bluuebunny/crossref_metadata_2025 huggingface dataset:
An Environmental Mapping Methodology Adapted to the Needs of Petroleum Operators
Authors: Veyradier L. , Coquelet D. , Dutrleux E.
Published: December 2007

Environmental mapping programs were carried out in three countries of intensive petroleum activity, located in the Gulf of Guinea: Gabon, Nigeria and Congo. The aim was to produce maps of environmental sensitive variables (thematic maps), which are used by the petroleum operating companies for improving the management of the environment. The maps are particularly useful for oil spill response organization or environmental assistance in the development of infrastructures. Whilst carrying out these applications, a mapping methodology adapted to the petroleum industry was developed and tested.

In the first section, this methodology is described and illustrated by the above mentioned applications. The specific locations are selected according to their ecological, socio-economic or petroleum special interest. Remote sensing data are used as an initial source of information. Two types of thematic maps are produced: the first one dedicated to the ecological components, and the second one to the infrastructures and the environmental sensitivity, assessed from the ecological and socio-economical components. These maps can be integrated into atlases with accompanying text, and in order to make them more operational, all the mapping data collected are integrated into a Geographical Information System (GIS).

In the second section, we present the innovative aspects of these R&D works, which concern mainly the adaptation of remote sensing for the environmental expertise and the use of GIS for full data integration and easy updating.
BHA Design Algorithm for Extended Reach Wells
Authors: Agawani Mamdouh M. , Rahman Sheik S. , Maidla Eric E.
Published: December 2007

A design criterion is developed to select the optimum bottomhole rotary assembly configuration (drill collar size and stabilizer positions). This allows maximum correction in the hole inclination by changing the weight on the bit while drilling a section of a hole. A computer algorithm is written in FORTRAN code to optimize the bottomhole assembly configuration. This algorithm can be used with any BHA model that calculates forces at the bit under static or dynamic conditions. A case study is presented to explain the design algorithm.

Introduction

Directional wells are usually kicked off from vertical by some type of bent sub/bent housing and downhole motor. When the hole inclination becomes sufficiently high, drilling may resume with a steerable system or a rotating system.

In conventional rotary systems a packed-hole assembly uses a sufficient number of stabilizers so that no significant change in hole angle occurs. Likewise, proper stabilizer positioning can increase the hole angle via the fulcrum principle, or it can decrease via the pendulum principle (1985). Conventional rotary systems are normally designed to drill holes with a constant rate of change of inclination. However, discrepancies between prediction and field results frequently occur. Therefore, experience and knowledge are necessary tools in the selection of such a drilling system.

Steerable systems are widely used in drilling horizontal and extended reach wells. This is mainly because, drilling direction can be changed in a more controllable way to follow a predetermined trajectory without the need of changing the assembly. The bottomhole configuration of steerable systems, however, creates major torque and drag problems while drilling highly deviated wells in the sliding mode. It becomes difficult to have even torque distribution on the bit which is essential to control tool-face. High drag can limits the ability of maintenance of a constant weight on the bit. This reduces penetration rate and makes it hard to control tool-face as the reaction torque at the bit varies. Furthermore, drag can limit the total horizontal displacement.
FLEX: An Object-Oriented Reservoir Simulator
Authors: Verma Santosh , Aziz Khalid
Published: December 2007

This paper describes the design of FLEX, an object-oriented, flexible grid, black-oil reservoir simulator. An object-oriented decomposition of a reservoir simulator helps in dealing with the complexity of this problem. This approach is particularly useful because of the difficulties associated with generation and use of flexible grid geometries (like Voronoi, median, boundary adapting grids, etc.).

The entire problem is divided into subsystems like geometry, gridnodes, gridnode connectivity, grid, reservoir fluid flow, and matrix. Each of these subsystems have objects which are closely related. The dependency of these subsystems is established. A detailed analysis of each subsystem leads to identifying the classes, which are a set of objects having similar behavior. Attributes and behavior of the classes are assigned. After establishing relationships between the classes, they are arranged into hierarchies. About one hundred major classes have been identified and designed to achieve the desired behavior from FLEX. The programming language used is C++.
Inverse Methods and Advanced Statistics in Well-Test Interpretation
Authors: Domski P.S. , Roberts R.M. , Avis J.D.
Published: December 2007

A new approach to quantifying parameter uncertainty has been implemented in the numerical welltest simulator GTFM. The method incorporates inverse techniques, advanced statistical analysis, and probabilistic techniques. The approach is holistic in that it accounts for uncertainty introduced at all stages of the testing and analysis procedure. The methodology expands upon accepted methods by giving greater emphasis to model assumption diagnostics and parameter uncertainty.

