperfect infor- mation about real economic activity, including supply, demand, and inventory accumulation, and speculative

315

STEVE SHEPHERD Bakken Workforce Development Panel  

Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

helped area community and tribal colleges to equip, furnish, and develop programs to train students. United Tribes Technical College received TAACCCT funding for a consortium...

316

Red Leaf Resources and the Commercialization of Oil Shale  

E-Print Network [OSTI]

Red Leaf Resources and the Commercialization of Oil Shale #12;About Red Leaf Resources 2006 Company commercial development field activities #12;Highlights Proven, Revolutionary Oil Shale Extraction Process Technology Significant Owned Oil Shale Resource #12;· The executive management team of Red Leaf Resources

Utah, University of

317

Oil production models with normal rate curves Dudley Stark  

E-Print Network [OSTI]

Oil production models with normal rate curves Dudley Stark School of Mathematical Sciences Queen;Abstract The normal curve has been used to fit the rate of both world and U.S.A. oil production. In this paper we give the first theoretical basis for these curve fittings. It is well known that oil field

Stark, Dudley

318

Oil and Gas Production Optimization; Lost Potential due to Uncertainty  

E-Print Network [OSTI]

Oil and Gas Production Optimization; Lost Potential due to Uncertainty Steinar M. Elgsaeter Olav.ntnu.no) Abstract: The information content in measurements of offshore oil and gas production is often low, and when in the context of offshore oil and gas fields, can be considered the total output of production wells, a mass

Johansen, Tor Arne

319

Preliminary Reference Case Results for Oil and Natural Gas  

Annual Energy Outlook 2013 [U.S. Energy Information Administration (EIA)]

Wolfcamp 1,983 1,983 24,882 24,882 5 Denver Bakken 1,441 1,441 39,179 39,179 Greater Green River - - 31,141 31,141 Montana Thrust Belt 602 602 5,433 5,433 Powder River 2,417...

320

Oil gravity segregation in the Monterey formation, California  

SciTech Connect (OSTI)

The Monterey Formation is a fractured siliceous shale that is the principal reservoir and source rock for oil fields in the Santa Maria basin and the western Santa Barbara Channel. Monterey crudes in producing offshore fields are high-sulfur oils that range from 10[degrees] to 35[degrees] API. The oils in Monterey fractured reservoirs display a systematic increase in API gravity with increasing height above the oil-water contact. The rate of change in API gravity with depth in Monterey oil fields generally ranges from 0.5[degrees] to 1.2[degrees] API/100 ft. The oil-water contact usually occurs at an oil gravity of 10[degrees] API (the gravity at which the density of the oil and the water is equal). The maximum API gravity in a Monterey oil field is related to the level of thermal exposure experienced by the formation in the adjacent depocenter. Monterey oils are sourced by high-sulfur kerogens that generate heavy oils at low levels of thermal exposure, but generate progressively higher gravity oils at higher levels of thermal maturity. Comparison of the maximum API gravity found in 33 Monterey-sourced oil fields with the maximum temperature experienced by the Monterey Formation within three miles of the field (the most likely migration distance) suggests that a temperature of 260[degrees]F (127[degrees]C) is required to generate 20[degrees] API oil, and a temperature of 330[degrees]F (166[degrees]C) is required to generate 30[degrees] API oil.

Hornafius, J.S. (Mobil Exploration and Producing, Bakersfield, CA (United States))

1994-04-01T23:59:59.000Z

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


321

California State Offshore Crude Oil + Lease Condensate Reserves...  

U.S. Energy Information Administration (EIA) Indexed Site

Withheld to avoid disclosure of individual company data. Release Date: 4102014 Next Release Date: 4302015 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries...

322

California Federal Offshore Crude Oil + Lease Condensate New...  

U.S. Energy Information Administration (EIA) Indexed Site

disclosure of individual company data. Release Date: 4102014 Next Release Date: 4302015 Referring Pages: Crude Oil plus Lease Condensate New Reservoir Discoveries in Old Fields...

323

California Federal Offshore Crude Oil + Lease Condensate Reserves...  

U.S. Energy Information Administration (EIA) Indexed Site

Withheld to avoid disclosure of individual company data. Release Date: 4102014 Next Release Date: 4302015 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries...

324

Texas State Offshore Crude Oil + Lease Condensate New Reservoir...  

U.S. Energy Information Administration (EIA) Indexed Site

disclosure of individual company data. Release Date: 4102014 Next Release Date: 4302015 Referring Pages: Crude Oil plus Lease Condensate New Reservoir Discoveries in Old Fields...

325

California State Offshore Crude Oil + Lease Condensate New Reservoir...  

U.S. Energy Information Administration (EIA) Indexed Site

disclosure of individual company data. Release Date: 4102014 Next Release Date: 4302015 Referring Pages: Crude Oil plus Lease Condensate New Reservoir Discoveries in Old Fields...

326

Texas State Offshore Crude Oil + Lease Condensate Reserves New...  

U.S. Energy Information Administration (EIA) Indexed Site

Withheld to avoid disclosure of individual company data. Release Date: 4102014 Next Release Date: 4302015 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries...

327

The future of oil supply  

Science Journals Connector (OSTI)

...Department of Energy [64] argued...options such as electric vehicles and...prospects of electric vehicles (EVs...cells, and the energy use, driving...diverse urban planning and fuel taxation...Laherrere, J. 2000 Distribution of field sizes...future of oil. Energy Explor. Exploit...

2014-01-01T23:59:59.000Z

328

Iraq: World Oil Report 1991  

SciTech Connect (OSTI)

This paper reports that no reliable information on Iraqi E and P operations and only a few reports on oil field facilities damage have been available since last August. Most of what is known originated from the Middle East Economic Survey (MEES), the authoritative newsletter covering the Middle East. According to MEES reports in major northern oil fields (Kirkuk, Bai Hasan and Jambur) is put at 800,000 bpd. The northern fields and the pipeline system through Turkey to the Mediterranean Sea that serves as an export outlet for the area apparently were not damaged much by coalition air strikes or subsequent fighting by the Kurds. Last May production was estimated at 250,000 bpd, presumably from northern fields. If and when U.N. sanctions are lifted, Iraq should be able to export promptly through the Turkish line.

Not Available

1991-08-01T23:59:59.000Z

329

China's Global Oil Strategy  

E-Print Network [OSTI]

capability to secure oil transport security. Additionally,international oil agreements: 1) ensuring energy security;security, and many argue that as the second-largest consumer of oil

Thomas, Bryan G

2009-01-01T23:59:59.000Z

330

Understanding Crude Oil Prices  

E-Print Network [OSTI]

2007”. comparison, Mexico used 6.6— Chinese oil consumption17. Oil production from the North Sea, Mexico’s Cantarell,Mexico, Italy, France, Canada, US, and UK. Figure 10. Historical Chinese oil

Hamilton, James Douglas

2008-01-01T23:59:59.000Z

331

Understanding Crude Oil Prices  

E-Print Network [OSTI]

2004. “OPEC’s Optimal Crude Oil Price,” Energy Policy 32(2),023 Understanding Crude Oil Prices James D. Hamilton Junedirectly. Understanding Crude Oil Prices* James D. Hamilton

Hamilton, James Douglas

2008-01-01T23:59:59.000Z

332

Understanding Crude Oil Prices  

E-Print Network [OSTI]

business of having some oil in inventory, which is referredKnowledge of all the oil going into inventory today for salebe empty, because inventories of oil are essential for the

Hamilton, James Douglas

2008-01-01T23:59:59.000Z

333

Understanding Crude Oil Prices  

E-Print Network [OSTI]

2004. “OPEC’s Optimal Crude Oil Price,” Energy Policy 32(2),percent change in real oil price. Figure 3. Price of crude023 Understanding Crude Oil Prices James D. Hamilton June

Hamilton, James Douglas

2008-01-01T23:59:59.000Z

334

Understanding Crude Oil Prices  

E-Print Network [OSTI]

2004. “OPEC’s Optimal Crude Oil Price,” Energy Policy 32(2),percent change in real oil price. Figure 3. Price of crudein predicting quarterly real oil price change. variable real

Hamilton, James Douglas

2008-01-01T23:59:59.000Z

335

China's Global Oil Strategy  

E-Print Network [OSTI]

by this point, China’s demand Oil Demand vs. Domestic Supplycurrent pace of growth in oil demand as staying consistentand predictions of oil supply and demand affected foreign

Thomas, Bryan G

2009-01-01T23:59:59.000Z

336

Understanding Crude Oil Prices  

E-Print Network [OSTI]

and Income on Energy and Oil Demand,” Energy Journal 23(1),2006. “China’s Growing Demand for Oil and Its Impact on U.S.in the supply or demand for oil itself could be regarded as

Hamilton, James Douglas

2008-01-01T23:59:59.000Z

337

Field test of microemulsion flooding, Chateaurenard Field, France  

SciTech Connect (OSTI)

A pilot test of microemulsion flooding was conducted in a single five-spot pattern in the Chateaurenard field in France. The test had to accommodate a 40-mPa*s (40-cp) oil viscosity and a regional pressure gradient across the pattern. A very clear oil bank was observed, resulting in a substantial increase in oil production. 9 refs.

Putz, A.; Chevalier, J.P.; Stock, G.; Philippot, J.

1981-04-01T23:59:59.000Z

338

PREDICTIVE MODELS. Enhanced Oil Recovery Model  

SciTech Connect (OSTI)

PREDICTIVE MODELS is a collection of five models - CFPM, CO2PM, ICPM, PFPM, and SFPM - used in the 1982-1984 National Petroleum Council study of enhanced oil recovery (EOR) potential. Each pertains to a specific EOR process designed to squeeze additional oil from aging or spent oil fields. The processes are: 1 chemical flooding, where soap-like surfactants are injected into the reservoir to wash out the oil; 2 carbon dioxide miscible flooding, where carbon dioxide mixes with the lighter hydrocarbons making the oil easier to displace; 3 in-situ combustion, which uses the heat from burning some of the underground oil to thin the product; 4 polymer flooding, where thick, cohesive material is pumped into a reservoir to push the oil through the underground rock; and 5 steamflood, where pressurized steam is injected underground to thin the oil. CFPM, the Chemical Flood Predictive Model, models micellar (surfactant)-polymer floods in reservoirs, which have been previously waterflooded to residual oil saturation. Thus, only true tertiary floods are considered. An option allows a rough estimate of oil recovery by caustic or caustic-polymer processes. CO2PM, the Carbon Dioxide miscible flooding Predictive Model, is applicable to both secondary (mobile oil) and tertiary (residual oil) floods, and to either continuous CO2 injection or water-alternating gas processes. ICPM, the In-situ Combustion Predictive Model, computes the recovery and profitability of an in-situ combustion project from generalized performance predictive algorithms. PFPM, the Polymer Flood Predictive Model, is switch-selectable for either polymer or waterflooding, and an option allows the calculation of the incremental oil recovery and economics of polymer relative to waterflooding. SFPM, the Steamflood Predictive Model, is applicable to the steam drive process, but not to cyclic steam injection (steam soak) processes.

Ray, R.M. [DOE Bartlesville Energy Technology Technology Center, Bartlesville, OK (United States)

1992-02-26T23:59:59.000Z

339

Understanding Crude Oil Prices  

E-Print Network [OSTI]

2007”. comparison, Mexico used 6.6— Chinese oil consumption17. Oil production from the North Sea, Mexico’s Cantarell,

Hamilton, James Douglas

2008-01-01T23:59:59.000Z

340

Desulfurization of heavy oil  

Science Journals Connector (OSTI)

Strategies for heavy oil desulfurization were evaluated by reviewing desulfurization literature and critically assessing the viability of the various methods for heavy oil. The desulfurization methods includin...

