bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Field-Scale, Three-Dimensional Simulator for Thermal Oil Recovery
Authors: Dogru A. H. , Odeh A. S. , Jines W. R. 
Published: December 2007

ABSTRACT
This paper describes a field-scale, three-dimensional thermal simulator, THERMS. THERMS is primarily used to design and predict the performance of steam flooding and in-situ combustion of oil. In addition, hot water or gas injection can be simulated. The model has been designed to handle large-scale thermal field projects. A novel numerical solution has been developed which allows THERMS to simultaneously simulate thermal pilots at different locations together with the remaining areas of the reservoir. This feature enables the model to properly account for the interaction between the pilot and its surroundings, which is necessary for reliable simulation results.
THERMS treats the burning front, in the in-situ combustion process, as a moving heat source. A special flow enhancement algorithm is used to maintain the fuel consumption at the laboratory measured value, if so desired. Detailed kinetics and thermodynamics relations are not treated. Thus, THERMS is best suited for in-situ combustion of heavy oil in contrast to light oil.
Numerically, THERMS' algorithm is strongly coupled and fully implicit which gives it the required stability to simulate difficult reservoir conditions. A nine-point finite difference formulation option significantly reduces the grid orientation effects. THERMS can run in a scalar or vector mode.
Simulation of a 12-Pattern Field Trial of Light Oil Steamflooding
Authors: Blunschi J. H. 
Published: December 2007

ABSTRACT
As part of a field trial of light oil steamflooding in the Buena Vista Hills Field, California, a simulation study was undertaken using a compositional thermal simulator. The objectives of the study were to quantify the influence of reservoir heterogeneity on recovery and to predict size and location of a solvent bank during the field trial.
Two simulation models were constructed, consisting of a 4-component oil and detailed grid systems sufficient to describe the recovery processes. A 2300-cell, 4-layer model of 12 inverted five-spot patterns and one row of adjacent patterns surrounding the pilot allowed the study of the influence of heterogeneity on recovery. A 1900-cell, fractal model of 1/8 of a confined five-spot was used to examine the development of the solvent bank. Both models were history matched with the first 14 month of injection/production data from the pilot.
A high permeability zone and high pore volume compressibility were identified as major controls on recovery. Different arrival times of solvent banks at the producers and vertical trapping of oil makes the detection of solvent banks at the producers difficult. Prediction runs with the history matched model indicated a poor prospect for a hot water after steam flood.
Reservoir Description From Seismic Lithologic Modeling: Part 2—Substantiation by Reservoir Simulation
Authors: de Buyl M. , Ullah S. , Guidish T. 
Published: December 2007

Abstract
Two independently derived reservoir models of a stratigraphically complex oil field in Alberta, Canada, were used as the bases for reservoir simulation and history-matching. This study is an attempt to compare the applicability of each method for obtaining a reliable description of the reservoir.
As discussed in paper SPE 15505, the first reservoir model was based on log and core data from six producing and two dry wells drilled within a portion of the field on which a 3-D seismic survey had been acquired; the second reservoir model was developed by supplementing well data with petrophysical parameters derived from seismic lithologic modeling of the 3-D seismic reflection data.
Using structure and net porosity-thickness models developed by these two approaches at two different stages of the field development drilling, history-match calculations of water cut were made on each model using the limited reservoir production and pressure history available to date. The results suggest that the seismically enhanced reservoir model produces a more accurate simulation of the observed performance than that achieved with a "conventional" reservoir model based solely on well control. This observation is particularly true at earlier stages of development drilling when inadequate reservoir descriptions can be produced based on limited well control. This study supports the potential technical benefit of using 3-D seismic data to obtain an improved reservoir description and thereby, lead to improved design of field development and operational programs.
A Method for Pressure Buildup Analysis of Drillstem Tests
Authors: de Franca Correa A. C. , Ramey H. J. 
Published: December 2007

