bluuebunny/crossref_metadata_2025_split huggingface dataset:
Price Effects on Developmental Well Completions, Reserve Additions, and Oil Production in West Texas
Authors: Holtz M. H. , Beike D. K. 
Published: December 2007

ABSTRACT
Ninety-seven percent of the oil reserve additions in West Texas during the 1980's are attributable to development and redevelopment of existing reservoirs. This reserve growth occurred during a large fluctuation in deregulated oil prices. Therefore, the 1980's provide a time period in which models can be developed to determine the effects of deregulated oil prices on reserve growth and thus the oil supply from West Texas.
In 1981, price deregulation within the United States resulted in an oil market in which the West Texas oil supply became sensitive to world oil price. The economic factors controlling West Texas oil supply varied widely during the subsequent decade. Average annual oil price ranged from $10.40 to $33.80 (1982 $). Average well-drilling costs ranged from $29.12 to $74.40 (1982 $) per foot. At the same time, inflation ranged from 5 to 12 percent, while the annual average real prime interest rate ranged from 4.6 to 10.6 percent. These economic factors were the basis for investment decisions that resulted in 35,600 development well completions, 4,452 million stock-tankbarrels(MMSTB) of developmental reserve additions, and 4,689 MMSTB of oil production during the 1980's in West Texas.
During the 1980's, oil price controlled the number of development well completions, the amount of developmental reserve additions, and oil production in West Texas. The oil price increases of the early 1980's resulted in increased reserve additions after an initial time lag; that is, annual reserve additions declined for the first two years of the decade, and increased in 1983. The number of development wells completed and the amount of oil production also display a time lag. In contrast, drilling costs and drilling rig utilization rose immediately after this price increase. In the second half of the 1980's with the sharply decreasing price in 1986, an immediate and concomitant decline in rig utilization, development well completions, and reserve additions occurred. Between 1985 and 1986, annual reserve additions declined from 744 to 174 MMSTB (nearly 75 percent) before recovering to approximately 540 MMSTB in the latter part of the decade. Thus, there was a time lag in the response of oil supply parameters to price increases but not to sharp price decreases. This time lag is related to supply and demand mechanisms controlling a deregulated oil price. It also provides insight into the assessment of how future oil price variations will affect the West Texas oil supply.
An Approach to Assessing Risk in Coalbed Methane Prospect Evaluation
Authors: Vanorsdale C. R. 
Published: December 2007

ABSTRACT
The economic evaluation of drilling prospects requires assessing the degree of risk involved and its impact on reserve estimates. In developed areas, risk can be determined in a fairly straightforward manner. In remote wildcat areas, risk can almost never be adequately identified or quantified. Between these extremes lie complex reservoirs -- reservoirs so heterogeneous that each well drilled could exhibit production characteristics unlike those of its neighbors.
This paper illustrates the use of a risk assessment methodology in a case study of Fruitland coal prospects in the San Juan Basin of New Mexico. This approach could be applied to coalbed methane prospects or any unconventional or highly heterogeneous reservoir with appropriate modification. The utility of this approach is made apparent in a graphical analysis that relates reserves, rate of return and payout time for managerial or financial presentation. This graphical technique and the underlying risk assessment were used to aid a conservative management team in evaluating participation in a multi-well coalbed project.
Innovative Technologies Reduce Cost of Offshore Marginal Field Developments in Northwestern Europe
Authors: Giannesini J-F. , Champion D. , Badour D. 
Published: December 2007

ABSTRACT
This paper examines the characteristics of as yet undeveloped North Sea discoveries and shows that a significant number of fields will be able to benefit from the development of new production systems integrating, in particular, the advantages of horizontal drilling and multi-phase production. A detailed analysis of the northwestern Europe offshore discoveries shows that, by the end of this century and the beginning of the next one, North Sea operators will have to focus on increasingly small accumulations located in medium water depths and generally not too far from existing installations.
Those for which the distance to an existing or scheduled installation is less than about 15 km could be candidates for satellite development as it is now conceived. However, production from the discoveries located farther away than conventional tie-in distances will require new production systems to be used.
The different economic simulations described in this paper show that, for most of the fields considered, conventional development is not well suited because it is economically risky, even if new techniques such as horizontal drilling are used to bring about an appreciable improvement in their cost effectiveness.
New development methods will thus have to be created. For example, by combining a light floating support with a multi-phase pumping system and horizontal wells, the study case we have used shows that the technical cost of the oil can be reduced by 25%, while the internal rate of return can be multiplied fourfold compared to conventional development.
In the years to come, systems of this type will enable North Sea operators to considerably widen the fields of application of satellite development and thus make production from numerous fields that have been neglected in the past economically cost effective.
A Comparative Evaluation of Evolving Nigerian Petroleum Development Policies
Authors: Chukwu P. O. , Ikoku C. U. 
Published: December 2007

