bluuebunny/crossref_metadata_2025_split huggingface dataset:
Quantification of Production Prediction Uncertainty and Its Impact on the Management of Oil and Gas Price Risk
Authors: Edwards R. A. , Hewett T. A. 
Published: December 2007

Abstract
Oil and gas commodity price risk is a manageable component of economic risk, and can be reduced or controlled by the use of financial derivative securities such as futures, forwards and options. The ability to manage oil and gas commodity price risk is dependent, in part, upon the ability to quantify uncertainty in production forecasts and reserve evaluations. Based on the explosive growth of commodity price risk management strategies and the ability of sophisticated reservoir characterization and modeling algorithms to quantify uncertainty, the prevalence of probabilistic production and reserve evaluations will continue to increase, as well as the importance of the petroleum engineer in the process of financial risk management. In this paper, a historical review of the volume of transactions involving oil and gas derivative securities shows the broad based growth of risk management strategies among oil and gas producers. Additionally, this paper presents a methodology and describes a computer model which incorporates financial derivative securities into a stochastic economic model of oil and gas producing properties.
Pressure Transient Analysis of Two Horizontal Wells in the Ann Field
Authors: Ghazarian V. , McCoy T. F. , Beebe G. D. 
Published: December 2007

Summary
The Ann gas field offshore United Kingdom was successfully developed in 1993 using two subsea completed horizontal wells in a layered Rotliegend sandstone. Requirements for well test design, implementation and the subsequent interpretation of transient pressure data from a layered reservoir test are discussed. Use of field appraisal data for validation of initial test interpretations, which have formed the basis for prediction of long term performance, is emphasized. In addition, field data for the first six months of production are presented and recommendations to optimize testing and improve performance of horizontal wells in layered reservoirs are made.
Downhole Mass Flow Rate Measurements Enhance the Analysis of Well Test Data: A Field Example
Authors: Paux F. , O’Callaghan A. W. , Deruyck B. G. , de la Combe J. L. Boutaud 
Published: December 2007

Abstract
Measurements associated with drillstem tests (DSTs) comprise surface flowrates and downhole pressure and temperature. Sandface rate and fluid density are important data but are generally not measured for lack of the appropriate instrumentation. These measurements are occasionally available when a production logging survey is conducted during DST operations. This is, however, not often the case because of the risk of spinner clogging when the well is cleaning up or when significant sand production occurs.
This paper presents a DST data set composed of continuous downhole density and mass flowrate measurements in addition to the "standard" pressure and temperature. It was acquired with a prototype fullbore multiphase flowmeter located below the tester valve.
Sandface fluid density provides a means to monitor the clean up period. Sandface rate measurements are used to convolve the reservoir pressure response and to estimate reservoir permeability and skin from flowing transients. Of particular interest in this field example, the additional measurements provide evidence of the formation of a gas cap below the tester valve during the main shut in, allowing interpretation of the apparently incoherent build up response.
Geostatistical Integration of Geological, Petrophysical, and Outcrop Data for Evaluation of Gravity Drainage lnfill Drilling at Prudhoe Bay
Authors: Hand J. L , Moritz A. L. , Yang Chung-Tien , Chopra A. K. 
Published: December 2007

Abstract
An integrated geostatistical methodology for a site-specific reservoir description was used in reservoir simulations to establish additional recovery benefits for gravity drainage infill wells for the Romeo interval for Drill Sites 2 and 5 at Prudhoe Bay. The available geological information varied over multiple scales and included: a detailed chrono-stratigraphic framework relating rocks of similar depositional times, a detailed depositional model with facies associations described at each well from log and core data, and analog outcrop training images obtained using photomosaics.
The reservoir description methodology transformed the facies associations at each well into indicator variables and used these variables to analyze vertical and lateral spatial correlation. Conditional truncated gaussian simulation was then used to generate 3D facies association maps within the model area constrained by the chrono-stratigraphic framework. Input from geologists was critical in the evaluation of the geological realism of the computed facies association maps. Porosity and permeability vertical and lateral spatial correlations were then determined for each facies association. Vertical correlation was determined from variogram analysis while lateral correlation was determined from the outcrop training images. Conditional sequential gaussian simulation was then used to distribute 3D porosity and permeability, separately within each facies association, throughout the model area. A pressure solver was used to scale up the 3D fine scale permeability distributions to grid blocks appropriate for direct input into a flow simulation model.
The conditional simulation methods allowed the integration of geological information on a number of different scales, thereby capturing the 3D complexity of the Romeo interval. The 3D facies association description generated using this methodology was judged by geologists to depict a very reasonable geological picture of the DS-2,5 Romeo interval. The pressure solver used to scale up the fine scale permeability distributions maintained the major permeability features apparent in the fine scale distribution which were important to reservoir performance.
Implementing a Total Productive Management (TPM) System in Production Operations
Authors: Carpentier P. L. , Devereux J. E. , Harper D. R. , Miller R. W. 
Published: December 2007

