bluuebunny/crossref_metadata_2025_split huggingface dataset:
Pressure Maintenance Operations in the Sharon Ridge Canyon Unit, Scurry County, Tex.
Authors: Lacik Harold A. , Black Joseph L. 
Published: December 2007

Abstract
The Sharon Ridge Canyon Unit is a pressure maintenance project using fresh surface water injected on a peripheral pattern. Canyon Reef limestone of Pennsylvanian age, occurring at approximately 6,700 ft, comprises the producing reservoir. The original producing mechanism was that of an undersaturated solution-gas drive. Rapid pressure decline and the threat of climbing gas-oil ratios pointed toward the need for pressure maintenance. Performance to date under the influence of water injection has been very encouraging. During six years of water injection, the volumetric average reservoir pressure has increased 338 psi, from 1,583 to 1,921 psi. The producing gas-oil ratio has been reduced from about 1,300 to about 900 cu ft/bbl. Before water injection, it was necessary to withdraw approximately 2.3 reservoir bbl in order to place 1 bbl of oil in the stock tank. Now, 1 bbl of stock-tank oil requires a withdrawal of only 1.8 reservoir bbl. Peripheral portions of the reservoir which have experienced encroachment by the injected water have performed better than predicted. Based on this history and recovery predictions, ultimate recovery as a result of this water injection will be at least 50 per cent of the original oil in place. This is twice the predicted recovery without pressure maintenance.

Introduction
With the completion of Humble Oil and Refining Co.'s R. E. Bishop 1 (now known as Tract 35, Well 1) in March, 1949, the Sharon Ridge Canyon field was discovered. This field is located approximately 20 miles southwest of Snyder, Tex., and its Pennsylvanian reef reservoir was divided from the Kelly Snyder and Diamond "M" fields by means of arbitrary lines. In Nov., 1951, the Sharon Ridge Canyon field was combined with the Diamond "M" field. Less than two years after the discovery well had been completed and with the field only 75 per cent developed, the operators met and formed the "Sharon Ridge Canyon Engineering Committee". A great amount of work and study directed toward a conservation program resulted in the formation of the Sharon Ridge Canyon Unit, with 100 per cent of the operators signing the agreement. On May 1, 1955, unitized operations commenced with a peripheral water-injection pressure maintenance program.
JPT
P. 645^
Ultimate Resistance Against a Rigid Cylinder Moving Laterally in a Cohesionless Soil
Authors: Reese Lymon C. 
Published: December 2007

Abstract
The ultimate resistance against a rigid cylinder which is moved laterally in a cohesionless soil is a function of the geometry of the cylinder and the properties of the soil. An approximate method is developed for computing this resistance and is tested against results of laboratory experiments. Satisfactory agreement between the method and experiment was obtained. Not only was the ultimate resistance against the cylinder measured, but careful measurements were made of the shape of the rupture surfaces. These measurements should allow the development of a more rigorous computation procedure.

Introduction
A critical aspect in the design of offshore drilling platforms is assuring the stability of the platform during a hurricane. The large horizontal loads from waves and wind make a severe loading condition. Piles are generally employed as the foundation since they can be effective in resisting both horizontal and vertical loads. Spuds are sometimes used with a mat foundation, where the spuds are designed principally to resist horizontal loads and the mat designed principally to resist vertical loads. The research reported in this paper is related to one aspect of the problem of laterally loaded piles or spuds in sand. The complete solution to the problem of the laterally loaded pile in sand would require the prediction of soil resistance against the pile as a function of pile deflection; only the ultimate resistance against short piles is considered in this paper. A considerable amount of additional research will be necessary to obtain a complete solution to the problem of the laterally loaded pile in sand; however, the work reported here should be useful as a guide in the performance of some of the additional research.

