bluuebunny/crossref_metadata_2025_split huggingface dataset:
Neural Network Training-Data Selection Using Memory-Reduced Cluster Analysis for Field Model Development
Authors: Chen Dingding , Quirein John , Wiener Jack , Grable Jeff , Smith Harry 
Published: December 2007

Abstract
This paper is related to neural network processing of near well bore geological logging data. The paper has been prepared to address the increased use and interest in artificial intelligence technologies in the interpretation of open-hole and/or casedhole formation evaluation data.
A typical neural network model is developed from a training well or wells where measurements are available. The model is tested on a validation well or wells before it is applied to a specific field /reservoir. Quite often models are developed with limited data: for example single well data should be retrained with multi well data to improve its scope and applicability. Unfortunately, some efforts to upgrade can result in choosing to use sub-optimal training algorithms because of the need to deal with an extensively increased data size. The consequence is a reduction in predictive accuracy. To improve accuracy, it is wise to have ways (1) remove faulty, redundant and insignificant data, (2) detect inconsistent data, (3) have the ability to "add", i.e., duplicate samples in key target zones.
This paper discusses how cluster analysis can be integrated with graphic visualization and fuzzy decision making to support training-data selection in field model development based on multiple well data. A case study using cased hole logging data from a pulsed neutron tool demonstrates the method and its application in predicting the response of open hole triple-combo logs (neutron porosity, formation density and deep resistivity).
The Performance of Pseudofunctions in the Upscaling Process
Authors: Azoug Youcef , Tiab Djebbar 
Published: December 2007

Abstract
To obtain a reliable characterization of complex reservoirs, geoscientists and petroleum engineers commonly build geologic or geostatistical reservoir models which contain more than a million grid cells. However, for flow simulation such a detailed description demands a great deal of information and processing time. Therefore, less complex models are usually preferred where the number of grid cells must be reduced by a factor of 10 or more. Such scaling up necessarily involves the loss of information that must be captured through upscaling porosity, permeability and the use of pseudofunctions. The main objective of this paper is to determine a general method for using pseudofunctions for upscaling multiphase flow in 3D anisotropic heterogeneous reservoirs with different capillary and gravity numbers and applying the method to a real field case "Hassi Messaoud Field - Algeria".
The performance of different types of pseudofunctions is evaluated under different capillary and gravity numbers, and upscaling levels. As a part of this research study a software package to calculate pseudofunctions has been developed. It includes: (1) the input option from ECLIPSE restart files (2) generates pseudo curves for three phase three-dimensional problems using Kyte and Berry, Pore Volume, Stone, and Transmissibility Weighted methods, and (3) generates output file format which can be read by ECLIPSE 100™. A variety of homogeneous fine grid models representing different flow regimes were considered in this study and the performance of several pseudofunction methods was compared. All the pseudo function methods succeeded in reproducing the fine grid watercut and maintained oil production for the capillary dominated, equilibrium, viscous dominated flows, however, for the gravity dominated flow they failed to match the fine grid curve exactly. Although this shortcoming of the pseudofunction curves gives better results than the rock curves.
Next in this study, the results of the waterflood of a heterogeneous 3-D model of HMD Zone 17 are presented. This real field model confirmed the homogeneous case results: for high flow rates the pseudofunctions can be applied successfully to upscale from fine to coarse grid simulation.
New Hydraulic Fracturing-Fluid Technology Increases Production in the Barnett Shale and Reduces Impact on the Environment
Authors: Parker Mark , Slabaugh Billy , Walters Harold , Hart Thomas , Walsh F. Howard Howard , Haley Will , Harper Joe , Weaver Jim 
Published: December 2007

Abstract
Hydraulic fracturing-fluid systems are used to create fractures in hydrocarbon-producing reservoirs and to transport proppant into the fracture to support it and provide optimum production increase. Many reservoirs in North America and the world would not be economical prospects without this technology. Currently, most systems use water-soluble polymers composed of guar or guar derivatives. Additional materials are used to optimize the fluid characteristics for the application and to degrade the water-soluble polymer, making the fluid easier to recover from the well before production. The recovered fluids cannot be used again and must be disposed of in a proper manner.
A new hydraulic fracturing-fluid system has been developed that can provide excellent performance during the fracturing process with post-fracture treatment-fluid recovery approaching 100%. This fluid has the added benefit of being reusable after it is recovered following the treatment and before production. The benefits of reusing the treatment fluid include the cost savings associated with recovery and reuse of chemicals, the cost savings from reduced water volume requirements for subsequent treatments, and the elimination of disposal costs. In addition, the total volume of chemicals required for fracturing operations is significantly less, reducing the demand on the environment.
Reuse of this fluid system requires field analysis of the returned fluid and treatment of the fluid to preserve and maintain it for future use. To achieve the best results from the recovery, preparations should be made to capture and store the fluid for subsequent treatments.
This paper presents the application of the fluid system and the concept for recycling and reuse. The results of eleven treatments in the Barnett Shale in the Fort Worth Basin using the new fluid system and the recycled fluid system are provided.
Old/New Techniques Translate into Big Savings and Enhanced Stimulation in the Brown Dolomite/Hugoton Fields of Texas and Kansas
Authors: Ely John W. , Martin Michael A. , Duenas Jose J. , Trythall Jerry R. 
Published: December 2007