Approach

Model assumption diagnostics are used to distinguish between competing flow models. Candidate flow models are evaluated based on the distribution of residuals between the measured data and the model response. A flow model is accepted if its residuals are normally distributed and discarded if the residuals deviate from the normal distribution.

Typically, parameter uncertainty from pressure-transient tests is analyzed using a discrete sensitivity analysis in which a single parameter is varied while keeping all other parameters constant. More recently, inverse techniques have focused on the estimation of confidence intervals which put bounds on the values of fitting parameters. This approach is limited by the assumption that there are no correlations among fitting parameters. and that non-fitting parameters are known perfectly.

For our new probabilistic-based approach, joint-confidence regions are calculated to quantify the fitting-parameter uncertainty resulting from parameter correlation. For non-fitting parameters. distributions are assigned, sampled using a Latin Hypercube sampling routine, and an inverse procedure performed for each set of sampled parameters. This process results in a distribution of joint-confidence regions for the fitting parameters (Fig. 1), which in turn is an expression of uncertainty in the non-fitting parameters. The new approach also makes it possible to graphically display the correlations between fitting and non-fitting parameters for sampled populations.

Forward simulations using parameter combinations from Figure 1 result in virtually no change in the goodness-of-fit of the simulations to the data (Fig. 2). This approach to quantifying parameter uncertainty differs from other approaches in that the simulated fit shows no degradation within the parameters uncertainty range because correlations between parameters is not neglected.

Conclusions

Uncertainty in fitting-parameter values can result from uncertainty in the conceptual flow model, data noise, correlations among fitting parameters, and correlations among fitting parameters and imperfectly known nonfitting parameters.

P. 267
Mathematical Model for Immiscible Displacement Honouring Hysteresis
Authors: Bedrikovetsky P. , Marchesin D. , Ballin P. R.
Published: December 2007

To describe two-phase displacement with hysteresis we use the Buckley-Leverett model with the imbibition, drainage and scanning fractional flows. Mathematical theory for the initial-boundary non-self-similar problems is developed. Structure of solutions is presented together with the physical interpretation of phenomena.

Analytical solutions for the injection of the water slug with the gas drive and for the sequential injection of water and gas slugs with the water drive are obtained. The solutions show that the hysteresis decreases the gas flux in the case where the drainage relative permeability is lower than the imbibition one, which is a positive effect for the WAG injection.
Environmental Performance Indicators With Emphasis On ISO Development And Application In Oil Industry
Authors: Refsnes Karin , Kjelaas Anton G.
Published: December 2007

A set of preliminary specific environmental indicators reflecting significant environmental aspects for the company has been developed. The choice of final indicators will be based upon the company's own priorities and interpretation of stakeholders interests and environmental impacts. The selected indicators are relative whereever possible. Indicators are identified mainly in the operational area and the management area. Some indicators are also proposed within the external impact area. Indicators in the operational area focus on emissions to air (CO2, NOx, VOC, CH4), energy, discharges to sea from drilling, production and pipelines, waste generation, accidental releases and disposal of platform installations.
Characterization and Flow Modeling of a Heterogeneous Carbonate Reservoir in Daleel Field, Oman
Authors: Abbaszadeh Maghsood , Koide Naoki , Murahashi Yoya
Published: December 2007

This paper presents applications of deterministic and geostatistical reservoir characterization methods to the heterogeneous carbonates of the upper Shuaiba formation in Daleel field, Oman. High resolution reservoir descriptions based on the integration of logs, core, pressure transient tests, geology and seismic data are constructed; and properly upscaled for use in reservoir simulation models in history matching of field performance data. Deterministic descriptions utilize three and six layer models to assess the impact of layering heterogeneity on reservoir performance. Conditional geostatistical methods of SGSIM and SISIM with and without explicit modeling of geology generate fine-scale realizations of porosity and hydraulic flow units, which are then used to construct permeability and initial water saturation distributions. Permeability heterogeneity is upscaled to coarse-scale simulation gridblocks by an improved upscaling method based on an upstream-weighted interblock transmissibility algorithm.