Abstract
In 1993, Shell Western E&P Inc. implemented a pilot Total Productive Management system for Production Operations in the Wasson Field near Denver City, Texas. As a result, significant changes have been made in the work processes used by personnel in Operations, and there has been a dramatic reduction in operating expenses.
In less than two years, Shell employees have been able to achieve cost savings of more than $3 million per month at Shell-operated producing properties in the Wasson Field.
Because of the success of the Wasson Field pilot, TPM systems are now also being implemented at other locations and properties operated by Shell Western E&P Inc.
This paper describes the eight activities that characterize the Total Productive Management (TPM) system that is now in place in the Wasson Field. The benefits that have occurred and problem areas that affected implementation of TPM are also discussed. Three key pieces of the TPM system are addressed in the paper: Surface Maintenance and Repair; Rig Work; and Operations.
The Auger Monitoring and Control System
Authors: Forster L. D. , Bailliet R. M. , Casada D. B. , Schafer D. R. 
Published: December 2007

Abstract
The paper describes the comprehensive Monitoring and Control System developed for Shell’s Auger Tension Leg Platform. The platform includes a large production facility, a full capability drilling rig and marine and utility support system. The Monitoring and Control System consists of a host computer system networked to programmable logic controllers which handle the various processes, and several specialized subsystems. The Monitoring and Control System represents a relatively seamless integration of many diverse systems. Commonality of hardware and operator interfaces ensures operator effectiveness, minimizes training, and enhances safety. The design approach taken with this system has application to large, complex facilities. With a suitable communications system, the system can be applied to facilities which are geographically separate. The system is centralized and gathers virtually all process and other operational data into a central monitoring and control room. More than 40 PLCs, all of the same family, along with several specialized subsystems are networked via fiber optics to the redundant host computer system. The system integrates marine, utility and production systems into an effective tool for managing platform operation.
Intelligent Interfaces for Fracturing Simulators: Part II—System Implementation and Application
Authors: Xiong Hongjie , Lancaster D. E. , Sherry K. J. 
Published: December 2007

ABSTRACT
Hydraulic fracturing is one of the most effective stimulation methods for increasing oil and gas recovery. There are several powerful 3-D (and pseudo 3-D) numerical simulators available in the industry for designing hydraulic fracture treatments. With each model, the accuracy of the simulation results depends heavily on the input data used. Thus, it is important to prepare a complete and accurate input data set for these simulators. This can be difficult to do, however, not only because lots of data items are required, but also because many decisions must be made, such as selecting fracturing fluids, selecting proppants, and determining the optimal pumping schedule and technique.
Using artificial intelligence methods, we have developed a powerful, interactive software application that uses a series of friendly and intelligent interfaces used to acquire the large amount of data needed by fracture simulators. In these interfaces, the user is guided through a set of screens specific to his problem. More importantly, the system helps the user make many decisions, such as selecting fracturing fluids and additives, selecting proppants, and selecting pumping schedules and pumping techniques. The system includes several databases from which a considerable amount of information can be accessed automatically, such as typical formation data, fluid rheology, and proppant conductivities. The system also provides a powerful expert help facility. In addition, based on the fracture simulation results, the system produces data sets that can be used to run reservoir performance and economics software.
This paper presents the methodology we used to implement the system and fully describes the different parts of the system, including the knowledge bases, fuzzy logic evaluators, data acquisition blocks, and databases. The paper also describes the expert help facility in the system. A companion paper1 describes how we designed the system.
Evaluation of Bottom Hole Pressures in 40 Soft Rock Frac-Pack Completions in the Gulf of Mexico
Authors: Mullen M. E. , Stewart B. R. , Norman W. D. 
Published: December 2007

Abstract
The purpose of this paper is to share findings that resulted from a study of pressures recorded from bundle carrier and wash pipe gauges run during frac-packing operations. The original premise was to correctly evaluate and identify fracture pressure responses associated with the "tip-screen-out" techniques used for frac-pack placement. The first attempts at frac pack pressure evaluation were done using data collected from bundle carriers in the workstring. Once washpipe data was obtained, it was noted that the bundle carrier data was distorted by phenomenon below the gauges in the well bore. The fluid friction generated through the crossover tool and friction associated with the slurry path around the screen proved to be a source of the observed distortion. Data collected from bottom hole pressure gauges attached to the wash pipe below the gravel pack running tool indicated that in several cases the observed pressure increase is associated with friction and not from the fracture inflation associated with "tip-screen-outs."
It was noted that serious swabbing effects can accompany the movement of the service tool. This swabbing has in the past been considered negligible. The swab effect can potentially damage the completion beyond repair. This swab can pull formation material into the perforations tunnels and annulus, creating a severe pressure drop through that portion of the perforated interval. The implications can be detrimental to well performance. Early BHP data collection altered procedures for service tool movement and provided insight toward correcting friction pressure calculations.
A Comparative Study of Succinoglycan Gravel Pack Gel Properties to Those of HEC
Authors: Cole R. Clay , Ali Syed A. 
Published: December 2007

