bluuebunny/crossref_metadata_2025_split huggingface dataset:
Gas Injection in the Safah Field, Oman
Authors: Chen Hsiu-Kuo 
Published: December 2007

Abstract
The Safah field contains 640 million barrels of oil-in-place and 62 billion cubic feet of gas cap. The field is divided into East and West lobes. The East lobe is subdivided into Northeast and Southeast lobes based on PVT properties. The Northeast lobe contains saturated oil with gas cap and the Southeast lobe has undersaturated oil. To arrest reservoir pressure decline and to improve oil recovery, two associated gas injection projects are currently underway in the East lobe. There is a gas cap injection in the Northeast lobe and a down-dip pattern gas injection in the Southeast lobe. Results to date are very encouraging with gas injection contributing about 13 % of field oil production in September 1994. For that month, the field oil production was 34,200 B/p. Total incremental oil through September 1994 is 4.38 million barrels. Comparison of the incremental oil between the gas cap and the oil leg injection indicates that (1) the response is faster for gas injection into the oil leg, and (2) the benefit of gas injection in the oil leg of the Southeast lobe is greater than that of the gas injection into the gas cap in the Northeast lobe.
3D Visualization of Waterflood Sweep, Petrophysical & Lithologic Data for Reservoir Management
Authors: Dudenas P. J. , Cole J. C. , Esmail W. J. , Dunlap C. P. 
Published: December 2007

ABSTRACT
A large Jurasic Middle Eastern oil field is currently undergoing peripheral waterflooding. The flood front advance from down-dip water injection in often irregular. To ensure efficient reservoir management, it is important that flood front and other aspects of the fluid distribution be monitored and modeled as accurately as possible, in conjunction with available geological data.
Sweep efficiency is routinely evaluated through the use of pulsed neutron and production logs. This data, in addition to all other production data, is used for reservoir management purposes in determining performance for individual wells and for the total field. Traditional 2D images of vertical and areal sweep data often underestimate the complexity of the actual fluid distribution in the reservoir. New workstation-based modeling technology now allows these data to be visualized interactively in 3D, allowing for a much faster and more detailed evaluation of the displacement process.
We incorporated engineering and geological data in the form of sweep efficiency, petrophysical and lithologic data, into a 3D model. The ability to visualize the current and incremental sweep data, along with geological parameters, provides a better understanding of how the flood front is advancing. Factors important in controlling the advance of the front can quickly be brought into focus. In addition, the model can easily be updated with new data.
In this paper, we have shown how the 3D model has helped to improve the areal and vertical conformance through better areal distribution and flow profile control. Results from the model have helped in optimizing development well locations in areas where the flood front is lagging. This integrated 3D model provides a valuable tool for everyday reservoir management activities.
Use of Stochastic Characterization to Select Horizontal Well Trajectories in a Heterogeneous Carbonate Reservoir
Authors: AlHanai W. T. , AlMahdi A. M. , Deeb M. A. 
Published: December 2007

ABSTRACT
Reservoir characterization by stochastic methods allows to deal with complex spatial facies distributions and provide predictions of reservoir internal architecture between wells. Here, a stochastic description is developed for a carbonate reservoir that possesses a complex internal architecture with Significant variations in reservoir properties and random facies spatial distribution. The stochastic characterization starts with conditional simulation of the spatial distribution of the reservoir facies and lithologies followed by estimation of the properties, constrained to the simulated facies geometry. Validation of the realizations is obtained through the information gathered from new wells. The generated stochastic realization is used to define the optimum trajectories of the planned horizontal wells.
Application of Polymeric Damage Removal Treatment Results in Multi-Fold Well Productivity Improvement: A Case Study
Authors: Brannon Harold D. , Tjon-Joe-Pin Robert M. 
Published: December 2007