Rashad Javadli; Arno de Klerk

2012-03-01T23:59:59.000Z

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


341

China's Global Oil Strategy  

E-Print Network [OSTI]

China’s domestic oil supply will peak, and demand Robertpeak will come around 2020, 24 and that by this point, China’s demand Oil

Thomas, Bryan G

2009-01-01T23:59:59.000Z

342

Tall oil pitch  

Science Journals Connector (OSTI)

n....Undistilled residue from the distillation of crude tall oil. It is generally recognized that tall oil pitches contain some high-boiling esters and neutral...

2007-01-01T23:59:59.000Z

343

China's Global Oil Strategy  

E-Print Network [OSTI]

Analysts agree that the Persian Gulf region will continue tos oil imports. 17 The Persian Gulf region is particularlyaccess to oil from the Persian Gulf because of conflict

Thomas, Bryan G

2009-01-01T23:59:59.000Z

344

oil1990.xls  

Annual Energy Outlook 2013 [U.S. Energy Information Administration (EIA)]

(dollars) (dollars) (dollars) (dollars) Table 1. Consumption and Expenditures in U.S. Households that Use Fuel OilKerosene, 1990 Residential Buildings Average Fuel Oil...

345

Oil Sands Feedstocks  

Broader source: Energy.gov (indexed) [DOE]

Centre for Upgrading Technology 'a Canada-Alberta alliance for bitumen and heavy oil research' Oil Sands Feedstocks C Fairbridge, Z Ring, Y Briker, D Hager National Centre...

346

Crude Oil Domestic Production  

U.S. Energy Information Administration (EIA) Indexed Site

Data Series: Crude Oil Domestic Production Refinery Crude Oil Inputs Refinery Gross Inputs Refinery Operable Capacity (Calendar Day) Refinery Percent Operable Utilization Net...

347

Reactivation of an Idle Lease to Increase Heavy Oil Recovery through Application of Conventional Steam Drive Technology in a Low-Dip Slope and Reservoir in the Midway-Sunset Field, San Jaoquin Basin, California, Class III  

SciTech Connect (OSTI)

The objective of this project is not just to produce oil from the Pru Fee property, but rather to test which operational strategies best optimize total oil recovery at economically acceptable rates of production and production costs.

Schamel, S.

2001-01-09T23:59:59.000Z

348

Reactivation of an Idle Lease to Increase Heavy Oil Recovery through Application of Conventional Steam Drive Technology in a Low-Dip Slope and Reservoir in the Midway-Sunset Field, San Jaoquin Basin, California, Class III  

SciTech Connect (OSTI)

The objective of the project is not just to commercially produce oil from the Pru Fee property, but rather to test which operational strategies best optimize total oil recovery at economically acceptable rates of production volumes and costs.

Schamel, Steven; Deo, Milind; Deets, Mike

2002-02-21T23:59:59.000Z

349

Biochemically enhanced oil recovery and oil treatment  

DOE Patents [OSTI]

This invention relates to the preparation of new, modified organisms, through challenge growth processes, that are viable in the extreme temperature, pressure and pH conditions and salt concentrations of an oil reservoir and that are suitable for use in microbial enhanced oil recovery. The modified microorganisms of the present invention are used to enhance oil recovery and remove sulfur compounds and metals from the crude oil. 62 figures.

Premuzic, E.T.; Lin, M.

1994-03-29T23:59:59.000Z

350

Biochemically enhanced oil recovery and oil treatment  

DOE Patents [OSTI]

This invention relates to the preparation of new, modified organisms, through challenge growth processes, that are viable in the extreme temperature, pressure and pH conditions and salt concentrations of an oil reservoir and that are suitable for use in microbial enhanced oil recovery. The modified microorganisms of the present invention are used to enhance oil recovery and remove sulfur compounds and metals from the crude oil.

Premuzic, Eugene T. (East Moriches, NY); Lin, Mow (Rocky Point, NY)

1994-01-01T23:59:59.000Z

351

U.S. Federal Offshore Crude Oil + Lease Condensate New Reservoir...  

U.S. Energy Information Administration (EIA) Indexed Site

New Reservoir Discoveries in Old Fields (Million Barrels) U.S. Federal Offshore Crude Oil + Lease Condensate New Reservoir Discoveries in Old Fields (Million Barrels) Decade Year-0...

352

Towards an Automatic Metadata Management Framework for Smart Oil Charalampos Chelmis1  

E-Print Network [OSTI]

of the oil exploration process in the oil industry. Our system is capable of annotating models and images. Introduction Oil and gas organizations are in continuous pressure to investigate and employ innovativeTowards an Automatic Metadata Management Framework for Smart Oil Fields Charalampos Chelmis1 , Jing

Prasanna, Viktor K.

353

SOVENT BASED ENHANCED OIL RECOVERY FOR IN-SITU UPGRADING OF HEAVY OIL SANDS  

SciTech Connect (OSTI)

With the depletion of conventional crude oil reserves in the world, heavy oil and bitumen resources have great potential to meet the future demand for petroleum products. However, oil recovery from heavy oil and bitumen reservoirs is much more difficult than that from conventional oil reservoirs. This is mainly because heavy oil or bitumen is partially or completely immobile under reservoir conditions due to its extremely high viscosity, which creates special production challenges. In order to overcome these challenges significant efforts were devoted by Applied Research Center (ARC) at Florida International University and The Center for Energy Economics (CEE) at the University of Texas. A simplified model was developed to assess the density of the upgraded crude depending on the ratio of solvent mass to crude oil mass, temperature, pressure and the properties of the crude oil. The simplified model incorporated the interaction dynamics into a homogeneous, porous heavy oil reservoir to simulate the dispersion and concentration of injected CO2. The model also incorporated the characteristic of a highly varying CO2 density near the critical point. Since the major challenge in heavy oil recovery is its high viscosity, most researchers have focused their investigations on this parameter in the laboratory as well as in the field resulting in disparaging results. This was attributed to oil being a complex poly-disperse blend of light and heavy paraffins, aromatics, resins and asphaltenes, which have diverse behaviors at reservoir temperature and pressures. The situation is exacerbated by a dearth of experimental data on gas diffusion coefficients in heavy oils due to the tedious nature of diffusivity measurements. Ultimately, the viscosity and thus oil recovery is regulated by pressure and its effect on the diffusion coefficient and oil swelling factors. The generation of a new phase within the crude and the differences in mobility between the new crude matrix and the precipitate readily enables removal of asphaltenes. Thus, an upgraded crude low in heavy metal, sulfur and nitrogen is more conducive for further purification.

Munroe, Norman

2009-01-30T23:59:59.000Z

354

Ships After Oil  

Science Journals Connector (OSTI)

Ships After Oil ... Special self-propelled tenders planned for offshore drilling operations in Gulf ...

1956-07-02T23:59:59.000Z

355

OIL & GAS INSTITUTE Introduction  

E-Print Network [OSTI]

OIL & GAS INSTITUTE CONTENTS Introduction Asset Integrity Underpinning Capabilities 2 4 4 6 8 9 10 COMPETITIVENESS UNIVERSITY of STRATHCLYDE OIL & GAS INSTITUTE OIL & GAS EXPERTISE AND PARTNERSHIPS #12;1 The launch of the Strathclyde Oil & Gas Institute represents an important step forward for the University

Mottram, Nigel

356

Oil | Department of Energy  

Broader source: Energy.gov (indexed) [DOE]

Oil Oil Oil Oil Prices, 2000-2008 For the first time since 1995, U.S. oil production has surpassed imports. Explore the trend with our interactive chart. | Graphic by Daniel Wood, Energy Department. For the first time since 1995, U.S. oil production has surpassed imports. Explore the trend with our interactive chart. | Graphic by Daniel Wood, Energy Department. Oil is used for heating and transportation -- most notably, as fuel for gas-powered vehicles. America's dependence on foreign oil has declined in recent years, but oil prices have increased. The Energy Department supports research and policy options to increase our domestic supply of oil while ensuring environmentally sustainable supplies domestically and abroad, and is investing in research, technology and

357

Oil Dependencies and Peak Oil's Effects on Oil Consumption.  

E-Print Network [OSTI]

?? During the year of 2007, the world has experienced historically high oil prices both in nominal and in real terms, which has reopened discussions… (more)

Tekin, Josef

2007-01-01T23:59:59.000Z

358

Successful Sequestration and Enhanced Oil Recovery Project Could Mean More  

Broader source: Energy.gov (indexed) [DOE]

Successful Sequestration and Enhanced Oil Recovery Project Could Successful Sequestration and Enhanced Oil Recovery Project Could Mean More Oil and Less CO2 Emissions Successful Sequestration and Enhanced Oil Recovery Project Could Mean More Oil and Less CO2 Emissions November 15, 2005 - 2:45pm Addthis "Weyburn Project" Breaks New Ground in Enhanced Oil Recovery Efforts WASHINGTON, DC - Secretary Samuel W. Bodman today announced that the Department of Energy (DOE)-funded "Weyburn Project" successfully sequestered five million tons of carbon dioxide (CO2) into the Weyburn Oilfield in Saskatchewan, Canada, while doubling the field's oil recovery rate. If the methodology used in the Weyburn Project was successfully applied on a worldwide scale, one-third to one-half of CO2 emissions could be eliminated in the next 100 years and billions of barrels of oil could be

359

Reactivation of an idle lease to increase heavy oil recovery through application of conventional steam drive technology in a low dip slope and basin reservoir in the Midway-Sunset Field, San Jaoquin Basin, California  

SciTech Connect (OSTI)

This project reactivates ARCO`s idle Pru Fee lease in the Midway- Sunset field, California and conducts a continuous steamflood enhanced oil recovery demonstration aided by an integration of modern reservoir characterization and simulation methods. Cyclic steaming is being used to reestablish baseline production within the reservoir characterization phase of the project. During the demonstration phase scheduled to begin in January 1997, a continuous steamflood enhanced oil recovery will be initiated to test the incremental value of this method as an alternative to cyclic steaming. Other economically marginal Class III reservoirs having similar producibility problems will benefit from insight gained in this project. The objectives of the project are: (1) to return the shut-in portion of the reservoir to optimal commercial production; (2) to accurately describe the reservoir and recovery process; and (3) to convey the details of this activity to the domestic petroleum industry, especially to other producers in California, through an aggressive technology transfer program. One of the main objectives of Budget Period I was to return the Pru Fee property to economic production and establish a baseline productivity with cyclic steaming. By the end of the second quarter 1996, all Pru producers except well 101 had been cyclic steamed two times. Each steam cycle was around 10,000 barrels of steam (BS) per well. No mechanical problems were found in the existing old wellbores. Conclusion is after several years of being shut-in, the existing producers on the Pru lease are in reasonable mechanical condition, and can therefore be utilized as viable producers in whatever development plan we determine is optimum. Production response to cyclic steam is very encouraging in the new producer, however productivity in the old producers appears to be limited in comparison.

Schamel, S.

1996-11-01T23:59:59.000Z

360

Turbine cooling waxy oil  

SciTech Connect (OSTI)

A process for pipelining a waxy oil to essentially eliminate deposition of wax on the pipeline wall is described comprising: providing a pressurized mixture of the waxy oil and a gas; effecting a sudden pressure drop of the mixture of the oil and the gas through an expansion turbine, thereby expanding the gas and quickly cooling the oil to below its cloud point in the substantial absence of wax deposition and forming a slurry of wax particles and oil; and pipelining the slurry.

