bluuebunny/crossref_metadata_2025_split huggingface dataset:
Teamwork and Technique: Keys to Record Well in Roger Mills County, Oklahoma
Authors: White R. L. , Jolley G. M. , Hampton S. D. 
Published: December 2007

ABSTRACT
Tenneco Oil Company generated a prospect in Western Oklahoma that was not economically viable at the current projected drilling costs. This paper presents an innovative drilling contract and aggressive techniques utilized to make the prospect economical. The drilling contract created a teamwork atmosphere between the contractor and operator that resulted in a safe and record setting 13,380’ well.
Accurate Flow-Out Measurements for Kick Detection, Actual Response to Controlled Gas Influxes
Authors: Orban J. J. , Zanker K. J. 
Published: December 2007

Abstract
Early reliable detection using delta-flow offers the best approach to reducing the hazard associated with well kicks.
This paper describes the performance of a recently introduced return-line flowmeter for kick detection.
Controlled gas kicks were generated in a 1000 meter (3300 ft.) well and measurements performed. With the use of the new flow-out sensor, kicks were always detected a few minutes after the kick started downhole.
The new flow sensor allows direct measurement of influx during a "flow check" procedure.
This accurate flow-out measurement, together with the traditional flow-in evaluation from a pump stroke counter, is sufficient for kick or loss detection on most rigs when associated with continuous trend analysis of the variations in the ratio between flow-in and flow-out.
Expansion: Anti-Fluid Migration Technology Solves South Texas Fluid Migration Problems
Authors: Bour D. L. , East L. E. 
Published: December 2007

Abstract
Pressurized sands from water disposal caused corrosion problems in a south Texas production field. New casing strings were cemented inside older strings which had parted or had developed holes at the water disposal zone. Various cement blends were used, but one was especially successful in preventing annular invasion of the corrosive brine. The blend incorporated a chemical expansive admixture along with a unique and new anti-fluid migration additive. Cement blends of this type were used to cement these problem wells with excellent results. New wells in this area were also successfully cemented with the same type of blend, yielding excellent bond logs across the troublesome water zone.
Detailed information is given describing the various properties of the cement slurry. Case histories are presented detailing the problem and success of the special cement slurry.
Inflatable Packers: Production Application
Authors: Walsh M. D. , Holder D. J. 
Published: December 2007

Abstract
A retrievable packer and bridge plug have recently been developed which are designed to be run with coiled tubing for production operations. This 3.375-inch [8.573 cm] OD tool (reference is to packers and plugs collectively) is set and released within coiled tubing's pressure and pull limitations. An inflatable packing element is inflated with pumped fluids and is used as an anchor and seal. The inflatable element allows passage of the tool through tubing restrictions and can then be inflated and set in casing up to 7-inch [17.78 cm].
The authors have been associated with 29 jobs in the West Operating Area of Prudhoe Bay utilizing these tools. These tools have proven effective in their primary application of mechanical isolation for selective zone stimulations through coiled tubing. This paper provides a discussion of the tool, insight from the authors' experience into the application and limitations of these useful tools, as well as operational guidelines developed for their running and retrieval in production applications.
Accurate depth control is a concern when small intervals are available for setting. Elongation of coiled tubing under the pressures required for setting these tools is discussed. Operational guidelines are presented for determining length changes as a function of depth and pressure to ensure accurate control of setting depths. Depth control procedures presented here have permitted the setting of these tools within 15 inches [38.1 cm] of target at depths over 10,000 feet [3048 m] in deviated wells under favorable completion conditions.
Brief discussions of cost benefits and downhole injection chokes are also included.
Field Measurement of Viscosified Fluids
Authors: Hashemi R. , Caothien S. , Rovig J. 
Published: December 2007

ABSTRACT
Oilfield polymers such as HEC (Hydroxyethyl Cellulose) and Xanvis™ (Xanthan Gum) solutions are filtered to remove microgels and minimize formation plugging. Mechanical and hydraulic shearing of the gel alter the rheology of the polymers. Field data on various concentrations of HEC and Xanvis show the effects of each shearing mechanism on polymer viscosity, sand fall rate, and leakoff. A guideline for the on-site evaluation of the quality of sheared and filtered HEC is presented so that excessive shearing and unnecessary degradation of the gel can be recognized and prevented.
Don't Forget Consolidation
Authors: Beatty W.A. 
Published: December 2007

This paper was prepared for the SPE Symposium on Mechanical Engineering Aspects of Drilling and Production to be held in Fort Worth, Tex., March 5–7, 1967. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon requested to the Editor of the appropriate journal, provided agreement to give proper credit is made.
Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers Office. Such discussions may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
Proper application of lease consolidation and commingling methods can provide significant reductions in investment and operating costs for oil producing properties. Advantages, limitations, and possible dollar savings of various field proven consolidation methods and L.A.C.T. systems are reviewed.