The study shows that detailed and concise reservoir descriptions result in history matches that are more consistent with a variety of measured data. Generally, geostatistical techniques combined with geology and proper upscaling of permeability heterogeneity yield best results without artificial alterations in various fluid and rock properties. Although acceptable history matches could be obtained with less detailed reservoir descriptions, these required modifications to fluid and rock data beyond reasonable ranges, illustrating the need for detailed reservoir characterization.
An Integrated Study of the "S" Structure: A Case Study in Offshore Abu Dhabi, UAE
Authors: Lyon T. A. , Azer S. R
Published: December 2007

This paper is a case study of the S structure and is drawn from an integrated study involving interpretation of a 3D survey acquired in 1992. The S structure, located offshore Abu Dhabi, is a relatively low relief feature discovered in 1970. To-date nine wells have been drilled on the structure. The major oil reservoirs are in the Thamama (Lower Cretaceous) and Arab (Upper Jurassic) litho-stratigraphic units. The prime reason for acquisition of the 3D seismic was to better quantify the structural uncertainties. The results of the study have been used to plan future drilling locations and estimate their likely impact on uncertainty reduction.

The low relief of this structure makes depth conversion an important issue. Layer cake and single layer depth conversions were evaluated. The velocity models for the overburden were determined using a combination of well data and stacking velocities. The uncertainty in velocity determination has been estimated in order to allow the generation of minimum and maximum structural cases.

Paleo-stfucture maps were generated in order to study the evolution of the S structure. The paleo-reconstructions were derived from a combination of the 3D seismic, 2D seismic and the available well control in the sub-regional area. A detailed geological layering scheme derived from core analysis, thin sections and log correlation was integrated with the structural interpretation via geocellular modeling software.

The integrated model was used for sensitivity analysis, volumetrics and visualizing the reservoir description.
Seismostratigraphic Interpretation of Lower Thamama/Hahshan in SE Abu Dhabi
Authors: Landmesser P. , Saydam A. S.
Published: December 2007

Seimostratigraphy, areal distribution, and depositional environment of the Early Cretaceous age Lower Thamama/Habshan carbonate depositional sequences in the SE part of Onshore Abu Dhabi were studied using seismic, VSP, and well log data. Sequence boundaries were determined from the seismic data by extracting wavelets and establishing accurate correlations between the wells and the seismic data. The Global Eustatic sea-level curve and seismostratigraphic concepts were utilised to define four depositional sequences in Lower Thamama/Habshan, and predict their environment of deposition and lithology.
Water Shut-Off Case History Using Through – Tubing Bridge Plugs; October Field, Nubia Formation, Gulf of Suez, Egypt
Authors: Borling D. C. , Powers B. S. , Ramadan N.
Published: December 2007

Through-tubing bridge plug (TTBP) water shut-off (WSO) workovers in the October Field have resulted in an average incremental initial production increase of 2500 bopd per job. Average water cut (WC) was reduced from 55% to 16%. Seventy-eight WSO workovers have been completed since December 1991. Technical and economic success approach 90%. Just under $4.8 million dollars has been spent for an average cost of $61,500 per job. Costs paid out in less than two days using a normalized $13 per barrel crude price. Based on results achieved during the past 4.5 years, these WSO workovers establish the October Field as a notable and on-going case history for lower zone water control.

Water production from the October Field has gradually increased during the past decade. As a result, steeper production declines and gas lift operational problems developed. Based on reservoir characteristics, lower zone water was isolated using TTBP's conveyed by way of portable mast electric line units. A dump bailer was used to place a 14 foot cement cap over the TTBP to provide a permanent pressure seal. After a 24-hour shut in cement cure period, wells were almost always returned to production at a significantly higher oil rate and dramatically reduced WC. The cost of a rigless TTBP WSO workover is much less than conventional rig deployed WSO work which averaged over $500,000 per job. Prior to December 1991, rig WSO's were the only method used in the October Field. Hence, rigless WSO workovers have become vital for cost control. Rigless WSO work has also become a useful reservoir management tool for maximizing oil production and minimizing water production thereby conserving reservoir energy and optimizing lift gas.
Accuracy of SORw and SORg Monitoring in a Middle East Carbonate Reservoir
Authors: wiltgen Nick , Al-Merikhi Sultan , Al-Othman Ibrahim
Published: December 2007

Accurate knowledge of oil saturation and its distribution is essential for any reservoir being considered for redevelopment or for secondary and tertiary operations. Determination of oil saturation forms the only rational basis for prediction of recoverable oil reserves and it is critical in the selection, design and economic evaluation of an oil-recovery process.

As technology advances, more of this oil will come within our reach. However, it is essential that we understand the reservoir involved so that proper, economically viable technology can be applied. Thus, the importance of residual oil saturation (SOR) which in turn is the basis for the estimation of remaining oil-inplace.

