bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Basin-Scale Shared Earth Model for Prospecting to Drilling and Beyond
Authors: Vittachi A. , Jones S. , McKenna K. 
Published: December 2007

ABSTRACT
Recent developments in software are beginning to deliver the use of a single "toolkit" to store, visualize and synthesize geological, geophysical and engineering data – allowing, for the first time, the creation of "true" multidisciplinary Shared Earth Models (SEM).
There have been several hurdles to creating these models in the past: First, scale difference – pore scale for a petrophysicist, well scale for the driller, reservoir scale for the RE, and prospect or regional scale for the geoscientist have hindered tighter integration. Second, the wider E&P communities have viewed integration only in terms of their own team foci – partly due to the difficulty of amalgamating domain specific data – the geophysicist's preferred domain being time, a driller's being depth, and a reservoir engineer's being temporal and spatial data. Third, we have limited integration to a subset of the E&P community with, for example, economic models not being an integral component of SEM. As a result, mistakes have commonly been made at interfaces between disciplines as one group hands off its output to another.
Using a 3D modeling software platform, a SEM of the Columbus Basin in offshore Trinidad was constructed. Scalability is a key component of the SEM – with support for individual prospects or regional scale. The relational framework facilitates an environment that can rapidly make computations across scales, allowing, for example, a casing design to be generated taking a reservoir scale model and translating it to the well scale. With the advent of 4D data handling, basin evolution, migration of fluids, pressure and other time variant properties are integrated into the SEM. This flexibility allows fluid migration studies to be better linked with prospecting.
Creating a unified and scalable model promoted wider ownership and engagement – going beyond the geoscience and reservoir disciplines to engage the drilling, facility, economic and strategy communities. The SEM environment facilitated better cross-functional inferences to be made – with economic models being directly linked to the earth description and associated uncertainties.
New One-Trip Completion Technology for Sand Control Applications
Authors: Garfield G. 
Published: December 2007

Abstract
This paper will discuss a new technology that installs perforated casing and sand control in a single trip. The system incorporates telescoping perforations containing sand control media into ordinary API casing, run into the hole on standard liner hanger equipment. Applications for this technology include both producers and injectors, particularly those needing zonal isolation.
The key aspects of this technology, particularly the sand control media, sealing wax/polymer, and flow-actuated landing collar, will be discussed in great detail. Critical laboratory testing will also be reviewed, as well as installation procedures and cost analysis.

Application
The information presented in this paper is applicable to production and injection wells in sand producing formations.

Results, observations and conclusions
A new completion technology has been developed that eliminates the need for perforating and for pumping sand control media. A one-trip sand control completion method that has zonal isolation capability has been developed.

Significance of subject matter
New one-trip sand control completion technology offers a large potential for significant capital expenditure savings.
The Conceptual Design of a Non-Invasive Solids Free Drill-in Fluid
Authors: Martins A. L. , Waldmann A. T. A. , Ribeiro D. C. , Massarani G. 
Published: December 2007

Abstract
Designing drill in fluids which can guarantee minimum invasion into the reservoir rock is a must for open hole completion wells. The industry has proposed several ideas to deal with the problem, most of them based on adding bridging agents to the fluid formulation. Such agents would block pores near the well bore and, consequently, prevent additional fluid to invade the rock, but often require acid treatment for their removal.
A different concept is proposed for controlling invasion in this article: designing a polymer based fluid which would generate extremely high friction losses when flowing through a porous media without generating extra losses while flowing in the well. In this case the fluid would present proper flow and solids transport properties in the well and would not invade the rock formation.
Experimental results obtained with the flow of different polymer solutions through consolidated inert porous media show that the viscoelastic behavior of fluids can be a major restriction to fluid invasion. Based on a viscoelastic resistive force proposition for the porous media, flow characterizarion maps defining viscous flow, elastic flow and viscoelastic flow regions are obtained
This article deals with the optimization of the drilling fluid viscoelastic parameters, such as the first normal stress difference and the extensional viscosity, aimining the minimization of fluid invasion through oil reservoirs. The arrival of this rheology controlled invasion concept brings to the polymer manufacturers a new challenge: the development of a highly viscoelastic polymer with non damaging behavior and adequate wellbore properties.
M-6 Steam Drive Project. Preliminary Results of a Large Scale Field Test
Authors: Van Der Knapp Willem 
Published: December 2007

