bluuebunny/crossref_metadata_2025_split huggingface dataset:
Unusual Lacustrine Reservoirs and Seals of the Murteree Horst Area, Eromanga Basin, Australia
Authors: Williams N. V. , Theologou P. N. , Boult P. J. , Zwigulis Maris , Schlichting R. P. , Price R. A. 
Published: December 2007

ABSTRACT
The Murta Member within the Murteree Horst area consists of a very thin, high permeability sand (HPS) within predominantly low permeability, thinly laminated, carbonaceous siltstones collectively referred to as the low permeability region (LPR). This HPS has a thickness of about 1 foot and a large lateral extent of about 10,000 acres.
The HPS and LPR together have been postulated to contain an OOIP of up to 74 million bbls in the Murteree Horst area, however the LPR also acts as a capillary seal to the underlying McKinlay reservoir. The production behaviour of the Murta reservoirs has remained enigmatic since their discovery.
Under production the HPS initially shows a rapid pressure drop indicative of oil expansion drive in a closed or almost closed system. However eventually a water drive develops which behaves as though there is a very large or possibly infinite aquifer.
Although most of the postulated 74 MMB of oil was thought to be in the LPR it appeared none of the LPR oil was being produced. It was not clear whether this oil could be mobilised. This investigation suggests that oil contained within the LPR is largely immobile and may even be representative of oil migration conduits only.
Three-Dimensional Fully Coupled Flow: Consolidation Modelling Using Finite Element Method
Authors: Sukirman Y. B. , Lewis R. W. 
Published: December 2007

Abstract
A versatile numerical solution will be presented for simulating a compacting oil reservoir and its subsidence at the surface. The mathematical formulation was derived based on Biot's self consistent theory which describes a fully coupled governing equation system for a saturated oil reservoir. It consists of the equilibrium and continuity equations for oil, gas and water-phases flowing in a porous media. The non-linearities due to mobility and accumulation terms were implicitly determined at each iteration level. These non-linear variables account for the effects of reservoir heterogeneity, relative permeability contrasts, rock and fluid compressibility factors, capillary pressure and other rock properties.
An elastoplastic reservoir rock model, based on a Mohr Coulomb yield surface, was used for simulating the deformation behaviour of both reservoir and overburden/underburden formations. The Galerkin based finite element method will be applied to obtain simultaneous solutions to the governing equation system where the displacement and the fluid pressures are the primary unknowns. Finally, several simulations are to be conducted for predicting the overall performance of a compacting oil reservoir and its subsidence problem at the surface.
A Predictive Model Enhances Optimized Production and the Completion of the Production System
Authors: Farshad F. F. , LeBlanc J. L. , Root P. J. 
Published: December 2007

ABSTRACT
A gas or an oil production system is usually composed of several distinct elements, one of which can be characterized as "flow through the well completion section with the pressure drop from the sandface flowing pressure to the bottomhole flowing pressure". This segment consists of fluid flow through different types of completions such as openhole completion, perforated and gravel-packed or conventionally perforated tunnels that are not gravel-packed.
The prediction performance, the production optimization and the productivity of a gas or an oil well is strongly affected by a composite or total skin around the completion zone.
In perforated completions, the completion interval consists of the perforation tunnels extending from the inside casing wall through the casing and cement sheath to a point within the sandface near the wellbore. A principal factor in the design of a well completion is the consolidation or competency of a producing formation. If the completion is a gravel pack, as in the case of poorly or unconsolidated sands, perforation tunnels should be gravel-filled to a point outside the cement sheath or perhaps up to the cement sheath-sandface interface. In non-gravel packed perforated completions, as in the case of highly consolidated or competent formations, the perforation tunnels are probably unobstructed and extend to a point within the sandface. A thin zone of compacted formation surrounds each perforation tunnel creating a "skin effect" due to perforation damage.
The objective of this paper is to show that the economic development and production of gas or oil wells dictates consideration of two separate but related subjects: Total optimization of the production systemLimitation of pressure drop through gravel packed or conventionally perforated completions that are not gravel-packed.
This paper will show that the maximum production rates possible from gas wells are usually restricted by limiting design parameters. Proper evaluation of these critical areas can extend the life of the a well six to seven-fold. Although this paper is addressed specifically to gas wells, the techniques shown can be applied to oil wells as well as any other gas production system.
Simulation of Fluid Flow in Coal Using a Discrete Fracture Network Model
Authors: Choi S. K. , Wold M. B. 
Published: December 2007

ABSTRACT
A discrete element model for coal which combines simple mechanisms of matrix deformation and discrete fracture network fluid flow has been applied to investigate stress-induced permeability alteration and stress change around a wellbore during a step rate injection test. The model demonstrated that the dominant physical processes at a relevant length scale can be simulated.
Java Sea Gas Reservoir Development Design
Authors: Pathak Prabodh , Kasim A. T. , Yusmiati Ida , Ismoyo Hadi , Bukhari Tahir 
Published: December 2007