Five techniques to determine remaining oil saturation are currently used. They are coring, logging, chemical tracers, reservoir engineering studies and pressure transient tests. Normally, two or more of these methods are used together and the data evaluated as a whole since each technique has its own advantages and limitations. When evaluated together, a clear understanding of the total reservoir can be obtained.

Conventional logging tools and procedures have been used extensively for many years for determination of reservoir and fluid properties. Although SOR determinations normally require a higher degree of accuracy than is commonly achieved by conventional logging methods, the incentive to use logs for SOR measurements remains high. They are often cheaper and easier to use than is the case for other methods which are currently available for measuring SOR.
Oil Lift Curves Automation
Authors: Alkhatib Fatime
Published: December 2007

An automated tool that facilitates the utilization of oil lift curves (well head flowing pressure versus rate) is essential in order to obtain consistent and accurate lift results efficiently in E&P companies.

This paper describes the method used for implementing such a tool and how it integrates with other related information systems and software packages. It explains how these techniques can be applied in some reservoir and production areas to achieve the best well performance and make future predictions.

The theory employed in generating lift curves is based on locating the intersection between a well's Inflow Performance Relationship (IPR) and a Vertical Flow Performance (VFP) curve. It returns the flow rate and Bottom Hole Pressure (BHP).

IPR depends on reservoir pressure and a well's productivity index.

The VFP curve is generated from ECLIPSE or PROSPER analysis software package at specified values of the well's tubing head pressure, water fraction, gas fraction and artificial lift quantity.

Background

The business cycle starts when the daily oil allowables for all Well/Strings are defined at the beginning of each month by the Reservoir Section and sent to the Production Section. Consequently, the corresponding daily required well head flowing pressures (WHFPs) are manually derived at the office from the latest available Lift Curves initially generated by the Reservoir section. After the implementation of the derived WHFPs at the Field's site, the measured WHFP for each well/string is introduced to the oil allocation business process. The corresponding daily well/string estimated oil rates are also manually obtained from the same Lift Curves. At the end of the month, measured WHFPs and estimated oil rates are sent to the Reservoir Section. Data is revised and finalized by referring to the latest available lift curves in order to use, it in calculating the daily allocated oil rates. Lift Curves are updated by both parties from Production Flow Test Results to fit within the latest test points. On the other side they are used by Well Testing Section as a measure for accepting or rejecting Production Flow Tests. This depends on the location of the oil rate Vs WHFP point measured by the test, if it lies within the general trend of the latest Lift Curve or not.

P. 648
Resistivity Measurement in Anisotropic Horizontal Carbonate Wells
Authors: Al-Riyami A. , Boyd D. , Dajani N.
Published: December 2007

Conventional resistivity tools run in horizontal wells give misleading readings in highly anisotropic formations. These tools are designed to read beyond the invaded zone to obtain true resistivity of the formation. While this design feature is an advantage in vertical or deviated wells, it leads to errors in anisotropic horizontal wells where the tools are affected by neighboring layers. Conventional shallow resistivity measurements would not give true formation resistivity because of mud filtrate invasion.

In horizontal injector wells with zones of actual water saturation exceeding 60%, logging with conventional resistivity tools resulted in calculated water saturation of less than 30%. Production testing of the formation and changing casing setting depths are parts of the consequences of the unexpected low water saturation. Four different resistivity tools were ran in a well to investigate their relative responses.

The logging while drilling Geosteering Tool (GST*) was used for the first time in the Middle East to determine Rt of a horizontal well. The tool is shallow reading with the resistivity measurement located at the bit to minimize the effect of invasion. This resulted in a realistic water saturation of 70 – 80% compared to 20 – 30% obtained from conventional tools. Model simulation of the readings of both conventional tools and GST confirmed the field measurements.

For drill pipe conveyed application in horizontal wells, the Azimuthal Resistivity Imager (ARI*) provides 12 directional readings around the tool. Eliminating the adversely affected directional values allows proper Rt determination.

The paper will compare the results of the Azimuthal Resistivity Imager, Geosteering Tool, RESISTIVITY AT BIT and conventional tools. Modeling demonstrates the different response of electrical tools in the vertical versus horizontal plane. The paper will highlight the advantages and limitations of each resistivity tool particularly in horizontal anisotropic carbonates.
Classic and High-tech Tools for Improving Reservoir Behaviour Understanding – Example from an Offshore Abu Dhabi Field (UAE)
Authors: Lapointe Philippe , Bellorini Jean , Petricola Mario , Mahmoud Akbar
Published: December 2007

In order to improve oil recovery from the main oil producing reservoir of an offshore Abu Dhabi field, two gas injection pilots have been tested. To explain their relative performances, a combination of classic tools (cores, electrical logs) and high-tech tools (DSI, FMI, CT-Scan) as well as 3D seismic have been used to further investigate the reservoir anisotropy in one of the pilot area.