Abstract
The Hugoton /Brown Dolomite fields have been on production for well over 50 years and are presently producing at very low bottom hole pressures. Early in 2001 a fairly comprehensive study was made evaluating completion procedures with a large emphasis on ways to minimize cost and maximize production. In the study it was determined that virtually every fracturing fluid in the known world had been used in the formation. Additionally there appeared to be little difference in results based upon type of fluid, volume of fluid and proppant and or size of proppant.
Based upon the premise that the majority of the production was coming from natural fractures and that there was little chance of achieving high relative conductivities between these natural fractures and created fractures, a step change was introduced by using smaller proppant. This smaller proppant used in conjunction with fresh water only, would enter and hold natural fractures open. The technique is based upon success in other naturally fractured reservoirs using the "Waterfrac technique".
The technique is extremely simplistic using water with 40/70 sand only in the shallower Texas Panhandle wells with 5.5" casing and water with friction reducer and 40/70 proppant in the slightly deeper Hugoton Kansas wells with 4.5" casing. Early concerns related to watering out or drowning the very low-pressure zones but capillary imbibition allows all of the water to be absorbed by the formation and little or no frac fluid is produced. There are differences in completion techniques between Kansas Hugoton and Texas Panhandle Brown Dolomite relating to open hole versus cased wells and formation water production and these will be discussed separately in the paper.
A large part of the paper will be spent comparing production of these wells with more conventionally completed wells, using large proppant and crosslinked foam fluids. Additionally a review of the success achieved utilizing under balanced horizontal wells is compared to the waterfrac vertical completions.
Transient Pressure Analysis for a Vertical Gas Well Intersected by a Finite-Conductivity Fracture
Authors: Nunez Walter , Tiab Djebbar , Escobar Freddy H. 
Published: December 2007

Abstract
Pressure-transient analysis for gas wells has a great importance in the oil and gas Industry. Transient pressure responses of unfractured and hydraulically fractured gas wells may be affected by non-Darcy flow near the wellbore, such important effect needs to be taken into account when estimating reservoir and well parameters. An additional problem encountered in gas wells test analysis is the presence of the rate-dependent skin, which requires a search for another parameter (non-Darcy flow coefficient).
Several tests are performed in order to measure the deliverability of gas wells and to describe reservoir performance. Such specific tests as flow after flow, isochronal and modified isochronal were initially designed to obtain the absolute open flow potential of a well, however, the use of these tests has been extended to obtain additional information from the reservoir. Drawdown tests are focused in obtaining such data as wellbore storage, reservoir transmissivity, skin factor, flow efficiency and system geometry. Buildup tests lead us to the average pressure of the reservoir, however, proper analysis of buildup test provides values of permeability, wellbore storage and apparent skin factor. Buildup and drawdown tests are currently analyzed using type-curve matching procedures, which involves trial and error and conventional techniques.
Pseudopressure concept, which was used in this study, has shown to provide sufficient engineering accuracy in dealing with gas well test data. This study utilizes characteristic points, intersection and lines found on the pseudopressure and pseudopressure derivative plot to obtain fracture length, fracture conductivity, skin factor and reservoir permeability.
It was found that changing the non-Darcy factor, D, the shape of the pseudo-pressure curve varies from the original gas curve shape at D=0, which implies that an additional skin effect is added at high rates. On the other hand, the pseudopressure derivative curve remains on its original shape, then, in spite of increasing non-Darcy effect factor, D, the pseudopressure derivative curve is not affected by this additional skin effect added to the system because of the non-Darcy flow effect. The interpretation technique was successfully tested with simulated and field examples.
A New Robust Model for Natural Separation Efficiency
Authors: Marquez R. A. , Prado M. G. 
Published: December 2007

