bluuebunny/crossref_metadata_2025_split huggingface dataset:
Impacts of Environmental Regulations on Future Resource Development in Louisiana Wetlands
Authors: Harder Brian , John Chacko , Dupont Allen 
Published: December 2007

Abstract
Louisiana wetlands require careful management to allow exploitation of non-renewable resources without destroying renewable resources. Current regulatory requirements have been moderately successful in meeting this goal by restricting development in wetland habitats. Continuing public emphasis on reducing environmental impacts of resource development is causing regulators to reassess their regulations and operators to rethink their compliance strategies. In addition regulators need forecasts of future E&P trends to estimate the impact of future regulations. To determine future activity we created two econometric models of North and South Louisiana relating drilling activity, success ratio, and price to future wetland drilling locations. Results of the models indicate that environmental regulations have a small but statistically significant effect on drilling operations in wetland areas.
Operators want cost effective means of access that will reduce environmental impacts, decrease permitting time, and limit future liability. We examined the regulatory system and found that reducing the number of applications required by going to a single application process and having a coherent map of the steps required for operations in wetland areas would reduce regulatory burdens. Incremental changes can be made to regulations to allow one agency to be the lead for wetland permitting at minimal cost to operators.
In the interim, careful planning to account for environmental impacts in all stages of the exploration process can reduce environmental costs for operators. Operator emphasis should be on avoidance rather than mitigation. Alternative methods of access to avoid impacts exist but at present they are not cost effective for all locations. Future technological innovations such as waste minimization strategies, 3-D seismic and coiled tubing will lead to reduced environmental impacts and costs for operators.
A Three-Phase Centrifuge to Minimize Waste from Production Tank Bottoms and Sludges: An Economic Analysis
Authors: Polston C. E. , Bretz R. E. , Parkinson W. J. , Graham A. L. , Steele R. D. 
Published: December 2007

Abstract
The performance of a three-phase centrifuge process in separating tank bottoms into salable oil, brine and solids was scaled using the sigma method. The profitability was analyzed for a range of processed volumes for three business scenarios: producer owned, service company and a disposal facility. Centrifuge processes operated at full capacity in these situations may be very profitable investments but any investment decision should be heavily influenced by the annual volume to be processed, the quality of the feed and the price received for separated oil.
Evaluation of A Bacterial Bioluminescence Bioassay as A Predictive Surrogate for Mysid Chronic Estimator Tests with Produced Water
Authors: Korenaga G. L. , Stine E. R. , Henry L. R. , Grimsley J. R. , Daniel D. L. 
Published: December 2007

Abstract
Toxicity limits are appearing more frequently in permits for produced water discharges. A bioluminescent bacteria bioassay has been proposed as a screening tool to predict toxicity in higher organisms, which are more expensive and require longer testing times. Before such a surrogate screen can be used, a correlation must be demonstrated between toxicity in the surrogate and the species of interest.
This paper describes tests comparing produced water toxicity in the biolumnescent bacteria test and in the mysid shrimp chronic estimator test, which is frequently required in Gulf of Mexico discharge permits. Under these test conditions, the bacteria test was not adequately predictive of produced water chronic toxicity to the mysid shrimp.
Implementation and Operation of an Active Permeable-Barrier Trench System for the Containment of Groundwater Contamination
Authors: Ratliff M. 
Published: December 2007

Abstract
This paper is a case study of the implementation and operation of an active permeable barrier-trench system beneath an oilfield service facility in eastern New Mexico. The system was designed to prevent the migration of petroleum hydrocarbon contaminants into the groundwater. Gasoline-range contaminants were discovered during the removal of underground fuel storage tanks at the site.
The active permeable barrier trench system was installed in 1992 and consists of two trenches, which are 128 and 132 ft long and approximately 15 ft deep. Trenches extend approximately 3 ft below the surface of the water table and were installed in three phases. Each trench was lined with a water-permeable geotextile fabric barrier, which was used to keep silt from permeating into the trench, but still allowed water to freely flow through the fabric. Each trench was then filled with 8 vertical feet of 2-in. gravel to increase porosity and permeability within the furrow. The remaining 6 ft of trench was filled with soil and the entire area was capped with asphalt.
Each trench was fitted with an air transmission system, at a depth of 14 ft below grade, to bubble air into the passing groundwater. Air was supplied by a blower at the surface to strip volatile contaminants from the water column and increase the dissolved oxygen content of the groundwater to promote microbial activity. Nutrient feed pipes were set in the trenches at a depth of 12 ft below grade. The feed pipes were used to inject nutrients into the groundwater to promote microbial growth and increase hydrocarbon degradation. Vapor extraction lines were installed at a depth of 8 ft below grade to remove any volatilized hydrocarbons. The vapor extraction system was connected to a passive ventilation system at the surface. The system has been in operation for approximately 2 years with good results.
Geological Model Of The Jurassic Section In The State Of Kuwait
Authors: Yousif Samir , Nouman Ghalib 
Published: December 2007