Introduction
A continuous search for more efficient oil production methods has been necessitated by the ever increasing cost of labor and materials. Consolidation of oil producing properties is one important cost cutting method often overlooked. L.A.C.T. opened the door for consolidation/commingling applications by providing an accurate and dependable means of continuously metering and delivering oil from the producer to the purchaser. However, sufficient savings are seldom realized by L.A.C.T. alone unless utilized as an integral part of consolidation. Conversely, lease consolidation can be accomplished without L.A.C.T., but such applications are rare. Field proven consolidation methods will be described and the benefits, savings and limitations discussed.

METHODS
For the purpose of this paper, consolidation/commingling techniques will be divided into two general methods: the Multi Custody Transfer method in which crude from two or more leases is commingled after sale by the producer and the Single Custody Transfer method in which the crude is commingled at some point prior to sale. The orderly development from basic to more complete consolidation will become apparent as the two methods are discussed.
Multi Custody Transfer: The flow pattern for this basic consolidation method is illustrated on Plate No. 1. Production from each lease or zone is transported by individual flow line to a centralized battery site, treated by a separate treater and stored in separate tanks. A multi lease automatic custody transfer unit delivers the oil from the individual lease storage tanks to the pipe line and records the volume on the L.A.C.T. master meter register and the appropriate lease oil registers.
Analysis of Computational Procedures for Multicomponent Flow in Pipelines
Authors: Goyon J. C. , Shoham O. , Brill J. P. 
Published: December 2007

ABSTRACT
The compositions of vapor and liquid phases of a multicomponent system are functions of pressure and temperature. Therefore, the phase behavior of a fluid transported through a pipeline must be coupled to the pressure-temperature calculation algorithm. Both the Soave Redlich-Kwong and the Peng-Robinson EOS’s were considered.
A new procedure to calculate pressure and temperature profiles for multicomponent two-phase flow in pipelines was developed. This method, based on direct flash calculations at each pressure and temperature of interest, was compared to the method used by previous investigators based on interpolation of external arrays of physical properties.
The new procedure was found to be more accurate and easier to use than the one based on interpolation of external arrays. This was especially true when calculations were performed near the critical point.
The Use of Systems Analysis in the Design of a Gas-Lift System
Authors: Stinson R. 
Published: December 2007

ABSTRACT
This paper deals with the use of the total system approach in the evaluation and design of a gas lift system for a single or multiwell system. Computer generated analysis are used to demonstrate the effects tubing size, gas injection pressure and separator pressure have on production rates and gas volume requirements for wells within the system. The effects of gas injection volume, compressor suction pressure and discharge pressure on compressor horsepower requirements are considered in analyzing the gas lift system design. The evaluations in this paper are based on a group of wells with similar reservoir characteristics. The analytical techniques shown in this paper would be applicable for the analysis and design of a larger type system incorporating wells with varrying production capabilities.
Pressure Pulsing Waterflooding in Dual Porosity Naturally Fractured Reservoirs
Authors: Peng C. P. , Yanosik J. L. 
Published: December 2007

ABSTRACT
Conventional waterflooding in naturally fractured reservoirs can be uneconomic due to poor oil recovery performance. A technique to improve the oil recovery performance is pressure pulsing water-flooding. The technique is cyclic and consists of alternately pressuring and depressuring the reservoir. During the pressuring phase, water is injected and forced under high pressure to flow from the fractures into the matrix. Fluids are produced from the reservoir during the depressuring phase. The reservoir pressure is allowed to drop until either the oil production rate becomes too low or the producing gas-oil ratio becomes excessive. Cycles are repeated as long as the process is economic.
This paper presents results of a simulation study to determine the important parameters which affect the success of pressure pulsing waterflooding. A dual porosity generalized compositional model was used for the simulations. The results show the success of pressure pulsing waterflooding is dependent on the interconnected fracture network, relative permeabilities and oil fluid properties. The fracture network allows injected water to move rapidly away from the wellbore throughout the reservoir system. Matrix relative permeabilities affect the amount of oil and water retained in the matrix rock during the depressuring phase. Gas collapse during the pressuring phase allows water to enter the matrix rock, and gas evolution in the depressuring phase drives oil from the matrix rock into the surrounding fractures. It is illustrated that the effectiveness of pressure pulsing waterflooding can be improved by conservation of gas in the reservoir and/or by supplemental gas injection in the pulsing cycles before water injection.
Jabiru Field Simulation: A Case History
Authors: Wallace T. D. , Balnaves C. 
Published: December 2007