The logs indicate the presence of a fracture system. The full comprehensive core versus log calibration allows to extend the results found to the non cored intervals. The combination of the classic and high-tech tools leads to a better understanding of reservoir behaviour and heterogeneities.
Improvement of Wellbore Injection Profiles In Stratified Reservoir Using Polymer Treatment
Authors: El-Hadidi S. , Dabbouk C. , Falade G.K. , Al-Ansari F.
Published: December 2007

The main focus of this paper is the applications of polymer treatment in controlling injectivity profiles and the improvement of the conformance of the near-wellbore injection profiles. Reservoir high permeability zones causing distortions of water injection profiles at the wellbore, and the possible existence of layer barriers were identified using conventional investigation tools such as Open Hole Logs, Production Logging Tools, Formation Micro Scanners.

A polymer screening procedure was put in place so that appropriate polymer formulations for use as agents for reducing fluid mobility in the high permeability zones at the wellbore can be identified. The use of these polymer formulations facilitated the improvement of near-wellbore conformance of injectivity profiles.

The success or failure of field application or the polymer treatment program was ascertained by using a monitoring program which combined the application of the Production Logging Tools with well test analyses.

Introduction

The presence of high permeability streaks and fractures is a common occurrence in stratified carbonate reservoirs. If these reservoirs are subjected to patterned waterflooding operations, it is not uncommon for the highly permeable zones to accept most if not all of the water injected. This tends to distort the injectivity profile at the wellbore and raises the possibility of an eventual poor reservoir coverage and sweep efficiency. Therefore, a successful water-flood project necessarily demands a clear understanding of reservoir characteristics with a view to identifying the incidence of high permeability streaks, channels, and layer barriers so that adequate remedial actions that can reduce their adverse effects of water-flood performance can be put in place. One of such remedial actions which have gained prominence in the recent past, is the use of Polymer1,2,3 and Non-polymer4,5 agent in injection/Production wellbore profile modification.

In this paper, we present the screening, monitoring and evaluation procedures for a successful application of a cross-linked polymer formulation on water injection wells in order to improve the wellbore conformance of injectivity profiles.
Improved Oil Recovery by Pattern Gas Injection Using Horizontal Wells in a Tight Carbonate Reservoir
Authors: Dello L. , Miyake S. , Kawaguchi K. , Kimoto M.
Published: December 2007

This paper presents an evaluation on the combined use of horizontal wells and gas injection in a tight reservoir. The application of geo-statistics and compositional reservoir simulation are demonstrated in the evaluation to model heterogeneity and understand fluid behaviour.

Normally, gas injection performance in a low-relief reservoir is poor due to adverse gravity segregation. Furthermore, gas injection performance tends to worsen if permeability improves toward the top of the reservoir.

The combined use of horizontal wells and gas injection under various configurations was evaluated to optimise oil recovery in the tight part of a major reservoir in a giant oil field offshore Abu Dhabi. This part of the reservoir is characterised by very low permeability (<5 millidarcy average) with the best permeability in the upper portion.

The evaluation concludes that the use of horizontal wells in a line drive pattern together with gas injection should greatly improve oil recovery in this tight reservoir. The improvement is attributed to the combined effect of linear flow and a large pressure gradient between the injector and producer due to the low permeability, drastically reducing the effect of gas over-ride due to gravity. Hence, as permeability increases, gas injection is predicted to be less effective. The results from the evaluation were used to optimise a pilot gas injection project.

The effect of permeability heterogeneity at the scale modelled is not likely to be detrimental to gas injection. This is because the reservoir is predominantly of low permeability, even though, statistically, high permeability does exist. The geo-statistical modelling suggests that the likelihood of high permeability continuity is low and therefore is not likely to channel gas to producers. More important in the predicted performance of the geostatistical models is the method of up-scaling and permeability averaging. Misleading conclusions may result if the averaging process does not correctly account for the predominant flow regime.
Installation of GRE Pipeline in Bunduq Offshore Field
Authors: Tsutsumishita K.
Published: December 2007

Installation of GRE Pipeline in Bunduq Offshore Field.