Samir Yousif and Ghalib Nouman

Abstract
Until the end of the seventies, the knowledge of the Jurassic Geology in the State of Kuwait was very limited, since only one deep well was drilled and bottomed in the Triassic sediments. Few scattered wells partially penetrated the Jurassic sequence.
During the eighties, appreciable number of wells were drilled through the Jurassic, and added a remarkable volume of information. Consequently it was necessary to analyse the new data, in order to try to construct a Geological model for the Jurassic in the State of Kuwait.
This paper includes a number of isopach maps explaining the Jurassic depositional basin which also helps in trying to explain the Jurassic basin in the Arabian Gulf basin. Structural evolution of the Jurassic sequence indicated an inversion of relief when compared with the Cretaceous sequence. In fact, the main Cretaceous arches were sites of sedimentation troughs during the Jurassic period.
This fact marks a revolution in the concepts for the Jurassic oil exploration. One of the very effective methods of the definition of the Jurassic structures is the isopaching of the Gotnia Formation. Najmah, Sargelu and Marrat Formations include the main Jurassic reservoirs which were detected as a result of the exploration activities during the eighties.
Selective stratigraphic and structural cross sections have been prepared to demonstrate and explain the nature of the Jurassic sediments.

Introduction
Since the discovery of oil in the State of Kuwait up to 1975, all oil discoveries were related to Cretaceous and Tertiary reservoirs. Only three wells were drilled to test oil in the Jurassic Formations in Minagish, Sabriyah and Burgan areas. The results of testing these wells were negative.
After nationalization of the oil industry in Kuwait, a number of deep test wells had been drilled and oil was discovered in two reservoirs within the Jurassic section. Consequently, a development plan was set to develop these reservoirs in Minagish, Magwa, Burgan, Umm-Gudair, Abdulyiah and Dharif areas.
This study deals with the regional geology of the Jurassic section in the State of Kuwait, using relevant data from some selective well, which represent the geographical distribution within the main Kuwait area.
P. 231
The Use of the Rima Full Field Simulator as a Field Planning Tool
Authors: Meyer Heiko , Brouwer Gerrit , van Rossem Steven 
Published: December 2007

Heiko Meyer,* Gerrit Brouwer,* Steven van Rossem

Abstract
A full field simulation model is being used to plan future development activities in the Rima field. A development strategy has been defined for the field using this powerful tool as long term planning tool. Future development of the field will be by short horizonta/sub-horizontal infill and flank wells, A second version of this tool is used to optimize individual wells within the framework given by the long-term planning tool, The procedure to optimize new wells is described. Since future development activities will be close to existing wells, the quantification of accelerated production is crucial in the evaluation. Results show that–local kv/kh-ratio,–dip of top reservoir and–completion lengths of existing wells have the biggest impact on optimized horizontal well lengths.
An example of the Rima West flank development is given. Based on simulation results the original field development plan has been changed, leading to development wells with:–reduced drilling costs,–higher Ultimate Recovery (UR) per well and, therefore,–a more cost-effective field development.

Introduction
The Rima field has a STOIIP of 161 million m3. It is producing under a strong bottom water drive from the underlying Haima aquifer with a thickness of several hundred meters. It is expected to provide sufficient pressure support throughout the field's production lifetime.
Although 60% of the field's UR (30% of STOIIP) has been produced already, it is still one of the biggest oil producing fields in Oman with an average oil production of 14,000 m3/d at a 70% water cut from 83 producing wells. Twenty of those wells were drilled as horizontal producers mainly in the flanks of the field and in some crestal areas. 9 of these wells have been drilled in locations with nearby vertical producers. For these wells the exact positioning is crucial to their success. 90% of the remaining 70 well locations are in similar 'tight locations'.

GEOLOGICAL SETTING
The Rima field is located towards the Northern end of the Eastern flank of the South Oman Salt Basin in the concession area of Petroleum Development Oman (fig. 1, see also fig.1 of SPE 29812).
P. 211
The Application Experience of Electrical Submersible Pump (ESP) in Offshore Oilfields, Bohai Bay, China
Authors: Li Kuiyuan 
Published: December 2007

Li Kuiyuan

Abstract
The electrical submersible pump (ESP) was introduced for producing oil in Bohai Bay oilfields of China in wells and they are mainly used in Chengbei Oilfield, SZ36 - 1 Oilfield and BZ428 - West Oilfield, etc. Since then, some experiences have been accumulated. In this paper, ESP well completion, matched running parameters with the productivity of the well, performance diagnosis, extending the running life of ESP unit and preparation of the standby ESP units are discussed.