ABSTRACT
Analysis of the pressure response obtained from a drill stem test (DST) provides important additional information for deciding whether it is economical to complete a well.
Interpretation of DST pressure buildup data has been based on the Horner method. The basic assumption of the Horner method is that the well is produced at a constant rate before the shut-in. When rate changes with time, a cumbersome application of the superposition principle is required to analyze the pressure buildup data.
Furthermore, the solution of the diffusivity equation for a constant production rate gives a declining flowing pressure with time, but most DST's show an increasing flowing pressure during production. Therefore, the application of the Horner method may lead to inconsistent results in the interpretation of DST pressure buildup data.
An original approach was used to model the DST problem. A DST can be characterized as a changing wellbore storage problem following an instantaneous pressure drop at the well. During production the wellbore storage coefficient is given by the rate of fluid accumulation inside the wellbore. After the shut-in of the well the wellbore storage mechanics change due to the compressibility of the fluid below the bottom hole valve. Therefore, using this concept, the flowing and the pressure buildup phases are modeled with a single inner boundary condition.
In this paper an analytical solution correct for both the flowing and shut-in periods was obtained by solving the diffusivity equation with a single inner boundary condition which included the mixed conditions for flow and buildup. Both a skin effect and wellbore storage were considered. Solution was obtained by Laplace transformation.
The solution was used to develop methods of interpretation for the pressure buildup period of drill stem tests. Application of these new methods of interpretation to DST field data may provide the initial reservoir pressure, the formation permeability and the skin effect. The interpretation methods are based on graphical analysis of the data and are easily applied in the field.
The interpretation methods are generalized to include multiple production-shut-in cycles, including step changes in the wellbore storage coefficient due to changes in the drill pipe diameter and/or due to variations in fluid properties.
Unlike the results obtained from the application of the Horner method, interpretation of field data using these new methods show excellent agreement between the parameters obtained from the analysis of the first and second shut-in periods of short term double-cycled DST's.
Field examples are presented.
Bright Lights on Petroleum Technology
Authors: Mills R. C. 
Published: December 2007

ABSTRACT
The existing downturn in the oil and gas industry and uncertainties of future events demand the use of new and evolving technologies to more accurately identify prospects and economically develop the more remote, presently unproducible reserves. Inventiveness in solving exploration and development difficulties is not new to our industry but the less attractive, unstable market climate of today calls for imaginative approaches to conducting our business. The development and application of a wide array of sophisticated technologies will be the hallmarks of the successful companies in future decades.
Technical Personnel Development in a Period of Scarce Resources and High Uncertainty
Authors: Donohue D. A. T. , Lang K. R. 
Published: December 2007

ABSTRACT
Now that the serious staff reductions have taken place and morale is beginning to return; and now that crude prices are still very uncertain, but we are gaining confidence that the oil industry will survive; it is time to consider the petroleum engineering training and development needs of the future. In this paper we begin with statistical information on the petroleum engineer, including recent changes in population and age distribution. Then, using the results of a questionnaire submitted by 17 operating oil companies, we summarize the expected increase in petroleum engineers in the period 1987-90, the key areas of training and development that are expected to be needed during the next three years, and the principal method of delivering such training. Finally, we comment on ways in which companies can achieve better performance from its engineers during periods of limited staff size and an uncertain economic environment.
Carbonated Waterflood Implementation and Its Impact on Material Performance in a Pilot Project
Authors: Blackford T. A. 
Published: December 2007

ABSTRACT
Carbonated waterflooding is an enhanced oil recovery process developed in the early 1950's that may have potential application in several West Texas reservoirs. The process consists of saturating injection water with CO2 in order to swell the remaining oil-in-place, and thereby increase the amount of recoverable oil in a reservoir. The process usually involves less investment and CO2 demand than miscible CO2 flooding.
The effects of carbonated waterflooding on equipment material performance were monitored during a two well carbonated water injection pilot test conducted by Amoco Production Company in the Slaughter Field, Hockley County, Texas. Stainless steel and aluminum bronze material showed no deterioration during the test period. However, severe problems were encountered at holidays in the internal plastic coating of carbon steel pipe and fittings. Injection well material performance data and observations are presented to support these findings. In addition, the surface equipment design used to saturate injection water with CO2 will be presented. No attempt will be made to discuss the impact of carbonated waterflooding on injection well or reservoir performance.
The Perils of Market Value Averages
Authors: Diggle F. J. , David A. 
Published: December 2007

ABSTRACT
Although knowledgeable purchasers buy oil and gas properties at a price to meet hurdle rates of return, there Is a great deal of Interest to both buyer and seller in what the current "market" is for the purchase or sale of properties. Measures of market value for oil and gas properties include such traditional yardsticks as dollar per barrel-oil-equivalent ($/B0E), risked present worth (PW), three year cumulative cash income, and present worth discounted at various rates.1 In this paper, we examine some of these yardsticks with a focus on actual figures. Additionally, the gap between prices that buyers are willing to pay for smaller and larger properties is examined.
Infill Drilling Economic Analysis of Carbonate Oil Reservoirs in West Texas
Authors: Laughlin B. A. , Jardon M. A. , Wu C. H. 
Published: December 2007