Abstract
Gas deliveries were started from the Offshore North-West Java Sea (ONWJ) concession area to Indonesian electricity generating facilities in 1993. This paper addresses the development and reservoir engineering of shallow gas fields underlain by bottom aquifers. A multi-disciplinary team of geologists, geophysicists, reservoir engineers, production engineers and facilities engineers conducted an extensive study to optimize the development plan. This paper shows that the critical coning rates for high permeability reservoirs with a large gas column thickness are very high and the reservoirs can be drained effectively by vertical wells. Low permeability reservoirs with a small gas column thickness require horizontal wells to increase production rates and ensure high recovery efficiencies. Water breakthrough is early in the field life and there is substantial gas production after water breakthrough. This paper uses the concepts generated from single-well models to develop the reservoir depletion plans for four gas fields in the ONWJ concession.
Numerical Geology: Predicting Depositional and Diagenetic Facies From Wireline Logs Using Core Data
Authors: Altunbay Mehmet , Barr D. C. , Kennaird A. F. , Manning D. K. 
Published: December 2007

ABSTRACT
To exploit a reservoir, the geological model must accurately define the depositional environment and the effects of diagenesis on the pore network. Current methods for establishing the geological model of a field usually require subjective, qualitative interpretation of geological and petrophysical data. A method -Numerical Geology - has been developed that greatly reduces the subjectivity in geological modelling efforts. This method also allows geological attributes to be quantified and predicted.
Numerical Geology involves the integration of petrophysical, petrological and geological data with wireline log responses. The geology of "Hydraulic or Flow Units" intervals with similar hydraulic characteristics is described using conventional sedimentology, petrography and core analysis data. These data are translated into a matrix of geological indices classified according to hydraulic unit profile of the section. Hydraulic units are then predicted for uncored sections based on their unique log signatures that are obtained from cored sections. By combining predicted hydraulic units profile with the matrix of geological indices for eachflow unit, profiles of geological attributes are derived. The prediction reliability of hydraulic units is calculated based on the uniqueness of log signatures for each flow unit. Therefore, the confidence level for geological predictions can be assigned to estimated profiles of geological attributes. This eliminates much of the subjectivity from future geological interpretations and predictions.
A Model for Multiphase (Gas-Water-Oil) Stratified Flow in Horizontal Pipelines
Authors: Neogi Sudarsan , Lee Aihsin , Jepson W. P. 
Published: December 2007

ABSTRACT
A mechanistic model for gas-liquid-liquid systems has been developed. Given the superficial velocities of the constituent phases and their physical properties, and the pipe diameter the corresponding oil and water film thicknesses in three phase stratified flow canbe predicted. Experimental data has been obtained for gas velocities upto 7 m/s. The model predictions agree well with the experimental data.
Pressure Drop in Perforated Pipes: Experiments and Analysis
Authors: Su Ze , Gudmundsson J. S. 
Published: December 2007

ABSTRACT
The total pressure drop in horizontal wells is considered to consist of reversible (acceleration) and irreversible (wall friction, perforation roughness, mixing effects) pressure drop. The fundamental equations for pressure drop are presented along with relationships used for pipe junction flow. Experiments on a perforated pipe with 144 perforations, geometrically similar with wellbore casing (12 SPF, 60° phasing), are presented and analyzed. The results are applied to a typical horizontal oil well in the North Sea. It was found that the total pressure drop consists typically of 80 percent wall friction, IS percent mixing effects (including perforation roughness) and 5 percent pressure drop due to acceleration.
The Application of Pressure Drop Through a Horizontal Well Correlation to Oil Well Production Performance.
Authors: Arshad Azmi M. , Manan Muhammad A. , Ismail Abdul R. 
Published: December 2007

ABSTRACT
From the petroleum engineering standpoint, pressure drop through a horizontal wellbore is very small and is negligible in predicting the production performance. However, not much research has been done to study this phenomenon and more importantly to prove the above assumption.
This paper discuss the application of published pressure drop through a horizontal well correlation in the prediction of horizontal oil-well production performance. The correlation relates two-phase pressure drop along the hole to the fluid inflow from the reservoir. This correlation together with friction and hydrostatic effects were used to determine the total pressure drop from the wellhead to the well tip. The calculations by iteratively solving pressure drop along pipe equations with reservoir flow equations was done with the aid of computer program.
The study proves that pressure drop is very important in predicting the inflow rate distribution along wellbores especially when using small perforated rough pipes and dealing with long horizontal wellbores.
The Separation of Solids and Liquids With Hydrocyclone-Based Technology for Water Treatment and Crude Processing
Authors: Ditria J. C. , Hoyack M. E. 
Published: December 2007

