bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Dynamic Computer Model of a Kicking Well: Part II—Model Predictions and Conclusions
Authors: Nickens H. V. 
Published: December 2007

ABSTRACT
The response of a kicking well for representative kick situations has been calculated using the dynamic model described in Part I: "The Theoretical Model". Kick size, gas distribution, control method, casing shoe position, shut-in procedure and choke control procedure are considered and the resulting effects on the casing shoe and surface casing pressure are presented.
The increase in surface pressure as the distributed gas migrates under shut-in conditions is also calculated. The resulting rate of increase of surface casing pressure gives an apparent gas rise velocity of 1000 ft/hr, consistent with the field rule-of-thumb, although the actual, rise velocity is about 2000 ft/hr for distributed gas.
An Approximate Theory of Oil/Water Coning
Authors: Wheatley M. J. 
Published: December 2007

ABSTRACT
The problem of water coning into a partially-penetrating oil well is considered. An analytical theory is developed which approximately describes the flow of oil into the well in the presence of a cone of water beneath the well. In particular, a procedure is given for computing the critical oil production rate.
Results for critical rate are presented for a range of formation thicknesses, penetration ratios, drainage and well radii and horizontal to vertical permeability ratio. Comparisons are made with other data available in the literature.
A New Approach to Differential Sticking
Authors: Courteille J. M. , Zurdo C. 
Published: December 2007

ABSTRACT
This paper presents a new theorical and experimental study of the forces involved along the pipe/cake/formation triple bond when differential pressure sticking has been established.
This has been done by recording the pressure at differents points of the pipe/cake and cake/formation interfaces in a laboratory device reproducing the drilled hole conditions. Results show that the resistance at any point of the pipe/cake/formation bond is mainly affected by the pore pressure existing at that point.
Evaluation of Low-Resistivity Simpson Series of Formations
Authors: Schulze R. P. , Ives G. L , Smalley E. A. , Smith W. E. 
Published: December 2007

ABSTRACT
Units of the Simpson series of formations are evaluated by means of computing both a "textural" parameter, W, and the volume of mud filtrate that has displaced fluids originally present in the formation. This analysis is performed primarily through the use of response equations for an electromagnetic wave propagating through the formation. The first computation uses the interval transit time and the resulting solution for Sxo. The second one uses the attenuation of the wave.
The textural parameter is used as both m and n in Archie's equation for water saturation. The m and n values agree with the range of values reported in core measurements for the Simpson. The resulting water saturation computations agree with production from examples.
Computing the volume of moved fluids leads to a prediction of the amount of connate water displaced by the mud filtrate. This, in turn, leads to predictions about the water that the well will produce and a rough idea about the bulk volume of irreducible water.
These predicted and computed values agree fairly well with production from examples. The Simpson series in Oklahoma is often characterized by low-resistivity pays, and the resistivity from an induction log is typically low in these formations. The water saturations computed from Archie's equation using m=n=2 are very high and are often in disagreement with production. Two very real possibilities for this disagreement are the use of wrong values for m and n and the presence of high bulk volumes of irreducible water. The techniques described in this paper help solve these two problems.
Sodium Carbonate Preflush Theoretical Analysis and Application to Chateaurenard Field Test
Authors: Rivenq R. , Sardin M. , Schweich D. , Putz A. 
Published: December 2007

