bluuebunny/crossref_metadata_2025_split huggingface dataset:
Waterflood Performance Projection Using Classical Waterflood Models
Authors: Wu C. H. 
Published: December 2007

ABSTRACT
A semi-empirical method is proposed to forecast waterflood performance using classical waterflood models. The approach adopts an average flood pattern for waterflood performance projection. The pattern waterflood performance was obtained by using a semi-empirical approach based on a comparison of the computed results from Buckley-Leverett-Welge, Dykstra-Parsons, and Craig-Geffen-Morse methods. The approach allows the engineers to adjust the effects of. dominant factors such as displacement mechanisms, vertical variation of horizontal permeabilities, mobility ratio, and areal sweep efficiency. The technique also allows for fillup of initial gas saturation which can be adjusted to match the response time. The field-wide waterflood performance is computed using the average pattern waterflood performance and a prescribed pattern development schedule. The technique can be used for initial waterflood project evaluation or for matching the performance of a matured waterflood. The approach is practical and helpful for reservoir engineers working on waterflood project evaluation and management.
The approach has many inherent limitations. There are numerous assumptions made in the Buckley-Leverett-Welge, Dykstra-Parson, and Craig-Geffen-Morse methods such as homogeneous reservoir layers with constant porosity, permeability, and initial saturation. The proposed approach does not provide individual well performance and does not give a unique answer to the waterflood performance forecast problem. Due to the inherent limitations, the reservoir engineers should exercise good reservoir engineering judgements when using the proposed waterflood calculation technique.
A field example is used to illustrate the steps for completing the waterflood performance projection. A package of personal computer programs could easily be developed to relieve reservoir engineers from repetitive and laborious calculations and aid in parametric sensitivity study.
Short Radius Drilling Technology Utilizing Mobile Service/Workover Rig
Authors: Keelean L. , Harris S. S. , Petronio N. 
Published: December 2007

Abstract
The paper will discuss a multi-well, short radius lateral drilling project in a gas producing shale formation in northern Michigan. A description of short radius drilling tools and associated equipment, and the mobile service rig and auxiliary equipment will be presented. Drilling and completion procedures including mobilization, de-mobilization, rig-up and rig-down will be summarized, along with graphical representations of time curves, cost curves and directional section profiles.
The benefits of packaging multiple services and how it may apply to establishment and development of a learning curve will be evaluated. Limitations of both the short radius lateral equipment, and the mobile service rig will be reviewed, along with available optional equipment that is compatible with both systems. The economics of utilizing a mobile service rig versus a conventional drilling rig will be discussed.
Experimental Study of Erosion in Diverter Systems Due to Sand Production
Authors: Bourgoyne A. T. 
Published: December 2007

ABSTRACT
When drilling from a bottom supported structure, the best procedure for handling a threatened blowout from a shallow gas formation is to divert the gas flow away from the structure and drilling personnel. Case histories were reviewed in which failures occurred during diverter operations due to erosion caused by sand production. A model diverter system was constructed to evaluate this problem and provide information that can be used in the design of diverter systems. A number of pipe fittings used at bends in diverter systems were experimentally evaluated. The effect of flow velocity, liquid content, and sand concentration were included in the study.
It was found that very rapid wear can occur at velocities near sonic velocity. Wear rates of 8-in./hr were measured for short radius "Ells." The rate of erosion was found to be about two orders of magnitude higher for gas/sand mixtures than for liquid/sand mixtures. An equation was developed for predicting the wear rate for various field conditions. Recommendations are given for improving the erosion resistance of diverter systems.
The Transition Pressure: A Quick Method for Quantifying Polyacrylamide Gel Strength
Authors: Smith J. E. 
Published: December 2007

ABSTRACT
Because of the large numbers of gel systems and field specific variables that affect gel strength, several gels must be tested to choose the right one for a given field application. An apparatus designed for quickly quantifying gel strength, called the TGU Apparatus, was designed for screening large numbers of gel systems. The TGU is a counterpart to the Screen Factor Apparatus which is used for testing polymers. Like the Screen Factor Apparatus, the TGU Apparatus has a screen pack, made up of five 100-mesh screens, through which the test solution is flowed. Unlike a Screen Factor test, pressure is applied to the solution to force it through the screens in a TGU test. By plotting flow rate against pressure, a Transition Pressure is obtained. The Transition Pressure is proportional to the strength of the gel and is used to compare gels quantitatively. It takes fifteen minutes of lab work to obtain a Transition Pressure for a gel.
In this paper, instructions are given for obtaining Transition Pressures for gels using the TGU Apparatus. An example of how the Transition Pressure was used to determine the best gel for a given field situation follows. Lastly, a correlation between Transition Pressure and gel performance in sand packs is presented.
New Options for Scaling Steam Injection Experiments
Authors: Kimber K. D. , Farouq Ali S. M. 
Published: December 2007