ULTIMATE LATERAL RESISTANCE AGAINST A LONG WALL IN SAND
To aid in the understanding of the theory which is developed for a cylinder, the theory for earth pressure against a wall is reviewed. In Fig. 1(a), a long wall of height H is shown embedded in soil. Soil resistance will develop as the wall is deflected, and the soil resistance will increase with deflection until some limiting value is reached. In this discussion, and those following, it is assumed that all points on the wall deflect equal amounts. A possible shape of the real curve which relates soil resistance to deflection is shown by the dashed line in Fig. 1(b); however, as a means of simplifying the discussion, an idealized curve (shown by the unbroken lines) is drawn. If such a wall as this were furnishing the horizontal support for an offshore structure, the dashed curve in Fig. 1 would be the information needed in performing a foundation analysis, with the idealized curve possibly being an acceptable substitute.
SPEJ
P. 355^
Laboratory Tests and Field Implementation of Gas-Drag-Reduction Chemicals
Authors: Li Ying-Hsiao , Chesnut G. R. , Richmond R. D. , Beer G. L. , Caldarera V. P. 
Published: December 2007

SummaryDrag reduction in gas-transmission lines can be achieved by applying a thin chemical coating on the pipe inner surface to reduce friction between the flowing gas and pipe wall. Newly identified molecules used for gas-drag reduction can strongly bond to metal surfaces and form a smooth film to mitigate gas turbulence at the gas/solid interface. Effective gas-drag reducers have properties similar to corrosion inhibitors and lubricants or a combination of both. Fatty acids, oxylated fatty acid amines, and/or amides with carbon numbers between 18 and 54 can provide this type of behavior.1 The desired scenario is based on positively charged amine and amide functional groups providing strong binding to the metal surface and the long-chain hydrocarbon part serving as a compliant or lubricating surface to mitigate turbulence at the gas-phase boundary.2A field test using Nalco 945 corrosion inhibitor at High Island 24L [a 7.625-in. inside diameter (ID) and 6.25-mile-long gas line from an offshore platform to the inland facilities in Sabine Pass, Texas] demonstrated gas-throughput improvement up to 20% at its peak performance. The improvement can be defined either as a reduction in pressure drop at a constant flow or as a flow-rate increase at a constant pressure drop. In this case, the gas-drag reducer resulted in a decrease in pressure drop from 180 to 150 psi and an increase in flow rate from 50 to 52 MMscf/D, while maintaining discharge pressure at about 840 psi. Its effectiveness peaked at the third week after one injection treatment, and then gradually tapered off. Benefits lasted more than 2 months.
The Differentiation Method in Rheology: IV. Characteristic Derivatives of Ideal Models in Couette Flow
Authors: Savins J.G. , Wallick G.C. , Foster W.R. 
Published: December 2007

Abstract
The dual differentiation-integration method of rheological analysis is applied to Couette flow. Using machine processing techniques, a spectrum of characteristic derivative functions for a variety of ideal Generalized Newtonian and viscoplastic models has been developed: As for the case of Poiseuille flow the functions for Generalized Newtonian models as a class are strikingly different from the corresponding functions for the class of viscoplastic models. It is shown that this dual scheme of analysis is a highly sensitive analytic method for determining the applicable range of a rheological model. The unique characteristics of this function in the case of viscoplastics may lead to a more precise detection and evaluation of the yield point or yield stress in these materials.

Introduction
It has been shown that the dual differentiation- integration method of analysis is a discriminating and flexible method for interpreting flow behavior and determining the applicable range of a particular model from Poiseuille flow experiments. In the preceding paper the basic equations governing the Couette flow experiment were reviewed and the significance of changes in boundary conditions on data analysis in the case of the viscoplastic discussed. In this paper the dual method of analysis is applied to Couette flow using the suites of rheological models considered previously.