Abstract
This paper contrasts the many different characteristics of hydroxyethyl cellulose polymer gels (HEC) with those of succinoglycan (SGC), a polysaccharide biopolymer. The properties included in this study are those related to gravel packing. All data and opinions are based on a comparison of HEC gels that had been properly hydrated, sheared, and filtered against SGC gels that were not sheared but were also filtered through 3.2-micron rated paper.
This paper does not dwell on previously published shortcomings of HEC polymer,1-4 but by directly comparing HEC to SGC, it reveals unique new advantages that could improve the quality of gravel packs.
Major New Developments in Hydraulic Fracturing, with Documented Reductions in Job Costs and Increases in Normalized Production
Authors: Cleary M. P. , Doyle R. S. , Teng E. Y. , Cipolla C. L. , Meehan D. N. , Massaras L. V. , Wright T. B. 
Published: December 2007

Abstract
A number of developments over the past five years have led to dramatic changes in the design and execution of hydraulic fracturing treatments. Five primary new issues are described: convection, tortuosity, rock/fracture (non-linear) response, appropriate use of rheology/flow-rate and permeability variation effects. Consequences include "paradigm shifts", such as inverse relations between appropriate proppant concentration and reservoir permeability. Resulting integrated cost-effective and rewarding methodologies for fracture execution are emphasized and the methodology is illustrated with just a few case-studies, selected to emphasize a variety of technical features as against absolutely optimum execution. Suitable generic implementation and procedures, using greatly reduced fluid volumes, are outlined in sufficiently general form to allow (practically optimum) job execution on any well, particularly in low-permeability reservoirs.
The variation between (nominally identical) wells, and the vital role of real-time analysis for on-site execution of adequate jobs, is demonstrated - including unique (but essential) representation of realistic/general physics in the models used to interpret adequate data-sets. The case-studies serve to illustrate the major issues, including many ancillary features involved in proper interpretation of pressure/flow data before, during and after fracturing treatments: it is emphasized here (and in a companion paper for higher permeability) that the proper/sensible combination of all freely-collectible data, including long-term production plots, which should be a natural part of all well operations, usually leads to (practically) unique interpretation of reservoir conditions and job effectiveness: good reservoirs are properly identified and poor-success cannot be so easily ascribed to poor kH. Well procedures and costs are thereby adapted to (optimum) production.
The Current State of Homopolar Pipeline Welding
Authors: Carnes R. W. , Haase P. W. 
Published: December 2007

Abstract
Homopolar pulse welding (HPW) has been proposed as a one-shot, single stage welding process for the joining of pipe in the J-lay configuration. A joint industries program (JIP) has been formed to develop this process for off-shore, deep water applications. Homopolar pulse welding utilizes the high current, low voltage electrical pulse produced by a homopolar generator to rapidly resistance heat the interface between abutting pipe ends, producing a full circumference resistance forge weld requiring no filler metal in only three seconds. This five year program began in February 1993, funded by a consortium of six oil companies (Shell, Exxon, BP, Texaco, Amoco, and Mobil) and one welding contractor (CRC-Evans). The program’s ultimate goal is to produce a prototype system suitable for installation on a barge. The goals for the first two years of the program include demonstrating suitability of the process by producing and evaluating welds in different grades and wall thicknesses of three inch nominal diameter API 5L line pipe. Funding for each year of the program is contingent upon meeting program goals for the previous year. In the first five quarters of the program, eighty four welds have been produced, tested and evaluated and a method for non-destructive testing of the production welds has been identified.
Evaluation of a Crosslinked CMHEC Fracturing Fluid in Stimulation of Fruitland Coal Seams in the San Juan Basin
Authors: Ely J. W. , Zimmerman Scott 
Published: December 2007

