bluuebunny/crossref_metadata_2025_split huggingface dataset:
Field Application of Laboratory Friction Pressure Correlations for Borate Crosslinked Fluids
Authors: Tan H. C. , Shah S. 
Published: December 2007

ABSTRACT
This paper presents (1) test procedures and equipment to model friction pressure behavior of borate crosslinked fluids in hydraulic fracturing operations, (2) effects of various parameters on friction pressure of borate crosslinked fluids, (3) field case histories, and (4) detailed discussion of the implications of findings resulting from this investigation. As a result of this investigation, improved friction pressure predictions are obtained and therefore bottomhole treating pressures have been interpreted more accurately. With a better understanding of formation characteristics from the more accurate BHTP, success rate of stimulation treatments using borate crosslinked fluids has been greatly improved.
Removal of Emulsified Crude Oil From Produced Water by Electrophoresis
Authors: Fang C. S. , Tong N. A. M. , Lin J. H. 
Published: December 2007

ABSTRACT
Emulsified oil droplets in water are surrounded by negative zeta potential, and as a result, they move toward the positive electrode, when an electric potential is applied. This electrophoresis velocity of droplets was measured at various electric potentials, 1.569, 2.61 and 5.23 volts/cm, and various temperatures in the range from 71°F to 116°F. The measured electrophoresis velocity is in the range from 0.4 to 1.6 mm/min, depending upon the electric potential applied.
Identification of Bypassed Gas Reserves Through Integrated Geological and Petrophysical Techniques: A Case Study in Seeligson Field, Jim Wells County, South Texas
Authors: Jirik L. A. , Howard W. E. , Sadler D. L. 
Published: December 2007

Abstract
Bypassed gas zones can be identified and developed by integrating advanced geologic methods and petrophysical techniques into field development strategies. These reservoirs may provide incremental gas reserve additions at relatively low cost to the operator. Seeligson field was studied as part of a Gas Research Institute-sponsored program designed to develop, test, and verity technologies and methodologies for maximizing the recovery of gas from conventional reservoirs in mature fields.
Detailed geologic evaluation of middle Frio reservoirs in Seeligson field reveals a stratigraphic framework composed of multiple, stacked fluvial channel-fill and splay deposits interstratified with floodplain mudstones. Channel-fill deposits are 10 to 40 ft (3 to 12 m) thick and approximately 2,500 ft (750 m) wide. Splay deposits are up to 20 ft (6 m) thick proximal to channels and extend several thousand feet away from the channel. Channel-fill and crevasse-splay sandstones are reservoir fades; levee and floodplain mudstones are thought to be barriers to flow, separating individual reservoirs vertically and laterally.
Recently developed cased-hole log evaluation techniques tested in Seeligson field demonstrate their superiority for locating bypassed gas. Based on geological and spatial considerations, 14 key wells within a 4 mi2 (10 km2) area of the field were selected for cased-hole petrophysical analyses. Pulsed-neutron and gamma-ray logs were recorded in these wells. After preliminary analyses, five wells were selected for full waveform acoustic logging. Porosity was calculated from the acoustic log and compared to pulsed-neutron porosity to determine gas effect. The logs were corrected for shaliness and combined with sigma (capture cross section) data to calculate water saturation. Long-normal resistivity curves from electric logs were digitized and integrated with the newly acquired data to calculate original open-hole water saturation. Plotting and comparing the logs graphically enabled gas-productive sands to be identified.
Five successful recompletions were made as a result of this study. By estimating reserves from current and initial production, using net present value of the gas, and dividing by the cost of the project, a highly favorable return on investment is estimated.
The Gas Research Institute’s Second Staged Field Experiment: A Study of Hydraulic Fracturing
Authors: Robinson B. M. , Holditch S. A. , Peterson R. E. 
Published: December 2007

