bluuebunny/crossref_metadata_2025_split huggingface dataset:
Design Considerations for Fracturing Job Sizing of Low-Permeability Gas Reservoirs of the Arkoma Basin
Authors: Robbins R. E. , Chen Shixin , Lemp S. P. 
Published: December 2007

ABSTRACT
Since no other single expenditure has a greater impact on a tight reservoir's profitability than a hydraulic fracture treatment, optimal job size selection is imperative. However, the actual reservoir deliverability improvement is usually quite different from the forecasted results. Poor fracturing results are primarily attributed to poor reservoir characterization and reduction of the in-situ fracture conductivity over the laboratory estimates. To estimate in-situ fracture conductivity, and subsequently enhance the fracturing job design, a historical correlation between job size and wellbore improvement was established. This correlation was based on the post-fracture evaluation of 70 wells in the Arkoma basin.
Matching our data with McGuire and Sikora's solution, the retained fracture conductivity ranged from 20% to 50% of laboratory estimates depending on the aggressiveness of proppant placement. The influence of a different thickness in propped height and net pay height was factored into the optimal job sizing process. When modified for this difference, the PKN modeled FCD was consistent with our field observation for low FCD treatments. A field estimate of the optimal job size was also developed from the historical correlation using a marginal benefit and marginal cost model. Ease of application and historical accuracy are the two major strengths of this approach.
Greater cost effectiveness was achieved when these design considerations were incorporated into the field practice in the Arkoma basin. Since this study surveyed the diverse reservoirs and depositional environments within the Pennsylvanian age, we feel the approach will be applicable in similar areas.
Ambient Air Quality Impacts of Natural Gas Compressor Stations
Authors: Ramsey S. H. , Roger P. L. 
Published: December 2007

ABSTRACT
Several hypothetical situations are presented analyzing the impacts which stack design can have upon ambient air quality concentrations due to nitrogen oxides emissions from natural gas compressor stations. Results show that relatively small changes in stack height, stack location, and stack orientation (for multiple source facilities) can dramatically affect air quality impacts.
A Generic Hand-Held Terminal for Production Data Acquisition
Authors: Moore R. D. , Dennison J. A. , Greenhill K. L. , Sisk L. B. 
Published: December 2007

Abstract
Over the past several years, the development of hand-held data terminal systems has improved the efficiency of production data collection. However, many of the early systems were designed for specific applications or areas and were not sufficiently generic to be used in all domestic operations without additional time and expense for code changes. Also, in some cases the early systems were not capable of collecting the full range of data necessary in all locations, i.e., data from different well types, different well testing methods, various types of compressors, various chemical injection procedures, etc. A system has been developed that provides the needed flexibility to handle the majority of data types required in any location without changes in the program code.
The system is a comprehensive production data acquisition and reporting system that provides a fast, accurate, and accessible information source. The production data is collected by the lease operator using a hand-held computer terminal, which has been customized for his route from menu screens on the personal computer. The hand-held terminal displays the previous day's data as it prompts the lease operator to enter the new data. After the lease operator completes his rounds, the hand-held terminal is connected to a personal computer in the field office, and the data is moved into a database system on the PC. The data in the database can be checked and edited if necessary, and daily, weekly, and monthly field reports can be generated as needed. The data is transferred to the area office overnight for managerial reports. It is then transferred to the mainframe for use in production allocation and reporting to state agencies.
Software development cost is a significant investment in a system of this type. However, the flexibility of this system has enabled it to be deployed throughout domestic operations and has significantly reduced the cost to each location.
A Study of the Effect of Condensate Formation on Performance Predictions in a Gas Pipeline Network
Authors: Mucharam L. , Adewumi M. A. 
Published: December 2007

Abstract
A unified model is presented for describing both single-phase and two-phase flow in complex gas pipeline networks. The form of the model is such that it can easily admit any energy-loss model that is expressible in a particular non-linear functional form of energy loss-flow rate relationship. Four popular single-phase gas pipeline design equations, namely, Darcy-Weishbach, Panhandle-A, Panhandle-B and Weymouth equations and a two-phase flow equation (Beggs-Brill) are used to test the development. All these tests are successful. A viable algorithm for solving the resulting equations is presented. Four field cases are analyzed using this model. Results show that Weymouth equation underpredicts pressure distribution for single-phase gas flow but predicts comparable pressure distribution to Beggs-Brill's two-phase model for two-phase flow in the network. The results further demonstrate significant effect of the presence of condensate on network performance.
Multiphase Long-Distance Pipeline Transportation: An Emerging Technology for Offshore Production
Authors: Rai R. , Sharma P. K. , Mukerjie R. K. 
Published: December 2007

