bluuebunny/crossref_metadata_2025_split huggingface dataset:
Postfracturing Gas-Well-Test Analysis Using Buildup Type Curves
Authors: Walsh D. M. , Leung K. H. 
Published: December 2007

Summary
Well-specific buildup type curves that incorporate non-Darcy effects and real-gas properties were used to obtain better estimates of fracture conductivities and lengths from postfracturing well tests in the Ravenspurn South gas field. Well productivities were calculated from the fracture parameters and used to optimize further fracturing and field development.
Prevention of Downhole Scale Deposition in the Ninian Field
Authors: Shuler P. J. , Jenkins W. H. 
Published: December 2007

Summary
Conventional adsorption scale-inhibitor squeezes and newer equilibrium squeezes have successfully prevented downhole scale at the Ninian field. A mathematical model matched or underpredicted the lifetime of the adsorption squeezes. Underprediction probably resulted from the exclusion of real phenomena, such as fluid crossflow and inhibitor precipitation. Both the model and the field data suggest that the most important design factor that determines squeeze life is the total amount of scale inhibitor injected. Equilibrium squeezes use a unique product that yields a longer treatment lifetime when designed properly. This process is more difficult to implement; it requires careful planning and quality control to be successful.
Geostatistical Modeling of Transmissibility for 2D Reservoir Studies
Authors: Desbarats Alexander J. , Dimltrakopoulos Roussos 
Published: December 2007

Summary
A geostatistical approach is used to characterize reservoir transmissibility with the aim of assigning simulator parameters in 2D models. Transmissibility is represented as a spatial random function where heterogeneity is described by the probability distribution and the variogram of sample values. The key element of the geostatistical model is the definition of block transmissibilities as spatial geometric averages. Published analytical results have shown that the effective transmissibility of infinite, statistically isotropic flow fields is equal to the ensemble geometric mean. Numerical results presented here show that a spatial geometric average is an excellent approximation of effective transmissibility in such finite fields as simulator gridblocks. The geostatistical model for transmissibility is used to show that the mean and variance of block-averaged values depend on the averaging area. As the averaging area is increased, mean block transmissibility decreases toward the ensemble geometric mean while the block variance decreases to zero. The geostatistical model is also used to investigate the kriging of block transmissibilities from well data. The current method of correcting bias in kriged values is found to cause artifacts of gridblock size in flow simulation results. The simpler, uncorrected kriging estimator is shown to preserve overall flow-field transmissibility, regardless of gridblock size.
Minimize Formation Damage by Rapid, Inexpensive Method of Completion- and Stimulation-Fluid Selection
Authors: Underdown D. R. , Conway M. W. 
Published: December 2007

Summary
Minimizing or removing formation damage is a major objective in completion and stimulation operations. Formation damage is minimized by selection of "nondamaging" fluid systems and operations on the basis of petrographic analysis and field experience. A technique known as the capillary suction time (CST) test, adopted from the drilling-fluid industry, provides a quick and inexpensive method for qualitative selection or screening of the least damaging fluid system for a particular formation. The CST test is a fundamental filtration method for determining the electrolyte concentration that will produce the maximum inhibiting effect on a formation. The method uses an instrument to measure the time required for a liquid to travel a calibrated distance on a standard porous filter paper. The CST procedure currently is used very successfully to select completion fluids and to evaluate stimulation-fluid additives. This paper explains the procedure, discusses limitations of the test, and presents laboratory and field data to show the value of the technique.
Operational Review of a Large-Scale Saturated-Steam Delivery System
Authors: Schoen D. M. , Frazier T. L. 
Published: December 2007

Summary
Since initiation in the mid-1960's, steamflooding operations have become increasingly complex. Whereas saturated steam delivery systems were once designed simply to deliver steam from a generator to an injection well, the requirements placed on these systems today are significantly broader. A need exists for controlling and counteracting the effects of phase splitting, and the ability to measure and control mass and heat injection rates at the wellhead is increasingly critical for reservoir analysis and economic success. In addition, the introduction of cogeneration plants as major suppliers of steam has been accompanied with new singular problems and forced redesign of delivery and support equipment.
Several unique solutions have been developed to meet these challenges. A monitoring system comprising more than 300 pressure transducers allows determination of line velocities and mass rates within the steam transmission network and calculation of injection wellhead pressure. A technique to measure steam quality and mass flow rate accurately has been developed and adapted for use with both ongoing displacement and stimulation service.
An Algorithm for Determining Smooth, Continuous Pressure Derivatives From Well-Test Data
Authors: Lane H. Scott , Lee W. John , Watson A. Ted 
Published: December 2007