Introduction
There are six gas & oilfields which have been developed in Bohai Bay area, China. Among which Chengbei Oilfield, SZ36 – 1 Oilfield, BZ428 -West Oilfield have entered the stage of artificial lift development. Widely used technology of artificial lift has become the major technical means for increasing and stabilizing the production. There are mainly three ways of artificial lift applied in offshore oilfields. Namely, they are electrical submersible pump (ESP), jet pump and progressive cavity pump (pcp). Of which ESP is the most widely used and makes up more than 70% of the total artificial lift wells.
Since 1986, the ESP was introduced in Bohai offshore oilfields, good development results and economic benefits have been achieved. And a complete series of technology, such as, unit quality inspection, the design and selection of downhole pump and well, ESP workover, performance diagnosis, pressure surveys of ESP well, downhole safety control production management and repairing of ESP unit, etc. have taken shape. For the time being, ESP wells make up more than 40.7% of the total production wells in Bohai offshore oilfields. The service life of ESP unit prolongs to 556 days comparing with initial 100 days. The longest service life has reached more than 1000 days.
P. 627
Completion Damage and Analysis of Related Factors of the Carboniferous Gas Reservoirs in the East Sichuan Basin
Authors: Chen Liping , Dong Mingsu , Ran Hong , Chen Jun 
Published: December 2007

Chen Liping, Dong Mingsu, Ran Hong, Chen Jun

Abstract
The analysis methods of completion damage of gas wells are presented in this paper by making use of transient testing and gas productivity index. we studied the impact of percolation capability, formation pressure, pressure coefficient, over-balanced pressure, and soak time on the completion damage. Meanwhile, we also researched completion damage of different reservoirs with high, medium or low permeability and gas deliverability.

Introduction
Petroleum geologists, drilling engineers and reservoir engineers all over the world have paid a lot of attention to reservoir protection. During the 7th five-year program in our country, drilling technology in protecting reservoir became key national project. In the process of studying the subject "drilling and completing technology in protecting gas well of carbonate reservoirs, Sichuan" sponsored by SPA*, transient testing technology was applied to analyze gas well impairment. That is, we succeeded in using "GDT" well test software to study and evaluate formation damage, and quantitatively forecast acidizing effectiveness.
However, it is difficult to obtain the steady data of pressure buildup after completion, owing to engineering, economic and other reasons. So it is necessary to develop new approaches to research and evaluate formation damage.
Based on the above situation, according to the test data after completion and treatment, we also succeeded in calculating and evaluating formation damage by making use of gas productivity index.

FEATURES OF THE UPPER CARBONIFEROUS GAS RESERVOIRS
The Upper carboniferous gas reservoirs in the Huanglong Formation (C2hl) are the major production formation in the East Sichuan, and even Sichuan. The discovered reserves account for 75 percent in East Sichuan, and 40 percent of Sichuan. Their major geologic features are as follows:

Geologic features
The Huanglong Formation overlapped on the mid-Silurian, and was eroded on the top Its depositional environment was limited sea, shoal evaporite sea platform algal flat facies. Reservoirs are exposed shoal tidal that algal dolomite and brecciated dolomite. The effective thickness is from 10.0m to 15.0, average porosity from 0.04 to 0.07, matrix permeability less than 1.0x10-3 m2. Voids are the main reservoir space, and structure fissures are the chief permeable channels. Zones full of fissures are of high H*phi values, which have substantial gas delivery capabilities. C2hl reservoirs are defined as fissure-void ones. Formation pressures being non-abnormal, fringe water being inactive, C2hl reservoirs can be assumed as isochoric ones.
P. 567
Utilizing Risk Tolerance to Optimize Working Interest
Authors: MacKay James A. 
Published: December 2007

SUMMARY
This Paper discusses a personal computer (PC) model that uses utility theory to calculate the Risk Adjusted Value (RAV) by combining the components of the Expected Value (EV) calculation with an assessment of the decision maker's Risk Tolerance (RT). The RT can be calculated from prior working interest decisions or approximated using company average RT. The RAV is always equal to or less than the EV for risk averse corporations. The RAV for risky ventures may be higher at less than 100% working interest (Wl), indicating the optimum Wl is less than 100%.
The distributions of RAV's for a venture or portfolio of ventures are calculated by varying the Wl at discrete intervals and recalculating the RAV or using the Solver (linear program add in) included with most spreadsheet software. The Solver can be further constrained to model a limited capital budget and then used as a portfolio optimizer. Uncertainty in any of the parameters can be accommodated using a Monte Carlo add in.
The Economic Impact of Strategic Risk on Petroleum Ventures: Examples from West Africa
Authors: Ethetton L. K. , Brumbaugh W. D. 
Published: December 2007