THEORETICAL CONSIDERATIONS

NEWTONIAN LIQUID
f (p) = p......................(1)
Substituting Eq. 1 in Eq. 4 of Ref. 3 and integrating yields
Dv = p1........................(2)
where Dv is the nominal shear rate at R1, viz:R2, and B is the radii ratio. Here R1
............(3)
...................(4)
....................(5)

GENERALIZED NEWTONIAN SYSTEMS
Odd Power
..........(6)
Integration after substitution of Eq. 6 in Eq. 4 of Ref. 3 yields
......(7)
and hence,
...(8)
........(9)
= .............(10)
Series (General)
............(11)
SPEJ
P. 177^
Experimental Investigation of Frictional Pressure Losses in Coiled Tubing
Authors: Azouz Idir , Shah S. N. , Vinod P. S. , Lord D. L. 
Published: December 2007

Summary
This paper presents an experimental investigation of tubular frictional pressure loss in coiled tubing (CT) and straight sections of seamed and seamless tubing. Fluids investigated include water, linear guar gum and hydroxypropyl guar (HPG), and borate-crosslinked guar gum and HPG, under conditions typically encountered in many CT field applications. The equipment used includes a system of one 1000-ft and two 2000-ft CT reels that can be arranged to provide total CT lengths of 1,000, 2,000, 3,000, 4,000, and 5,000 ft. The system also includes straight sections of seamed and seamless tubing with the same nominal diameter (1½ in.) and wall thickness (0.156 in.) as that of the CT. The investigation focuses mainly on the effects of CT curvature, tubing seam, fluid pH, and shear history on frictional pressure loss. Results obtained with water indicate that curvature, as well as the seam inside the CT, significantly affect the frictional pressure losses. Results obtained with various polymer solutions and gels, however, suggest that tubing curvature has a more significant effect on the frictional pressure losses than the tubing seam. Moreover, it is observed that, for borate-crosslinked HPG, the pressure gradient is dependent on both the fluid pH and the length of CT across which it is measured. However, for borate-crosslinked guar gum, the pressure gradient is a function of pH and is not very sensitive to the length of tubing along which it is measured.
Simplified Oil-Production Model With Viscous Flow, Gravity Drainage, Skin, and Instantaneous Oil/Steam Ratio for Mature Steamfloods
Authors: Closmann Philip J. 
Published: December 2007

Summary
A simplified model estimates oil production rates for mature steamfloods. The mechanisms included are gravity drainage and viscous flow of the oil induced by flowing steam. Three examples of vertical wells are presented. The oil/steam ratio is also illustrated, as well as the pressure drop in the steam phase. One application of the model to horizontal wells producing by gravity drainage is also presented.
Pressure-While-Drilling Data Improve Reservoir Drilling Performance
Authors: Ward Chris , Andreassen Espen 
Published: December 2007

SummaryA new downhole annular pressure-while-drilling (PWD) tool has been applied recently to assist in drilling the reservoir section on the Statfjord field, offshore Norway. For drilling success in these high-angle wells it is critical to maintain the mud weight and equivalent circulating density (ECD) within safe operating limits defined by the formation fluid, collapse, and fracture pressures. Operating outside these limits historically has led to expensive lost circulation, differential sticking, and packoff incidents. Monitoring the actual downhole pressure in real time with a PWD tool, rather than relying on inferred pressures from predictive models, has allowed the operator to stay within and to better define these operating limits. The operator used this improved hydraulics information to avoid pressure-related hole problems, to optimize drilling practices, to test hydraulics models, and to obtain a greater understanding of the formation pressure limits.
Innovative Technology for Tubular Connection To Eliminate Thread-Compound Grease
Authors: Tsuru Eiji , Maruyama Kazushi , Oka Masaharu , Higuchi Seijun 
Published: December 2007

Summary
The doping of thread-TCG (TCG) poses an environmental pollution threat, but it is essential to the performance of tubular connections. This paper deals with an innovative tubular-connection coating without TCG, and describes the galling resistance and connection performance under field conditions. To develop the new coating technique without TCG, pin-on-disk-type tribological tests were conducted. For the connections with the new coating, performance was evaluated with power tongs and full-sized testers. As a result of the testing, the make-and-break (M&B) of the connection without any liquid lubricant was accomplished by means of the new coating. The connection can maintain the same performance as the conventional connection with TCG. This new connection coating can solve the problems induced by TCG and simplify the running works of casing and tubing pipes.
Optimized Reservoir Management With Mixed Linear Programming
Authors: Currie J. C. , Novotnak J. F. , Aasboee B. T. , Kennedy C. J. 
Published: December 2007