ABSTRACT
The Gas Research Institute (GRI) is currently sponsoring a field-based research program to better understand the processes that control hydraulic fracture growth. In order to effectively conduct this research and validate the technologies under development, GRI has planned a series of Staged Field Experiment (SFE) wells. These SFE wells, which are drilled specifically for conducting research, are "staged" in the sense that a series of successively higher goals have been set for each well. These goals have been more completely described in previous publications.1 The first Staged Field Experiment was completed in 1987, the results of which have also been published.2,3
The first three SFE wells were planned to be drilled through the Travis Peak formation, while the fourth SFE well is scheduled to be completed in another basin containing significant gas reserves in a tight sand. The purpose of moving SFE No. 4 to another basin will be to apply and test any technologies developed in the GRI program in an entirely differently geologic environment. There are many research technologies that are being developed and tested in the SFE program, but the primary objective was to develop a fracture monitoring and fracture modeling system that could compute the shape and extent of a hydraulic fracture in real time. In order to obtain accurate and reliable input data for the fracture models, it was necessary to perform studies on geology, coring, logging, and well testing of tight gas sands. In an effort to substantiate and verify the models, additional research is being sponsored in the development of instrumentation and analysis techniques for measuring the dimensions of the fracture.
The second Staged Field Experiment, officially known as SFE No. 2, was successfully completed in 1989. An extensive amount of data was collected on this well from two different intervals of the Travis Peak that were tested and fracture stimulated. The purpose of this paper is to summarize all of the data that were collected and the analyses performed on these data. As a result of the work performed on SFE No. 2, a great deal was learned with regard to the completion and stimulation of the Travis Peak formation. A new strategy with regard to completion and stimulation of wells was developed that utilizes the integration of openhole log and in-situ stress data. These results are presented for the Travis Peak. Hopefully, this same approach can be applied on most tight gas sands.
Field Applications of Wireline Formation Testers in Low-Permeability Gas Reservoirs
Authors: Desbrandes R. , Yildiz T. 
Published: December 2007

Abstract
Wireline formation testing (WLFT) is a downhole testing technique used to determine the formation pressure, the formation pressure gradient, and the formation permeability and to collect formation fluids. Current WLFT tools are designed for high to medium permeability reservoirs. In this study, the results from WLFT runs in eight wells drilled in cooperation with the Gas Research Institute are presented. The tests were conducted by three major service companies. The merits of the WLFT tools, the information provided, and the possible misinterpretations of the data are reported.
A brief description of each formation tested is made in each well: rock type, shaliness, porosity, permeability, saturation, and formation pressure. The test results are characterized by the flowrate, the chamber size, the duration of drawdown, and the duration of the pressure buildup. Typical curves are presented. A statistical study of the successful tests is attempted.
The results obtained with a slow flow wireline tester (SFWT) are also presented. Based on the analysis of the SFWT runs and using a new modeling technique, a new interpretation method is proposed. The results indicate that the current WLFT tools will have to be modified to allow a better analysis of the drawdown period.
This study shows that meaningful data can be obtained with the WLFT tool in many instances, especially when a slow flow rate is used. The drawdown portion as well as the build-up portion of the pretest can be interpreted, and the drawdown data can confirm or, to some extent, replace the build-up data. The evaluation of low permeability gas formations will be greatly enhanced by using the new slow flow testers and the new interpretation technique.
Interpreting Short-Term Buildup Tests From Low-Productivity Gas Wells Using Deconvolution
Authors: Johnston J. L. , Lee W. J. 
Published: December 2007

ABSTRACT
This paper illustrates the application of deconvolution to analysis of wellbore storage distorted pressure buildup test data from low productivity gas wells. These wells generally require long times to reach tie correct semilog straight line, rendering conventional Horner analysis impractical. The deconvolution process removes the effects of wellbore storage and allows for the use of semilog analysis. Also, times required for buildup tests can be reduced by more than an order of magnitude with no loss in accuracy in results. In fact, analysis is sometimes even more definitive with the short-term, corrected test data than with much longer-term but uncorrected data because some important characteristics of a formation (such as the effects of layering or dual porosity) appear only in the first few hours of shut-in and are usually masked by wellbore storage distortion.
The problem with deconvolution is that it requires accurate sandface rates after shut-in. These rates are difficult and expensive to measure, so we present a method to calculate the sandface rates from the observed pressure buildup data. This paper presents verification of the rate calculation and the use of the calculated rates in deconvolution with simulated data. We also present several field cases from low permeability gas wells. The success of the deconvolution analysis implies that shorter tests may be run on low productivity gas wells, significantly reducing the cost of the tests and increasing opportunities to identify important reservoir heterogeneities.
The Effect of Microsilica on the Thermal Stability of Lightweight Cement Systems
Authors: Dillenbeck Robert L. , Mueller Dan T. , Orr Billy R. 
Published: December 2007

SUMMARY
In various formulations, microsilica cement slurries are finding increasing utility in oilfield cementing applications. In the course of these applications, many microsilica slurries are being used in environments which subject the set cement to bottom hole static temperatures in excess of 230°F.
While 35% fine silica by weight of cement (BWOC) has been extensively researched and accepted as a high temperature cement stabilizer, very little if any research has been published on the effectiveness of microsilica in this application. The results of this study reveal that microsilica displays promise as a viable alternative stabilizing material, with the added benefit of medium to low slurry density.
The Use of Selective Injection Equipment in the Rangely Weber Sand Unit
Authors: Franks A. P. 
Published: December 2007