ABSTRACT
Hydrocyclones have been used in a variety of process industries for over 100 years. They are a simple and effective device, but still widely misunderstood in the oil and gas industry. Hydrocyclones ideally lend themselves to numerous separation applications, overcoming conventional technical and economic operating constraints.
The objective of this paper is to "demystify" the basic operation of hydrocyclones and identify separation situations where hydrocyclones can offer significant advantages. These include a significant reduction in equipment size and weight which equates to significant costs savings on new projects, especially offshore. Hydrocyclones also provide the opportunity for additional processing capacity on existing facilities where little or no expansion space is available. Furthermore, hydrocyclones offer enhanced separation efficiencies when compared to conventional equipment.
When coupled with complementary conventional process equipment the resultant hydrocyclone based water treatment system is smaller than an equivalent conventional system. This results in an increase in process efficiency per volume utilized.
Computer Programs for Application to Large Volumes of Digitized Well Logs
Authors: Althaus V.E. , Lean J.D. 
Published: December 2007

Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussions may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
Large volumes of digitized well logs can only be used efficiently if computer programs are available to assist in digitizing quality control, data editing, storage and retrieval, analysis and display. To date, the major industry effort has been directed toward improved analysis programs. This paper summarizes several of the more important applications of computers to well logs.

Introduction
The number of uses of digitized well logs is increasing in the mineral industries. Standard and exotic analysis programs are yielding more information from logs than was previously economical by hand methods. These previously economical by hand methods. These programs are applicable to one or several programs are applicable to one or several wells in reservoirs, fields or basins. The efficient use of these analysis programs for multiple wells demands other computer programs to quality-check and edit the digitized data, to store and retrieve it and to display the analysis in a form appropriate to the study in progress. Underlying all uses of digitized well logs, however, it the assumption that the digitized data faithfully represent the measurements made by the logging sonde.

Data Quality
Many applications of digitized logs depend as critically on the digitizing process as they do on the logging operation. Porosity calculations are sensitive to errors in the amplitudes of digitized logs, and certain log correlation and filtering methods may require curves digitized in equal increments of arc length rather than in equal increments of well bore depth.
The computer can assist in the editing and quality control of the log data. The most widely accepted method of checking data is a plotback and overlay technique. While this plotback and overlay technique. While this method is the most accurate when used by technical persons, it has two limitations: it assumes the source document is the most accurate basic information, and it does not take advantage of the computer's speed.
Estimation of Water Saturation from Clay Microporosity Data
Authors: Hurst Andrew , Nadeau Paul 
Published: December 2007

ABSTRACT
Clay microporosity data are derived from image analysis of petrographic sections. These data allow estimation of clay-bound water and establish a quantitative relationship between clay texture and effective volume. Small quantities of highlymicroporous clay may cause drastic degradation of permeability with little effect on total porosity.
Teamwork: The Methodology for Successfully Drilling the Judy/Joanne Development
Authors: Kelly J. H. 
Published: December 2007

ABSTRACT
A "non-integrated" approach was used to manage development drilling of the Judy/Joanne field. Phillips Petroleum Company United Kingdom Limited ( the Operator ) elected to retain the role of project and operations coordinator. Others have felt it necessary to integrate the provision of drilling services to achieve operational effectiveness. The Operator approached the management of the operation on a more traditional tack but with the same goal. The management emphasis was on team building and ensuring each party's contribution was optimized. The "non-integrated" approach to service provision enabled the Operator to maximize the value of inhouse experience, to select the preferred suppliers based on safety and operational performance, and to maintain the leading role required of the lease holder. An incentive contract with the drilling contractor rewarded and penalized performance. It provided a "win/win" arrangement. Contracts with the third party companies were awarded on the basis of "best for purpose". The "non-integrated" approach has proven cost effective and an operational success [1].
Low-Cost Integrated Teamwork and Seismic Monitoring Improved Reservoir Management of Norwegian Gas Reservoir With Active Water Drive
Authors: Grinde Per , Blanché J. P. , Schnapper D. B. 
Published: December 2007