ABSTRACT
This paper examines how the desires of the Nigerian government as expressed in the Petroleum Development policies have acted as incentives or disincentives to further investment in oil field development in the face of uncertain economic environmental conditions and reserve sizes.
An economic analysis package was used in evaluating past and present fiscal and contractual policies. The Net Present Values (NPV) of large, medium and small hypothetic fields were computed for the principal environments of oil exploitation (onshore and offshore) in the Niger Delta. This was done for various policy combinations to determine the sensitivity of the policy based profitability to oil price, production cost, delay in field development and production, operating companies share of profit and discount rates. The results were analysed and the attractiveness of policy packages to new investors were compared and ranked.
It concludes that Government policies have evolved to diminish the profitability of investors from oil exploitation. The present policies would require incentives to attract new investors unless production costs are reduced, oil prices rise and medium to large fields are the most likely to be discovered. New entrants that have to "carry" government operate under the worst policies are not likely to be attracted under existing situations.
The Option between Exploration or Reserve Purchasing: The Argentine Case
Authors: Fidalgo S. J. 
Published: December 2007

ABSTRACT
An oil company that wants to increase its reserves has a first decision to make: the way to do it. Is it better to invest in exploration than to acquire reserves that have been already proved by rival companies? The market has been inclined to both options alternatively.
The 80's found the companies with a high cash flow as a consequence of the oil shocks that characterized the previous years. That circumstance as much as the expectations of a lower increase in prices in the medium range, favoured the purchases of reserves. Now, the situation seems to be reverted. This paper tries to find out what are the determinants that make an enterprise decide whether purchasing or exploring is better.
A good oportunity to analize these variables is given by the facts in which Argentina was involved between 1989–1990.
After several years of nonexistent growth in the oil industry, in 1985 Argentine administration announced a large exploration program for private companies. Most exploration agreements were signed in 1989.
On the other hand, YPF, the state petroleum company, auctioned to international buyers 38 oil fields. The purchase ended in July 1990. In view of this, some companies chose exploration while others decided in favour of investment in YPF fields.
After theoretical treatment of the elements that are the basis on which exploration and purchase is evaluated, this was confronted with the variables that the managers of those companies projected in order to prove its use in reality.
Risk Analysis Implications for U.K. North Sea Exploration and Development
Authors: Antia D. D. J. 
Published: December 2007

Abstract
The integration of parametric and nonparametric Monte Carlo risk analysis techniques with:- EDNP (Expected Discounted Net Profit) AnalysisAdvanced Tax Analysis TechniquesTailored Product DesignAppropriate cost and production structures.
can be used to rapidly:- Screen acreage and geological playsDefine the risk-return relationships associated with future explorationDetermine the optimum values for interest swaps, sale, purchase, farmin/farmouts, and work program bidsScreen different development optionsDetermine commercial success risks and economic return varianceDetermine the impact of significant oil/gas price changes on the relative profitability and risk-return relationships of different areas of the North Sea.
In the UK North Sea, a Monte Carlo EDNP analysis has been used to demonstrate how the technique can be used to rapidly:- Assess exploration acreageIdentify exploration risk-return relationships and identify under exploited playsAssess the impact of changing cost structures on a field's net returnAssess the relative worth of production units, fields, and acreage for acquisition and divestment.
Natural Gas Reserve Additions: Recent Trends and Future Potential in the Lower 48 States
Authors: Finley R. J. , Fisher W. J. 
Published: December 2007