SummaryAn algorithm for determining pressure-derivative functions from measured well-test data is presented. The pressure data are fit with a spline function that can account for curve shape constraints. The first and second derivatives of the resulting spline function are calculated analytically and can be used for type-curve matching. Two examples illustrate the performance of the algorithm.
New Dimensions in Geophysics for Reservoir Monitoring
Authors: Greaves R. J. , Beydoun W. B. , Spies B. R. 
Published: December 2007

Summary
Advances in geophysical survey techniques have improved surface and borehole methods used for reservoir delineation and description. These same techniques can be used to map changes in reservoir conditions caused by various types of reservoir flooding. This paper discusses reflection and borehole seismic techniques and borehole electrical methods used for secondary and tertiary recovery. The unique aspect of geophysical monitoring is that the surveys are repeated during field development, so changes in geophysical response can be observed. These data can be interpreted by reservoir geologists and engineers to reveal the distribution of the production process and then used in production planning.
Using Artificial Neural Nets To Identify the Well-Test Interpretation Model
Authors: Al-Kaabi Abdul-Aziz U. , Lee W. John 
Published: December 2007

Summary
This paper presents a new approach, based on artificial neural net technology, to identify a preliminary well-test interpretation model from derivative plot data. Artificial neural nets can identify patterns from incomplete and distorted data and also eliminate the need for elaborate data preparation, such as smoothing.
An Expert System To Design and Evaluate Matrix Acidizing
Authors: Blackburn C. R. , Abel J. C. , Day R. 
Published: December 2007

Summary
An expert system called ACIDMAN was developed to design matrix acid treatments that remove damage near the wellbore and increase production. Input data can range from unknown formation damage, for which the system designs a conservative treatment based on well history and geological probability, to cases with detailed formation information available, in which very precise treatments are prescribed. The system requests additional specific laboratory tests, when needed, to aid in product selection. Basic input data requested include well type and history, formation-damage mechanism, bottomhole temperature, reservoir pressure, formation permeability, lithology, porosity, interval size, and crude oil gravity. Output includes product selection, additives, treatment volumes, and treatment technique. Phase 1 of the ACIDMAN expert system was delivered in beta test in March 1990, and full implementation of all phases is planned during 1990.
Total Connectivity Speeds Research and Support Of Field Operations
Authors: Himes R. E. , Frost K. I. , Henry S. R. , Funkhouser J. D. 
Published: December 2007

Summary
Research and field support roles in the oilfield service industry have become increasingly complex in the last 15 years. Experimental apparatus are more dependent on the data-acquisition and processing capabilities of computers as the amount of data generated increases. Therefore, the need to network these computers for data transport has significantly increased. The type of network system selected depends on the goals to be achieved. Incorporation of existing equipment, communication between systems of different architectures, and future expandability are only a few of the necessary attributes. With these in mind, a computer network system was designed and is being implemented. The system combines local- and wide-area networks (LAN's or WAN's) of different protocols to acquire, process, and transport information worldwide. The result is faster development of new products and quicker response in support of field operations.
Use of a Relational Database on a PC Network for Reservoir Studies
Authors: Harwell D. C. , Hyche N. K. , Harmon R. A. , Wentz R. M. 
Published: December 2007

Summary
The prevelant trend in the petroleum industry regarding field development has incorporated a synergistic approach toward evaluating reservoirs. In Aug. 1988, Conoco’s Casper Div. took this approach of integrating the geoscience and engineering disciplines by creating four EOR study teams. Their mission was to determine the economic feasibility of CO2 injection, to improve secondary recovery operations, to increase operating gain, and to identify areas with development potential in preselected reservoirs. As part of this team concept, a computer network was created to assist the engineers and geologists in compiling and processing the massive amounts of data needed for the reservoir studies. The network was designed with data bases distributed among multiple servers. In essence, this network provides a "reservoir evaluation workstation, " which can be used interactively from each individual’s office. A wide range of software programs (i.e., interpretation tools) can be accessed with direct ties to the project data base. The network effectively connects PC’s, data bases, and a MicroVAX III computer into one integrated system.
Using a PC To Process MRI Data
Authors: Halimi H. I. , Capps K. , Poston S. W. 
Published: December 2007