Abstract
Over the past 10 years, many fracturing techniques and fluids have been utilized in stimulation of coal seams. Everything from straight water to linear gels to crosslinked guar or HPG, foam fracturing fluids, and even acid have been used in an attempt to find the optimum fracturing fluid for coal. None of these techniques appeared to work as well in relatively thick seams as the "collapsing cavity technique." Since most thinner or multi-seam coals are not applicable to collapsing cavity, the authors felt quite strongly that considerable damage was still occurring in the cleat system with conventional fracturing fluids. Additionally, straight water or slick water fracturing fluids simply did not have the proppant transport or the ability to obtain high near wellbore conductivity required for adequate coal seam stimulation.
In this paper, the authors present the results of over 60 fracture treatments that have been completed with totally residue free crosslinked CMHEC fracturing fluid.
It was felt that the colloidal solids present in broken gel, even with HPG and clay suspending agents used in continuous mix fracturing fluids, may result in damage in the very narrow cleat systems of the coal. Combined with the very clean fracturing fluid, the authors utilized the "forced closure technique," intense quality control and aggressive proppant schedules. The study has the advantage of being interspersed within wells that have been treated with foam, slick water, crosslink gel, straight water and some attempted cavitation techniques. The authors will present production data in evaluating the performance of the totally clean fluid. More than 1.5 years of production history is available.
Practical Application of In-Situ Stress Profiles
Authors: Cipolla C. L. , Liu Diabin , Kyte D. G. 
Published: December 2007

Abstract
This paper illustrates a comprehensive and economical approach to the application of reservoir data to optimize stimulation designs. The paper documents the selective application of in situ stress tests and dipole sonic logs to provide accurate stress profiles that can be used in concert with standard log and mini-fracture data to improve stimulation designs.
Measured stress data on 3 wells were used to calibrate open-hole logs to provide an estimate of stress profiles throughout a 300 square mile area of the Moxa Arch. Dipole sonic log-derived stress profiles were correlated to measured stress data. Calibrated stress profiles from dipole sonic logs and the measured stress data were then used to develop a correlation between gamma-ray logs and in situ stress. The log-based stress data was improved with the addition of over 50 mini-fracture tests. The combination of selected stress measurements, dipole sonic logs, and mini-fracture treatments resulted in optimized stimulation designs and cost savings of over $100,000 per well.
New, Simplified Methods for Modeling Multilayer Reservoirs Performing at Pseudo-Steady State
Authors: Ryou Sangsoo , Frantz J. H. , Lee W. J. 
Published: December 2007

ABSTRACT
This paper presents new correlating parameters for boundary-dominated, constant rate production from multilayer reservoirs. These parameters allow us to model well responses for multilayer systems having equal and unequal fracture lengths and boundary sizes, with equivalent single-layer systems. The paper also shows how we can use an equivalent skin factor in a single-layer model to simulate a multilayer reservoir with unequal positive skin factors in different layers. The paper includes a field example in which we applied the correlating parameters to a well producing from multilayer, tight gas sands in the Carthage Field.
Low Areal Sweep Efficiencies In Flooding Heterogeneous Rock
Authors: Pitts Gerald N. , Crawford Paul B. 
Published: December 2007

Abstract
This paper shows the very low areal sweep efficiencies to be expected when water flooding in heterogeneous rock. In this study the permeability of the rock matrix was assigned different values to a 400 point grid comprising the flooding pattern. The entire matrix was composed of rock permeabilities distributed randomly between some range. When the lowest permeability was 0.1 md and the highest 100 md. the average sweep was found to be only 20 to 30 percent of the total area for a five-spot pattern. Many examples are given and charts are presented for estimating the areal sweep in flooding heterogeneous five-spot, staggered line-drive and direct line-drive patterns.
Surprisingly, the direct line-drive square pattern gives a higher sweep for very heterogeneous rock than the staggered line-drive or five-spot patterns.
Introduction
Muskat presented the areal sweep efficiencies when flooding or cycling five-spot, direct line-drive and staggered line-drive patterns several decades ago.
Use of Seismic Attributes in Geological Description of Carbonate Rocks
Authors: Castrejón-Vácio Fernando , Porres-Luna A. A. 
Published: December 2007

Abstract
Seismic attributes have been used widely in order to obtain geological description of petroleum reservoirs, especially as a support for the definition of horizontal continuity of strata, with special emphasis on terrigeneous formations. Nevertheless the application of seismic attributes to the study of carbonate and naturally fractured reservoirs has been limited.
This paper shows the application of seismic attributes and seismic inversion to the geological and petrophysical characterization of a naturally fractured reservoir with complex lithology, which is characteristic of the most important producing formations in Mexico.
Taking into account petrophysical and lithological data obtained from core and well logs, it was possible to define some empirical relations that link the response of the seismic attributes with the petrophysical characteristics of the strata, such as porosity and fracturing, this relations are valid only for the carbonate formations at SE of Mexico. On the other hand, the horizontal continuity of lithology, as well as the detection of discontinuities, can be inferred from pseudo-velocity data obtained from the application of some seismic inversion techniques. It was carried out an analysis with the purpose of proving the effectiveness of these techniques for this kind of formations.
To obtain appropriate results from seismic data, it is necessary to consider the map of the main faults, since in areas with high fracture intensity, an important loss of amplitude from the seismic data frequently occurs.
The results from this techniques provide the basis for the definition of a realistic geological model, which is of prime concern for reservoir's characterization, numerical studies and EOR applications.