Abstract
The mature lower 48 states continue to yield substantial quantities of natural gas. Onshore reserve additions are dominated by reserve growth, indicating the increasing efficiency of conversion of infield resources to reserves. Total natural gas reserve additions for the 1980's will nearly equal the additions of the best decades of the 1950's and 1960's. Although significantly more wells were required in the 1980's, total additions have been stable for the last two decades at about 1.2 Bcf (34.0 MMcm) per well, and in 1986-88, additions averaged 2.1 Bcf (28.3 MMcm) per well. Disaggregation of 11 years (1979-89) of data for onshore less Appalachian (seven major producing states), Appalachian, and offshore areas shows that average onshore nonassociated gas per reserve growth completion has doubled from 1979-85 (0.9Bcf [25.5 MMcm]) to 1986-89 (2.2 Bcf [62.3 MMcm]). Appalachian region reserve growth has increased in these same periods from 0.07 to 0.13 Bcf/completion (2.0 to 3.7 MMcm/completion), but overall additions are not in proportion to the one-quarter of onshore reserve growth drilling in that region. Onshore reserve growth (adjustments, net revisions, extensions, and new reservoirs in old fields) has increased from an average 81 percent of production in 1979-85 to 92 percent in 1986-89.
Onshore net revisions became positive in 1983 and have steadily increased over seven years, the greatest gains occurring in 1986-89 even after discounting major positive revisions in Kansas in 1986 and in New Mexico in 1988. This discounting actually took place in 1989 data for western New Mexico (-2.133 Tcf [-60.4 Bcm]), but otherwise net revisions for major onshore producing states remained strong at +2.733 Tcf (+77.4 Bcm), or 98 percent of the 1988 level. Net revisions per onshore development completion reached 0.8 Bcf (22.7 MMcm) in 1986-89 from one-fifth or less of that level in 1979-85. It is these net positive revisions that probably most closely reflect recompletion and infill drilling of bypassed gas zones and incompletely drained compartments as mechanisms for extended nonassociated gas reserve growth based on depositional heterogeneity. The resource associated with this development is nearly 120 Tcf (3.40 Tcm) in the lower 48 states, about one-half of which (56 Tcf [1.59 Tcm]) is judged accessible at a wellhead price of &lt;$3.24/Mcf (1989$). Near-term supply-demand balance resulting in annual average wellhead prices of $2.25 to $2.50/Mcf (1990$) and realization that a substantial resource remains accessible, although in smaller increments, would allow continued efficiencies in extraction to meet market requirements into the 1990's.
Competitive Bidding for Oil and Gas Production Assets: How the Pie is Divided
Authors: Lohrenz J. 
Published: December 2007

ABSTRACT
Competitive bidders for oil and gas production assets seek to divide shares of "pies" of unknown value that each asset represents. Unlike with real pies, however, bidders' strategies can easily imply an expected negative share and the seller can reap more than 100% of the unknown asset values.
Environmental Control of Drilling Mud Discharge Through Dewatering in Cold Weather Climates: Effect of Ambient Temperature
Authors: Wojtanowicz A. K. , Ye Yawen 
Published: December 2007

ABSTRACT
The paper presents results of an experimental study into the effect of drilling mud temperature upon the dewatering performance. Three temperature ranges were considered: from flowline temperature to room temperature, from room temperature to freezing point, and the freeze (-4°F)/thaw (54°F) cycle. The tested drilling fluids included unweighted and weighted fresh water muds and a weighted salt water mud.
A sealed laboratory batch reactor was used in the experiments to prevent rapid vaporization of separated water at temperatures above 140°F. Also, ice or ice-salt baths were utilized for deep freezing. The dewaterability (net water removal) was measured with a bench-top plate press under constant expression pressure 30 psi.
The freeze/thaw treatment greatly enhanced dewaterability by releasing 34-39% by volume of the mud water. Mechanical dewatering followed; it required half the chemicals and released an additional 36-43% of water. The process proved to be very effective, reducing waste mud volume by 64-72%. It also seemed to be well-suited for the Arctic with its natural freeze/thaw cycles.
The results of experiments at temperatures above 70°F showed that there is little advantage to dewatering hot drilling mud diverted from active system. A 10% increase of water removal was observed above 140°F.
The experiments at temperatures below 70°F showed that in cold weather climates the waste drilling mud diverted from active system should be dewatered when its temperature is still above 40°F. Otherwise, more chemicals will be needed for separation enhancement or the dewatering process will become entirely ineffective.
Return Fluid Analysis From the Sadlerochit Formation, Prudhoe Bay, Alaska: A Laboratory Study—Part II
Authors: Fambrough J. D. , Brady J. L. , Almond S. W. 
Published: December 2007

ABSTRACT
Part I1-the field study, was presented as SPE 18223 at the national SPE meeting in Houston in 1988. It reported the results of a series of ionic analyses on returned fluids collected after a variety of acid treatments and the results of laboratory solubility tests on disaggregated core material. The field study had raised some key issues concerning the stimulation of the Sadlerochit formation. When and where was the precipitation of silica occurring downhole? Did this precipitation of silica result in significant formation damage? What was the relationship between the Si:AI ratios seen in the return samples analysis and those seen in standard acid solubility tests and acid core flow tests? Would an increase in the ratio of HCI:HF increase the Si:AI ratio and thus provide a more effective treatment? Was the Sadlerochit formation a source for the high ferric iron seen in the returned fluids?
To answer these questions an extensive laboratory study using Sadlerochit core plugs was initiated. SEM, thin sections, porosity, and permeability tests were done before and after acidizing a series of core plugs. The use of a high temperature, high pressure, ported flow cell provided the capability to monitor the acid treatment as it moved through each section of core material. Different HF acid systems (12% HCI:3% HF, 6% HCI:1.5% HF, 13.5% HCI:1.5% HF) were pumped through a set of core plugs and the effluents monitored under both continuous flow and flow after a shut-in time.
The results indicate that the Si:AI ratio decreases as the acid moves through the core. Lowering the HF concentration decreases the Si:AI ratio and the rate of change of this ratio as the acid reacts with the formation. Increasing the HCI:HF ratio had little effect on the Si:AI ratio of the spent acid. Si:AI ratios similar to those seen in the field study were seen only after a 14 hour shut-in at temperature with the Sadlerochit core material. No significant change in permeability was obtained after the silica was precipitated during the shut-in test. This suggests that although a large quantity of precipitated silica is left downhole, no significant loss in permeability occurs. This agrees with the overall production improvement seen in the HF acid treatments of the Sadlerochit formation.
Hydraulic Mining of Permafrost Placers by Boreholes
Authors: Khrulev A. S. 
Published: December 2007