RESUMEThe M-6 steam drive is being carried out in a fully depleted, heavy oil reservoir of the Tia Juana field, Bolivar Coast, Venezuela. The test comprises 151 wells of which 19 are injectors forming a semi-open hexagonal injection pattern.Prior to full scale injection at the start of 1978, three pilot hexagons were advanced, one in November 1975 and two in July and August 1976. Performance data of these hexagons and of the whole project over a period of 4 and 3-1/2 years, respectively, indicate that there is a remarkable uniformity in the behaviour of this steam drive if compared to a small scale test in the northern part of the giant oil field carried out in 1961 at a distance of 12 km of the M-6 project.The present test, though on a commercial scale, is still considered of an exploratory nature and meant to advance the existing knowledge in thermal recovery. For that reason a large amount of data have been assembled on steam generation and distribution, fuel consumption, petrophysical and geological studies, tracer tests etc. In evaluating the performance use is made of empirical, analytical and numerical models. Partial studies, carried out in the context of the project, merit special contributions to conferences like the SPE one. The purpose of this paper is to review the activities two interdisciplinary project teams are carrying out.
A New Technique for Obtaining Pressure Buildup Data in Oilwells
Authors: Kabir C. Shahjahan , Hasan Abu R. 
Published: December 2007

ABSTRACT
A mathematical model has been developed on the principle of mass balance of the gas component for an oilwell (pumping or flowing) which enables one to calculate the annular gas volume, including gas bubbles in the oil column. The knowledge of annular gas volume at a given instant of time can then be used to find the pseudo length of both oil and gas columns and hence the bottomhole pressures. This technique can be used to obtain pressure buildup data. In addition the flowing bottomhole pressure prior to the shut-in can be determined in the same manner to allow calculation of productivity index (PI) and to evaluate pumping well performance.
The proposed method has distinct advantage over the conventional acoustic well sounder (AWS) technique which measures the actual gas-liquid interface in the annulus. Experience has proven that the AWS technique becomes inconsistent and difficult to interpret, particularly when the oil has foaming tendencies. The AWS method requires knowledge of the gas-cut oil column gradient (estimated by an empirical correlation) when the flowing bottomhole pressure is below the saturation pressure. The advantages of the new method over the use of bottomhole recorders in a pumping oilwell is the cost saving (pump and rods need not be pulled), flexibility of data gathering and the obtaining early tine data (e.g. pws @ Δt = 0 for type curve analysis).
A field test has been conducted using high resolution pressure transducers to demonstrate the applicability and accuracy of the proposed method for a flowing oilwell.
Three-Dimensional Simulations of Uranium Leaching and Aquifer Renovation
Authors: Kossack Charles Ayres 
Published: December 2007

ABSTRACT
A multi-component, three-dimensional model was developed to simulate the fluid flow phenomena occurring during the in situ uranium leaching process and subsequent aquifer renovation. This fluid flow model uses knowledge of the total dissolved solids (TDS) history of the pregnant solution. The model history matches TDS trends of the plant and in doing so calculates the TDS concentration buildup in the pattern and ion excursions into the formation. Specialized subroutines are described which account for the operation of a surface plant (its effect on reinjected leachant solution) and transverse dispersion of ions.
The advantages of studying the fluid flow with a three-dimensional reservoir simulator is demonstrated by two case studies. The first application shows the effect on leaching and aquifer renovation when the completion intervals of the injectors and producers do not match. The second application-describes the effect transverse dispersion has on the buildup of TDS in a low permeability layer adjacent to a high permeability layer. A novel process is suggested to rapidly cleanup this contaminated low permeability layer during aquifer
New Mexico’s First Uranium in Situ Solution Extraction Project
Authors: Coleman K. A. , Stewart G. W. 
Published: December 2007

ABSTRACT
The New Mexico Environmental Improvement Division (NMEID) licensed New Mexico’s first in situ uranium solution extraction project, a pilot test, on December 26, 1978· The license was issued based on environmental data submitted by Mobil Oil Corporation, supple-mental information requested by NMEID, and independent calculations by NMEID.The pilot test is located in the southwestern quadrant of Section 9, Township 17 North, Range 13 West, McKinley County, New Mexico, within the Mobil Crownpoint project area.
The Crownpoint project area is distinct from existing commercial scale in situ projects in that the ore bodies are nearly 2,000 feet deep, three to four times the depth of ore bodies in Texas, and the permeability is lower. An extensive pilot test program of three years was planned for Mobil to determine the technical feasibility, environmental impact and economics of in situ solution extraction in the Crownpoint area prior to expansion into commercial production.
Mobil is maximizing environmental protection by the utilization of precautionary controls. To minimize any irreversible insult to the groundwater only a small portion of the aquifer is leached at any one time. Monitor wells are used for early detection of any potential horizontal and vertical leachate excursion. In the event of an excursion, production in the affected area would be increased relative to injection until the water quality is restored. Waste by-products will be stored in plastic lined ponds until the solids are permanently disposed at a licensed facility. Baseline data obtained during Mobil’s preoperational mon-itoring program will provide a comparison with the data from the operational monitoring program to aid in the development of restoration criteria. As leaching operations in one part of the ore body are completed the leach zone will be flushed with water purified.by reverse osmosis or electrodialysis as appropriate to facilitate on-going staged reclamation.
Preliminary data indicates the overall effective-ness of environmental controls employed in the operation. As New Mexico’s first uranium in situ solution extraction project, this information will provide the basis for the licensing and regulation of future in situ solution extraction development within the State.
The Relationship Between Ion Exchange Resin Properties and Uranium Recovery in Fluidized Bed Columns
Authors: Boyce Thomas D. 
Published: December 2007