ABSTRACT
In a previous paper1 we described the mechanisms of oil recovery by the microemulsion injected in Chateaurenard (France) micellar/polymer field tests. The calcium gradient created through the micellar slug as a result of cation exchanges between micelles, water and clays has been shown responsible for both high displacement efficiency of the microemulsion and trapping of surfactant in residual oil.
The efficiency of the same microemulsion is improved if calcium is removed ahead of the micellar slug and if the calcium gradient is replaced by a salinity gradient. In this paper we describe how this can be achieved by using a sodium carbonate preflush which induces precipitation of calcium from the clays as calcium carbonate.
A series of sandpack displacement tests have been carried out, both with and without oil present, to study the effect of a sodium carbonate preflush and to understand the mechanisms involved in such a process. Experimental results have confirmed that use of a 5g/l Na2CO3 preflush can increase the oil recovery rate up to twice its value without preflush, depending on preflush size and quantity of microemusion injected, and reduce correspondingly retention of the surfactant.
In order to interpret these tests a numerical simulator has been elaborated. It takes into account the dispersive properties of the sandpacks and the significant interactions between minerals and fluids. A good agreement between preflush displacement tests and simulations has been achieved using measured input parameters.
Pressure Transient Analysis for High-Permeability Reservoirs
Authors: Cinco-Ley H. , Samaniego-V. F. , Viturat D. 
Published: December 2007

ABSTRACT
Field experience has shown that pressure data measured in extremely high permeability reservoirs (kh ~ 106md-ft) are affected by wellbore effects such as storage, temperature changes, reservoir pres sure trend and noise in pressure measurements. These effects are particularly important in light of the small pressure response observed during a well test. The present work presents methods to analyze pressure drawdown and buildup tests performed under the influence of unknown linear reservoir pressure trend (m*). For a drawdown test a graph of t dpwf/dt vs t yields a straight line of slope m* and intercept m (semilog slope); for a buildup test a graph of dpws/dt vs tp/∆t(tp+∆t) gives a straight line of slope m and intercept m*. Field cases are presented to illustrate the application of this method and the effects of different wellbore phenomena; both surface shut-in and bottomhole shut-in examples are included.
Design of the Harmony and Heritage Platforms for Offshore California
Authors: Irick J.T. , Ruhl G.L. , Tucker M.C. 
Published: December 2007

Abstract
The Harmony and Heritage platforms are planned by Exxon Company, U.S.A., for installation planned by Exxon Company, U.S.A., for installation offshore California, in 1200 feet (366 m) and 1075 feet (328 m) of water, respectively. The design criteria and analysis procedures are an extension of the technology used for the 850-foot (259 m) water depth Hondo platform, about ten years ago. Each of various in-place (environmental) and installation loadings are discussed, and their relative impacts on jacket weight are evaluated.

Introduction
Exxon Company, U.S.A.'s Hondo platform was installed in the Santa Ynez Unit in the Santa Barbara Channel in 1976. The design and construction procedures of this 850-foot (259 m) water depth platform (which are described in References 1 and 2) have evolved to meet the additional challenges presented by the Harmony and Heritage platforms, the next developments for the Santa Ynez Unit. As shown in Figure 1, the Harmony platform will be located about 3 miles (4.8 km) west of the Hondo platform, and the Heritage platform will be located about 7 (11.3 km) miles west of Harmony. Pipelines are planned to extend from Heritage to Harmony, to Hondo, to a terminal.
Like Hondo, both platforms were designed by Exxon Company, U.S.A., with extensive support by its research affiliate, Exxon Production Research Company. Designs for a one-and two-piece option and for a Far East and West Coast jacket assembly are essentially complete. The anticipated schedule for the platform jacket design and construction is shown in Figure 2. To capture economies of scale, design and fabrication of the Heritage platform is planned to be simultaneous with that for Harmony, and water phase construction will be sequential. phase construction will be sequential. PHYSICAL FEATURES PHYSICAL FEATURES As shown in Figure 3, the Harmony and the Heritage platforms are similar to the Hondo platform. They are all 8-legged, pile founded platform. They are all 8-legged, pile founded structures for the support of drilling rigs, production equipment, and personnel quarters. production equipment, and personnel quarters. The size of the new platforms prohibits the use of any existing fabrication yards on the U.S. West Coast. Also, no existing barge is capable of carrying either jacket as a single unit across the Pacific. Thus, to encourage competitive bidding and launch barge development, both one-piece and two-piece (like Hondo) jackets were designed and offered to potential fabricators. potential fabricators. The deck structures on Harmony and Heritage are essentially identical. They are three-level modular decks, atop a module support frame. The deck plan is 180 feet by 145 feet (55 m by 44 m) with a total area of about 78,000 square feet (7300 m2). Two drill rigs and 60 well conductors are planned for each platform. The total topside weights above the module support frame is about 40,000 kips (mass 18,100 Mg) for each platform.
Time-Dependent Flow Behavior During Immiscible Displacement in Porous Media
Authors: O'Steen B. L. 
Published: December 2007