Abstract
Selective injection equipment (SIE) has been used in the Rangely Weber Sand Unit to improve the vertical conformance of both a mature waterflood and a full-scale CO2 flood. The Ershaghi technique of waterflood reserves estimation shows that SIE has improved ultimate waterflood recovery by approximately 6.6% of the original oil in place. Scoping economics, applied to historical production data, show that this additional oil recovery is profitable.
The application of SIE to the Rangely CO2 Project is reviewed, including information on corrosion, SIE run life, and the technique of "blanking" high-permeability thief zones to reduce inefficient cycling of CO2. A discussion is presented on SIE optimization through the use of injection profile data, permeability information, production and injection data, and reservoir simulation. The paper concludes by addressing the feasibility of applying SIE to other oil fields with similar reservoir characteristics.
Alternative Use of ESP's for Water Injection
Authors: Foote T. J. B. , Stalder J-P. 
Published: December 2007

Abstract
This paper describes the use of electrical submersible pumps (ESPs) for the enhancement of water injection on the BP operated Ula platform, situated in the Norwegian sector of the North Sea. The pumping scheme was designed to use off-the-shelf pumping equipment, in a manner not normally used in the offshore North Sea environment, to meet the requirements of rapid installation, minimum use of valuable deck space, high suction pressures and a high degree of safety in operation. Taking suction from the existing water injection manifold at 220 barg, two pumps in parallel were required to boost the injection pressure in two wells to 330 barg, and achieve a total injection rate of 25,000 bpd (3,975 m3/d).
To cope with the high suction pressure each ESP was housed in a suction can, capable of taking the full suction pressure, constructed mainly from off-the-shelf standard well casing. The pump/can units, each around 35 metres long, were installed in spare well conductors, resulting in minimum use of deck space.
The pump system was in operation for 9 months until the permanent uprated water injection system was commissioned.
A Practical Approach to Prevent Formation Damage by High-Density Brines During the Completion Process
Authors: Baijal S. K. , Houchin L. R. , Bridges K. L. 
Published: December 2007

Abstract
The potential for formation damage caused by the use of high density brines has only recently begun to be studied. Unfavorable fluid/rock interaction has been shown to produce mobile fines and swelling clays with the added potential for the precipitation of brine insoluble salts. Some operators have started lowering the pH of CaCl2 and/or CaBr2 brines by requiring a minimum of 8% ZnBr2. The hope was to prevent the precipitation of acid soluble salts. This approach has significant practical and economic limitations. This study evaluates alternatives to use of ZnBr2 as a primary component of standard CaCl2 and/or CaBr2 brines. Laboratory core flow tests were conducted to evaluate surfactant systems potential for preventing this formation damage.
Electronic Gas Measurement Deployment/Development Considerations
Authors: Allen J. M. 
Published: December 2007

Abstract
During the last few years, Amoco Production Company has identified concerns that needed consideration before deciding on the pursuit of Electronic Gas Measurement / Electronic Flow Calculation (EGM/EFC). Those considerations include 1) defining the existing system of measurement and volume calculation, and 2) defining the benefits EGM/EFC could provide and the functions required of the devices to provide those benefits. Then identified were the limitations of the various options that meet the functional requirements, and various other considerations.
Anyone who is considering EGM/EFC for their operations should weigh all the points made in the paper before a decision is made. Occasionally, not all the points or their interactions are identified in the decision process.
By having all the options and their interactions explained, prudent decisions on the deployment of EGM/EFC can be made. If careful consideration of the functions required to gain the expected benefits is made initially, the result will be reduced overall expense. These savings are from not installing additional equipment that attempts to provide the necessary beneficial functions. After full consideration, deployment of EGM/EFC devices may prove to be an effective alternative to the traditional chart recorder technology, but may not be appropriate for all applications.
Yield Points in Oilfield Cements
Authors: Clark P. E. , Sundaram L. , Balakrishnan M. 
Published: December 2007

Abstract
The determination of yield points in cement slurries is important in the complete description of slurry flow properties. Yield points affect both the start-up pressure after a temporary shutdown and void filling properties of cements. Values for the yield point are normally obtained by extrapolation of rotational or tube flow rheometer data. This technique is subject to both experimental and analytical errors.
Recently, several papers have described a more direct method of measuring yield points in slurries. A rotational viscometer equipped with a vane rather than a bob can be used to measure yield points accurately. The yield surface with the vane test fixture is in the fluid rather than at a fluid-solid interface as it is with a solid bob or a tube flow apparatus. Experiments with a vane fixture using a shear rate controlled rheometer can be subject to errors caused by windup of the torque spring. In this study a controlled stress rheometer was used to circumvent these problems.
Yield points for various oilfield cement slurries are presented. Data reflect the differences in additives, aging time and water content. The vane technique can be used to produce accurate and reproducible measurements of yield points in cements. Using a controlled stress instrument has several advantages in making these measurements.
Evaluating and Establishing Safety Ratings for Submersible Cables
Authors: Durham M. O. , Ashenayi K. , Guzy R. , Lea J. 
Published: December 2007