Summary
Nuclear magnetic resonance (NMR) imaging techniques are used to measure changing fluid saturations and relative permeabilities in porous materials.1, 2 The recorded signals are a measure of the volumes of the fluids residing in the pore spaces.3’4 A technique coupling public-domain image processing programs with in-house programs for downloading and interpreting NMR data has been developed at Texas A&M U. The new method permits a PC or Macintosh II computer system to be used in place of the more sophisticated and expensive graphics workstations. Raw NMR data files are downloaded by a parallel to serial link as 256 × 256 matrices of positive even integers. In-house developed C programs are used to convert the text files to binary data to reduce both storage requirements and image noise level. An interactive portion of the program permits the operator to choose the level where the good data start. These data are then extracted and processed into colored images. The extracted data are divided by 256 and a color table ranging from 0 to 255 is arranged. The end points are quantified by measuring these saturation values during the experimental run. The data are stored in binary form once a color has been assigned to each pixel. The process of converting the NMR files to binary files and assigning colors to the pixels takes 90 to 120 seconds of computer time. This process produces images with sufficiently good resolution to show saturation fronts and to distinguish features within the image.
Pre- and Postprocessing for Reservoir Simulation
Authors: Rogers W. L. , Ingalls L. J. , Prasad S. J. 
Published: December 2007

Summary
This paper describes the functionality and underlying programming paradigms of Shell’s simulator-related reservoir-engineering graphics system. This system includes the simulation postprocessing programs Reservoir Display System (RDS) and Fast Reservoir Engineering Displays (FRED), a hypertext-like on-line documentation system (DOC), and a simulator input preprocessor (SIMPL-SIM). RDS creates displays of reservoir simulation results. These displays represent the areal or cross-sectional distribution of computed reservoir parameters, such as pressure, phase saturation, or temperature. Generation of these images at real-time animation rates is discussed. FRED facilitates the creation of plot files from reservoir simulation output. The use of dynamic memory allocation, asynchronous I/O, a table-driven screen manager, and mixed-language (FORTRAN and C) programming are detailed. DOC is used to create and access on-line documentation for the pre- and postprocessing programs and the reservoir simulators. DOC can be run by itself or can be accessed from within any other graphics or nongraphics application program. DOC includes a text editor, which is the basis for a reservoir simulation tutorial and greatly simplifies the preparation of simulator input. The use of sharable images, graphics, and the documentation file network are described. Finally, SIMPLSIM is a suite of programs that uses interactive graphics in the preparation of reservoir description data for input into reservoir simulators. The SIMPLSIM user-interface manager (UIM) and its graphic interface for reservoir description are discussed.
Field Testing of Low-Friction-Gauge PDC Bits
Authors: Sinor L. A. , Brett J. F. , Warren T. M. , Behr S. M. 
Published: December 2007

Summary
This paper presents the results of developmental work applied to modify "off-the-shelf polycrystalline-diamond-compact (PDC) bit designs to incorporate low-friction-gauge technology. The low-friction gauge limits harmful bit-whirl tendencies by directing the radial bit imbalance to a gauge pad that makes smooth sliding contact with the wellbore wall. Field testing indicates that use of a low-friction gauge improves bit life and rate of penetration (ROP).
Successful Flow Testing of a Gas Reservoir in 3,500 ft of Water
Authors: Shaughnessy J.M. , Carpenter R.S. , Coleman R.A. , Jackson C.W. 
Published: December 2007

Summary
This paper reviews the planning and implementation of a flow test of a gas reservoir, including the general goal of the test, equipment used, problems anticipated, and the steps to minimize or to avoid problems. The well successfully tested at rates of 22.5 MMcf/D and 2,670 B/D condensate with a 2,800-psi flowing tubing pressure through a 46/64-in. choke for 4 days.

Introduction
The test of Viosca Knoll Block 957 Well No. 1 Sidetrack No. 2 was Amoco Production Co.'s deepest test from a floating rig. Viosca Knoll 957 is 115 miles southeast of New Orleans in 3,500 ft of water. The test, at a record water depth for the Gulf of Mexico, also set a world water-depth record for testing a gas reservoir.
Safety to crew and the environment were top priorities during the planning. A team consisting of drilling, completion, reservoir, and facilities engineers and a foreman were assigned to plan and implement the test. Early planning involved field, service company, and engineering groups. Every effort was made to identify potential problems and to design the system to handle them.
The goals of the test were to determine reservoir properties and reservoir limits. Several significant challenges were involved in the well test. The reservoir was gas with a potentially significant condensate yield. The ability to dispose of the large volumes of produced fluids safely without polluting was critical to maintaining uninterrupted flow. Potential shut-in surface pressure was 6,500 psi. Seafloor temperature in 3,500 ft of water was 39F. Preventing gas hydrates was a major problem. The inhibition was Preventing gas hydrates was a major problem. The inhibition was done by chemical injection into the flow stream before the gas and condensate reached ambient seafloor temperature. The ability to acidize was necessary. Optimum reservoir evaluation required varying the lengths and rates of the flow periods and shut-in times. During startup, hydrate inhibition was critical and a large volume of fluids in the surface tanks, both the tubing volume and produced fluids, required significant handling and proper disposal. produced fluids, required significant handling and proper disposal.
The well tested was the third sidetrack from a wellbore spudded in Jan. 1989 by the drillship Discoverer 534. Initial plans were to test the second sidetrack from the drillship in the spring, but a third sidetrack was added to the drilling program and the drilling was prolonged into the summer. Rather than begin testing operations in July, a decision was made to move the drillship off location and to bring back the ship or another rig after hurricane season. The time required to secure the ship for a hurricane when in the testing mode would require beginning to secure when the potential storm was at least 750 miles away (mid-Cuba). This was not considered practical; therefore, Penrod 78 was moved to location in late October after Hurricane Penrod 78 was moved to location in late October after Hurricane Jerry.
Multiwell, Multilayer Model To Evaluate Infill-Drilling Potential in the Oklahoma Hugoton Field
Authors: Fetkovich M. J. , Ebbs D. J. , Voelker J. J. 
Published: December 2007