Geer, J.S.

1987-10-27T23:59:59.000Z

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


361

NETL: Oil & Natural Gas Projects  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

Major Oil Plays in Utah and Vicinity/PUMP 2 Major Oil Plays in Utah and Vicinity/PUMP 2 DE-FC26-02NT15133 Goal The primary goal of this study is to increase recovery of oil reserves from existing reservoirs and from new discoveries by providing play portfolios for the major oil-producing provinces (Paradox Basin, Uinta Basin, and thrust belt) in Utah and adjacent areas in Colorado and Wyoming. The overall objectives of this study are to: 1) increase recoverable oil from existing reservoirs, 2) add new discoveries, 3) prevent premature abandonment of numerous small fields, 4) increase deliverability through identifying the latest drilling, completion, and secondary/tertiary recovery techniques, and 5) reduce development costs and risk. Performer Utah Geological Survey (UGS), Salt Lake City, UT

362

This Week In Petroleum Summary Printer-Friendly Version  

Annual Energy Outlook 2013 [U.S. Energy Information Administration (EIA)]

continuing oil production growth in the key oil-producing regions. Altogether, in the Bakken, Niobrara, Permian, and Eagle Ford, oil production is expected to increase by 70,000...

363

Increased oil production and reserves from improved completion techniques in the Bluebell Field, Uinta Basin, Utah. Annual report, October 1, 1994--September 30, 1995  

SciTech Connect (OSTI)

The Bluebell field produces from the Tertiary lower Green River and Wasatch Formations of the Uinta Basin, Utah. The productive interval consists of thousands of feet of interbedded fractured clastic and carbonate beds deposited in a fluvial-dominated deltaic lacustrine environment. Wells in the Bluebell field are typically completed by perforating 40 or more beds over 1,000 to 3,000 vertical feet (300-900 m), then applying an acid-fracture stimulation treatment to the entire interval. This completion 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. Geologic and engineering characterization has been used to define improved completion techniques. The study identified reservoir characteristics of beds that have the greatest long-term production potential.

Allison, M.L.; Morgan, C.D.

1996-05-01T23:59:59.000Z

364

NETL: News Release - NETL's Oil and Natural Gas Program Provides  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

24, 2007 24, 2007 Oil and Natural Gas Program Uses Stranded Gas to Revive Oil Production Project Generates Energy from Waste Gas to Restore Marginal Fields WASHINGTON, DC - A U.S. Department of Energy (DOE) project is turning "stranded" natural gas at marginal, or low-production, oil fields into fuel for distributed electric power. The breakthrough is bringing previously idle oil fields back into production and could boost domestic oil production by some 28 million barrels per year within the next 10 years, helping to reduce the Nation's dependence on foreign oil sources. Stranded gas is natural gas that is uneconomic to produce for one or more reasons: the energy, or Btu content, may be too low; the gas may be too impure to use; or, the volume may be too small to warrant a pipeline connection to the gas infrastructure. Non-commercial gas is sometimes produced along with oil, becoming an environmental liability. This unwanted byproduct of oil production has become a major problem in California oil fields where producers have been forced to abandon sites early, leaving valuable reserves of domestic oil untapped.

365

BUFFERED WELL FIELD OUTLINES  

U.S. Energy Information Administration (EIA) Indexed Site

OIL & GAS FIELD OUTLINES FROM BUFFERED WELLS OIL & GAS FIELD OUTLINES FROM BUFFERED WELLS The VBA Code below builds oil & gas field boundary outlines (polygons) from buffered wells (points). Input well points layer must be a feature class (FC) with the following attributes: Field_name Buffer distance (can be unique for each well to represent reservoirs with different drainage radii) ...see figure below. Copy the code into a new module. Inputs: In ArcMap, data frame named "Task 1" Well FC as first layer (layer 0). Output: Polygon feature class in same GDB as the well points FC, with one polygon field record (may be multiple polygon rings) per field_name. Overlapping buffers for the same field name are dissolved and unioned (see figure below). Adds an attribute PCTFEDLAND which can be populated using the VBA

366

Oil and gas resources in the West Siberian Basin, Russia  

SciTech Connect (OSTI)

The primary objective of this study is to assess the oil and gas potential of the West Siberian Basin of Russia. The study does not analyze the costs or technology necessary to achieve the estimates of the ultimate recoverable oil and gas. This study uses reservoir data to estimate recoverable oil and gas quantities which were aggregated to the field level. Field totals were summed to a basin total for discovered fields. An estimate of undiscovered oil and gas, from work of the US Geological Survey (USGS), was added to give a total basin resource volume. Recent production decline points out Russia`s need to continue development of its discovered recoverable oil and gas. Continued exploration is required to discover additional oil and gas that remains undiscovered in the basin.

NONE

1997-12-01T23:59:59.000Z

367

Essays on Macroeconomics and Oil  

E-Print Network [OSTI]

Oil Production in Venezuela and Mexico . . . . . . . . . .Venezuela with Mexico, another major oil pro- ducing countryOil Production and Productivity in Venezuela and Mexico . . . . . . . .

CAKIR, NIDA

2013-01-01T23:59:59.000Z

368

Essays on Macroeconomics and Oil  

E-Print Network [OSTI]

Oil Production in Venezuela and Mexico . . . . . . . . . .Oil Production and Productivity in Venezuela and Mexico . . . . . . . .2.6: Oil Production in Venezuela and Mexico 350 Productivity

CAKIR, NIDA

2013-01-01T23:59:59.000Z

369

AN ENGINE OIL LIFE ALGORITHM.  

E-Print Network [OSTI]

??An oil-life algorithm to calculate the remaining percentage of oil life is presented as a means to determine the right time to change the oil… (more)

Bommareddi, Anveshan

2009-01-01T23:59:59.000Z

370

Effects of no. 2 fuel oil on hatchability of marine and estuarine bird eggs  

Science Journals Connector (OSTI)

Eggs of Louisiana herons, sandwich terns, and laughing gulls were oiled with either 0, 5, or 20 ?l of No. 2 fuel oil in the field and in the laboratory. After 5 days of natural incubation, field-oiled and cont...

Donald H. White; Kirke A. King…

371

Economics of Peak Oil  

Science Journals Connector (OSTI)

Abstract ‘Peak oil’ refers to the future decline in world production of crude oil and the accompanying potentially calamitous effects. The peak oil literature typically rejects economic analysis. This article argues that economic analysis is indeed appropriate for analyzing oil scarcity because standard economic models can replicate the observed peaks in oil production. Moreover, the emphasis on peak oil is misplaced as peaking is not a good indicator of scarcity, peak oil techniques are overly simplistic, the catastrophes predicted by the peak oil literature are unlikely, and the literature does not contribute to correcting identified market failures. Efficiency of oil markets could be improved by instead focusing on remedying market failures such as excessive private discount rates, environmental externalities, market power, insufficient innovation incentives, incomplete futures markets, and insecure property rights.

S.P. Holland

2013-01-01T23:59:59.000Z

372

Simulation Study of the Polymer Flooding Applied to the Norne Field E-Segment.  

E-Print Network [OSTI]

?? The enhanced oil recovery (EOR) methods such as polymer flooding to increase oil production from water flooded fields are becoming more attractive. Water flooding… (more)

Amirbayov, Teyyub

2014-01-01T23:59:59.000Z

373

Electromagnetic Heating Methods for Heavy Oil Reservoirs  

SciTech Connect (OSTI)

The most widely used method of thermal oil recovery is by injecting steam into the reservoir. A well-designed steam injection project is very efficient in recovering oil, however its applicability is limited in many situations. Simulation studies and field experience has shown that for low injectivity reservoirs, small thickness of the oil-bearing zone, and reservoir heterogeneity limits the performance of steam injection. This paper discusses alternative methods of transferring heat to heavy oil reservoirs, based on electromagnetic energy. They present a detailed analysis of low frequency electric resistive (ohmic) heating and higher frequency electromagnetic heating (radio and microwave frequency). They show the applicability of electromagnetic heating in two example reservoirs. The first reservoir model has thin sand zones separated by impermeable shale layers, and very viscous oil. They model preheating the reservoir with low frequency current using two horizontal electrodes, before injecting steam. The second reservoir model has very low permeability and moderately viscous oil. In this case they use a high frequency microwave antenna located near the producing well as the heat source. Simulation results presented in this paper show that in some cases, electromagnetic heating may be a good alternative to steam injection or maybe used in combination with steam to improve heavy oil production. They identify the parameters which are critical in electromagnetic heating. They also discuss past field applications of electromagnetic heating including technical challenges and limitations.

Sahni, A.; Kumar, M.; Knapp, R.B.

2000-05-01T23:59:59.000Z

374

PREDICTIVE MODELS. Enhanced Oil Recovery Model  

SciTech Connect (OSTI)

PREDICTIVE MODELS is a collection of five models - CFPM, CO2PM, ICPM, PFPM, and SFPM - used in the 1982-1984 National Petroleum Council study of enhanced oil recovery (EOR) potential. Each pertains to a specific EOR process designed to squeeze additional oil from aging or spent oil fields. The processes are: 1 chemical flooding; 2 carbon dioxide miscible flooding; 3 in-situ combustion; 4 polymer flooding; and 5 steamflood. CFPM, the Chemical Flood Predictive Model, models micellar (surfactant)-polymer floods in reservoirs, which have been previously waterflooded to residual oil saturation. Thus, only true tertiary floods are considered. An option allows a rough estimate of oil recovery by caustic or caustic-polymer processes. CO2PM, the Carbon Dioxide miscible flooding Predictive Model, is applicable to both secondary (mobile oil) and tertiary (residual oil) floods, and to either continuous CO2 injection or water-alternating gas processes. ICPM, the In-situ Combustion Predictive Model, computes the recovery and profitability of an in-situ combustion project from generalized performance predictive algorithms. PFPM, the Polymer Flood Predictive Model, is switch-selectable for either polymer or waterflooding, and an option allows the calculation of the incremental oil recovery and economics of polymer relative to waterflooding. SFPM, the Steamflood Predictive Model, is applicable to the steam drive process, but not to cyclic steam injection (steam soak) processes. The IBM PC/AT version includes a plotting capability to produces a graphic picture of the predictive model results.

Ray, R.M. [DOE Bartlesville Energy Technology Center, Bartlesville, OK (United States)

1992-02-26T23:59:59.000Z

375

Canadian operators boost heavy oil production  

SciTech Connect (OSTI)

Recent technological advances in slurry pipelining, horizontal wells, and thermal recovery techniques have made recovery of Canadian heavy oil resources more economical. In addition, reduced government royalties have made investment in these difficult reservoirs more attractive. As a result, activity has increased in heavy-oil fields in Alberta and Saskatchewan. This paper review the various oil sand recovery projects under development in the area and the current government policies which are helping to develop them. The paper also provides brief descriptions of the equipment and technologies that have allowed a reduced cost in the development. Items discussed include surface mining techniques, horizontal drilling, reservoir engineering techniques, separation processes, and thermal recovery.

Perdue, J.M.

1996-05-01T23:59:59.000Z

376

RESULTS OF FIELD TESTING DOE  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

of Energy facility located within Naval Petroleum Reserve No. 3 (NPR-3), also known as Teapot Dome Oil Field, about 35 miles north of Casper, Wyoming. Teapot Dome Field, Natrona...