Abstract
Well productivity can be significantly reduced by permeability damage. The damage in many cases is due to inadequate degradation of gelled treating fluids and the residual polymeric filter cakes on the formation face. Several methods have previously been employed to remove polymeric damage in an effort to increase well productivity with limited success.
Polymer specific enzymes have been incorporated into a newly developed technique to facilitate removal of polymeric damage. The new remedial treatment is environmentally safe and can be applied over a wide pH range and at temperatures as high as 300°F. Laboratory analysis using the new system has shown that multi-fold permeability improvements can be achieved through polymeric damage removal.
A case study of several wells suffering from polymeric damage was conducted. Production histories and return flow analysis were evaluated to characterize the damage and guide the remedial treatment design. Several wells treated with the polymeric damage removal treatment demonstrate multi-fold improvements in well productivity.
Fateh Field Production Facility Reconfiguration Project
Authors: Dorcheus S. M. , Landis S. R. , Robertson C. A. 
Published: December 2007

ABSTRACT
Modification of the Dubai Petroleum Co. (DPC) Fateh Field central production facility has reduced wellhead pressures about 10% field-wide, resulting in increased oil production and incremental reserve addition. The facility reconfiguration has reduced operating and maintenance problems experienced with separators and inlet piping, while improving oil recovery.
A key challenge of the Reconfiguration Project was to devise a separation scheme which redistributed fluid between vessels, and an installation method which utilized existing equipment to the greatest extent possible, eliminated downtime during facility modifications, and minimized investment.
Several reconfiguration options were identified and evaluated. The evaluation combined computer simulation results of surface gathering and separation facilities with modelling efforts of the primary Fateh reservoirs. The preferred reconfiguration option was justified on the basis of increased oil uplift associated with the wellhead pressure reduction. The project was successfully completed in mid-January 1994.
This paper describes methods used to evaluate the identified options, project planning, and project implementation. Predicted and actual results are given, and key project execution steps are described.
Multi-Phase Flow Metering Using Dissimilar Flow Sensors: Theory and Field Trial Results
Authors: Mehdizadeh Parviz 
Published: December 2007

Abstract
This paper addresses a new approach to multi-phase flow metering. The Multi-Phase Flow Meter (MPFM) described combines dissimilar flow sensors to measure the flow rates of the gas and liquid components plus a microwave water content monitor to determine the oil and water fractions. A brief review of the alternate technologies and approaches to multiphase metering is included as a basis for explanation of the design choices in this meter. The predicted performance of the meter is compared against field tests that were conducted to assess the performance of the meter. These tests covered a wide range of fluid properties, gas void fractions up to 97%, 0–100% water cut, and various installation geometries. The field tests support the predicted overall accuracy of ±10% of the reading ( ± 2% of the full scale) for liquids and ± 10% of the reading (± 5% of the full scale) for the gas components of the flow.
Fundamental Concepts and Potential Applications of the Windowing Technique in Reservoir Simulation
Authors: Deimbacher F. X. , Komlosi Franz , Heinemann Z. E. 
Published: December 2007

Abstract
The term "windowing technique" means time-dependent replacement of grids and parameters during a simulation run. The window is a confined area within the block model and it contains an other grid than the surrounding basic grid. The basic grid is Cartesian, while the grids inside windows can be Cartesian but with a different spacing, or 2D or 3D irregular grids. A window may also contain a different parameterization of the same basic grid.
The basic Cartesian block model and the windows are independent entities. A well-defined relation between windows and basic grid permits the exchange of the grids during the run. Dual timestepping allows the use of large global timesteps outside windows and other (usually smaller) timesteps inside windows. Effective parallel processing of the windows is also possible.
Potential applications of windows are well test simulation models embedded in coarse grids, modeling of arbitrary-direction horizontal wells, different realizations of stochastic modeling, effective parameter updating during the life of a model, etc.
Upscaling of the Waterflood Reservoir Properties on the Core Level: Laboratory Study, Macro and Micro Modelling
Authors: Bedrikovetsky P. G. , Potsch K. T. , Polyanin A. D. , Zhurov A. I. 
Published: December 2007