ABSTRACT
The results of investigations and commercial tests of borehole hydraulic technology and equipment for gold and tin production from frozen placers through boreholes are given in this article. The variants of mining of small and thick placers through boreholes and the description of borehole equipment depending on conditions of use. The positive sides of borehole mining's application, problems appeared in the course of test and ways of their solution are shown.
Open-Cast Underground Technology of Permafrost Placer Mining in the Arctic
Authors: Lavrov N. P. , Lukjanov D. N. 
Published: December 2007

ABSTRACT
Perennialy frozen placers at depth of 10 to 30 m may be profitably mined by combining the opencast and underground mining procedures. According to this method, the placer is at first partially mined in opencasts, and then the underground mining is used to recover the rest of it.
The underground mining is carried out by means of systems of chambers with gravel rib pillars left or artificial backfills produced. The technique involving freezing of water is applied to construct artificial pillars. Overburden rocks are used as the stowing material. Underground gravels are recovered and transported to the washing site.
The opencast-underground technique is the most expedient for mining deep placers considering the problems of recultivation under the Arctic conditions.
Comparison Between Measured Global Ice Loads and Geotechnical Response of Arctic Offshore Structures
Authors: Blanchet D. , Hewitt K. J , Sladen J. 
Published: December 2007

Abstract
Global ice load criteria govern the stability of an Arctic offshore structure and its foundation. This paper reviews six case histories in which ice pressures have been measured, and the foundation response has been predicted and monitored. The global loads inferred from the two methods are compared and discussed.
Development of an Alaskan North Slope Soils Database for Drill Cuttings Reclamation
Authors: Schumacher J. P. , Gillespie J. D. , Malachosky E. , Hampton P. D. 
Published: December 2007

ABSTRACT
Reclamation of processed drill cuttings provides environmentally acceptable construction material for roads and pads thus minimizing the need to excavate materials from surface gravel pits. Regulatory agency policy goals of reduction in surface disturbance of Arctic environments, reduction of waste, and recycling of a natural resource can be achieved.
In order to adequately assess the compatibility of drill cuttings with the North Slope environment, information regarding the chemical composition of background soils is required. This paper reports on the work done by ARCO Alaska, Inc. to establish a primary database on the chemical composition of uncontaminated soils and gravels from various North Slope sites. Background samples have been analyzed by EPA Method 3050 techniques, and ranges for metals and salts have been accepted by the Alaska regulatory agencies.
Additionally, development of a secondary elutriate test method based on EPA Method SW924 is described as it was applied to analysis of background materials and drill cuttings. The technique evaluates the leachability of chemical constituents from various types of monofill materials.
Data are presented for materials excavated from several wells in the vicinity of the Prudhoe Bay Field. Processed and unprocessed drill cuttings are compared through analysis of the chemical constituents. Results indicate that the removal of clays and other fine particles through the water-based processing technique produces high grade construction material.
The techniques described in this paper are broadly applicable throughout the Arctic. Establishment of a chemical background database for the North Slope of Alaska will assist in minimizing environmental effects of placement of excavated material. In addition, techniques for processing and analyzing materials recovered from drilling operations in Alaska may be applicable to other Arctic areas where exploratory or development drilling is occurring.
Drilling Wastes Management for Alaska's North Slope
Authors: Fristoe B. R. 
Published: December 2007

ABSTRACT
In the early 1980s the State of Alaska's Department of Environmental Conservation determined that drilling waste disposal practices at the oil fields on the North Slope were not adequately protecting the environment. New regulations were promulgated in October, 1987 that required improved containment of wastes and better monitoring of waste disposal sites. Industry and the state have been working together to develop methods that will meet the requirements of the new regulations and a number of these methods have been tried in the field over the past few years. The methods, including waste reduction, injection of drilling wastes, deep hole burial using permafrost for containment, shallow hole burial using permafrost for containment, and treatment of waste for use as construction material, are discussed in context with the status in the development of each technology, concerns for each technology that the state has, and regulatory schemes that have been developed for each technology. Great strides in a number of these options have occurred over the past five years; however, extensive data on the new technologies have not been gathered and it is anticipated that refinement of them will continue for the foreseeable future.