377

Apparatus for distilling shale oil from oil shale  

SciTech Connect (OSTI)

An apparatus for distilling shale oil from oil shale comprises: a vertical type distilling furnace which is divided by two vertical partitions each provided with a plurality of vent apertures into an oil shale treating chamber and two gas chambers, said oil shale treating chamber being located between said two gas chambers in said vertical type distilling furnace, said vertical type distilling furnace being further divided by at least one horizontal partition into an oil shale distilling chamber in the lower part thereof and at least one oil shale preheating chamber in the upper part thereof, said oil shale distilling chamber and said oil shale preheating chamber communication with each other through a gap provided at an end of said horizontal partition, an oil shale supplied continuously from an oil shale supply port provided in said oil shale treating chamber at the top thereof into said oil shale treating chamber continuously moving from the oil shale preheating chamber to the oil shale distilling chamber, a high-temperature gas blown into an oil shale distilling chamber passing horizontally through said oil shale in said oil shale treating chamber, thereby said oil shale is preheated in said oil shale preheating chamber, and a gaseous shale oil is distilled from said preheated oil shale in said oil shale distilling chamber; and a separator for separating by liquefaction a gaseous shale oil from a gas containing the gaseous shale oil discharged from the oil shale preheating chamber.

Shishido, T.; Sato, Y.

1984-02-14T23:59:59.000Z

378

Abu Dhabi presses oil development program  

SciTech Connect (OSTI)

This paper reports that Abu Dhabi Co. for Onshore Operations (ADCO), the biggest oil producer in the United Arab Emirates, reports 1991 was a successful year despite the Persian Gulf war. Meantime, Abu Dhabi's Zakum, the second largest oil field in the Persian Gulf, boosted production to more than 300,000 b/d, and officials said production will rise further when a platform complex is recommissioned in 1993.

Not Available

1992-06-29T23:59:59.000Z

379

Heavy oil production from Alaska  

SciTech Connect (OSTI)

North Slope of Alaska has an estimated 40 billion barrels of heavy oil and bitumen in the shallow formations of West Sak and Ugnu. Recovering this resource economically is a technical challenge for two reasons: (1) the geophysical environment is unique, and (2) the expected recovery is a low percentage of the oil in place. The optimum advanced recovery process is still undetermined. Thermal methods would be applicable if the risks of thawing the permafrost can be minimized and the enormous heat losses reduced. Use of enriched natural gas is a probable recovery process for West Sak. Nearby Prudhoe Bay field is using its huge natural gas resources for pressure maintenance and enriched gas improved oil recovery (IOR). Use of carbon dioxide is unlikely because of dynamic miscibility problems. Major concerns for any IOR include close well spacing and its impact on the environment, asphaltene precipitation, sand production, and fines migration, in addition to other more common production problems. Studies have indicated that recovering West Sak and Lower Ugnu heavy oil is technically feasible, but its development has not been economically viable so far. Remoteness from markets and harsh Arctic climate increase production costs relative to California heavy oil or Central/South American heavy crude delivered to the U.S. Gulf Coast. A positive change in any of the key economic factors could provide the impetus for future development. Cooperation between the federal government, state of Alaska, and industry on taxation, leasing, and permitting, and an aggressive support for development of technology to improve economics is needed for these heavy oil resources to be developed.

Mahmood, S.M.; Olsen, D.K. [NIPER/BDM-Oklahoma, Inc., Bartlesville, OK (United States); Thomas, C.P. [Idaho National Engineering Lab., Idaho Falls, ID (United States)

1995-12-31T23:59:59.000Z

380

Oil removal for produced water treatment and micellar cleaning of ultrafiltration membranes  

E-Print Network [OSTI]

a research project that evaluated the treatment of brine generated in oil fields (produced water) with ultrafiltration membranes. The characteristics of various ultrafiltration membranes for oil and suspended solids removal from produced water were...

Beech, Scott Jay

2006-10-30T23:59:59.000Z

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


381

Horizontal low-void retorting of eastern and western oil shale  

SciTech Connect (OSTI)

Horizontal in situ retorting processes have been developed to recover oil from thin, shallow oil shale deposits. To date the most successful field tests have been conducted in Green River oil shale located in Utah. Consideration is being given to applying this technology to the New Albany oil shales in Indiana. Western Research Institute (WRI) conducted two horizontal in situ oil shale experiments using eastern oil shale and the results are compared with results obtained from a similar experiment using Green River oil shale. The objectives of the three experiments were to simulate the horizontal retorting process and determine oil yield, retorting zone profiles and product characteristics using alternative operating conditions for eastern and western oil shales. The tests proved that horizontal retorting could be simulated in the laboratory. However, air bypass problems occurred in the experiments, which probably reduced oil recovery compared with recovery from field tests. During the eastern oil shale tests plugging was encountered in the gas recovery system because of the production of a solid material containing sulfur compounds. This plugging could be a potential problem for future laboratory and field experimentation. The oil produced from eastern oil shale has different properties from western shale oil. The oil is highly aromatic and when hydrogenated may yield a prototype high density jet fuel. 10 refs., 8 figs., 11 tabs.

Fahy, L.J.

1986-02-01T23:59:59.000Z

382

Harvard University Job Market Candidates 2013-2014  

E-Print Network [OSTI]

in the Bakken Shale" Fields: Industrial Organization, Energy and Environmental Economics, Finance, Applied Naritomi, Joana (PEG) JMP: "Consumers as Tax Auditors" Fields: Public Finance, Development Economics

Chen, Yiling

383

Understanding the reservoir important to successful stimulation  

SciTech Connect (OSTI)

In anisotropic Bakken shale reservoirs, fracture treatments serve to extend the well bore radius past a disturbed zone and vertically connect discrete intervals. Natural fractures in the near-well bore area strongly control the well deliverability rate. The Bakken is one of the few shale formations in the world with commercial oil production. This article covers the Bakken reservoir properties that influence production and stimulation treatments. The concluding part will discuss the design and effectiveness of the treatments.

Cramer, D.D. (BJ Services Co., Denver, CO (US))

1991-04-22T23:59:59.000Z

384

Oil and Gas Supply Module  

Gasoline and Diesel Fuel Update (EIA)

Onshore Lower 48 Oil and Gas Supply Submodule, Offshore Oil and Gas Supply Submodule, Oil Shale Supply Submodule1, and Alaska Oil and Gas Supply Submodule. A detailed description...

385

Oil and Gas Supply Module  

Gasoline and Diesel Fuel Update (EIA)

Onshore Lower 48 Oil and Gas Supply Submodule, Offshore Oil and Gas Supply Submodule, Oil Shale Supply Submodule, and Alaska Oil and Gas Supply Submodule. A detailed description of...

386

NETL: News Release - DOE Project Turns Abandoned Oil Lease Into  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

March 27, 2001 March 27, 2001 DOE Project Turns Abandoned Oil Lease Into Million-Barrel Producer Advanced Technology Brings California Oil Field Back to Life BAKERSFIELD, CA - An abandoned Bakersfield, California oil lease, brought back to life in 1995 by a joint government-industry experimental project, has produced more than a million barrels of oil once thought unrecoverable. The Pru Lease Field is Now Back in Operation - Improved technology made possible by a joint DOE and private industry field test helped bring the Pru Lease back into production. - Because of the success, oil is now flowing from 100 new privately funded wells in the immediate vicinity, and experts predict that the advanced technologies demonstrated in the federally co-funded field test could lead

387

Innovative Technology Improves Upgrading Process for Unconventional Oil  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

09, 2013 09, 2013 Innovative Technology Improves Upgrading Process for Unconventional Oil Resources Washington, D.C. - An innovative oil-upgrading technology that can increase the economics of unconventional petroleum resources has been developed under a U.S. Department of Energy -funded project. The promising technology, developed by Ceramatec of Salt Lake City, Utah, and managed by the Office of Fossil Energy's National Energy Technology Laboratory, has been licensed to Western Hydrogen of Calgary for upgrading bitumen or heavy oil from Canada. A new company, Field Upgrading (Calgary, Alberta), has been formed dedicated to developing and commercializing the technology. Heavy oil is crude oil that is viscous and requires thermally enhanced oil recovery methods, such as steam and hot water injection, to reduce its viscosity and enable it to flow. The largest U.S. deposits of heavy oil are in California and on Alaska's North Slope. Estimates for the U.S. heavy oil resource total about 104 billion barrels of oil in place - nearly five times the United States' proved reserves. In addition, although no commercial-scale development of U.S. oil sands or oil shale has yet occurred, both represent another potential future domestic unconventional oil resource.

388

Oil and Gas Exploration  

E-Print Network [OSTI]

Metals Industrial Minerals Oil and Gas Geothermal Exploration Development Mining Processing Nevada, oil and gas, and geothermal activities and accomplishments in Nevada: production statistics, exploration and development including drilling for petroleum and geothermal resources, discoveries of ore

Tingley, Joseph V.

389

China's Global Oil Strategy  

E-Print Network [OSTI]

21, 2008. Ying, Wang. “ China, Venezuela firms to co-developApril 21, “China and Venezuela sign oil agreements. ” Chinaaccessed April 21, “Venezuela and China sign oil deal. ” BBC

Thomas, Bryan G

2009-01-01T23:59:59.000Z

390

Using Oils As Pesticides  

E-Print Network [OSTI]

Petroleum and plant-derived spray oils show increasing potential for use as part of Integrated Pest Management systems for control of soft-bodied pests on fruit trees, shade trees, woody ornamentals and household plants. Sources of oils, preparing...

Bogran, Carlos E.; Ludwig, Scott; Metz, Bradley

2006-10-30T23:59:59.000Z

391

Residential heating oil price  

Annual Energy Outlook 2013 [U.S. Energy Information Administration (EIA)]

heating oil price decreases The average retail price for home heating oil fell 6.3 cents from a week ago to 2.91 per gallon. That's down 1.10 from a year ago, based on the...

392

Residential heating oil price  

U.S. Energy Information Administration (EIA) Indexed Site

heating oil price decreases The average retail price for home heating oil fell 7.5 cents from a week ago to 2.84 per gallon. That's down 1.22 from a year ago, based on the...

393

Residential heating oil price  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

heating oil price decreases The average retail price for home heating oil fell 7.6 cents from a week ago to 2.97 per gallon. That's down 1.05 from a year ago, based on the...

394

Residential heating oil price  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

heating oil price decreases The average retail price for home heating oil fell 3.6 cents from a week ago to 3.04 per gallon. That's down 99.4 cents from a year ago, based on the...

395

US Crude oil exports  

Gasoline and Diesel Fuel Update (EIA)

2014 EIA Energy Conference U.S. Crude Oil Exports July 14, 2014 By Lynn D. Westfall U.S. Energy Information Administration U.S. crude oil production has grown by almost 50% since...

396

Oil shale retorted underground  

Science Journals Connector (OSTI)

Oil shale retorted underground ... Low-temperature underground retorting of oil shale produces a crude oil with many attractive properties, Dr. George R. Hill of the University of Utah told a meeting of the American Institute of Mining, Metallurgical, and Petroleum Engineers last week in Los Angeles. ... Typical above-ground retorting of oil shale uses temperatures of 900° to 1100° F. because of the economic need ... ...