Abstract
Strategic risks attend any and all business ventures. They arise from the nature of the particular business being pursued and the environment in which that business is being conducted. In the petroleum industry, considerable attention is devoted to quantifying technical risks, i.e., the risk of finding and producing hydrocarbons. However, strategic risks often impact economic viability more than technical risks. Accordingly, strategic risk analysis is critical to realistically evaluating petroleum ventures in today's turbulent business environment. While difficult to assess and quantify, strategic risks must be accorded equal status with technical risks. Competitor activity, contract terms, environmental sensitivity, political stability and market forces are typical strategic risks.
A strategic risk system correlates a company's capabilities with the quality of possible ventures. Internal strengths and weaknesses are thus matched against external opportunities and threats. This is known in the business literature as a SWOT analysis.
The degree of strategic risk is then proportional to the mismatch between the SWOT elements. Such a mismatch was not recognized during exploration of the West Africa Aptian Salt Basins play in the 1980s. Angola, Congo and Gabon all contain examples where failure to consider strategic risk ultimately resulted in "Gambler's Ruin".
Evidence and Results of Present Value Maximization for Oil and Gas Development Projects
Authors: Lohrenz J. , Bailey A. J. 
Published: December 2007

Abstract
In the business of developing oil and gas production, myriads of engineering decisions must be made all seeking to accrue net economic value, the more so the better. Those aggregated decisions and that goal ultimately lead to the expenditure of a development cost, ℘, to attain a peak production rate, q, from a recoverable reserve, Q. The hypothesis is that ℘, Q, and q should, therefore, reflect present value maximization. Here we characterize and find evidence of such optimal decision-making. In addition, empirical correlations amongst ℘, Q, and q show oil/gas development project economics of scale.
Ranking Exploration Opportunities - Some New Approaches
Authors: Moore C. R. K. , Tucker J. W. 
Published: December 2007

Abstract
Some new approaches to ranking exploration ventures are suggested. Risk capacity, reflecting the break-even odds of failure for any venture, provides a useful tool. The amount by which the perceived risk (chance factor) exceeds the inverse of risk capacity is a good measure of the quality of a venture. We define this dimensionless fraction Surplus Risk Factor (SRF) or, informally, Comfort. Expected value may be restated as the product of SRF and the present value of a discovery. Plotted against each other, these provide a useful basis for a value order plot.
Two other useful yardsticks are Exploration Cost Efficiency, the expected present value generated by a dollar of discounted exploration expenditure, and Predicted Finding Cost, based on the risk-weighted reserves.
Rationalizing Assets Through Trades (Win - Win or an Impossible Dream?)
Authors: Hickman T. Scott , Seanard Keith C. 
Published: December 2007

Abstract
In view of the asset concentration strategy being pursued in the US by major oil companies, trading producing interests appears to be an ideal approach. Interest in trading is at an all time high. Most easy trades have been done. New trade proposals are more complex and consequently are harder to accomplish. A major barrier to trades is the traditional competitive mind set of management. Trades will increase as attitudes evolve.
A Problem With Experts
Authors: Capen Edgar C. 
Published: December 2007

Abstract
In this litigation society, more and more professionals in the oil business may find themselves in court, either as a party to a lawsuit or as an expert witness empowered by the court to help clarify issues. Unfortunately, some of those who call themselves experts don't even come close. At least part of the problem comes from people with petroleum related degrees who also feel compelled to claim expertise in economics and probabilistic analysis. ’Tain't necessarily so. Thus in the courtroom we see hired guns who will come up with whatever principles their clients want to see espoused.
Production Effects of Fluid Loss in Fracturing High-Permeability Formations
Authors: Elbel J. L. , Navarrete R. C. , Poe B. D. 
Published: December 2007

ABSTRACT
When fracturing zones having high permeability there is concern of damage to the matrix due to deeply penetrating fluid leakoff along the fracture and/or due to materials in the fluid that minimize the amount of leakoff. Materials used to minimize leakoff also have the potential to damage the proppant pack conductivity.
Previous tests have shown that high shear rates at the tip of the fracture may prevent the formation of external filter cakes, increasing the magnitude of spurt losses in highly permeable formations. This paper provides laboratory data on materials used to control spurt loss of linear gels [HEC], viscoelastic surfactant fluid and crosslinked borate-guars in formations having up to 500 md permeability. The depth of penetration into the matrix and magnitude of the permeability reduction to the matrix and proppant conductivity is shown.
This data is then used in a finite fracture conductivity production simulator that includes simulation of fracture face damage. Simulations are made for various fluid-loss additives controlling leakoff with different fracturing fluids over a range of formation permeabilities as well as other reservoir conditions and production modes. The simulations show the production effects of limiting the fluid loss penetration at the expense of permeability reduction in the formation and the propped fracture.