ABSTRACT
Scaled model experiments are a valuable aid to steamflood design and simulation. They can also be an important adjunct to numerical simulators, when numerical simulators do not represent a recovery process adequately. Field data for history matching and data describing interaction between various components, additives, and porous media may not be readily available. Scaling techniques that are currently being used can also be limited, as they require porous media and pressure conditions different from those of the field being studied. Any properties dependent on pressure (e.g. PVT properties) or porous media (e.g. relative permeabilities) are not scaled accurately. New scaling criteria were developed which allow field porous media and pressure conditions to be used. Two of the new approaches achieve this in a novel manner by relaxing the requirements of geometric similarity. The advantages and disadvantages of each approach were investigated.
In order to compare the capabilities of the scaling approaches, experimental results from a large model were compared with those from smaller models which were scaled using each approach. The ability of each approach to predict such parameters as energy and temperature distribution, oil production rate, water-oil ratio, steam zone size and steam breakthrough are presented.
The scaling approaches which use field porous media and pressure conditions yielded results in agreement with those of an accepted high-pressure approach from the literature. The new approaches provide scaling options which should be better for steam processes which use additives (PVT properties must be scaled), processes which use pressure cycles (fluid compressibilities must be scaled), and processes in which it is essential to use the same porous media as found in the field.
Vertical Expansion of the 10-Pattern Steamflood, Kern River Field, California
Authors: Hajdu P. E. , Merrell J. M. , Sanford S. J. 
Published: December 2007

ABSTRACT
In 1984 the 10-Pattern steamflood was expanded upward into two drive zones overlying the original steam-flooded sands. Neutron and temperature logs from new wells associated with the expansion project showed heating and unexpected liquid depletion in the target sands. This depletion resulted in low pressure and temperature steam zones forming in these sands. In the third year of the project a heating analysis using data from observation wells indicated that the drive zones were thermally mature at the low steam zone temperatures. As a result of the analysis, steam injection into one of the drive zones was changed to hot water and steam injection rate into the other, less mature, drive zone was reduced by 70 %.
Capacitance Water-Cut Probe Utilization in the Kern River Field
Authors: Hohn P. P. , Morton F. R. 
Published: December 2007

ABSTRACT
Lower oil prices have increased the demand for accurate well gauging results in recent years. A primary component of the well gauging system is the water cut probe. At Texaco's Kern River thermal operation a quality assurance and preventive maintenance program has been successfully implemented. In its first - year this program has been useful in maintaining proper calibration of water cut probes and in identifying failures before they significantly affected well gauging results.
Type-Curve Analysis Using the Pressure Integral Method
Authors: Blasingame T. A. , Johnston J. L. , Lee W. J. 
Published: December 2007

ABSTRACT
This paper presents new type curves and type curve plotting functions which use integration rather than differentiation of well test data. These functions provide more unique type curve matches for noisy data because the integral of these data yields a much smoother function. The type curves presented in this work were generated from analytical solutions and are applied in exactly the same manner as in conventional type curve analysis.
A Numerical Approach to the Diagnosis of Sucker Rod Pumping Installations and its Verification with Downhole Pump Field Measurements
Authors: Chacin J. E. 
Published: December 2007

ABSTRACT
Most current diagnostic techniques that stablish downhole conditions from polished rod measurements, are based on simplified analytical solutions and thus have inherent limitations. In the present investigation these limitations are fully explored and a new diagnostic approach, based on the method of characteristics, is introduced in order to overcome said limitations. This new approach is more flexible (since it can be easily extended to include deviated and directional wells), allows the estimation of computational error, yields a more accurate downhole load estimation and compares very favorably with state-of-the-art codes.
A specially designed Downhole Instrumentation Unit (DIU) was used to obtain downhole measurements (at the, pump) in a test performed in a 5625 feet deep rod pumped well. The DIU is a microprocessor based 5 feet long "intelligent sucker rod" that can be screwed in anywhere along the rod string. The results of this test show that the diagnostic technique using the method of characteristics provides a very good estimation of actual loads along the rod string and at the subsurface pump.
The Effect of High-Density Perforating on the Mechanical Crush Resistance of Casing
Authors: King G. E. 
Published: December 2007