ABSTRACT
The Jabiru field forms part of a northeast-southwest trending complexly faulted, structural high. Massive marine sands of Juassic age and of excellent quality are truncated by two unconformity surfaces. The 60 m oil column is underlain by an extensive aquifer which provides strong bottom-water drive. The field came on stream at 2100 m3/d in August 1986 and is currently producing through two subsea wells to a floating production facility at a rate of 4540 m3/d. Two further wells are planned to come on stream by mid-1988, increasing field potential to about 8740 m3/d.
Reservoir simulation has played a key role in the development of the Jabiru field. Initial models ranged from 2-dimensional/2-phase radial to 3-dimensional/2-phase cartesian, to allow preparation of and increase confidence in forecasts of field behavior. The most serious limitations of these simulations lay in the geological models used and the prediction of water breakthrough.
This paper is intended as a case history discussing the evolution of the reservoir simulation models through five significant revisions and compares the results obtained at each stage. The variation of model parameters is presented always with the aim of understanding a complexly faulted reservoir experiencing strong bottom-water drive. Different solution methods and gridding options have been employed and emphasis is placed on the need to be judicious when applying several simulator options concurrently. In particular the use of segregated flow and the relative merits of placing a finer grid around wells to model the coning behavior are discussed.
This paper is aimed at the practicing reservoir engineer and, by frankly outlining the route undertaken by BHP Petroleum, some of the pitfalls and problems as well as benefits of reservoir simulation are exemplified.
Fracture Design Considerations in Naturally Fractured Reservoirs
Authors: Cipolla C. L. , Branagan P. T. , Lee S. J. 
Published: December 2007

ABSTRACT
The ability to effectively enhance production through hydraulic fracturing is dependent on an accurate description of the reservoir production mechanism(s). Fracture designs may differ greatly depending on the production mechanism(s). The complex nature of hydraulically fractured reservoirs in which the predominant production mechanism is a set of interconnected, naturally occurring fractures is investigated in this paper. The paper integrates general reservoir simulation results with actual field data from a naturally fractured reservoir in the Piceance Basin, Colorado.
The study investigates a variety of natural fracture/matrix properties and compares the productivity of these naturally fractured reservoirs to homogeneous reservoirs with the same average flow capacity. The paper also investigates the influence of natural fracture anisotropy on hydraulic fracture design. The effect of damage to the natural fracture system is illustrated and compared to analogous homogeneous reservoirs. The economic considerations associated with many of the reservoir production mechanisms are presented.
The results of the reservoir simulations indicate that optimum fracture lengths for isotropic, naturally fractured reservoirs are identical to those estimated for homogeneous reservoirs having the same average flow capacity. Therefore, accepted fracture design considerations to determine optimal fracture length and conductivity can be used in isotropic, naturally fractured reservoirs based on the average flow capacity of the reservoir. However, fracture design considerations are more complex when the effects of natural fracture damage and anisotropy are encountered.
The Evaluation of Oil Saturation Through Casing Using Carbon/Oxygen Logs
Authors: Woodhouse R. , Kerr S. A. 
Published: December 2007

ABSTRACT
Carbon/oxygen logging is used to determine oil saturation in cased holes without knowing formation water salinity.
When the carbon/oxygen tool is used alone, in non-extreme conditions, the accuracy of the interpreted So is calculated to be ±23 saturation units at 20% porosity. The uncertainty increases rapidly as porosity decreases.
Field examples illustrate its potential value and practical problems created by the measurement statistics, borehole fluid changes and remaining mud filtrate.
The Application of a Modular Measurement While Drilling System for Directional Control and Formation Evaluation in Horizontal Wells
Authors: Harrell J. W. , Dickinson R. T. , Wiley W. W. 
Published: December 2007

ABSTRACT
The application of measurement while drilling technology is fast becoming a crucial part of many successful horizontal drilling programs.
The need for accurate directional and geological control is essential in order to meet predefined angle build rates and locate and stay within target horizons. This need is further emphasized in the smaller radius, slim hole, high angle wells that are now being drilled.
This paper describes the application of a modular multi-sensor measurement while drilling system for use in most types of conventional and high angle directional wells for formation evaluation and directional control.
Several case histories will be presented from diverse operating environments covering the following drilling applications: conventional directional build programs, medium radius operations, slim hole drilling, and other special drilling applications.
Finally the paper will cover future measurement while drilling developments and the possible benefits for high angle and horizontal drilling techniques.
The Role of Reservoir Simulation in the Development of Some Major North Sea Fields
Authors: Wood A. R. O. , Young M. S. 
Published: December 2007