Abstract
The aim of the paper is to develop a mathematical model for waterflooding at high velocities in short cores under laboratory conditions. The model is based on the theory of non-equilibrium two-phase flow in a porous medium. The asymptotic solution includes the capillary pressure and non-equilibrium effects. It allows for determining an expression for the stabilized zone, which leads to an optimal core length and an optimal displacement velocity. With these parameters it is possible to plan waterflooding tests for determining the relative phase permeabilities with a given accuracy.
Water Coning and Critical Rates in Vertical and Horizontal Wells
Authors: Menouar H. K. , Hakim A. A. 
Published: December 2007

ABSTRACT
Producing oil at a water cut higher than necessary has always been a preoccupation for practising engineers. The existence of a critical rate above which excessive water production occurs has been mentioned earlier in Muskat’s work on bottom water drive and in Dietz’s paper on edge water drive. Since these pioneer studies, numerous papers have been published on critical rate. Some of these studies were based on laboratory experiments, others were based on analytical derivations; both approaches have limitations. In this study, a simple and accurate method to calculate the critical rate is presented. This method can be implemented either by numerically solving the equations of flow or by directly using a numerical simulator. The calculations are consistent with the present literature. However, there is disagreement with existing literature in at least two instances.
For horizontal wells, most of the studies present the critical rate as an increasing function of the anisotropy ratio. The present study shows that this is true only for 0.5 &lt; a &lt; 1. In fact, for 0.01 &lt; a &lt; 0.1, critical rate is a strongly decreasing function of anisotropy ratio. This is not a mere theoretical case. Many reservoirs with discontinuous thin silt barriers are believed to display very low anisotropy ratios.
Most of the studies describe the vertical well critical rate as a decreasing function of the anisotropy ratio, opposite in behavior to horizontal wells. Although the present study agrees with the general trend, it shows that there is in fact a harmonious continuity between vertical and horizontal wells and short horizontal wells display a behavior in between.
Other results of this study present relations in dimensionless form that describe the effect of anisotropy ratio, horizontal well lengths, well penetration and reservoir geometry on critical rates.
A Laboratory Study of Nuclear Magnetic Resonance Relaxation and its Relation to Depositional Texture and Petrophysical Properties — Carbonate Thamama Group, Mubarraz Field, Abu Dhabi
Authors: Kenyon W. E. , Takezaki H. , Straley C. , Sen P. N. , Herron M. , Matteson A. , Petricola M. J. 
Published: December 2007

ABSTRACT
We performed laboratory measurements to deter= mine whether NMR logging would improve log evaluation of the Mubarraz Field. The Mubarraz Field is a carbonate field in offshore Abu Dhabi, that produces from the Cretaceous Thamama Group.
Existing log evaluation using classical logs has some shortcomings. Some zones that are not highly resistive actually produce water-free oil. This is because Mubarraz samples often have a large amount of mi-croporosity. The microporosity occurs because samples are highly micritized, and grain-sized particles are generally peloidal with internal microporosity. The microporosity holds a large volume of capillary-bound water, which results in low resistivities in zones that still have producible oil in large pores. An additional evaluation problem is that permeability varies widely while porosity remains almost constant. As a result, permeability vs. porosity correlations are less valuable than normal.
In laboratory measurements on Mubarraz samples, we found that NMR relaxation measurements can provide: good estimation of the capillary-bound water volume at an air/water capillary pressure of 25 psi, using a cutoff on NMR T2 relaxation time of 190 ms.good identification of the grainstones as opposed to the lower-permeability textures (packstone … mudstone) with a T2 threshold of about 225 milliseconds.estimates of permeability that are significantly better than can be obtained from porosity alone.
NMR relaxation measurements contain information about the pore size distribution, and it is this information that permits estimation of production-governing parameters. The estimators are based on parameters that can be obtained from continuous NMR logging.
We compared NMR measurements with a synthesis of laboratory measurements that characterize micro-geometry. The synthesis is based on modeling wackestones as packed near-spherical particles of equal size. Values computed from this model for permeability, surface area and mercury injection agree with measured values. This model is a useful starting point for more complex models.
We also observed that lower values of cementation exponent m were associated with higher dolomitexalcite ratios and shorter NMR relaxation time T2. The variations in m are large enough to affect interpretation of water saturation from resistivity logs. We tentatively ascribe these associations to the presence or absence of dolomite rhombs which fill solution pores. Solution pores are generally accompanied by high cementation exponents. When they are large, solution pores exhibit NMR relaxation times that are large. Their long relaxation times make interpretation of NMR logs more difficult, because they are indistinguishable from the long relaxation times of intergranular pores that are associated with high permeability.
Estimating The Full Costs Of Oil And Gas Production
Authors: Stauffer T.R. 
Published: December 2007