ABSTRACT
A series of tests to describe the effect of numerous holes in casing on the mechanical crush resistance has been run in casing and in L-80 steel tube models. The tests were run with big holes and normal hole sizes for perforations in phasings of 0°, 180°, 120°, 90°, and 60°. Shot density was varied in the model tubes from 4 to 36 shots per foot. The actual perforated casing was at 12 shots per foot. All of the perforated casing and tubing sections were compared to strength remaining in unperforated pipe of the same specimen.
The tests were carried out in a compression machine under a controlled rate of loading with strain gauges attached at critical points along the plane of expected failure. The casing and tube specimens were loaded between steel platens. The data for the test are plotted in the form of load vs deflection. Strain gauge data are also presented. The information generated includes observations of the effect of entrance hole size, phasing (lateral hole separation), shot density (linear hole separation at a specific phasing), and effect of the position of the plane of perforations to the plane of application of load.
Improved Productivity from Low-Pressure Gas Wells Through the Utilization of Wellsite Compression
Authors: Neal H. L. 
Published: December 2007

ABSTRACT
The deliverability of Amoco operated wells in the four main fields in the Arkoma Basin has been improved by the installation of wellsite compression. The compressor candidates were identified by a compressor simulation test. A study investigated the economics of purchasing versus leasing a wellsite compressor. Compressors were installed and the success of the installation depended on the initial sizing parameters used and the reservoir characteristics. Several operational improvements evolved which enhanced the profitability of these installations.
The Impact of Fracturing Fluids on Conductivity and Performance in Low-Temperature Wells
Authors: Thomas R. L. , Brown J. E. 
Published: December 2007

ABSTRACT
A study investigating the performance of low temperature wells following hydraulic fracturing is presented. Emphasis is placed on proper fracturing fluid and breaker selection to minimize proppant damage and maximize fracture conductivity. The study indicates borate crosslinked fluids yield minimal damage whereas organometallic crosslinked fluids consistantly yield severe damage. A detailed discussion of the impact of fluid-induced proppant damage on well performance is given.
Although previously reported laboratory work has addressed the topic of in-situ fracture conductivity, the results of conductivity damage in wells with low bottomhole static temperatures have not been reported. A detailed discussion of extensive laboratory conductivity testing at 100 ° F is presented to address the issue of conductivity impairment (damage) in low temperature wells. The conductivity and permeability of Jordan sand placed with several fluids incorporating various crosslinkers and breaker systems is reported. The data indicate crosslinked fracturing fluids can be used in low temperature wells to yield high fracture conductivity. However, the amount of damage observed is a function of both the crosslinker and breaker system.
Subsequent to laboratory testing, the impact of the fluid/breaker system on the performance of oil and gas wells was evaluated. Numerous fracture design and production simulations were performed to evaluate the effect of fluid systems on well performance. These data indicate production can increase 50% or more simply by incorporating a "cleaner" fracturing fluid system.
In conclusion, fracturing fluid and breaker selection are variables that must be considered when designing a fracture treatment in a low temperature well. This study indicates proppant placed with a borate crosslinked fracturing fluid containing a persulfate/amine breaker exhibits minimal conductivity impairment resulting in improved well performance.
The Effect of Speed Variation on the Operating Range of Submersible Pumps
Authors: Kobylinski L. S. 
Published: December 2007

ABSTRACT
A manufacturer must consider several factors when setting a particular pump's recommended operating range. Limits may be based purely on the wear life limitations of the pump thrust washer or on a predetermined minimum acceptable efficiency or head. Other factors must be considered in setting operating limits, including the need for sufficient fluid flow to allow for motor cooling and avoiding vibration induced by operation at very high or low flow rates. Operation at near shut-off conditions will cause localized overheating, particularly of the thrust washers resulting in excessive wear and premature failure.
This paper discusses pump axial thrust and pump thrust washer limitations. Tests were performed to determine actual values of pump thrust and washer wear. A series of curves showing a pump "operating range" based purely on axial thrust considerations are included.
Algorithm for More Accurately Predicting Nitrogen-Charged Gas-Lift Valve Operation at High Pressures and Temperatures
Authors: Winkler H. W. , Eads P. T. 
Published: December 2007