Summary
A 3D simulation was conducted on a portion of the Oklahoma Hugoton gas field to evaluate infill-drilling potential. The impor- tance of understanding the behavior of layered, no-crossflow reservoirs is emphasized by matching detailed performance histories. Further insight into this long-lived field is obtained by forecasting performance, both for continued current operations and for infill drilling on each proration unit.
Flexible Riser and Mooring System Develops Small Oil Fields in the North Sea
Authors: Thompson A. M. , Holmes G. A. A. H. , Benstead P. J. 
Published: December 2007

Summary
The flexible riser and mooring system (FRAMS) provides a technically straightforward, commercially attractive method of developing small oil fields. A passively moored 60, 000-deadweight-ton (60, 000-DWT) tanker with deck-mounted equipment provides a swivelless well fluid and injection water path from and to the wellheads. The system can be disconnected rapidly in severe weather.
Technical Requirements for GOC Monitoring in Horizontal Wells by Direct-Arrival Travel-Time Inversion
Authors: Elde Rigmor M. , Mæland Einar , Petersen Steen A. 
Published: December 2007

Summary
This paper describes a theoretical study of the technical requirements for gas/oil contact (GOC) monitoring in horizontal wells. The goal is to detect changes in the velocity field related to the GOC in a producing reservoir. Examples are based on synthetic travel-time data. The necessary accuracy of location of the source and the receiver is determined so that a difference in the observed travel time can give information about the GOC displacement.
Mobility Control for Steamflooding With High-Temperature-Resistant Additives
Authors: Stoll R. D. , Gudenau H. W. , Lupik M. W. 
Published: December 2007

Summary
Steamflooding efficiency can be increased by foaming injected surfactants in deoiled reservoir zones to divert steam into higher-oil-saturation zones. The purpose of this project is to develop test facilities (static tests and flooding trials) to check the applicability of various high-temperature-resistant surfactants at temperatures up to 572°F.
Sulfonate Retention by Kaolinite at High pH—Effect of Inorganic Anions
Authors: Bavière Marc , Ruaux Eliane , Defives Daniel 
Published: December 2007

Summary
At high pH and with surfactant concentrations well above the critical micelle concentration (CMC), the pH-dependent part of adsorption is small. Retention depends especially on the sodium-ion activity and on the type and valence of inorganic anions. As the anionic charge increases, adsorption at a given ionic strength decreases. This behavior correlates with the effect of anions on the sulfonate activity in solution.
Interpretation of a Pulse Test in a Layered Reservoir
Authors: Kaneda Ryuzo , Saeedi Jawaid , Ayestaran Luis C. 
Published: December 2007

Summary
An interwell pressure test, designed and implemented as a pulse test, was performed in the Arab zones of an offshore field in Abu Dhabi. The interpretation of three pulses yielded inconsistent results for transmissibility and storativity. The pressure response data were interpreted with a two-layer analytical model after a numerical simulator was used to modify the pressure response for the interference from a third well. The two-layer analytical model provided an excellent match of the modified pressure response. We conclude that conventional pulse-test interpretation methods cannot be satisfactorily applied to the pressure response in a two-layer system.
Immiscible CO2 Process for the Salt Creek Field
Authors: Bargas C. L. , Montgomery H. D. , Sharp D. H. , Vosika J. L. 
Published: December 2007

Summary
An immiscible CO2 flooding process was investigated for use at the Salt Creek field, WY. This proposed process with CO2 slug and 100% carbonated chase water may recover an incremental 8.6% original oil in place (OOIP). However, tertiary recovery of this light crude is sensitive to the reservoir crude composition, temperature, and pressure. Initial studies and simulations led to a proposed process pilot.