SummaryReservoir engineers face a large number of possible development plans for major offshore oil fields. Some of the factors affecting development include product-processing capacities, drilling-rig availability, extended use of existing platforms, enhanced-recovery options, and subsidence-avoidance requirements. Reservoir simulation is an accepted technique for estimating production from oil and gas fields. Each possible development scenario is simulated separately to obtain future oil- and gas-production estimates from wells included in the scenario. Simulation results are analyzed for each run, and the optimal plan is selected. Enumerating all the possible drilling schedules is a difficult task, and, even with clusters of advanced scientific workstations, the computational requirements of simulation can be overwhelming.This paper describes the application of linear mixed integer programming (MIP) to the combinatorial problem of generating the optimal redevelopment scenario for the Ekofisk field in the Norwegian sector of the North Sea. The MIP model determines the optimal redevelopment program and drilling schedule while maintaining operationally feasible product-processing requirements, drilling-rig use, and well/platform relationships. Optimality is based on the net present value (NPV) of the estimated production forecasts for the wells selected. Total recovered reserves is an alternative optimization criterion. Reservoir simulations generated the estimated production forecasts used in iterative runs of the optimized model. We discuss success of the approach and extensions.
Determining Residual Oil With The Nuclear Magnetism Log
Authors: Robinson J.D. , Loren J.D. , Vajnar E.A. , Hartman D.E. 
Published: December 2007

Given a reservoir with an immobile oil saturation, a mobile water phase, and proper open-hole conditions, the nuclear magnetism logging tool can be used to determine the amount of residual oil and the vertical distribution of the residual oil near the wellbore. Unique to the method is that the interpreter can control the precision of the results obtained.

Introduction
Methods of determining oil in place using underground surveys are indirect; that is, secondary properties are measured and the desired primary characteristics are derived from empirical relations with these secondary properties. Most of these methods must account properties. Most of these methods must account for contributions that both rock and fluid make to the measured signal. The nuclear magnetism log (NML) is unique because its signal is from the pore fluid alone. In this report we present a technique that takes advantage of this response characteristic of the NML and enables us to estimate immobile oil after water displacement.The NML tool detects protons in molecules of whatever liquids are contained in a formation immediately adjacent to the wellbore. In Ref. 1 it has been shown that if both water and oil are present the total response is equal to a contribution present the total response is equal to a contribution from the oil phase (which is relatively uninfluenced by confinement in rock pores), plus a contribution from the water phase (which is highly influenced by the pore size and matrix properties of the rock).The tool that was used to obtain the field results presented here caused magnetic fields to be applied presented here caused magnetic fields to be applied to the formation as shown in Fig. 1a. During time Tp the induced magnetization grows toward an equilibrium value proportional to the field strength Hp according to(1)
Upon removal of the high field, the induced magnetization decays toward a lower equilibrium value proportional to the low-field strength, HL, according to(2)
The growth and decay of the induced magnetization described by Eqs. 1 and 2 are illustrated in Fig. 1b.After the low field is removed the protons respond to the presence of the earth's magnetic field and proton free-precession takes place in the process of proton free-precession takes place in the process of achieving equilibrium. An exponentially decaying voltage with decay constant T2 and amplitude proportional to the magnetization is induced in the proportional to the magnetization is induced in the coil of the tool and is expressible as(3)
Fig. 1b illustrates the induced voltage as it decays during the free-precession period. The second term of Eqs. 1 through 3 is a sum because the T1 of the response from the water will depend upon the size of the pore in which it is contained.
JPT
P. 226
Common Business Objects: Demonstrating Interoperability in the Oil and Gas Industry
Authors: McLellan S. G. , Abusalbi Najib , Brown Johnny , Quinlivan W. F. 
Published: December 2007