ABSTRACT
Many alternatives arise during the development of major oil and gas fields. Reservoir simulation has a firmly established role in helping to select which of these alternatives will give the optimum development. This is especially true in the North Sea where development and operating costs are relatively high and it is cost effective to study options in detail before proceeding in the field.
General reservoir simulation principles are now well known by reservoir engineers but they are summarised in this paper as an introduction for a wider audience.
A case history is presented which shows how reservoir simulation has been important at all stages in the development of BP’s Magnus field. Figures are presented to show how estimated Magnus field reserves have changed with the acquisition of new data and improved interpretation techniques. Reserves histories for other major North Sea fields are also discussed.
An Analysis of Naturally Fractured Reservoir Performance Using a Novel Fractured Reservoir Simulator
Authors: Litvak B. L. , Satter A. , Etebar S. 
Published: December 2007

ABSTRACT
This paper presents our experience in the studies of naturally fractured reservoirs using a state-of-the-art fractured reservoir simulator. Characteristic features of fractured reservoirs were analyzed during simulation of two reservoirs and laboratory imbibition experiments. One simulation study involving a North Sea reservoir required an accurate description of the imbibition processes. Production history and rise of free water level (FWL) in the fracture system were matched by changing the degree of imbibition and fracture porosity in the reservoir. The results of the study were used to justify waterflooding.
For a naturally fractured offshore reservoir in the United States, the simulator was used to predict production performance as influenced by matrix permeability, fracture porosity, compressibility and capillary pressure. The simulation results were utilized in the reservoir development plan.
Elevated Temperature Multiphase Rock-Fluid Properties for High and Low Tension Systems
Authors: Okoye C. U. , Oungpasuk P. , Wang P-H. , Hayatdavoudi A. , LeBlanc J. L. 
Published: December 2007

ABSTRACT
Numerical simulation of steam-chemical oil recovery processes require high temperature multiphase rock-fluid properties such as relative permeabilities and capillary numbers. These parameters are needed to predict and evaluate oil recovery performance and efficiency. Experiments in both Berea sandstone and sandpacks have been conducted to measure relative permeabilities of high and low tension oil-water mixtures at elevated temperatures. A new mathematical model consisting of sets of empirical correlations based on experimental data have been developed for relating endpoint relative permeabilities to both residual and mobile oil-water saturations and capillary numbers to residual oil-water saturations.
The tests were run over a wide range of temperature, 72° to 400°F, and overburden pressure range of 500 to 1000 psia. It is our belief that this model is new for the range of temperature and pressure of steam oil recovery processes with chemical additives. Predictive results made with empirical correlations are in good agreement with experimental results.
Enhancement of Real-Time Hydraulic Fracturing Models with Full 3-D Simulation
Authors: Cleary M. P. , Barr D. T. , Willis R. M. 
Published: December 2007

Abstract
In a major advance over previous capabilities for prefracturing design and real-time field application of hydraulic fracturing models, the ability to accurately handle complex pumping schedules and reservoir conditions has been achieved by developing the capabilities for full three-dimensional hydraulic fracture analysis and combining these with the speed of lumped model simulations. These lumped (spatially integrated) models have already been used for the design and realtime analysis of numerous fracture treatments. Now, a fully 3-D code, based on finite elements and surface integrals, developed as part of a comprehensive field monitoring and analysis project for the Gas Research Institute, is being used to analyze fracture geometries and pressure distributions for many variations of viscosity scheduling and stress barrier placement. Analysis of these 3-D results produces integration coefficients which can be implemented in the lumped models. These coefficients enable the lumped model to accurately account for viscosity and pressure variations in the fracture, and for differences in confining stress magnitude in the strata above and below the payzone. This work allows the lumped models to be made more quantitatively correct by incorporating the essence of full 3-D modelling capabilities without any loss of execution speed. The effectiveness of the methodology is demonstrated by performing simulations with a number of data sets from field operations as input.
Improvement of Massive Hydraulic Fracture Treatments in the Cotton Valley Formation of East Texas
Authors: Pearson C. M. , Lynch K. W. , Schmidt J. H. , McCaslin N. F. 
Published: December 2007

ABSTRACT
In 1986 Arco Oil & Gas Company commenced an on-going development drilling program in the Oak Hill field area of east Texas. The formation of interest was the Taylor section of the Cotton Valley tight gas sand. Wells required stimulation with massive hydraulic fracture treatments due to the extremely low matrix permeability. This paper presents a case history of the stimulation program over an 18 month period during which 28 wells were fractured. The evolution of the fracture design is discussed in six phases of design change and evaluation.
The importance of real-time continuous quality control information is shown for identifying problems which if undetected could lead to an incorrect evaluation of the treatment design. Improvements are shown through on-site analysis of treatment data and evaluation of production results.