1967-02-27T23:59:59.000Z

397

Innovative Technology Improves Upgrading Process for Unconventional Oil  

Broader source: Energy.gov (indexed) [DOE]

Technology Improves Upgrading Process for Unconventional Technology Improves Upgrading Process for Unconventional Oil Resources Innovative Technology Improves Upgrading Process for Unconventional Oil Resources April 9, 2013 - 1:57pm Addthis Washington, DC - An innovative oil-upgrading technology that can increase the economics of unconventional petroleum resources has been developed under a U.S. Department of Energy -funded project. The promising technology, developed by Ceramatec of Salt Lake City, Utah, and managed by the Office of Fossil Energy's National Energy Technology Laboratory, has been licensed to Western Hydrogen of Calgary for upgrading bitumen or heavy oil from Canada. A new company, Field Upgrading (Calgary, Alberta), has been formed dedicated to developing and commercializing the technology. Heavy oil is crude oil that is viscous and requires thermally enhanced oil

398

Geotechnical properties of oil-contaminated Kuwaiti sand  

SciTech Connect (OSTI)

Large quantities of oil-contaminated sands resulted from exploded oil wells, burning oil fires, the destruction of oil storage tanks, and the formation of oil lakes in Kuwait at the end of the Gulf War. An extensive laboratory testing program was carried out to determine the geotechnical characteristics of this material. Testing included basic properties, compaction and permeability tests, and triaxial and consolidation tests on clean and contaminated sand at the same relative density. Contaminated specimens were prepared by mixing the sand with oil in the amount of 6% by weight or less to match field conditions. The influence of the type of oil, and relative density was also investigated by direct shear tests. The results indicated a small reduction in strength and permeability and an increase in compressibility due to contamination. The preferred method of disposal of this material is to use it as a stabilizing material for other projects such as road construction.

Al-Sanad, H.A.; Eid, W.K.; Ismael, N.F. [Kuwait Univ., Safat (Kuwait). Dept. of Civil Engineering] [Kuwait Univ., Safat (Kuwait). Dept. of Civil Engineering

1995-05-01T23:59:59.000Z

399

Biochemical upgrading of oils  

DOE Patents [OSTI]

A process for biochemical conversion of heavy crude oils is provided. The process includes contacting heavy crude oils with adapted biocatalysts. The resulting upgraded oil shows, a relative increase in saturated hydrocarbons, emulsions and oxygenates and a decrease in compounds containing organic sulfur, organic nitrogen and trace metals. Adapted microorganisms which have been modified under challenged growth processes are also disclosed. 121 figs.

Premuzic, E.T.; Lin, M.S.

1999-01-12T23:59:59.000Z

400

Exploiting heavy oil reserves  

E-Print Network [OSTI]

North Sea investment potential Exploiting heavy oil reserves Beneath the waves in 3D Aberdeen the potential of heavy oil 8/9 Taking the legal lessons learned in the north Sea to a global audience 10 potential Exploiting heavy oil reserves Aberdeen: A community of science AT WORK FOR THE ENERGY SECTOR ISSUE

Levi, Ran

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


401

Utah Heavy Oil Program  

SciTech Connect (OSTI)

The Utah Heavy Oil Program (UHOP) was established in June 2006 to provide multidisciplinary research support to federal and state constituents for addressing the wide-ranging issues surrounding the creation of an industry for unconventional oil production in the United States. Additionally, UHOP was to serve as an on-going source of unbiased information to the nation surrounding technical, economic, legal and environmental aspects of developing heavy oil, oil sands, and oil shale resources. UHOP fulGilled its role by completing three tasks. First, in response to the Energy Policy Act of 2005 Section 369(p), UHOP published an update report to the 1987 technical and economic assessment of domestic heavy oil resources that was prepared by the Interstate Oil and Gas Compact Commission. The UHOP report, entitled 'A Technical, Economic, and Legal Assessment of North American Heavy Oil, Oil Sands, and Oil Shale Resources' was published in electronic and hard copy form in October 2007. Second, UHOP developed of a comprehensive, publicly accessible online repository of unconventional oil resources in North America based on the DSpace software platform. An interactive map was also developed as a source of geospatial information and as a means to interact with the repository from a geospatial setting. All documents uploaded to the repository are fully searchable by author, title, and keywords. Third, UHOP sponsored Give research projects related to unconventional fuels development. Two projects looked at issues associated with oil shale production, including oil shale pyrolysis kinetics, resource heterogeneity, and reservoir simulation. One project evaluated in situ production from Utah oil sands. Another project focused on water availability and produced water treatments. The last project considered commercial oil shale leasing from a policy, environmental, and economic perspective.

J. Bauman; S. Burian; M. Deo; E. Eddings; R. Gani; R. Goel; C.K. Huang; M. Hogue; R. Keiter; L. Li; J. Ruple; T. Ring; P. Rose; M. Skliar; P.J. Smith; J.P. Spinti; P. Tiwari; J. Wilkey; K. Uchitel

2009-10-20T23:59:59.000Z

402

Chapter 2 - Offshore Oil and Gas Drilling Engineering and Equipment  

Science Journals Connector (OSTI)

Abstract This chapter introduces the drilling engineering and equipment in the field of offshore oil and gas.It starts by introducing the drilling platform used in the offshore oil and gas. Then it presents the wellhead and wellhead devices used in the offshore oil and gas. After these two, it begins to introduce the drilling engineer including preparation, working procedure, well completion and so on. Finally, it roughly introduces the new technology in drilling and new drilling rig nowadays.

Huacan Fang; Menglan Duan

2014-01-01T23:59:59.000Z

403

RAPID/Geothermal/Well Field/California | Open Energy Information  

Open Energy Info (EERE)

& Well Field Permit Agency: California Department of Conservation, Division of Oil, Gas, and Geothermal Resources Drilling & Well Field Permit Before drilling can commense,...

404

Manufacture of refrigeration oils  

SciTech Connect (OSTI)

Lubricating oils suitable for use in refrigeration equipment in admixture with fluorinated hydrocarbon refrigerants are produced by solvent extraction of naphthenic lubricating oil base stocks, cooling the resulting extract mixture, optionally with the addition of a solvent modifier, to form a secondary raffinate and a secondary extract, and recovering a dewaxed oil fraction of lowered pour point from the secondary raffinate as a refrigeration oil product. The process of the invention obviates the need for a separate dewaxing operation, such as dewaxing with urea, as conventionally employed for the production of refrigeration oils.

Chesluk, R.P.; Platte, H.J.; Sequeira, A.J.

1981-12-08T23:59:59.000Z

405

A new type of whole oil-based drilling fluid  

Science Journals Connector (OSTI)

Abstract To meet the demand of ultra-deep well drilling and shale gas well drilling, organic clay and a oil-based filtrate reducer were developed and a whole oil-based drilling fluid formula was optimized. The performance of organic clay, oil-based filtrate reducer and the whole oil-based drilling fluid were evaluated in laboratory, and the whole oil-based drilling fluid was applied in drilling process for further test of its performance. Long carbon chain quaternary ammonium salt was used as modifying agents when synthesizing organobentonites. Oil-based filtrate reducer was synthesized with monomers of lignite and amine class. The laboratory tests show that the organic clay can effectively increase the viscosity of oil-based drilling fluid and the oil-based filtrate reducer can reduce the fluid loss. Their performances were better than additives of the same kind at home and abroad. The organic clay and oil-based filtrate reducer had great compatibility with the other additives in oil-based drilling fluid. Based on the optimal additives addition amount tests, the whole oil-based drilling fluid formula was determined and the test results show that the performances of the whole oil-based drilling fluids with various densities were great. The laboratory tests show that the oil-based drilling fluid developed was high temperature resistant, even at 200 °C, as density varies from 0.90 to 2.0 g/cm3, it still held good performance with only a little fluid loss, good inhibition, great anti-pollution, and good reservoir protection performance. Field application result shows that the performance of the oil-based drilling fluid is stable with great ability to maintain wellbore stability and lower density than the water-based drilling fluid; drilling bits can be used much longer and the average penetration rate is increased; the oil-based drilling fluid can satisfy the drilling requirements.

Jiancheng LI; Peng YANG; Jian GUAN; Yande SUN; Xubing KUANG; Shasha CHEN

2014-01-01T23:59:59.000Z

406

Kuwait pressing toward preinvasion oil production capacity  

SciTech Connect (OSTI)

Oil field reconstruction is shifting focus in Kuwait as the country races toward prewar production capacity of 2 million b/d. Oil flow last month reached 1.7 million b/d, thanks largely to a massive workover program that has accomplished about as much as it can. By midyear, most of the 19 rigs in Kuwait will be drilling rather than working over wells vandalized by retreating Iraqi troops in February 1991. Seventeen gathering centers are at work, with capacities totaling 2.4 million b/d, according to state-owned Kuwait Oil Co. (KOC). This article describes current work, the production infrastructure, facilities strategy, oil recovery, well repairs, a horizontal pilot project, the drilling program, the constant reminders of war, and heightened tensions.

Tippee, B.

1993-03-15T23:59:59.000Z

407

Persian Gulf: their oil, our need  

SciTech Connect (OSTI)

The degree of reliance of the US on Persian Gulf petroleum as well as problems facing Persian Gulf nations are addressed in this report. While US dependency on oil imports from Saudi Arabia is down, Japan and other western allies are very dependent on Saudi oil. The consequences of being deprived of Persian Gulf oil are described. The status and implications of the Iran-Iraq war are discussed in detail. The Arab countries in the region fear attacks on their oil fields by enemies and have developed a regional point defense strategy involving Saudi Arabia, Kuwait, Bahrain, Qatar, the United Arab Emirates and Oman. OPEC's role in the area is described. The possibility of US intervention if needed to keep the Strait of Hormuz open and to protect the Gulf states from violence is also addressed. (DMC)

Brossard, E.B.

1984-01-01T23:59:59.000Z

408

Shallow oil production using horizontal wells with enhanced oil recovery techniques  

SciTech Connect (OSTI)

Millions of barrels of oil exist in the Bartlesville formation throughout Oklahoma, Kansas, and Missouri. In an attempt to demonstrate that these shallow heavy oil deposits can be recovered, a field project was undertaken to determine the effectiveness of enhanced oil recovery techniques (EOR) employing horizontal wells. Process screening results suggested that thermal EOR processes were best suited for the recovery of this heavy oil. Screening criteria suggested that in situ combustion was a viable technique for the production of these reserves. Laboratory combustion tube tests confirmed that sufficient amounts of fuel could be deposited. The results of the in situ combustion field pilot were disappointing. A total overall recovery efficiency of only 16.0 percent was achieved. Results suggest that the combustion front might have moved past the horizontal well, however elevated temperatures or crude upgrading were not observed. Factors contributing to the lack of production are also discussed.