ABSTRACT
The use of ion exchange resins for the concentration and recovery of uranium from low grade solutions is a recognized process which has been practiced for many years. The method of application has generally been downflow through fixed beds. Such a system resembles a water filter and consequently any suspended matter in the feed will be filtered out resulting in high pressure drops, channeling, inefficient operation, etc.
Many uranium ores produce very fine particles or slimes which are difficult and costly to separate from the leach liquor. Attention has been given to methods that would minimize or eliminate the need for solution clarification and thus obviate the considerable capital and operating expense involved in clarification.
The most recent method developed for recovery of uranium from unclarified solutions is the use of fluidized bed contactors. In a fluidized bed contactor, the feed solution is passed upflow expanding the resin into a fluidized state. The moving and fluidized particles create a "choke" effect upon the rising liquid and a steady state turbulence is achieved.
Thermal Alterations of Asphaltenes in Peace River Tars
Authors: Waxman M. H. , Deeds C. T. , Closmann P. J. 
Published: December 2007

ABSTRACT
In 1973-74 Shell Canada Limited and Shell Explorer Limited conducted a steam injectivity and productivity test in the Peace River Bullhead sand.1 The test comprised several phases. Cold production was started on September 12, 1973. Steam injection into the same well commenced on November 29, 1973 and ended on February 6, 1974. After a 54-day soak period, backflow began on April 1, 1974 and ended on October 1, 1974. A total of 122,000 barrels of steam were injected at rates as high as 2366 B/D at less than fracturing pressure. After 175 days of back-flowing, approximately 29,900 barrels of tar were produced at an oil/steam ratio of 0.23. Temperatures as high as 311°C (591°F) were observed in the formation. On the basis of results from this test, an expanded pilot has been proposed for Peace River.2,3
In support of the above effort, laboratory work was undertaken in order to obtain mobility data for Peace River tar in its parent core material at temperatures and stress conditions simulating reservoir zones downstream of a steam condensation front. Because of possible effects on flow properties, the asphaltene and maltene components of produced tars were examined. Both the quantity and degree of thermal alteration of the asphaltenes were considered, in order to assess the influence of these factors on observed flow behavior. Based on information learned in these studies, a series of flow experiments was undertaken and will be reported in our following paper.4
Mineral-free tar was obtained from Peace River core material by means of separation procedures which minimized compositional changes of the native tar. Experimental extraction procedures and resulting tar properties for Batches 1, 2, and 5 are described in Reference 4. The maximum temperature to which these extracted tars were exposed was 70°C (158°F).
Peace River Tar Flow Experiments Under in Situ Conditions
Authors: Waxman M. H. , Closmann P. J. , Deeds C. T. 
Published: December 2007

ABSTRACT
In a preceding paper1 we described some chemical properties of Peace River tars, i.e., solvation properties of asphaltenes and their reflection of the thermal history of the tar in the reservoir. It was suggested that the thermal alteration observed in tar samples produced during the Shell 1973-74 field test at Peace River could lead to important changes in the flow properties of the tar relative to its initial unaltered state.
With the above factors in mind, we have performed a series of flow experiments with Peace River cores preserved as nearly as possible in their natural state. The conditions chosen were such as to simulate the hot zone present in the Bullhead Sand reservoir during the 1973-74 field test.
All flow runs were made at temperatures of 380 – 389°F (193-198°C). The sand plugs were subjected to an isostatic effective stress of~ 1,100 psig (7,584 kPa), with the overburden pressure held at~ 1,500 psig (10,342 kPa) and the back pressure on the fluids at ~ 400 psig (2,758 kPa). This was intended to simulate original in-situ burial conditions.
The Search for Oil and Gas in Mexico
Authors: Baptista Cesar O. 
Published: December 2007

Abstract
I would like to thank the organizing committee of this simposium, in particular to Mr. Phil Schultz, for inviting me to participate in this event, thus giving me the opportunity and the privilege to address such a prominent audience.
I am sure that the subjects discussed here will be of special importance, mainly for those that, like myself, work in the oil industry. May the best success crown the endeavor of all and each one of you.
Throughout a large portion of the world, the evolution of society during the last one hundred and fifty years has been truly impressive. The dramatic improvement of the standard of living that has favored large human conglomerates has been of such an extent, that it has no precedent within the history of humankind.
Internal Audit of Oil and Gas Reserves
Authors: May Alan , O'Neill Donald B. 
Published: December 2007