Abstract
Multiphase flow is widely encountered in the petroleum industry. It is expected that a significant part of the future production of oil and gas in Offshore will come from deeper water and in many cases from marginal fields. Rigid fixed platform system with production and processing facuity located in the same field may not be economical in such cases.
Many oil companies are investing heavily to develop multiphase technology, with the ultimate goal to transport unprocessed multiphase well fluid for a long distance. Initial efforts for development of multiphase pumping and metering have been successful. The R&D backup for flow modelling is being provided by the research centres.
In the present study, a review of present state of multiphase long distance transportation, multiphase pumping, metering and flow modelling have been presented. The case histories of long distance multiphase flow from Indian Onshore and Offshore fields have been presented. Pour new field developments with multiphase well fluid transportation have been presented which are currently under execution.
The Forces Created in Wellhead Equipment During Blowdown After a Nitrogen Foam Fracture Operation
Authors: Hand K. L. , Lyons W. C. 
Published: December 2007

Abstract
The reaction forces in wellhead equipment due to the flow-back of nitrogen foam fracture fluids are analyzed. The forces in the flow-back lines are analyzed for both unchoked and choked lines. The reaction forces are found to be excessive and uncontrollable for unchoked lines with normal field equipment and procedures. The reaction forces in choked flow-back lines are controllable and a safe choke size can be determined for the anticipated wellhead pressure. A new technique for controlling blowdown operations is discussed and preliminary designs for equipment to be used in applying such a technique are given.
A New, High-Strength and High-Corrosion-Resistant Titanium Alloy for Oilwell Use
Authors: Okada M. , Kuroda A. , Kitayama S. , Shida Y. , Ueda M. , Kudo T. , Nagashima K. , Ueda H. 
Published: December 2007

Abstract
A new corrosion resistant, high strength and economical titanium alloy has been developed. This alloy is based on T1-6A1-4V with small Pd and Ni additions. This new titanium alloy tubes showed higher strength and toughness balance compared with the conventional titanium alloys through the Ni addition and the fine bi-modal microstructure. Corrosion resistance of this new alloy has been significantly improved by the addition of small amount of Pd, showing a surprising superior corrosion resistance to conventional alloys in severe conditions including hostile sour environments. Pd addition of this alloy is about 0.05%, which is smaller than that of corrosion resistant Ti-0.15%Pd alloy. Thus, this new alloy may have significant merits to conventional materials as Ni base high alloys, ie. light weight, high strength and superb corrosion resistance.
In this paper, comparison of various properties between the new alloy and conventional alloys including titanium and nickel base alloys were presented. The result of pipe and tube performance of this alloy was also presented.
Performance of a Peripheral Waterflood Project in the Main Body ‘B’ Reservoirs (Stevens) at the Elk Hills Oil Field, California
Authors: Ezekwe N. , Smith S. , Wilson M. , Humphrey M. , Murphy J. 
Published: December 2007

Abstract
The peripheral waterflood in the Main Body ‘B’ Reservoir located in the Elk Hills Oilfield, Kern County, California, is mature with remaining reserves estimated at 122 MMBO from initial reserves of 212 MMBO.
Pressure maintenance early in the life of the reservoir improved oil recovery. Recent performance data indicate that the MBB Reservoir is layered and has potential for bypassed reserves.
Future geologic, reservoir and production activities will be dominated by defining, correlating and managing the reservoir by layers.
Design and Implementation of the First Arctic Offshore Waterflood, Endicott Field, Alaska
Authors: Adamson G. R. , Hellman H. L. , Metzger R. R. 
Published: December 2007

ABSTRACT
The Endicott Field is the first Arctic offshore producing oil field. Early reservoir studies showed that optimum recovery would require start-up of waterflooding within the first two years of production. This paper describes the engineering and geological work done to implement and optimize the Endicott Field waterflood.
The reservoir at Endicott Field is contained within the Mississippian Kekiktuk Formation. These multistory fluvial sandstones are characterized by wide variations in rock properties. Thick areally extensive shales combined with sealing intra-reservoir faults, serve to subdivide the field into seven distinct reservoir management sub-zones.
The design and implementation of this waterflood project extensively used simulation studies. These studies showed that waterflooding would nearly double the recovery and there were significant benefits for returning the field to original pressure. Simulation models optimized both the number and placement of production and injection wells.
The first production facility sealift included waterflood facilities. This enabled a pilot program to be implemented within five months after production start-up to shake down facilities, determine well injectivity and obtain early waterflood performance data.
The Evaluation of Prudhoe Bay Waterflood Conformance and Reservoir Characterization by Thermal Modeling
Authors: Severson C. D. , Selisker G. R. 
Published: December 2007