Satchwell, R.M.; Johnson, L.A. Jr. [Western Research Institute, Laramie, WY (United States); Trent, R. [Univ. of Alaska, Fairbanks, AK (United States)

1995-02-01T23:59:59.000Z

409

Carcinogenicity Studies of Estonian Oil Shale Soots  

E-Print Network [OSTI]

determine the carcinogenicity of Estonian oil shale soot as well as the soot from oil shale fuel oil. All

A. Vosamae

410

FE Oil and Natural Gas News  

Broader source: Energy.gov (indexed) [DOE]

oil-natural-gas-news Office of Fossil Energy Forrestal oil-natural-gas-news Office of Fossil Energy Forrestal Building 1000 Independence Avenue, SW Washington, DC 20585202-586-6503 en Energy Department Authorizes Additional Volume at Proposed Freeport LNG Facility to Export Liquefied Natural Gas http://energy.gov/articles/energy-department-authorizes-additional-volume-proposed-freeport-lng-facility-export Energy Department Authorizes Additional Volume at Proposed Freeport LNG Facility to Export Liquefied Natural Gas

411

Crude Oil, Heating Oil, and Propane Market Outlook  

Gasoline and Diesel Fuel Update (EIA)

Oil, Heating Oil, and Propane Market Outlook Oil, Heating Oil, and Propane Market Outlook 8/13/01 Click here to start Table of Contents Crude Oil, Heating Oil, and Propane Market Outlook Short-Term World Oil Price Forecast Price Movements Related to Supply/Demand Balance OPEC Production Likely To Remain Low U.S. Reflects World Market Crude Oil Outlook Conclusions Distillate Prices Increase With Crude Oil Distillate Stocks on the East Coast Were Very Low Entering Last Winter Distillate Demand Strong Last Winter More Supply Possible This Fall than Forecast Distillate Fuel Oil Imports Could Be Available - For A Price Distillate Supply/Demand Balance Reflected in Spreads Distillate Stocks Expected to Remain Low Winter Crude Oil and Distillate Price Outlook Heating Oil Outlook Conclusion Propane Prices Follow Crude Oil

412

Airborne Studies of the Smoke from the Kuwait Oil Fires  

Science Journals Connector (OSTI)

...smoke from the Kuwait fires produced a small-scale...Concluding Remarks The airborne studies of the smoke from the Kuwait fires provided a large...1. Uncontrolled releases of oil began in January...and the oil field fires began in late February...Zimmerman). 3. An airborne study of the smoke...

Peter V. Hobbs; Lawrence F. Radke

1992-05-15T23:59:59.000Z

413

Reactivation of an Idle Lease to Increase Heavy Oil Recovery through Application of Conventional Steam Drive Technology in a Low Dip Slope & Reservoir in the Midway-Sunset Field, San Jaoquin Basin, California  

SciTech Connect (OSTI)

In January 1997 the project entered its second and main phase with the purpose of demonstrating whether steamflood can be a more effective mode of production of the heavy, viscous oils from the Monarch Sand reservoir than the more conventional cyclic steaming. The objective is not just to produce the pilot site within the Pru Fee property south of Taft (Figure 1), but to test which production parameters optimize total oil recovery at economically acceptable rates of production and production costs.

Schamel, Steven

1999-11-09T23:59:59.000Z

414

Ventures: Conoco abandons Iranian oil deal  

SciTech Connect (OSTI)

Conoco (Houston), the oil and gas subsidiary of DuPont, has backed out of a deal to develop offshore oil fields for Iran as a result of a week of intense pressure from the Clinton Administration. Under the agreement, Conoco Iran, a Netherlands-based affiliate, would have developed two oil fields in the Persian Gulf. The deal, valued at $1 billion, would have been the first between Iran and a U.S. company since Washington severed relations with Teheran in 1980. Conoco says it operated within the law and with the knowledge of the U.S. government in the three years the deal was being negotiated. President Clinton announced an executive order barring such deals last Tuesday, after Conoco executives informed the Administration that the deal would be abandoned if an order was issued.

Westervelt, R.

1995-03-22T23:59:59.000Z

415

Int. J. Oil, Gas and Coal Technology, Vol. 1, Nos. 1/2, 2008 65 Copyright 2008 Inderscience Enterprises Ltd.  

E-Print Network [OSTI]

Int. J. Oil, Gas and Coal Technology, Vol. 1, Nos. 1/2, 2008 65 Copyright © 2008 Inderscience Enterprises Ltd. Building the foundation for Prudhoe Bay oil production optimisation using neural networks E-mail: siskd@Bp.com Abstract: Field data from the Prudhoe Bay oil field in Alaska was used

Mohaghegh, Shahab

416

Fast Marching Method with Multiphase Flow and Compositional Effects  

E-Print Network [OSTI]

. ........................................................................................................... 96 Fig. 3.6 Modified VLE flash procedure with oil-gas capillary pressure. ................... 99 Fig. 3.7 Capillary pressures of the (a) Bakken oil shale sample and (b) Shale gas sample...

Fujita, Yusuke

2014-08-06T23:59:59.000Z

417

This Week In Petroleum Printer-Friendly Version  

Gasoline and Diesel Fuel Update (EIA)

like those in the Bakken Formation is not the same as the extraction of oil from oil shale plays. See This Week In Petroleum, March 4, 2009.) Natural Gas. Proved reserves of...

418

World Oil: Market or Mayhem?  

E-Print Network [OSTI]

The world oil market is regarded by many as a puzzle. Why are oil prices so volatile? What is OPEC and what does OPEC do? Where are oil prices headed in the long run? Is “peak oil” a genuine concern? Why did oil prices ...

Smith, James L.

2008-01-01T23:59:59.000Z

419

Measuring and mi-ga-ng impact of offshore oil development on  

E-Print Network [OSTI]

Measuring and mi-ga-ng impact of offshore oil development on seabirds and other effects are concentrated in the offshore ­ vicinity of the oil field J. 2001. Seabirds at risk around offshore oil pla=orms in the north

Jones, Ian L.

420

An evaluation of known remaining oil resources in the United States: Appendix. Volume 10  

SciTech Connect (OSTI)

Volume ten contains the following appendices: overview of improved oil recovery methods which covers enhanced oil recovery methods and advanced secondary recovery methods; the benefits of improved oil recovery, selected data for the analyzed states; and list of TORIS fields and reservoirs.

NONE

1993-11-01T23:59:59.000Z

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


421

Mass transfer in eccentric binaries: the new oil-on-water smoothed particle hydrodynamics technique  

Science Journals Connector (OSTI)

......us to place the oil layer closer to the surface. 2.5 Production of the single-star...reliability of the oil-on-water model...Because the potential field is circular, corotating...5. Figure 6 The cumulative number of oil particles released......

Ross P. Church; Johann Dischler; Melvyn B. Davies; Christopher. A. Tout; Tim Adams; Martin E. Beer

2009-05-11T23:59:59.000Z

422

DOSKIL: A New Mechanism for Controlling Stick-Slip Oscillations in Oil Well Drillstrings  

E-Print Network [OSTI]

-1191" #12;2 a) b) Fig. 1. Oil drilling system in the field (a). Basic scheme of a vertical drilling system1 DOSKIL: A New Mechanism for Controlling Stick-Slip Oscillations in Oil Well Drillstrings Carlos: macperu@us.es Abstract Limit cycles occurring in oil well drillstrings result from the interaction between

Boyer, Edmond

423

Earth'sFuture Remote sensing of fugitive methane emissions from oil and  

E-Print Network [OSTI]

and tight oil reservoirs to exploit formerly inaccessible or unprofitable energy resources in rock are drilled out. In the production process of tight oil, co-occurring natural gas is typically used to drive. Therefore, methane emissions from field production of oil and gas from tight reservoirs have the potential

Dickerson, Russell R.

424

Externality Regulation in Oil and Gas Encyclopedia of Energy, Natural Resource, and  

E-Print Network [OSTI]

Externality Regulation in Oil and Gas Chapter 56 Encyclopedia of Energy, Natural Resource Unitization: Compulsory unitization legislation enables a majority of producers on an oil or gas field resource, congestion exter- nality, minimum oil/gas ratio, monopsony power, pipeline transportation, no

Garousi, Vahid

425

Oil and Gas CDT Quantifying the role of groundwater in hydrocarbon systems using noble gas  

E-Print Network [OSTI]

Oil and Gas CDT Quantifying the role of groundwater in hydrocarbon systems using noble gas isotopes by groundwater (or oil) degassing. Other natural gas fields may have been produced in-situ or migrated as a free expert academics from across the CDT and also experienced oil and gas industry professionals

Henderson, Gideon

426

A Multimedia Workflow-Based Collaborative Engineering Environment for Oil & Gas Industry  

E-Print Network [OSTI]

A Multimedia Workflow-Based Collaborative Engineering Environment for Oil & Gas Industry Ismael H the control and execution of large and complex industrial projects in oil and gas industry. The environment governmental oil & gas company. The necessity of collaboration is especially acute in the field of computer

Barbosa, Alberto

427

Vegetable oil fuel  

SciTech Connect (OSTI)

In this article, the future role of renewable agricultural resources in providing fuel is discussed. it was only during this century that U.S. farmers began to use petroleum as a fuel for tractors as opposed to forage crop as fuel for work animals. Now farmers may again turn to crops as fuel for agricultural production - the possible use of sunflower oil, soybean oil and rapeseed oil as substitutes for diesel fuel is discussed.

Bartholomew, D.

1981-04-01T23:59:59.000Z

428

US oil consumption, oil prices, and the macroeconomy  

Science Journals Connector (OSTI)

Since the oil price shock of 1973–74, researchers have waged ... national income. Studies examining the relationship between oil prices, oil consumption, and real output have produced remarkably ... to dramatical...

Ali F. Darrat; Otis W. Gilley; Don J. Meyer

1996-01-01T23:59:59.000Z

429

Lower oil prices also cutting winter heating oil and propane...  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

Lower oil prices also cutting winter heating oil and propane bills Lower oil prices are not only driving down gasoline costs, but U.S. consumers will also see a bigger savings in...

430

Effects of Oil and Oil Dispersants on the Marine Environment  

Science Journals Connector (OSTI)

13 April 1971 research-article Effects of Oil and Oil Dispersants on the Marine Environment R. G. J. Shelton In the context of marine pollution, the term 'oil' can cover a very wide range of substances and usually...

1971-01-01T23:59:59.000Z

431

Enhanced Oil Recovery to Fuel Future Oil Demands | GE Global...  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

to Fuel Future Oil Demands Enhanced Oil Recovery to Fuel Future Oil Demands Trevor Kirsten 2013.10.02 I'm Trevor Kirsten and I lead a team of GE researchers that investigate a...

432

NETL: News Release - Alabama Injection Project Aimed at Enhanced Oil  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

March 1, 2010 March 1, 2010 Alabama Injection Project Aimed at Enhanced Oil Recovery, Testing Important Geologic CO2 Storage DOE-Sponsored Citronelle Project Appears Ideal Location for Concurrent CO2 Sequestration and EOR Operations Washington, D.C. - Carbon dioxide (CO2) injection - an important part of carbon capture and storage (CCS) technology - is underway as part of a pilot study of CO2 enhanced oil recovery (EOR) in the Citronelle Field of Mobile County, Alabama. A project team led by the University of Alabama at Birmingham is conducting the injection. Study results of the 7,500-ton CO2 injection will provide estimates of oil yields from EOR and CO2 storage capacity in depleted oil reservoirs. In the United States, CO2 injection has already helped recover nearly 1.5 billion barrels of oil from mature oil fields, yet the technology has not been deployed widely. It is estimated that nearly 400 billion barrels of oil still remain trapped in the ground. Funded through the Department of Energy's Office of Fossil Energy, the primary goal of the Citronelle Project is to demonstrate that remaining oil can be economically produced using CO2-EOR technology in untested areas of the United States, thereby reducing dependency on oil imports, providing domestic jobs, and preventing the release of CO2 into the atmosphere.

433

Oil and Gas (Indiana)  

Broader source: Energy.gov [DOE]

This division of the Indiana Department of Natural Resources provides information on the regulation of oil and gas exploration, wells and well spacings, drilling, plugging and abandonment, and...

434

Waste oil reduction: GKN  

SciTech Connect (OSTI)

This report details the steps required to establish a waste oil management program. Such a program can reduce operational costs, cut wastewater treatment costs and produce a better quality wastewater effluent through such means as: reducing the volume of oils used; segregating oils at the source of generation for recovery and reuse; and reducing the quality of oily wastewater generated. It discusses the metal-working fluid recovery options available for such a program, namely settling, filtration, hydrocyclone, and centrifugation. Included are source lists for vendors of oil skimmer equipment and coolant recovery systems.