Summary
The PetroTechnical Open Software Corp. (POSC) was organized in 1990 to define technical methods to make it easier to design interoperable data solutions for oil and gas companies.1–7 When POSC rolls out seed implementations, oilfield service members must validate them, correct any errors or ambiguities, and champion these corrections into the original specifications before full integration into POSC-compliant, commercial products.8–10 Organizations like POSC are assuming a new role of "promoting formation of projects where E&P companies and vendors jointly test their pieces of the migration puzzle on small subsets of the whole problem."11,R12 We describe three such joint projects. While confirming the value of such open cross-company cooperation, these cases also help to redefine interoperability in terms of business objects that will be common across oilfield companies, their applications, access software, data, or data stores.13,R14
Cocurrent and Countercurrent Imbibition in a Water-Wet Matrix Block
Authors: Pooladi-Darvish Mehran , Firoozabadi Abbas 
Published: December 2007

Summary
Imbibition in water-wet matrix blocks of fractured porous media is commonly considered to be countercurrent. The modeling studies of this paper indicate that when a matrix block is partially covered by water, oil recovery is dominated by cocurrent imbibition, not countercurrent. It is also found that the time for a specified recovery by the former can be much smaller than that by countercurrent imbibition. Consequently, use of the imbibition data by immersing a single block in water and its scale-up may provide pessimistic recovery information. Moreover, it is shown that the application of the diffusion equation for modeling of oil recovery by cocurrent imbibition leads to a large error. Through a detailed study of the governing equations and boundary conditions, significant insight is provided into the mathematical and physical differences between co- and countercurrent imbibition.
Sequential Semi-Implicit Algorithm for Computing Discontinuous Flows in Porous Media
Authors: Vegas-Landeau M. A. , Propp Rick , Patzek T. W. , Colella Phillip 
Published: December 2007

Summary
This paper presents a novel numerical algorithm for computing incompressible, discontinuous, two-phase flows in two-dimensional (2D), inhomogeneous, and isotropic porous media. The algorithm uses Bell et al.'s hybrid sequential semi-implicit approach1 for both accuracy and efficiency of the calculations. The explicit part uses a high-order Godunov2 scheme with a modified Van Leer geometrical slope limiter, similar to those used in shock dynamics. The implicit part is a two-step solver. The first step is a Crank-Nicolson saturation solver, and the second is a Poisson solver for the phase pressure. Both use fast, multilevel, multigrid solvers with the number of operations of the order of O[N log(N)], where N = number of gridpoints. Two numerically stiff reservoir engineering problems are presented to demonstrate the low numerical dispersion and second-order accuracy of our method.
Integration of a Field Surface and Production Network With a Reservoir Simulator
Authors: Hepguler Gokhan , Barua Santanu , Bard Wade 
Published: December 2007

Summary
Reservoir simulation studies allow engineers to identify development strategies that can maximize the economic recovery of hydrocarbon resources. During the life of a field, the reservoir engineer confronts numerous decisions about the placement and operation of wells for production or injection. Traditionally, engineers evaluate the costs and benefits associated with competing development strategies by using reservoir simulation tools in different scenarios. The numerical reservoir simulator is used in forecasting recovery of reserves under existing production schemes and in evaluating the effects of changing operating conditions. This approach limits the overall benefit of a field study because it does not consider the effects that flows in wellbores and surface facilities have on the economic performance of the recovery programs. Yet, the costs of compression, separation, fluid injection, or water treatment can have a significant effect on the success of production strategies. When the goal is to identify an optimal hydrocarbon-recovery scheme, a compelling case arises for the computational integration of subsurface- and surface-simulation technologies.
In this paper, we discuss an integrated computational solution for management of reservoir-production strategies and field development. The approach is implemented by coupling a reservoir simulator (Eclipse) with a surface and production network simulator and optimizer (Netopt). Parallel Virtual Machine (PVM) interface provides the coupling communication mechanism that integrates the two simultaneously running simulators. At each timestep, the network simulator and the reservoir simulator provide a consistent integrated solution after rate and pressure convergence is achieved within a predetermined tolerance.