ABSTRACT
The evaluation of vertical sweep has been a long standing problem when determining waterflood efficiency in massive sandstones. As a result of reservoir heterogeneities and gravitational effects the vertical distribution of water near an injection well is typically different than its distribution in the reservoir. A thermal modeling approach has been successfully applied to this problem in the Sadlerochit sands at the Prudhoe Bay field to attain a greater understanding of the vertical sweep efficiency in a portion of this reservoir.
A thermal simulator was used to construct a 3-D model of one half of a 320 acre inverted 9-spot waterflood pattern in the Flow Station 2 waterflood area of Prudhoe Bay. The model was history matched to a temperature profile taken in a replacement injector drilled 720 feet (220m) away from its original location. The amount and location of reservoir cooling observed is a function of the water volume that has passed through it at a given location and its associated conductive and convective cooling. The replacement well modeled was drilled 4.75 years after injection had been initiated in the original well. The analysis thus provides an understanding of the vertical water distribution in the reservoir 720 feet (220m) from an injector, 4.75 years after the initiation of secondary recovery.
The producing sand modeled is approximately 170 feet thick and is characterized by a high permeability (0.1-5.0 darcy) thief zone at its top and 0.5 to 1.0 darcy sands below. In this waterflood pattern approximately 62% of the injectant had entered this thief zone. Thermal modeling indicated that 60% of the water had slumped from this thief interval into the sands below, 720 feet (220 m) from its injection point. This result indicates that although the thief zone has taken a high percentage of the water injected into the pattern, the vertical distribution of that water in the reservoir is far different from its distribution at the sand face as measured in the wellbore. By quantifying the volume of water that slumped out of the thief zone, an estimate of vertical permeability was determined and our understanding of vertical sweep efficiency greatly enhanced.
An Improved Linear Chemical Model for Alkaline Steamflooding
Authors: Okoye C. U. , Ping-Hu W. , Oungpasuk P. , Hayatdavoudi A. 
Published: December 2007

ABSTRACT
Laboratory displacement tests using alkaline steamflood and conventional steamflood were successfully conducted. The results from the experiments were used to obtain correlation equations which in turn were used to simulate oil recovery performances.
A chemical displacement model which incorporates the thermal and chemical oil recovery mechanisms was used to history match the experimental oil recovery performances. The model prediction of the oil recovery performances matches fairly well with the experimental results. Furthermore, the model was tested with data obtained from the displacement tests and it led to some modification and adjustment until its application for history matching and prediction became satisfactory.
The model predicts higher oil recovery for caustic steamflooding over conventional steamflooding and agrees quite well with the experimental results obtained. The experimental results show that caustic steamflooding recovers more oil with increase in temperature, but above 300°F the incremental oil recovery becomes insignificant. The optimum temperature for enhanced oil recovery by caustic steamflood seems to be about 300°F. At a given temperature caustic steamflooding recovers more oil than conventional steamflood by between 18 to 35% and 8 to 13% of the original oil in place for primary and secondary recovery processes respectively.
A Simplified Approach for In-Situ Characterization of Desorption Properties of Coal Seams
Authors: Anbarci K. , Ertekin T. 
Published: December 2007

ABSTRACT
A simplified analysis technique to determine the desorption characteristics of coal seams using pressure transient analysis is presented. The proposed technique is based on formulation of single phase gas flow in coal seams with unsteady state sorption/diffusion phenomena in coal matrix and laminar flow in cleat system. The matrix geometry is represented by using spherical elements.
A line source solution which defines the pressure distribution in an infinite-acting radial-cylindrical coal seam is used in the development of the proposed analysis technique. The simplified analysis presented in this paper is first tested against a previously developed closed form solution which describes the pressure transient behavior of coal seams. The proposed solution shows excellent agreement with this more rigorous solution, and its versatility is demonstrated through a simple analysis procedure which does not require the use of computationally laborious functional groups. Furthermore, a pressure transient data generated by a coal seam degasification numerical model is analyzed successfully using the methodology presented here. As an example application of the proposed technique to the analysis of drawdown test data is also included.
The proposed inverse solution procedure which is devised as a viable pressure transient analysis technique is applicable to coal seams and other unconventional gas reservoirs where adsorption/desorption phenomena are effective. The methodology introduced in this paper has the potential of providing the necessary tools that can be used in in-situ determination of the transport properties and the sorption characteristics of the coalbed methane reservoirs.
A Numerical Well Test Model
Authors: Puchyr P. J. 
Published: December 2007

Abstract
This paper describes a pressure transient analysis model which uses a numerical reservoir simulator to generate the pressure solutions. The accuracy of the solution is controlled by the grid and the wellbore-reservoir interaction. The methods used to construct the grid, and the representation of the wellbore-reservoir interaction are described. The simulation results are compared to a new large compressibility analytic solution, and to conventional analytic solutions.
Simulation of Slattery South Field, a Minnelusa ‘A’ Reservoir
Authors: Towler B. F. 
Published: December 2007