T.R. Stauffer
SPE Member

Abstract
Methods for calculating the full-cycle, economic costs of new oil production are compared and tested for accuracy. The method pioneered by M.A. Adelman is generalized and shown to be accurate over a wide range of conditions.
The estimated "costs" are most accurate where reliable data on reserves are available, but useful results are still obtainable as long as the reservoir decline rates can be approximately determined. Even where data on expenditures in the given area are not published, synthetic costs can still be estimated by extrapolation as long as the drilling data are believed to be reliable.
The methodology is illustrated for the case of the PDO concessions in Oman.

Introduction
This analysis develops and tests a method for calculating the economic costs of incremental oil or gas production. It can be used most readily where data on the expenditures is available - as for the Canadian provinces or regions of the U.S. - or for companies which file reports consistent with GAAP. Even more usefully, it also can be applied to areas such as the former USSR, where data on production and drilling are published and reasonably reliable, but where the expenditure data are quite worthless.
The most frequent reporting of "costs" data is not generally useful. The usual data are "expenditure costs", i.e. the outlays in a given year are divided by the gross reserves added in that year. This measure of "cost", even when arithmetically accurate, is conceptually flawed:–It does not incorporate the time cost of money, since the reserves added would be produced over an extended period.–The "cost" commingles outlays for current development with those for longer-term exploration programs.
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Practical Requirements for Sand Production Implementation in Heavy Oil Applications
Authors: Dusseault M. B. , Geilikman M. B. , Roggensack W. D. 
Published: December 2007

Abstract
Cold production as a new primary production process can be used successfully in heavy oil unconsolidated sandstones. Ideal reservoirs are 5–15 m thick uncemented sands with high saturations of &lt;20°API oils with gas in solution without free water or gas zones. However, application of Cold Production to many other cases in other parts of the world imust be investigated. Strategies to initiate sand production involve aggresive perforation and swabbing measures. Keeping sand production stable after initiation requires pumps to cope with large initial sand ratios in a foamy oil form for several weeks, and smaller amounts of sand and foamy fluid continuously for many months. Restoring stable sand production after blockage is currently an "art", and various workover methods are used: better controlled work-over approaches and new technologies are needed. Sand and "gorp" separation from oil at surface is necessary, economic and environmentally sound disposal of these materials probably involves re-injection into depleted reservoirs.
Discussion on The New Technology of Plugging in Termal Recovery
Authors: Shenghou He , Yongming Li 
Published: December 2007

Abstract
The energy produced by steam injected to bottom-hole can generate ultrasonic wave through ultrasonic generator connected at the bottom of the steam injection tubing string, which induces bottom-hole oil-water mixture to form supermicro emulsion. With continuous steam injection, the emulsion accmulates toward high permeable zone. Thus steam injection profile has been improved and steam overlap overcome. Good results have been obtained in lab experiments and field application in Le An Oilfield by using this technology. This paper presents the study and application of this technology and other effective technology for plugging in Le An oilfield.
Optimizing Steamflood Performance Utilizing a New and Highly Accurate Two Phase Steam Measurement System
Authors: Huff B. D. , Warren P. B. , Whorff Fred 
Published: December 2007