ABSTRACT
This paper presents the results of an economic analysis of infill drilling in 16 carbonate oil reservoirs located in West Texas. The economic analysis included the evaluation of incremental waterflooding recovery over primary and infill drilling recovery over initial waterflooding.
Because of limited field and economic data available for this study, many assumptions were made to complete the economic evaluations. Two major cases of economic evaluation were performed: Case I used the past production and economic data to 1986 and the projection of these data from 1986 on to the assumed economic limit, and Case II used the past infill production data as if the projects were initiated in January 1986 and on to the assumed economic limit.
Results showed that about 68% of the infill drilling projects studied had an infill drilling incremental payout of less than two years with an incremental discounted cash flow rate of return greater than 20%. Only 3 7% of the projects studied had a waterflood incremental economics with the same criteria. Decreasing the well spacing generally decreased the infill drilling incremental payout and increased the incremental cash flow rate of return. As the OOIP/WS (well spacing) increased, the general trend showed an increasing infill drilling incremental net present value.
Results from Case II studies showed that for a $15/STB ($94/m3) oil price in 1986, about 68% of the infill drilling projects studied had an infill drilling incremental payout of less than two years with an incremental discounted cash flow rate of return greater than 20%. As the OOIP/WS increased, the general trend also showed an increasing infill drilling incremental net present value. When the oil price in 1986 was increased from $15/STB ($94/m3) to $25/STB ($157/m3), the increase in the incremental net present value (INPV) was substantial. For example, at a value of 20 for OOIP/WS (Means Field/San Andres), the INPV increased from $76 MM to $122 MM.
Numerical Simulation of Gas Drainage From Coal Seams
Authors: Spencer S. J. , Somers M. L. , Pinczewski W. V. , Doig I. D. 
Published: December 2007

ABSTRACT
A rigorous two-phase, three dimensional numerical simulator for water and gas drainage from coal seams is presented. The coal seam is modelled as a duel porosity system in which the cleat is represented by a macropore or fractured network which allows two-phase flow of gas and water to degasification wells. Flow in this network is modelled in terms of Darcy's law with allowance for a Klinkenberg type correction for gas slippage. Both permeability and porosity may be specified as functions of seam stress.
A micropore network allows diffusion of gas desorbed from the coal matrix to enter the macropore system. The desorption process is modelled on the basis of equilibrium Langmuir isotherms and desorption rate is calculated from a numerical solution of a transient diffusion problem in characteristic microspheres. Comparison of the model with previously published models based on a simpler quasi-steady state assumption for the gas desorption process suggests that the quasi-steady state assumption is not generally applicable for simulation of coal seam drainage. The model is demonstrated to be a useful tool both in interpreting results from laboratory scale gas drainage experiments and in evaluating the performance of field scale drainage and gas production developments.
In-Situ Seismic Monitoring EOR: The Petrophysical Basis
Authors: Nur A. M. , Wang Z. 
Published: December 2007

SUMMARY
This paper presents laboratory experimental results on wave velocities in hydrocarbons, rocks and sands versus saturation, pore and confining pressures, temperature, and CO2 content. The results suggest that seismic, especially high resolution seismic methods can be used in detecting anomalous pore pressures, tracking thermal fronts and mapping high temperature regions in thermal EOR processes, and monitoring CO2 flooding and water flooding processes in reservoir insitu. However, much of the methodology and technology required still remains to be developed before routine field applications can be made.
Gullfaks Subsea Wells: An Operator's Implementation of a New Sand Production Prediction Model
Authors: Massie I. , Nygaard O. , Morita N. 
Published: December 2007

SUMMARY
Early studies concerning the sand producing tendencies of the Gullfaks reservoirs concluded that wells should be completed with sand control measures from the start of production. Results from a newly developed Computer Based Sand Production Prediction Model indicated that the Rannoch sands could be produced sand-free through natural completions. Specific guidelines must be followed in the design of the completion and also included in the reservoir management programme. The production phase of Gullfaks commenced with 4 subsea production and one subsea injection well, completed by selective perforation with high completion efficiency. The model prediction of no sand production has been confirmed by results from all wells after 6 months of production. This paper reviews the field implementation of the guidelines from the model for the 4 subsea wells completed in the Rannoch sands.
Hydraulically Fractured Gas Well Productivity Modeling
Authors: Nierode Dale E. 
Published: December 2007

ABSTRACT
The validity and sensitivity of using a fracture geometry model in combination with a finite difference reservoir simulator for the analysis of fractured gas well productivity are examined in this paper. The validity of combining the Khristianovich-Zheltov1,2 fracture growth model with a single phase, gas reservoir simulator is established by comparing field data in low, moderate, and high permeability gas reservoirs with calculations. It is shown that all aspects of well behavior including drawdown, buildup, production flowmeter, core data, and finite reservoir size can be quantitatively modeled. The sensitivity, or uniqueness, of the fit to field data is demonstrated by computer-generated studies of a typical 2-dimensional-acting gas well, and by a similar analysis applied to one of the field data sets.
The paper contains a complete set of data for four wells that were fractured with eight fracture treatments. The data are in a form that can be readily used by anyone wishing to apply an alternative analysis. It is concluded from the evaluations in this paper that a 2-dimensional fracture shape model is adequate to quantitatively describe fracture dimensions for use in either long-term well productivity extrapolations or in optimal fracture treatment design.
Control of Microbiologically Influenced Corrosion in Oilfield Production Equipment
Authors: Littmann E. S. 
Published: December 2007