ABSTRACT
There is general consensus in the oil and gas industry that estimating reserves, both quantities and the associated values, is an imprecise science. Nevertheless, in the past two or three years, the reserve estimate has become a very important component of public reporting in the industry; and those that disclose or rely on reserve information (officers, directors, underwriters, lenders) have a responsibility to determine the estimates have been appropriately determined. This change in emphasis is not only due to the Securities and Exchange Commission rules regarding audited reserve information (now postponed) but is also caused by changing economics in the petroleum industry with crude prices and finding costs both rising rapidly. Thus, it is incumbent upon all oil and gas companies to place a higher priority on internal controls over, and internal audit coverage of, the reserve estimation process.
This document, INTERNAL AUDIT OF OIL AND GAS RESERVES should assist companies in their review of controls over the reserve estimation process and suggests an approach that internal auditors may wish to consider when auditing the functioning of such controls.
The approach described in this document involves a review of existing information rather than a full redetermination of reserves. By following the procedures outlined, the internal auditor can assess whether the work was based on proper assumptions, accurately documented and carefully performed by qualified persons under the direction of unbiased supervisors. The cost of this approach is much lower (usually no more than 10%) compared to a complete redetermination by an outside party.
The suggested audit plan requires first that an understanding be gained of the environment in which reserves are estimated. This includes the company's organization, qualifications of estimators, review procedures and other standardized approaches for reporting exceptions and monitoring of property operations. Second this understanding is confirmed through discussions with appropriate personnel, review of internal reports and, where necessary, field locations visits. Finally, based on this understanding and the confirmation thereof, the internal auditor selects a number of properties to be reviewed in detail. The sample should be representative (chiefly large but some small properties) and should comprise a majority of the Company's reserves but only a relatively small percentage of the properties. By following the detailed procedures outlined in the approach, the auditor should, if no exceptions in his test procedures are noted, be persuaded that the reserve information has been reasonably determined.
Work Commitment Bidding as a Method of Subsidizing Development of Federally Owned Energy Resources
Authors: Said Mark C. 
Published: December 2007

ABSTRACT
Work commitment bidding is available for mineral leasing on the Outer Continental Shelf, and has been considered for leasing the National Petroleum Reserve in Alaska. This leasing system isan imprecise method of subsidizing domestic energy development. While certain non-market benefits arguably exist to warrant a subsidy on domestic production or a tariff on imports, work commitment bidding does not appear preferable to methods which raise the price received by domestic producers. Significant administrative problems also complicate any proposed use of work commitment bidding. Use of a fixed minimum work commitment offers a theoretically possible way of counteracting risk-averse behavior in high-cost exploration areas. But for such a system to work, the government must be able to adequately predict the exploration behavior of a risk-neutral firm on the tract. Areas of further study are suggested.
The Impact of Taxes on Exploration Economics in USA
Authors: Neal Randall L. , Reed Margaret E. 
Published: December 2007

ABSTRACT
This paper discusses the impact of taxes at the state and federal level on typical on-shore oil and gas exploration economics in the USA. Taxes considered are the windfall profits excise tax, state production (or severance) taxes, state income tax, and federal income tax. Also considered will be market prices for oil and gas in the USA. The effect of government take as a percent of revenue, on rate of return, discounted payout, and discounted cumulative cash flow is shown on the attached tables.
The conclusion drawn is that tax laws, while rarely the most important factor to be considered when drilling a well, can have significant impact on the profitability of oil and gas ventures, and should be considered when determining where to drill. Hypothetical exploration wells were analyzed for the impact of tax laws on project profitability. The results of this study show that when factors other than taxes are postulated to be the same (such as producing rate, capital, operating costs, and prices), cash flow can vary by as much as 68% due to the differences in the tax laws. Other significant findings for the cases studied include: (a) that discounted payout varied by as much as 1.8 years, (b) that rate of return differed by up to 67% and (c) the total tax rate as a percentage of revenue had a maximum variance of 33%.
Drilling Cost Escalation in the Gulf of Mexico
Authors: Friesen George W. 
Published: December 2007

ABSTRACT
This paper presents the historical trend and defines the causes of drilling cost escalation in the Gulf of Mexico during the 1970's.
The three major components of escalation are: 1) inflation, 2) supply-demand imbalance (demand pull) and 3) decreases in drilling efficiency. The decade was divided into three periods. During each period one component of escalation was responsible for most of the rise in costs. From 1970 through 1973 only inflation pushed costs upward. During 1974 and 1975 a supply-demand imbalance caused most of the escalation. Since 1975, decreases in drilling efficiency have produced the major component of escalation. During any one year or period of years, the sum of the three components will give the total escalation rate. The reasons why different components contribute more toward escalation during certain years than others are shown by following the timing of oil and gas price increases, the overall quality of the acreage offered each year in offshore lease sales and the resulting drilling activity.