Abstract
A new highly accurate steam measurement system has been developed for the measurement of steam quality and flow rate. This system consists of a "V" cone (differential pressure device) and a vortex meter (velocity device) in series, along with temperature and pressure sensors all interfacing with an electronic datalogger. These basic mechanical meters are both rugged and relatively inexpensive for field monitoring purposes. Tests performed in active steam drive projects prove the viability of this system. As a result, every injector in our Coalinga field (around 100 steam injectors) have been economically justified for utilizing this new technology, Ever since the application of steam for commercial EOR operations, the petroleum industry has been searching for a method to determine both steam quality and flow rate for monitoring, analyzing and optimizing steam drive projects. This paper presents an overview of the new system, the background and development work that has been completed to date, and the reservoir analysis and economic justification required to implement this project.
Permanent Instrumentation for Production Optimization and Reservoir Management
Authors: Chalaturnyk Rick , Moffatt Terry 
Published: December 2007

Abstract
The application of existing pressure measurement technology in an Innovative, cost effective manner provides an opportunity to obtain producing bottomhole pressure and temperature over the life of a well - without impacting the producing environment of the well. Utilizing an engineered housing design, pressure sensors are installed on the outside of production casing with special pressure ports providing access to internal and/or external pressures, A brief description of this innovative technology is provided along with comparisons to existing techniques for bottomhole pressure measurement. The application of permanent systems in vertical, slant and horizontal wells is discussed for primary, EOR and thermal recovery processes. Field results for slant and horizontal well installations are presented and discussed. Bottomhole pressure measurements of the cementing process for horizontal wells show that classic assumptions regarding hydraulic isolation may need reassessment. The role of permanent bottomhole pressure/temperature installations for production optimization and reservoir management is reviewed and discussed. Considerable effort is currently being expended to provide effective pump control options for all pumping systems (progressing cavity system, ESP and rod pumps). Permanent installations provide an ideal solution to pump control: direct input of bottomhole pressures into variable frequency drives allows pump control based on the one variable upon which pump control should be based - bottomhole pressure.
Design of a Commercial SAGD Heavy Oil Project
Authors: Edmunds N. R. , Suggett J. C. 
Published: December 2007

Abstract
CS Resources is currently undertaking the construction of an 800 m3/day (5,000 bpd) thermal project near Senlac, Saskatchewan. The Senlac Thermal Project will use a steam assisted gravity drainage (SAGD) process to recover as much as 3.2 е6 m3 (20 mmbbl) of 13°API oil from a Dina channel sand.
This paper discusses some of the production and facility engineering issues arising in this full scale SAGD scheme. Compared to primary or conventional thermal operations, some of the unusual aspects are: very high injection and production rates from individual wells; the need to manage the large amount of heat in the production stream; and a pronounced interdependence between the various project components. Reservoir description, production forecasting, and facility optimization are briefly discussed.
COSH Performance and Economic Predictions for Six Field Types in Western Canada
Authors: Lau E. C. , Good W. K. , Kanakia V. 
Published: December 2007

Abstract
The COSH Process (COSH is the acronym of Combustion Override Split-production Horizontal-well) was conceived based on experience gained from a number of successful gravity drainage processes and the less fortunate fireflood process. Typical combustion operational problems such as early oxygen breakthrough, severe sanding and gas locking of downhole pumps are minimized by using an innovative well arrangement to segregate and control the fluid flows. This process is perceived to work very well in a wide variety of reservoirs, ranging from oil sands to conventional bottom water reservoirs.
In February 1994, a joint ADOE/Industry COSH Process Development Task Force consisting of 18 industry, government and research member companies was formed to assess the commercial development potential of COSH in Western Canada. The performance and economics of six high potential field applications, including Athabasca McMurray tar sands, Provost McLaren channel sand, undeveloped Cold Lake Clearwater oil sands, Battrum Roseray, Bellshill Lake Blairmore sand and cyclic steam stimulated Cold Lake Clearwater oil sands, were studied. This paper compares the results of this study and outlines the major technical issues identified by the Task Force.