ABSTRACT
This document will define procedures to evaluate cables used with electrical submersible pumps (ESP). A standard rating system based on the performance results will be advanced. This system of scoring will permit the selection of a safe and suitable cable for the environmental requirements of a well. It is not the intent of this publication to specify what cable should be used or in any way set up a series of requirements that must be met before a cable may be run in a well.
This procedure will describe the evaluation techniques in detail, establish a standard reporting form for results, and set forth a rating system for each type of cable. The procedures outlined here are for samples of generic cable types. The prescribed evaluations are best done in a controlled environment by an independent laboratory.
Unlike test procedures whose objective is to qualify whether a cable works or not, the objective of this research is to quantify the performance degradation in various conditions.
Optimum Cable Selection for Electrical Submersible Pumps
Authors: French S. W. 
Published: December 2007

ABSTRACT
This paper discusses common methods of power cable design for electrical submersible pumps and presents a new method which can result in a more optimal design. A procedure is developed for estimating the maximum expected operating temperature of the conductor for each cable size. An accurate selection of power cable insulation type can be made for each cable size based upon the maximum operating conductor temperature. Total cable investment cost can then be determined for each cable size. Power loss calculations are also provided to predict the power cost of the cable. The final cable selection can be determined by economic analysis. Other factors that should be considered when selecting the cable for a specific ESP installation are also discussed.
Sorption and Fate of Phosphonate Scale Inhibitors in the Sandstone Reservoir: Studied by Laboratory Apparatus With Core Material
Authors: Kan A. , Yan L. , Bedient P. B. , Oddo J. E. , Tomson M. B. 
Published: December 2007

ABSTRACT
Phosphonates are commonly used in the petroleum industry to control scale and corrosion. In order to understand the fate of phosphonates in the reservoir after an inhibitor squeeze, both the kinetics and the equilibrium aspects of phosphonate sorption have been studied in the laboratory using batch apparatus and sandstone core flow-through apparatus. Diemylenetriaminepenta(methylene phosphonic acid) (DTPMP) was used in the experiments. The adsorption process includes the following four stages: (1) molecular diffusion; (2) dissolution of mineral from sandstone surfaces; (3) adsorption; and (4) solid phase maturation. The adsorption is kinetically important and the amount adsorbed is affected by both flow velocity and calcium concentration. A new radial-flow transport equation to simulate the transport of phosphonate in an inhibitor squeeze is also reported.
Design and Field Testing of Matrix Acid Diversion Treatments in Widely Varying Permeability Zones
Authors: Dietrich M. J. , Hunter W. L. 
Published: December 2007

Abstract
The effectiveness of matrix acid stimulation treatments is limited in widely varying permeability zones due to poor diversion. A unique combination of nitrogen foam, oil-soluble resins and HEC diversion agents was developed to ensure complete acid contact throughout the multiple layer zones in a gravel packed offshore Gulf Coast Louisiana well. Through the use of radioactive tracers and on-line pressure monitoring of the tubing and annulus, onsite adjustment of diverter concentration at various points during the treatment was achieved. The diversion of acid throughout these widely varying permeability zones was proven effective based on two logging runs and observed surface pressure responses. The case history with supporting data is included in the paper.
Maximizing Injection Rates in Wells Recently Converted to Injection Using Hearn and Hall Plots
Authors: Jarrell P. M. , Stein M. H. 
Published: December 2007

Abstract
A new technique is presented which aids in maximizing water injection rates in wells recently converted to injection, thereby accelerating offset oil production response. This method is applicable to waterflood operations where injection wells are surface pressure controlled and where bottom-hole injection just below formation parting pressure (FPP) is desired.
Two plotting methods are shown to be instrumental in monitoring the acceleration of fill-up and average reservoir pressure growth in an actual field case. One is the Hall method1: plotting a function of bottom-hole injection pressure versus cumulative water injection, and the other was Introduced by Hearn2: plotting the inverse injec-tivity index versus cumulative water injection.
After initiating injection into several converted wells at pressure limits well below the average offset parting pressures, periodic surface pressure increases were made at each well over a period of several months. Monitoring the Hall and Hearn plots as the pressure and rates increased rendered qualitative interpretations of whether the rates were being maintained below FPP. Accelerated reservoir pressure growth was achieved which resulted in earlier than expected offset oil response.
Application of these plots also reduce, and sometimes eliminate, the need to perform periodic step-rate tests designed to determine FPP during the injection start-up period, thereby significantly reducing operating costs.