Abstract
This paper presents a mechanistic model to predict natural separation efficiency. Based on drift-flux model, a new mathematical formulation was developed to estimate natural separation efficiency. The new model considers the existence of the slip velocity not only in the vertical direction, but also in the radial direction. The new and robust model is a function of important variables such as geometric characteristics of the bottomhole, slip velocity at both vertical and radial direction and the gas and liquid flow rates. Available experimental data was used to obtain a new correlation for the bubble drag radius, as a function of gas flow rate. Predictions of the model have been compared and verified against experimental data, showing good agreement.
Economic Comparisons of Multilateral and Horizontal Wells in Water-Drive Reservoirs
Authors: Rivera Nestor , Jensen Jerry L. , Spivey John P. , Jardon Mike 
Published: December 2007

Abstract
Reservoir studies can help determine what parameters or configurations make multilateral wells (MLs) more economical than single-branch horizontal wells (HWs). We simulated 5 years of production from a water-drive reservoir and evaluated the results, using a range of economic criteria. The reservoir simulator uses a multisegment wellbore model to enable better handling of complex well trajectories and detailed description of pressure losses in the horizontal, building angle, and vertical sections of the well. The study compared Levels 3 and 6 ML junction configurations to HWs. We modeled natural flow applications considering normal gravity oil (20 to 29° API) in a homogeneous reservoir with permeability ranging from 10 to 1,250 md. Detailed well-cost estimates for each configuration included taxes, royalties, and water-handling costs. We found that accounting for friction and hydrostatic pressure losses through all the sections of the well created more realistic models. For the cases we studied, a two-branch ML produces 13% more oil than a HW in highpermeability reservoirs and 80% more oil in low-permeability formations with low viscosity oil (1 cp). In addition, the ML well produces 10 to 15% less water than the HW. The extra production of the ML over the HW increases to more than 50% in low-permeability and higher than 90% in lowpermeability. The ML has a higher net present value—20% or greater—than the HW for all permeabilities. Using a profit-toinvestment ratio, the ML is more attractive than the HW in the lower permeability cases. Results using other economic metrics gave similar results.
Utilizing "Over-Seas" Technology Improves the Cementing Processes in the DJ Basin of Colorado
Authors: Shaefer Mark , Clausen Fred 
Published: December 2007

Abstract
Cementing a liner string from the older Codell wellbores down to the J-Sand formation has been an important project in the DJ Basin for Kerr-McGee. The existing Codell wellbores have been deepened with a liner string because in 1998 the J-Sand well spacing was reduced from 160 acres down to 40 acres. The decrease in the spacing requirements created an infill drilling and deepening program in the DJ Basin. Typical cement volumes for J-Sand deepenings liner strings have been small, requiring 35 sacks of cement. The small cement volumes combined with the high bottom hole temperature (265°F) and narrow casing/hole clearances have made cementing practices difficult to implement for the service companies and operators in the DJ Basin. Traditional cementing practices have resulted in a +/- 10% failure rate in cementing the liner strings. The 10% failure rate and the "gray hair" factor that comes with cementing liners has been overcome with the use of overseas technology. Instead of dry powder cement, a Fluidized Cement Premix (FCP) has been utilized and pumped on more than 100 liner cement jobs with no problems for the service company or operator.
The objective of this paper is to identify and evaluate the benefits derived from switching from the conventional dry slurry to the FCP slurry. The benefits will be shown through the use of a statistical comparison of job success plus cost and a qualitative comparison of cement bond log signatures. The economic benefits will be explored for both the operators and the service company.
Economic Completion Slurries Utilized in Partially Depleted Reservoirs
Authors: Purvis D. L. , Merritt J. W. 
Published: December 2007

Abstract
Cementing production casing in partially depleted reservoirs is a common problem in the Mid-Continent. The industry is continually looking for alternative slurry designs to lower annular pressures during cementing while maintaining the material properties needed for stimulation and zonal isolation. In order to be viable, the resulting technology must decrease density while preserving compressive strength, fluid loss and free water properties of the cement. Cement slurries using foam or hollow spheres are capable of meeting these requirements. The additional equipment and material cost required usually prevent these systems from being economical when mixed between 13.5 and 14 ppg (lb/gal).
Recent technical developments have lead to the creation of slurries weighing 13.8 ppg containing 60% pozzolan and 40% API cement. These economical slurries exhibit mechanical properties comparable to standard API slurries having much higher densities. Laboratory testing and bond logs are presented and compared along with recommended applications.
Ratings Standardization for Production Packers
Authors: Fothergill John 
Published: December 2007

Abstract
Longstanding ambiguity surrounding performance ratings for production packers continues to be a topic of concern, as increasingly demanding completion environments drive more critical product selection processes. Inconsistencies in manufacturer testing methodologies and design validation procedures have previously not supported a quality selection process. Completion engineers, not equipped with a thorough understanding of the nuances of packer performance characteristics under various load conditions, have been dependent upon the technical expertise and good faith of the manufacturer.
This paper gives the completion engineer a working understanding of applied packer performance ratings. The evolution of qualifying testing procedures is discussed, as well as the most recent advancements in the standardization process. Ratings standardization set forth in ISO 14310, establishing both quality control and design validation grades, is described. Completion engineers and other decision makers, as well as salesmen need this information for informed product comparisons and proper matching of product to application.
Remediation of Salt-Impacted Soil and Waste
Authors: Deuel Lloyd E. , Holliday George H. 
Published: December 2007