Hunt, G.

1995-08-01T23:59:59.000Z

435

Understanding Crude Oil Prices  

E-Print Network [OSTI]

disruptions, and the peak in U.S. oil production account foroil increased 81.1% (logarithmically) between January 1979 and the peak

Hamilton, James Douglas

2008-01-01T23:59:59.000Z

436

What substitutes for oil?  

Science Journals Connector (OSTI)

... bagasse, ethyl alcohol, vegetable oils, methane and hydrogen; as well as hydro and nuclear power generation, conservation methods, and solar, wind and tidal energy.

David Spurgeon

1978-06-29T23:59:59.000Z

437

Crude Oil Prices  

Annual Energy Outlook 2013 [U.S. Energy Information Administration (EIA)]

Information AdministrationPetroleum Marketing Annual 2001 41 Table 21. Domestic Crude Oil First Purchase Prices (Dollars per Barrel) - Continued Year Month PAD District II...

438

Crude Oil Prices  

U.S. Energy Information Administration (EIA) Indexed Site

Information AdministrationPetroleum Marketing Annual 2002 41 Table 21. Domestic Crude Oil First Purchase Prices (Dollars per Barrel) - Continued Year Month PAD District II...

439

Crude Oil Prices  

Gasoline and Diesel Fuel Update (EIA)

Information AdministrationPetroleum Marketing Annual 2000 41 Table 21. Domestic Crude Oil First Purchase Prices (Dollars per Barrel) - Continued Year Month PAD District II...

440

Crude Oil Prices  

Annual Energy Outlook 2013 [U.S. Energy Information Administration (EIA)]

Information AdministrationPetroleum Marketing Annual 1999 41 Table 21. Domestic Crude Oil First Purchase Prices (Dollars per Barrel) - Continued Year Month PAD District II...

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


441

Crude Oil Prices  

U.S. Energy Information Administration (EIA) Indexed Site

Information AdministrationPetroleum Marketing Annual 1998 41 Table 21. Domestic Crude Oil First Purchase Prices (Dollars per Barrel) - Continued Year Month PAD District II...

442

NETL: Oil & Gas  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

Oil & Gas Publications KMD Contacts Project Summaries EPAct 2005 Arctic Energy Office Announcements Software Stripper Wells Efficient recovery of our nation's fossil fuel resources...

443

Oil's Impact on Our National Security | Department of Energy  

Broader source: Energy.gov (indexed) [DOE]

Oil's Impact on Our National Security Oil's Impact on Our National Security Oil's Impact on Our National Security April 25, 2011 - 6:12pm Addthis John Schueler John Schueler Former New Media Specialist, Office of Public Affairs Our dependence on foreign oil not only impacts hard working Americans at the pump, but it also compromises the security of our troops, as transporting large quantities of oil to our armed forces is often a dangerous and costly endeavor. The Department of Energy is committed to reducing our dependence on oil and supporting our armed forces, and that's why we've been collaborating with the Department of Defense throughout this administration to develop clean energy technologies and get them into the field. Tomorrow, Deputy Secretary Daniel Poneman will join Deputy Secretary of

444

NETL: News Release - DOE Oil Recovery Project Extends Success through  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

5 , 2007 5 , 2007 DOE Oil Recovery Project Extends Success through Technology Transfer New Technologies & Techniques Boost U.S. Proved Oil Reserves, Travel the Globe WASHINGTON, DC - A groundbreaking oil-recovery project funded by the U.S. Department of Energy (DOE) is coming to a close, but its success will continue to be felt throughout the United States and the world. MORE INFO Read 03.10.06 Techline: DOE-Funded Project Revives Aging California Oilfield The project, titled "Increasing Heavy Oil Reserves in the Wilmington Oil Field Through Advanced Reservoir Characterizations and Thermal Production Technologies," began in 1995 with the goal of increasing recoverable heavy oil reserves in those sections of the Wilmington oilfield operated by Long

445

New EOR system being tested. [Enhanced oil recovery  

SciTech Connect (OSTI)

Oil and gas operators - and drilling contractors, if they own production - are watching with a great deal of interest an innovative enhanced oil recovery system now being tested in Missouri and Canada which, if present results prove to be the rule, will help gain recovery rates of double current oil production using conventional means. The new system, vapor therm, is being offered to oil and gas operators who either are now engaged in steam injection projects or plan to in the near future. The vapor therm system is designed for use in specific heavy oil reservoirs. What's more, existing steam generating equipment in field use need not be eliminated, since the system has been designed to be retrofitted to such steam generating facilities with little or no downtime involved. The system combines inert gases with injected steam to produced greatly enhanced recovery of oil for the same amount of steam injected in conventional steamflood operations.

Not Available

1982-04-01T23:59:59.000Z

446

Far-Field Optical Nanoscopy  

Science Journals Connector (OSTI)

...speed, sensitivity, and cost-efficiency are constantly...mathematically. Operating with oil, glycerol, and water-immersion...recent field-corrected oil-immersion lenses...Setting the current benchmark, these STED-4Pi...fluorophores encourages the exploration of this concept. Depleting...

Stefan W. Hell

2007-05-25T23:59:59.000Z

447

Louisiana State Offshore Crude Oil + Lease Condensate Reserves...  

U.S. Energy Information Administration (EIA) Indexed Site

State Offshore Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0...

448

Drunk On Oil: Russian Foreign Policy 2000-2007  

E-Print Network [OSTI]

world’s largest natural gas reserves, about twice that oftotal recoverable reserves. 139 Gas fields are declining asgas. 12 Russia has around 6% to 10% of the world’s known oil reserves.

Brugato, Thomas

2008-01-01T23:59:59.000Z

449

Improving CO2 Efficiency for Recovering Oil in Heterogeneous Reservoirs  

SciTech Connect (OSTI)

The work strived to improve industry understanding of CO2 flooding mechanisms with the ultimate goal of economically recovering more of the U.S. oil reserves. The principle interests are in the related fields of mobility control and injectivity.

Grigg, Reid B.; Svec, Robert K.

2003-03-10T23:59:59.000Z

450

Sovent Based Enhanced Oil Recovery for In-Situ Upgrading of Heavy Oil Sands  

SciTech Connect (OSTI)

With the depletion of conventional crude oil reserves in the world, heavy oil and bitumen resources have great potential to meet the future demand for petroleum products. However, oil recovery from heavy oil and bitumen reservoirs is much more difficult than that from conventional oil reservoirs. This is mainly because heavy oil or bitumen is partially or completely immobile under reservoir conditions due to its extremely high viscosity, which creates special production challenges. In order to overcome these challenges significant efforts were devoted by Applied Research Center (ARC) at Florida International University and The Center for Energy Economics (CEE) at the University of Texas. A simplified model was developed to assess the density of the upgraded crude depending on the ratio of solvent mass to crude oil mass, temperature, pressure and the properties of the crude oil. The simplified model incorporated the interaction dynamics into a homogeneous, porous heavy oil reservoir to simulate the dispersion and concentration of injected CO{sub 2}. The model also incorporated the characteristic of a highly varying CO{sub 2} density near the critical point. Since the major challenge in heavy oil recovery is its high viscosity, most researchers have focused their investigations on this parameter in the laboratory as well as in the field resulting in disparaging results. This was attributed to oil being a complex poly-disperse blend of light and heavy paraffins, aromatics, resins and asphaltenes, which have diverse behaviors at reservoir temperature and pressures. The situation is exacerbated by a dearth of experimental data on gas diffusion coefficients in heavy oils due to the tedious nature of diffusivity measurements. Ultimately, the viscosity and thus oil recovery is regulated by pressure and its effect on the diffusion coefficient and oil swelling factors. The generation of a new phase within the crude and the differences in mobility between the new crude matrix and the precipitate readily enables removal of asphaltenes. Thus, an upgraded crude low in heavy metal, sulfur and nitrogen is more conducive for further purification.

Norman Munroe

2009-01-30T23:59:59.000Z

451

Journal of Sedimentary Research, 2014, v. 84, 837838 DOI: http://dx.doi.org/10.2110/jsr.2014.73  

E-Print Network [OSTI]

of bitumen (this is, after all, an oil-producing shale) while the slide is cured on a hot plate, can also­LOWER MISSISSIPPIAN UPPER SHALE MEMBER OF THE BAKKEN FORMATION, WILLISTON BASIN, NORTH DAKOTA, U made on cores of the Bakken Shale and presents a methodology to examine and describe these cores

Polly, David

452

HEAVY AND THERMAL OIL RECOVERY PRODUCTION MECHANISMS  

SciTech Connect (OSTI)

This technical progress report describes work performed from January 1 through March 31, 2003 for the project ''Heavy and Thermal Oil Recovery Production Mechanisms,'' DE-FC26-00BC15311. In this project, a broad spectrum of research is undertaken related to thermal and heavy-oil recovery. The research tools and techniques span from pore-level imaging of multiphase fluid flow to definition of reservoir-scale features through streamline-based history matching techniques. During this period, previous analysis of experimental data regarding multidimensional imbibition to obtain shape factors appropriate for dual-porosity simulation was verified by comparison among analytic, dual-porosity simulation, and fine-grid simulation. We continued to study the mechanisms by which oil is produced from fractured porous media at high pressure and high temperature. Temperature has a beneficial effect on recovery and reduces residual oil saturation. A new experiment was conducted on diatomite core. Significantly, we show that elevated temperature induces fines release in sandstone cores and this behavior may be linked to wettability. Our work in the area of primary production of heavy oil continues with field cores and crude oil. On the topic of reservoir definition, work continued on developing techniques that integrate production history into reservoir models using streamline-based properties.

Anthony R. Kovscek

2003-04-01T23:59:59.000Z

453

Prudhoe Bay Oil Production Optimization: Using Virtual  

E-Print Network [OSTI]

77659, Mohaghegh, Hutchins, Sisk BACKGROUND Fuel gas supply (at the flow stations and gathering centers total field oil production by optimizing the gas discharge rates and pressures at the separation wells flowing to eight remote, three-phase separation facilities (flow stations and gathering centers

Mohaghegh, Shahab

454

Optimization Methods in Oil and Gas Exploration  

Science Journals Connector (OSTI)

......function of the cumulative number of well-feet...where c denotes cumulative discoveries in billions...barrels, d denotes cumulative drilling in thousands...in an established oil-producing region...resources between production drilling, delineation...finding a large field, and another specified......

E. M. L. BEALE

1986-01-01T23:59:59.000Z

455

Feasibility study of heavy oil recovery in the Appalachian, Black Warrior, Illinois, and Michigan basins  

SciTech Connect (OSTI)

This report is one of a series of publications assessing the feasibility of increasing domestic heavy oil production. Each report covers select areas of the United States. The Appalachian, Black Warrior, Illinois, and Michigan basins cover most of the depositional basins in the Midwest and Eastern United States. These basins produce sweet, paraffinic light oil and are considered minor heavy oil (10{degrees} to 20{degrees} API gravity or 100 to 100,000 cP viscosity) producers. Heavy oil occurs in both carbonate and sandstone reservoirs of Paleozoic Age along the perimeters of the basins in the same sediments where light oil occurs. The oil is heavy because escape of light ends, water washing of the oil, and biodegradation of the oil have occurred over million of years. The Appalachian, Black Warrior, Illinois, and Michigan basins` heavy oil fields have produced some 450,000 bbl of heavy oil of an estimated 14,000,000 bbl originally in place. The basins have been long-term, major light-oil-producing areas and are served by an extensive pipeline network connected to refineries designed to process light sweet and with few exceptions limited volumes of sour or heavy crude oils. Since the light oil is principally paraffinic, it commands a higher price than the asphaltic heavy crude oils of California. The heavy oil that is refined in the Midwest and Eastern US is imported and refined at select refineries. Imports of crude of all grades accounts for 37 to >95% of the oil refined in these areas. Because of the nature of the resource, the Appalachian, Black Warrior, Illinois and Michigan basins are not expected to become major heavy oil producing areas. The crude oil collection system will continue to degrade as light oil production declines. The demand for crude oil will increase pipeline and tanker transport of imported crude to select large refineries to meet the areas` liquid fuels needs.