Abstract
This paper shows how new techniques, using integrated seismic and reservoir modelling, have shown there is no need to drill two previously proposed additional producers on the Heimdal gas field. Older simulations had shown this to be necessary in order to recover locally trapped gas. The study emphasizes the necessity of close team work to obtain the detailed reservoir description needed for such a study.
A multidisciplinary team of geologists, geophysicists and reservoir specialists performed this study to reappraise the Heimdal Field. Using seismic attributes from 3D (mainly 2D amplitude versus offset AVO) a detailed structural and seismic stratigraphic interpretation provided the geometrical basis for the field model. A heterogenetic approach (identifying potential flow barriers) to detailed geology was then applied using regional experience and detailed field data including the production characteristics. The resulting reservoir model also incorporated offset fields on common regional aquifers, to properly monitor and predict the dynamic pressure behaviour and aquifer energy in this series of connecting, Paleocene, turbiditic sands.
Two repetitive seismic campaigns have been acquired since the pre-production 3D seismic survey. Mapping of the water encroachment was accomplished using advanced interpretation techniques of 2D AVO and inversion. The results have been integrated into the dynamic matching process in the reservoir simulation.
Targetting the Guinevere Horizontal Well: A Case Study Involving Geostatistics, Reservior Description, Reservoir Simulation, and Drilling Engineering
Authors: Fisher W. C. , Bond D. J. , Skeith G. L. , Bonnett Nigel , Gadgil A. G. 
Published: December 2007

ABSTRACT
The 48/l 7b-G2 well was the second and final development well on Guinevere; a UK Southern North Sea Rotliegendes gas field.
Guinevere is an aeolian reservoir developed within a faulted anticline with a partial gas column. A horiwntal well as the primary prod ucer was deemed necessary to avoid water influx problems.
The surface location was constrained by the existing vertical well. Optimisation of the bottom hole location and reservoir target was achieved by integrating analysis from a variety of disciplines. The location of the horiwntal section was determi ned by considering the following factors: The thickness of the gas column was prognosed using geostatistical depth conversion methods based on 30 seismic. This was integrated with fault detection and seismic amplitude as an indicator of reservoir quality. Additionally the target horiwn was derived from a detailed geological model and the orientation of the internal reservoir heterogeneity determined the optimum well orientation. Potential interference of the existing vertical and horiwntal wells also influenced the location of the G2 well.
Drilling constraints placed limits on our ability to satisf y all of these requirements.
A well location was chosen which satisfied most of the above considerations. This involved a 160 degree left hand turn in the borehole trajectory. In early 1993 the well was drilled to the chosen location and a 3500 ft horizontal section was successfully completed. The well has proved to be the most prolific in the Lancelot complex.
Assessment of Choke Valve Erosion in a High-Pressure, High-Temperature Gas Condensate Well Using TLA
Authors: Birchenough P. M. , Cornally Darren , Dawson S. G. B. , McCarthy Patrick , Susden Steven 
Published: December 2007

ABSTRACT
Many planned new developments in the North Sea will involve the exploitation of hostile high pressure, high temperature gas condensate reserves. The extremely high pressure letdown over the wellhead choke leads to very high flow velocities, and consequent risks of erosion damage occurring to the choke internals. In a recent study, measurements of erosion have been performed during an offshore well test under flowing conditions using advanced Thin Layer Activation techniques and scaled Laboratory tests.
A New Graphical Technique for Well Performance Projections
Authors: Henry William A. , Vest Gary L. , Tyler James C. 
Published: December 2007

Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussions may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
This paper presents a technique which combines the Rawling and Schellhardt steady state back pressure equation and the standard pressure decline relationship of a gas reservoir to form a graphical display of a well's ability to produce against any one of a multitude of back pressures. This graphical display is constructed on an individual well basis and summarized to form a graph which represents the producing ability of a reservoir or group of reservoirs. This procedure is performed through the use of procedure is performed through the use of a Burroughs 5500 computer and the results are shown on graphs drawn by a Calcomp plotter. In addition to graphical plotter. In addition to graphical presentations, this information is also stored on presentations, this information is also stored on magnetic tapes which can be used in automated studies. The curves are designed to show deliverability and effective producing time as a function of cumulative producing time as a function of cumulative production against three specified back production against three specified back pressures. An interpolation technique is pressures. An interpolation technique is then employed which will allow any back Pressure between a minimum and maximum Pressure between a minimum and maximum to be utilized. The effective use of these curves will allow an engineer to immediately answer for management such questions as how much gas could a well, field, etc., deliver, assuming certain system requirements such as horsepower, etc., in a specified time interval selected by the user? By generating curves for all wells in a reservoir or field and knowing the appropriate allocation formula, we have investigated the future producing capabilities in light of current or producing capabilities in light of current or future regulatory limitations. By summation of the individual well results into curves representing a reservoir or groups of reservoirs, we make up a composite curve representing a field gathering system attached to our mainline pipeline. Utilizing these gathering system composite curves and an allocation procedure for scheduling gas volumes from procedure for scheduling gas volumes from the individual gathering systems, a total pipeline system availability study against pipeline system availability study against varying market conditions can be made for a specified time period.

Introduction
It is obviously important for the management of any gas transmission company to have the facility to very quickly review their gas supply situation to maintain continuity with a changing market.