ABSTRACT
Previously reported experimental results for oil/water displacements in Berea sandstone are reexamined in an attempt to better understand the observed behavior. Contrary to the original interpretation of these results, it is concluded that traditional Buckley-Leverett theory, including capillary dispersion and hysteresis effects, is incapable of even qualitatively describing the observed displacement behavior. This failure of Buckley-Leverett theory is attributed to the inability of Darcy's law to adequately describe multiphase flow in the vicinity of a flood front. A simple time-dependent expression for the fractional flow is proposed, at a heuristic level, to explain the experimental results and support the assertion of unsteady flow. The conservation and proposed flow equations, in linearized and in characteristic forms, are analyzed to deduce the basic solution behavior. Numerical solutions are also presented. The theoretical results are found to qualitatively reproduce many of the observed displacement features.
Fracturing a High-Permeability Oil Well at Prudhoe Bay, Alaska
Authors: Hannah R. R. , Walker E. J. 
Published: December 2007

ABSTRACT
This paper details a successful fracturing of a high permeability oil well at Prudhoe Bay, Alaska. The treatment was complicated by the zones proximity to water, poor leak-off control and the need for a large quantity of proppant.
A calibration treatment was performed prior to the proppant laden treatment to verify the leak-off coefficient and to determine height growth tendencies. This treatment indicated a grossly higher fluid loss rate than the pre job estimate and a more conservative treatment was designed. Temperature/gamma logs indicated the redesigned treatment would not propagate to the water zone.
The treatment was pumped successfully and the well cleaned up and responded to the treatment with a productivity increase of 1.33 out of a maximum theoretical of 1.6. This is considered good for a fracture of such modest dimensions.
Measuring Capillary Pressure and Relative Permeability in a Single Centrifuge Experiment
Authors: O'Meara D. J. , Crump J. G. 
Published: December 2007

ABSTRACT
Two of the most important properties governing reservoir fluid flow are relative permeability and capillary pressure. Unfortunately, conventional techniques for measuring one are not without complications from the other. Worse yet, these complications become particularly inextricable for flow experiments on the short core samples typically available for analysis. The advantage of the present method is that it simultaneously measures both properties in an experiment where their effects have been largely decoupled.
The present method entails using an automated centrifuge to measure fluid productions at several speeds and history-matching the production data with the aid of a numerical simulator. Although history-matching problems are, in general, not well posed, the present case is exceptional. In each speed step the asymptotic production is determined only by capillary pressure and the transient behavior is determined mainly by relative permeability. Consequently, the effects can be distinguished.
A numerical simulator, tailor-made for centrifuge experiments, is presented along with typical results of history-matching. The error in a conventional capillary pressure is also estimated.
The Application of the Cubic and Quadratic Forchheimer Equations in the Design of High-Rate, Gravel-Packed Gas Well Completions
Authors: Buell R. S. , Crafton J. W. 
Published: December 2007

ABSTRACT
The addition of the cubic term to the quadratic Forchheimer equation is evaluated in the design of high-rate, gravel-packed, gas well completions. The impact of the cubic term on the Rawlins and Schellhardt1 back pressure plot, non-Darcy plot as used by Jones et al.2 and Himma-tramka,3 and the rate sensitive skin plot as used in references 4 and 5, is evaluated. The authors conclude that high-rate, gravel-packed gas well completions can be designed with sufficient accuracy under field conditions without the inclusion of the cubic term. An example calculation is done using the cubic term to illustrate its effect. A design procedure is presented for inside casing gravel pack design.
Well Testing With a Non-Newtonian Fluid in the Reservoir
Authors: Huh C. , Snow T. M. 
Published: December 2007