ABSTRACT
Microbiologically influenced corrosion (MIC) is rapidly becoming one of the most researched areas of corrosion science.
Despite this research there have been relatively few case histories published where MIC was shown to be the major cause of corrosion in oil production equipment.
This case history describes a large oil producing system that once had an extensive history of no corrosion related problems in the production equipment. Shortly after a polymer flood was initiated, some wells began to encounter severe corrosion problems. Standard corrosion control programs were not successful in controlling the problem and laboratory analysis run on deposits strongly suggested MIC.
The corrosion related problems were finally controlled with a nonionic, nonsurface active biocide. The success of this product further validates the conclusion that the well failures were due to MIC.
A New Model for Studying Oilwell Pumping Installations
Authors: Chacin J. E. , Purcupile J. C. 
Published: December 2007

ABSTRACT
A digital discrete model, similar to the analog model investigated by Midwest Research, has been developed to study pumpoff, pumping with anchored tubing, and gas interference downhole conditions. The calculated surface dynagraphs are presented for unanchored tubing, anchored tubing, 60% gas interference, 20 gas interference, and 80% pumpoff.
This model is similar to the analog model pioneered by Howe and Midwest Research. However, because it uses a digital simulation, a wide variety of downhole conditions can be modeled. The upper limit on the frequency of this model (which also applies to RP11L calculations) is also presented.
Compositional Two-Phase Vertical Lift Performance Modeling of Crude Oil and Retrograde Gas-Condensate Wells
Authors: Salisburg P. E. , Peden J. M. 
Published: December 2007

ABSTRACT
Estimation has been made of the applicability and reliability of five well known oil well pressure drop prediction methods and for each method guidelines are presented concerning their accuracy as a function of flowrate, tubing size, liquid velocity, water cut and wellbore angle of deviation. New methods are presented for modelling pressure loss in retrograde gas-condensate wells. These methods employ redefined flow pattern map boundaries based upon the utilisation of available well test data and are superior in accuracy to existing multi-flow regime and no-flow regime, methods of interest. Fourteen crude oil compositions, five retrograde gas-condensate compositions and a total of 102 welltest pressure surveys from a wide range of North Sea fields are used to ascertain the suitability of the correlations. The fluid PVT properties are generated by the Peng Robinson equation of state and the Schmidt Wenzel equation of state is employed for improved liquid density predictions. Generally, the predictions compare most favourably with laboratory measured data. In addition, full consideration of transient heat-transfer to the formation is included in the modelling.
Gas Pulsation Analysis by Portable Computer
Authors: Davis B. J. , Whitman S. K. 
Published: December 2007

ABSTRACT
Pipeline pulsation frequencies can be qualified, quantified, and recorded using a portable computer, an analog to digital converter board, and sophisticated commercial data acquisition and fourier transformation software, along with proprietary data manipulation programs. This newly developed hardware/software combination has many advantages over alternative pulsation detection systems, including the ability to record, on-site, the pulsation waveform for analysis used in designing attenuating acoustical filters. Case Histories illustrate the system's use.
Perforating the Horizontal Well: Designs and Techniques Prove Successful
Authors: Weirich J. B. , Zaleski T. E. , Mulcahy P. M. 
Published: December 2007

ABSTRACT
The application of well servicing equipment to that of horizontal well completions present specific design considerations that do not arise in the norm of conventional well completions. Although tubing conveyed perforating has been most suited to highly deviated wells and long intervals, horizontal well designs must consider other factors. Short radius turns, long measured depths and extended pay intervals give rise to mechanical complications while running the guns, obtaining an underbalance, detonating the charges, and removing the guns from the well. Addressing reservoir characteristics by selecting perforation geometry and shot orientation is also an integral phase in the completion design. The judicious utilization and application of perforating equipment will result in the primary objective of optimum production.
Gravel Packing of Horizontal Wells
Authors: Dickinson W. , Anderson R. R. , Dickinson W. , Dykstra H. 
Published: December 2007

ABSTRACT
One hundred percent gravel packing of horizontal wells has been demonstrated in the laboratory using bidirectional (two lift), water slurrified gravel packing. The first lift provides 70–90+% fill. A second, subsequent, reverse direction lift provides both 100% fill and consolidation. Deviation has been varied from 70° to 110°; the process is self-regulating.