ABSTRACT
The published nitrogen temperature correction factors (Ct) are used to calculate the change in bellows-charge pressure with temperature. If these Ct-factors are used to calculate the test rack opening pressures for the gas lift valves in a high operating injection gas pressure system, the error in the temperature correction may prevent successful gas lift operations. An accurate correlation for calculating the changes in nitrogen pressure with temperature is presented in this paper.
Analysis of Well-Testing Data from a Restricted-Entry Well
Authors: Ding W. , Onur M. , Reynolds A. C. 
Published: December 2007

ABSTRACT
This work investigates the analysis of well test pressure data from a restricted-entry well using pressure and pressure derivative type curves constructed from constant-rate solutions. For cases where wellbore storage effects are negligible, it is shown that type curves constructed from constant rate solutions can be used to analyze rate data from wells producing at a constant bottom-hole pressure and that these type curves can also be used to analyze data obtained from gas wells. For cases where data are influenced by wellbore storage and skin effects, it is shown that a new analysis procedure using complete-penetration type curves based on dimensionless pressure and a dimensionless pressure/pressure derivative group can usually be used to obtain a complete analysis of data. The analysis procedures presented yield estimates of horizontal permeability, the mechanical skin factor and the vertical permeability.
Inhibitor Treatment by Coil Tubing Unit Can Now be Performed While Maintaining Production
Authors: Going W. S. 
Published: December 2007

ABSTRACT
A new chemical injection valve run on coil tubing allows inhibitor treatment of well tubing without interruption of well production. Chemical injection is controlled at the surface by hydraulic pump pressure and flow rate to provide uniform distribution along the entire tubing length. The inhibitor is discharged into the production stream and will rapidly deposit onto the tubing wall. The valve is deployed with existing coil tubing service equipment and a minimum of additional tools.
The Coil Tubing Inhibitor Valve is a back pressure regulator. The valve design is based on a state-of-the-art side pocket mounted chemical injection valve for wells completed with a continuous inhibitor system. The valve mechanism consists of a nitrogen biased piston directly connected to the valve stem. The piston has integral metal-to-metal seal cups that are sized to the cylinder bore for exceptional sealability. A redundant elastomer seal complements the rugged all-metal seal design. Inhibitor fluids discharging from the valve strikes a high speed turbine which breaks-up the discharge stream into a radially directed spray completely encircling the turbine. This discharge pattern provides 100% tubing wall coverage as the valve is moved upwards through the well.
Typical batch inhibitor treatment methods require production shut-in periods. With tubing displacement from surface treatments, the lost production period often includes an extended recovery time for the well to return to pretreatment production rate. With the coil tubing injection valve the cost of treatment is offset by incremental production compared to treatments that require that the well be shut-in. The precise metering of chemicals over the target interval reduces the overall chemical cost by reducing over treatment and wasted chemicals.
Identification and Treating of Downhole Organic Deposits
Authors: Addison G. E. 
Published: December 2007

Abstract
Cost-effective oil production of wells that are known to have a history of downhole organic scale deposition is possible when a program of identification, testing, and chemical application is correctly instituted. Stimulation of production can result if there is available crude and pressure in the formation being bottled up by organic scale deposits. Removal of these "roadblocks' will allow the migration of additional crude. It is much cheaper to remove the roadblock, instead of building new roads, i.e., fracturing.
There are two different types of organic deposits or scale. One is composed primarily of paraffin and the other of asphaltenes. Both paraffin and asphaltenes are natural constituents of most crude oils and their presence is not necessarily a cause for alarm. Only if the well seems to have problems is an investigation warranted. With the different constituency of the deposits comes the requirement to treat them in a different manner.
Acquisition Strategy Development
Authors: Caldwell R. H. , Heather D. I. 
Published: December 2007

ABSTRACT
Analysis of consummated U.S. based oil and gas acquisitions in terms of price paid for a given reserve magnitude yields fundamental conclusions. The historical price paid can be directly correlated with the then current wellhead price and also with the outlook for the future. Separating transactions into principally oil versus principally gas, yields separate correlations and is the main cause of difficulties when averaging $/BOE data.
Acquirers can be subdivided into groups that operate in defined "acquisition territories," such territories having economic, legal and physical boundaries. By defining acquisition territory, the likely competition mix and price usually paid can be modelled based on an analysis of past transactions. This knowledge is invaluable in both strategy formulation and in bid price estimation.
This analysis documents historical acquisition trends (based on over 600 transactions) and performs basic correlations with price, industry sector, and business cycle position. This data provides correlations for development of predictive models and hence the ability to tailor acquisition/divestiture strategy to the ever-changing business environment.