ABSTRACT
A Reservoir Simulation study of the Slattery South field has been made to determine the drive mechanisms present in the field and to determine the amount of oil that has been produced from under eighty undeveloped acres in sec 30 of the field in order to resolve a drainage dispute. The primary drive mechanism has been shown to be solution gas drive in conjunction with fluid expansion and gravity drainage. Of the 308,928 STB of oil drained from the offended lease, 107,145 STB has been produced in well Burroughs A-18, and 131,420 STB has been produced in Ham Krause No.1.
Delineation of Favorable Areas for EOR From Differential Oil-in-Place Calculations in Bell Creek Field, Montana
Authors: Cheng A. M. , Sharma B. 
Published: December 2007

ABSTRACT
Based on examination of the distribution of differential oil-in-place (OIP) in a reservoir, a method is presented to identify the effect of geological heterogeneities on nonuniform oil production. A well differential oil-in-place (DOIP) is defined by the equation: DOIP = volumetric OIP at a given spacing − material balance equation OIP. This method is based on the theory that positive differential OIP areas could indicate the presence of geological heterogeneities like high clay content, sealing faults, or different types of flow barriers, whereas negative differential OIP areas may imply presence of highly permeable clean sands, nonsealing faults, fractures, etc. By using the fairly complete geological and engineering data from 54 wells in the four sections enclosing the Department of Energy Tertiary Incentive Project (TIP) area of Bell Creek (MT) field, a differential OIP map was prepared. The map indicated several areas with significantly positive and negative differential OIP anomalies.
An overlay of the DOIP map with maps of structural anomaly, clay content, porosity, permeability, Dykstra-Parsons coefficient, and log-derived heterogeneity index indicated that low-permeability valley-fill sediments with a high degree of clay content and several sealing faults coincided with areas having a significantly positive differential OIP. High-permeability barrier sandstones adjoined by numerous small, conductive faults (throws around 10 ~ 20 ft) with excellent drainage efficiency were responsible for a significantly negative differential OIP. DOIP contour patterns indicated that optimum injection sweep efficiency could be obtained by locating the injectors parallel to a cluster of differential oil-in-place contour lines covering the area to be flooded.
The differential OIP was strongly dependent on geological heterogeneities and was an effective index for measuring the role of different heterogeneities on oil production in a reservoir. Main applications of the method are to determine: (1) remaining oil reserves, (2) geological heterogeneities, (3) well drainage area and efficiency, (4) optimal well spacing, and (5) best injection and production well sites for waterflooding, infill drilling, EOR, and horizontal well drilling programs. Results of the method can be used independently or integrated with other information for optimal reservoir production planning.
Application of PD' Well Testing of Naturally Fractured Reservoirs
Authors: Okoye C. U. , Songmuang A. , Ghalambor A. 
Published: December 2007

ABSTRACT
This study presents the exact semi-analytical dimensionless pressure derivative solutions of transient pressure in naturally fractured reservoirs with pseudosteady state and transient stat interporosity flows. Integration by part technique was used to obtain in Laplace space dimensionless pressure derivative solutions which were used to generate new type curves. The type curves are dimensionless pressure derivative and dimensionless pressure-pressure derivative functions.
Dimensionless pressure-pressure derivative type curves are easier to use than existing type curves for transient pressure analysis of natural fractured reservoirs because they require only horizontal sliding to obtain matching.
Some of the type curves were used to analyze and interpret published field examples of transient pressure data. The results of the analyses show good agreement with published results. The validity of both our results and the published results were varified by using them, as well as the given rock and fluid properties, to simulate transient pressures for the duration of the test periods. Comparison of the closeness of simulated pressures with given pressures provides a level of confidence in the models and type curves used for data analysis and interpretation.
Transient Pressure Analysis for Variable Rate Testing of Gas Wells
Authors: Samaniego V. F. , Cinco-Ley H. 
Published: December 2007

ABSTRACT
A method is presented to analyze variable rate tests in gas wells considering the effect of damage and high-velocity flow. This is a direct method that allows an estimation of the turbulent term coefficient D and the skin factor without using a trial and error procedure. The methods are applicable to infinite acting radial flow.
The method considers a step-function approximation of the flow rate. It consists of two parts: a) a graph of ∂Δpp(p)∂t∑j=1N(qi−qj−1t−tj−1)
is made from which we can estimate the formation conductivity kh and b) a graph of 1.1513[Δpp(p)m1qN−[∑j=1N(qj−qj−1qN)log(t−tj−1)+log  (1ϕμ(pi)ct(pi)rw2)+log(4βtγ1)]   vs   qN
is made that yields an estimate of the parameter D and of the skin factor s. This method can also be applied to continuosly varying rate flow tests.