Olsen, D.K.; Rawn-Schatzinger, V.; Ramzel, E.B.

1992-07-01T23:59:59.000Z

456

Feasibility study of heavy oil recovery in the Appalachian, Black Warrior, Illinois, and Michigan basins  

SciTech Connect (OSTI)

This report is one of a series of publications assessing the feasibility of increasing domestic heavy oil production. Each report covers select areas of the United States. The Appalachian, Black Warrior, Illinois, and Michigan basins cover most of the depositional basins in the Midwest and Eastern United States. These basins produce sweet, paraffinic light oil and are considered minor heavy oil (10{degrees} to 20{degrees} API gravity or 100 to 100,000 cP viscosity) producers. Heavy oil occurs in both carbonate and sandstone reservoirs of Paleozoic Age along the perimeters of the basins in the same sediments where light oil occurs. The oil is heavy because escape of light ends, water washing of the oil, and biodegradation of the oil have occurred over million of years. The Appalachian, Black Warrior, Illinois, and Michigan basins' heavy oil fields have produced some 450,000 bbl of heavy oil of an estimated 14,000,000 bbl originally in place. The basins have been long-term, major light-oil-producing areas and are served by an extensive pipeline network connected to refineries designed to process light sweet and with few exceptions limited volumes of sour or heavy crude oils. Since the light oil is principally paraffinic, it commands a higher price than the asphaltic heavy crude oils of California. The heavy oil that is refined in the Midwest and Eastern US is imported and refined at select refineries. Imports of crude of all grades accounts for 37 to >95% of the oil refined in these areas. Because of the nature of the resource, the Appalachian, Black Warrior, Illinois and Michigan basins are not expected to become major heavy oil producing areas. The crude oil collection system will continue to degrade as light oil production declines. The demand for crude oil will increase pipeline and tanker transport of imported crude to select large refineries to meet the areas' liquid fuels needs.

Olsen, D.K.; Rawn-Schatzinger, V.; Ramzel, E.B.

1992-07-01T23:59:59.000Z

457

PIA - Northeast Home Heating Oil Reserve System (Heating Oil...  

Office of Environmental Management (EM)

Home Heating Oil Reserve System (Heating Oil) More Documents & Publications PIA - WEB Physical Security Major Application PIA - GovTrip (DOE data) PIA - WEB Unclassified...

458

Gabon: World Oil Report 1991  

SciTech Connect (OSTI)

This paper reports on Gabon's largest oil field, Rabi Kounga, and a flurry of smaller reservoirs which have boosted production to 300,000 bopd. Regional geology is so complex that it generates a large discovery only once every twenty years, and operators come and go due to low discovery ratios, following market ups and downs. A hard core four remain: Elf first, Shell, British Gas, which bought Tenneco, and Amoco. Shell's Rabi Kounga discovery, which stretches from shore to shelf, boosted exploration and renewed interest for onshore licenses. The low discovery rate, however, reflects the complexity of Gabonese basins.

Not Available

1991-08-01T23:59:59.000Z

459

Reactivation of an idle lease to increase heavy oil recovery through application of conventional steam drive technology in a low dip slope and basin reservoir in the Midway-Sunset field, San Jaoquin Basin, California. Annual report, June 13, 1995--June 13, 1996  

SciTech Connect (OSTI)

This project reactivates ARCO`s idle Pru Fee lease in the Midway-Sunset field, California and conducts a continuous steamflood enhanced oil recovery demonstration aided by an integration of modern reservoir characterization and simulation methods. Cyclic steaming is being used to reestablish baseline production within the reservoir characterization phase of the project. During the demonstration phase scheduled to begin in January 1997, a continuous steamflood enhanced oil recovery will be initiated to test the incremental value of this method as an alternative to cyclic steaming. Other economically marginal Class III reservoirs having similar producibility problems will benefit from insight gained in this project. The objectives of the project are: (1) to return the shut-in portion of the reservoir to optimal commercial production; (2) to accurately describe the reservoir and recovery process; and (3) to convey the details of this activity to the domestic petroleum industry, especially to other producers in California, through an aggressive technology transfer program.

Deo, M.; Jenkins, C.; Sprinkel, D.; Swain, R.; Wydrinski, R.; Schamel, S.

1998-09-01T23:59:59.000Z

460

Lead Corrosion and Oil Oxidation  

Science Journals Connector (OSTI)

... tests the horn was AISI 304, the balls were variously high purity Al, Cu, SAE 52100 steel, and Pb. The oil was a refined paraffinic mineral oil into which ... oil Bearing

J. K. APPELDOORN; P. PACOR; V. RIDDEI

1972-10-20T23:59:59.000Z

Note: This page contains sample records for the topic "oil fields bakken" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


461

Courting the oil that plays hard to get  

SciTech Connect (OSTI)

Marathon Oil first applied its patented oilfield polymer-making plant at the Wyoming Byron Field in 1982. The polymer-augmented waterflooding process improves recoverability. The concept is now in use in oil fields in Oregon and Texas at a reasonable cost. The additional oil available through polymer-augmented waterflooding will reduce imports and make a significant contribution to domestic production. Five patents were necessary for the process, which has been under development since the 1960s, with 19 patents still pending. 8 figures.

Not Available

1984-01-01T23:59:59.000Z

462

Waxy crude oil production in the South China Sea  

SciTech Connect (OSTI)

The Phillips Petroleum International Corporation Asia (PPICA) Xijiang Field Development Project is a unique project resulting in the production of a waxy crude oil. The crude oil is produced on two platforms feeding a final production unit located on an FPSO (Floating Production, Storage and Off-loading) vessel located between the platforms. The crude from these two fields contains a high concentration of wax and has a relatively high pour point temperature. The crude composition and oil properties are listed in two tables. Special consideration was needed with respect to operating temperatures, start-up and shutdown procedures.

Low, W.R.; Gerber, E.J.; Simek, L.A.

1996-12-31T23:59:59.000Z

463

CONGRESS BLASTS OIL INDUSTRY  

Science Journals Connector (OSTI)

IN PACKED HEARINGS last week before angry members of Congress, the heads of BP, ExxonMobil, Chevron, ConocoPhillips, and Shell Oil defended their industry in light of the April 20 BP oil rig explosion in the Gulf of Mexico, which has led to the worst ...

JEFF JOHNSON

2010-06-21T23:59:59.000Z

464

Oil Quantity : The histori  

E-Print Network [OSTI]

model for Prudhoe Bay. Figure 11: Historical Prudhoe Bay oil production data, modeled economically Production (million bbl per Month) Historical Production Best Fit (Hist. Tax w/ELF, Ref. P) High Price 120 140 160 19 Oil Quantity Con Wel N E A N N ng Results e Bay : The histori Bay over tim : Prudhoe Ba

Lin, C.-Y. Cynthia

465

The Geopolitics of Oil  

Science Journals Connector (OSTI)

...reduce their production by a similar...barrels ofoil a day. Although the...barrels of oil per day. It is likely...Virtually all the OPEC producers, particularly...their oil. In 1973, 90 percent...increase indigenous production, and ac-celerate...

1980-12-19T23:59:59.000Z

466

Balancing oil and environment... responsibly.  

SciTech Connect (OSTI)

Balancing Oil and Environment…Responsibly As the price of oil continues to skyrocket and global oil production nears the brink, pursuing unconventional oil supplies, such as oil shale, oil sands, heavy oils, and oils from biomass and coal has become increasingly attractive. Of particular significance to the American way is that our continent has significant quantities of these resources. Tapping into these new resources, however, requires cutting-edge technologies for identification, production, processing and environmental management. This job needs a super hero or two for a job of this size and proportion…

Weimer, Walter C.; Teske, Lisa

2007-01-25T23:59:59.000Z

467

Essays on Macroeconomics and Oil  

E-Print Network [OSTI]

Oil Production in Venezuela and Mexico . . . . . . . . . .and Productivity in Venezuela and Mexico . . . . . . . . OilEllner, ”Organized Labor in Venezuela 1958-1991: Behavior

CAKIR, NIDA

2013-01-01T23:59:59.000Z

468

Chinaâs Oil Diplomacy with Russia.  

E-Print Network [OSTI]

??In Chinaâs view, it is necessary to get crude oil and oil pipeline. Under Russia and China strategic partnership, China tries to obtain âlong term… (more)

Chao, Jiun-chuan

2011-01-01T23:59:59.000Z

469

Peak oil: diverging discursive pipelines.  

E-Print Network [OSTI]

??Peak oil is the claimed moment in time when global oil production reaches its maximum rate and henceforth forever declines. It is highly controversial as… (more)

Doctor, Jeff

2012-01-01T23:59:59.000Z

470

oil | OpenEI  

Open Energy Info (EERE)

oil oil Dataset Summary Description This dataset comes from the Energy Information Administration (EIA), and is part of the 2011 Annual Energy Outlook Report (AEO2011). This dataset is table 134, and contains only the reference case. The data is broken down into Crude oil, dry natural gas. Source EIA Date Released April 26th, 2011 (3 years ago) Date Updated Unknown Keywords 2011 AEO EIA end-of-year reserves gas oil Data application/vnd.ms-excel icon AEO2011: Oil and Gas End-of-Year Reserves and Annual Reserve Additions- Reference Case (xls, 58.4 KiB) Quality Metrics Level of Review Peer Reviewed Comment Temporal and Spatial Coverage Frequency Annually Time Period 2008-2035 License License Open Data Commons Public Domain Dedication and Licence (PDDL) Comment Rate this dataset

471

Chapter 5 - Crude Oil  

Science Journals Connector (OSTI)

Abstract Oil has been the number one source of energy in the world since the middle of the twentieth century. The world is very dependent on petroleum for transportation fuels, petrochemicals and asphalt. But ever increasing demand has caused the price of oil to spike in recent years, and only the world economic crisis has been able to temper demand and bring the price down to more reasonable levels. However, the demand and price are likely to shoot up again when the economy recovers. At the same time, the peak oil theory of M. King Hubbert predicts that world oil production is likely to peak soon. This prediction raises questions about what source of energy will come to the fore when oil is not able to keep up.

Brian F. Towler

2014-01-01T23:59:59.000Z

472

NETL: Oil & Natural Gas Projects: Alaska North Slope Oil and Gas  

Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

Alaska North Slope Oil and Gas Transportation Support System Last Reviewed 12/23/2013 Alaska North Slope Oil and Gas Transportation Support System Last Reviewed 12/23/2013 DE-FE0001240 Goal The primary objectives of this project are to develop analysis and management tools related to Arctic transportation networks (e.g., ice and snow road networks) that are critical to North Slope, Alaska oil and gas development. Performers Geo-Watersheds Scientific, Fairbanks, AK 99708 University of Alaska Fairbanks, Fairbanks, AK 99775 Idaho National Laboratory, Idaho Falls, ID 83415 Background Oil and gas development on the North Slope is critical for maintaining U