ABSTRACT
When a reservoir contains a non-Newtonian, polymer-containing fluid such as those injected during a surfactant or polymer flood, well test data cannot be interpreted using conventional well-test theory. This is because fluid viscosity depends not only on the distribution of polymer within the reservoir, but also on the non-Newtonian rheology of the polymer-containing fluid. A well testing method which accounts for both the polymer concentration distribution and non-Newtonian rheology is presented.
For the method presented here, the pressure transient equation is solved together with the polymer transport equation to obtain the pressure response for any assumed radial distribution of polymer within the reservoir. An optimization technique is then employed to give the best fit to the field data. Thus, for a given distribution of polymer in the reservoir, appropriate formation parameters -- porosity, permeability, and thickness -- can be deduced. Conversely, with the known values of formation parameters, an attempt can also be made to obtain the approximate distribution of polymer within the reservoir. Unlike previous solutions for non-Newtonian rheology, the non-linear character of the equations is preserved. Also, an adaptation of the Carreau model, which describes the polymer rheology more realistically than the commonly-employed power-law model, is used. Application of this new method to interpret field data is discussed with examples.
A Microcomputer-Based Oil and Gas Consultant System
Authors: Rieke H. H. , Perry R. D. 
Published: December 2007

Abstract
The purpose of this article is to introduce, to the independent oil and gas operators, the concept of a microcomputer-based consultant system that employs interactive video. An interactive computer-video system is a powerful information tool. It has many applications in exploration, drilling, completion, stimulation, production, and business aspects of the petroleum industry.
Such an interactive computer system conviently provides the rules and knowledge required to improve and to maintain the quality of work in a particular discipline. This unique software/ hardware application integrates all activities which are mandatory in improving the oil and gas production potential of exploration and development wells. It can be simply described as an intelligent video workstation employing a structed electronic approach for handling the day-to-day field operations and business activities. Now, the microcomputer can be effectively used as a cost saving aid in decision making and problem diagnosis. The system will furnish the small operator with the same capabilities as those possessed by large oil companies.
Well Control Practices for Air-Drilled Holes
Authors: Willis R. B. 
Published: December 2007

Abstract
The fast paced and hydrostatic-free nature of air drilling presents unique problems when blowouts are encountered. Well control practices for air drilling lag considerably behind techniques applied for fluid drilling. The formation at the surface casing shoe is commonly the weak link during killing operations and any well control plan must protect against shoe breakdown. The technique described below is based on monitoring pressures at the choke manifold to keep pressures at the shoe below breakdown pressure. In the field, air drilled well control requires rugged, easy to maintain equipment and a simple well control plan.
Wellsite Determination of Bottomhole Condition for Rod Pumping Wells
Authors: Wilkins D. S. , Yu J. P. , Puon P. S. , Huddleston K. L. 
Published: December 2007

ABSTRACT
Sucker rod pumping is one of the major oil recovery systems in the Appalachian area. In order to analyze the performance of a pumping well, the bottomhole condition of the well should be monitored. The pressure at the formation in a well should be known at different conditions. In addition to determining the producing and static bottomhole pressure, the study of the pressure build-up when a well is shut-in is important. There are several methods for obtaining this pressure build-up data. The acoustical liquid level instrument has been traditionally used to locate the liquid level to determine if the well is "pumped off". The depth to the liquid level can be used to calculate the producing bottomhole pressure. The same calculation can be utilized to monitor the bottomhole pressure during a well test. These pressures may then be used to determine the skin damage present in a well. Substantial work is now being done by several companies with acoustical build-up tests. This paper reviews skin damage and the application of methods to test for its presence.
A Study of Reservoir Parameters Affecting Gas Well Spacing in West Virginia
Authors: Aminian K. , Ameri S. , Saradji M. S. , Locke C. D. 
Published: December 2007