Abstract
Salt impacted soil and waste remediation imposes one of the most difficult challenges to oil and gas operators, because of the expense and extended treatment time. Additionally, salt impacted land constitutes a fertile litigation target regardless of capability and practical land use. Expensive judgments in Oklahoma and Louisiana are becoming common. It is only a matter of time before similar court actions are brought in other oil and gas provinces. Proper remediation or corrective action avoids or mitigates these judgments. This paper offers practical methods for reducing remediation/re-remediation time and expense associated with produced water releases, production pit closures and spent saline drilling fluid/cuttings remediation.
The paper provides field-tested guidelines for mitigation; treatment, and post closure reconstitution of salt impacted soil and solid wastes. Currently, the technical literature offers little guidance in how to locate, mitigate, treat and reconstitute new or previously treated impacted soil/waste.
Based on our research, we conclude most salt-impacted areas can be treated to regain pre-impact land use capability status. The elapsed remediation time ranges up to 7 years. In severe cases, the operator may elect a long-term (30+ year) passive treatment appoach by planting salt tolerant species (halophytes).
The remediation methods presented in the paper are proven practical by long-term use and observed reconstitution of salt damaged land.
Collaboration in Knowledge Sharing
Authors: Rawdon Jack C. 
Published: December 2007

Abstract
The demand for oil and gas will increase substantially in the next ten to twenty years. The energy industry knows where oil and gas supplies are located, and can meet the demand if the industry promotes the benefits of collaboration in knowledge sharing. The industry will need highly qualified technical communities of practice who can communicate effectively and expand new technologies and best practices.
These key technical community professionals will effectively transfer and promote knowledge sharing among peers to ensure the success of major projects. These knowledge sharing communities of tomorrow will be a key component for corporations to be successful in their quest to protect the health, safety and environmental aspects of their projects. The knowledge sharing community core team business model is instrumental in expanding best practices and delivering recommendations in an easy and effective manner.
Successful corporations will seek to improve and increase their collaborative efforts on a global scale. Those corporations investing the proper time and talent in community business models today will reap the profits of collaboration in knowledge sharing, and secure a successful seat in the global energy arena of tomorrow.
U.S. Natural Gas Market: Recent Dynamics and Future Concerns
Authors: Schubarth S. K. , Byrd A. C. , Wickham J. F. 
Published: December 2007

Abstract
The US Natural Gas Market has moved through some very dynamic events over the past few years1. The fact that ninety-nine percent of all gas consumed in the US comes from the North American Continent plays a large part in the lack of stability in pricing of Natural Gas. The nature of the production stream feeding the demand for gas has changed drastically in the past decade. The potential demand for gas during peak usage periods of each year has changed dramatically and the maturity of the available gas development projects have all led to a greatly different market than ten years ago.
This paper will focus on the three main points of interest; first, the production supply of gas in the US and how the underlying decline rate of produced gas has changed. Second, the root cause of the recent gas price increase and resulting fall. What caused it and how likely is it to occur again. Lastly, What will it take to meet the increasing demand for natural gas into the future?
Overview of Coalbed Methane Best Management Practices and Mitigation Techniques Using Geospatial Techniques
Authors: Arthur J. Daniel , Patton Jason , Richmond Tom 
Published: December 2007

Abstract
During the second half of the 1990's, Coalbed Methane (CBM) production increased dramatically nationwide to represent a significant new source of income and natural gas for many independent and established producers. Matching these soaring production rates during this period were the advancements in Geographical Information Systems (GIS) technologies generating terra-bytes of new data for the oil & gas industry. Coupled to these accelerating initiatives are Sub-Bituminous coal from an outcrop in the Montana Powder River Basin many environmental concerns relating to production wastes and water table depletion of fresh water resources. It is these concerns that have prompted the conceptualization of this project for the development of Best Management Practices (BMP) and mitigation strategies utilizing GIS technologies for efficient environmental protection in conjunction with effective production of CBM. This has been accomplished by developing a framework to take advantage of a combination of investigative field research joined with leading edge GIS technologies for the creation of environmentally characterized regions of study. This paper will provide a summary of CBM BMPs as well as the use of an Internet-Based GIS application for geospatial analysis relative to CBM development and evaluation of various mitigation techniques and best management practices.