Abstract
Well spacing has a significant effect on gas reservoir deliverability optimization. A single well seldom provides the desired rate of production from a given reservoir. Generally, the total rate of gas production increases with the number of the wells completed in the gas reservoir. At the same time, inter-well interference tends to reduce this increase in total rate of production as the number of producing wells are increased. Consequently, there must exist a well-spacing which will result in the most efficient recovery from a natural gas reservoir. This optimum well spacing depends upon the producing formation characteristics as well as economics of field development.
The overall objective of this paper is to provide a general guideline based on reservoir engineering principals for efficient well spacing pertaining to gas producing formations in West Virginia. The objective was achieved by developing a general reservoir model which simulates the flow of gas in a reservoir containing several wells. The model was then used to study the parameters which affect well interference and spacing. The model has the advantage of also accounting for the inertial component of pressure drop in gas flow through porous media, a factor which was found to affect well interference.
Reservoir data pertaining to Big Injun and Benson formations were collected and interpreted. The interpreted data were statistically analyzed and the results were utilized in conjunction with the model to provide general guidelines pertaining to spacing for gas wells producing from these two horizons in West Virginia.
Testing CO2-Foam for Mobility Control at Rock Creek
Authors: Heller J. P. , Boone D. A. , Watts R. J. 
Published: December 2007

ABSTRACT
This paper reports the objectives, design and progress of a field test of "CO2-foam" as a lowered mobility displacing fluid. It includes the background of mobility control considerations leading to the trial, and describes the influence on it of various operational conditions and constraints. The Rock Creek oil field of Roane County, West Virginia, has been produced since 1906 from a low permeability sandstone with high clay content, and is now near the end of economic life. The area utilized in this test is a smaller portion of two ten-acre five-spots that have been subjected to a conventional CO2 flood and subsequent waterflooding, in addition to gas recycling and primary production. A major goal of the test was to determine whether the oil remaining in this area could be displaced by a slug of thickened CO2 to form a mobile oil bank that could be detected at a nearby observation well. A second goal was to test the injectivity of CO2-foam as liquid CO2 and dilute surfactant solution were pumped simultaneously down fiberglass tubing into the injection well. The design of the test was based on published measurements of the ability of the chosen surfactant (Alipal CD128) to form a foam-like dispersion with liquid CO2, on stability at reservoir temperature (73°F; 23°C), on the extent of adsorption onto the reservoir rock, and on the appropriate values of the relative mobility of the CO2-foam (0.2 cp-1). Although it has been possible to inject the target quantity of CO2 foam, the injection of chase water has not yet been completed.
OPEC and Adam Smith
Authors: Roberts M. L. 
Published: December 2007

ABSTRACT
Unless OPEC can discipline itself to production levels that will result in the spot price of crude being equal to or greater than the contract price of crude, the demand for OPEC crude, along with the price of crude, will continue to erode for the remainder of the decade.
Because of the quantum jump in energy prices during the 1973-74 and 1979-80 periods, certain irreversible forces have been set in motion that have changed the structural demand for energy. These forces have resulted in a decline in energy demand per real GNP in the major industrialized nations of in excess of 24%, indicating price elasticities of between −0.3 and −0.5. This suggests that, regardless of the strength in the economies of the nations of the industrialized world, an "off oil" policy has been put into place through conservation, efficiencies, substitutions, and new technology. Moreover, superimposed on this major structural change in demand for petroleum has been the amount of nonOPEC oil and nonpetroleum supplies coming into the market at an annual rate of 1.0-2.0 million BD per year.
The bottom line to these structural changes is pressure on OPEC to reduce production and/or prices in order to maintain its viability as an organization. Failure to exercise the discipline or proration suggests that Adam Smith's Economics 101 will continue to wind down oil prices for the remainder of the decade and possibly beyond.