Production losses of up to 100,000 STB per year were created by the need for testing at an offshore wellhead platform with multiple wells. This led the operator to take a course of action to reduce these losses.

Todays paper covers investigation of the alternatives considered. The selection and installation of a Glass Reinforced Epoxy (GRE) test flow line as the solution to the problem.

Introduction

A remote multi well platform, located in an Abu Dhabi Offshore Field and having a 270 meter ion flow line to a Central Collector Platform had no test facilities. Consequently when one well was to be tested the other wells had to be shut down leading to significant losses in production.

As future plans are for additional wells on the Wellhead Platform, production losses would increase with an increase in flow testing requirements.

A number of options were assessed. Installing a separate GRE flow line was considered the most viable both economically and technically.

Options Considered

1. Installation of a Multiphase Flow Meter

This option appeared to be the most economical. However, at the time of evaluation the equipment was unproven and not considered to be sufficiently accurate (10%). Extensive piping modifications would have been required to install a test header facility as well as a data link to the main complex.

2. Use of Barge Mounted Test Facilities

This option was considered and rejected as a viable alternative. The system is too dependent on weather conditions and was not considered to be cost effective in the long term.

3. Installation of a Test Separator on the Wellhead Platform.

The installation of a test separator on the Wellhead Platform was found to be the highest cost option, as major modifications would be required.

P. 118
Cyclic Borehole Effects in Deviated Wells
Authors: Bellay Gene , Al-Waheed Hilal , Audah Thabet
Published: December 2007

Highly deviated wellbores sometimes suffer from a cyclic variation in borehole size. Even though the caliper oscillations may be relatively small, a salty mud can combine with the periodic hole size variation to produce wireline data that has been severely compromised. Interestingly, it may be the deepest reading tool (resistivity) which suffers the largest degradation

A straight-forward solution, calibrated to specific wellbore conditions, has been developed which facilitates a much more representative formation evaluation.
The Modern Techniques Of Creative Problem Solving
Authors: Khoorl Ahmed , Ahmed Aftab
Published: December 2007

Introduction

This paper briefly discuses techniques available to modern managers for solving organizational problems and stresses the need to adopt a wholistic approach while doing so.

The paper also highlights the "4 key dimensions of organisation" i.e. organisational process, design, culture and politics and emphasises that any rational and viable solution has to consider all the key dimensions.

Finally, the revolutionary complementrist approach of "triple loop learning" versus the currently practiced "single loop learning" is examined.

2. BACKGROUND

In order to appreciate why organisational problems have grown in complexity one has to go as far back as the second Industrial Revolution. In those days enterprises were family or individual owned. In the early years of the second industrial revolution, very few rules and regulations were in place and enforced by the government, if any at all. Therefore, the industrialists amassed tremendous wealth and power.

The early industrialists could do whatever they wanted within their enterprises. They treated their employees as replaceable machine parts that could easily be discarded once they no longer functioned satisfactorily. Work required little skill while unskilled and uneducated workers were plentiful. They had relatively low levels of aspirations and virtually no social security other than that provided by their families. Therefore, they were willing to work under extremely undesirable conditions to avoid economic destitution.

By the end of World War I things started to change. There were a number of reasons for this transformation, among them: increased education of the work force, increased skills required of the work force as mechanisation increased, increased regulation of working conditions by the government and the "intrusion" of unions into such areas as work conditions, job security and compensation.

Perhaps the most important reason for the transition was the fact that many enterprises could not realize their growth potential even if all the profit they generated was plowed back into them because additional capital required for growth was hard to come by. Consequently, owners either had to constrain their enterprises' growth and retain complete control over them or to go public, thereby relinquishing some ownership and control while generating the required capital.

The survival rate of those enterprises that sought growth rather than control was much higher than those that didn't.

Because of continuing advances in mechanisation, the skills required of workers continued to increase. Workers with the required skills were not as plentiful as those without them. P. 684
The Importance Of Strategic Management For The Long Term Success Of Organizations
Authors: Khoori Ahmed , Ahmed Aftab
Published: December 2007

Introduction

Every business organization has a strategy, whether formal, informal or unstructured, since all organisation's are heading somewhere. However, only successful organizations know where they are heading and how they are going to get there.

There is an old saying, "if you don't know where you are going all roads will take you there". Simply said, you will not know what route to follow unless you know your destination. Similarly, in the business world you will not achieve your objectives unless you know what they are. In todays competitive environment the concept and the process of the strategic management is becoming essential for survival and as such is being widely used by both profit and non-profit organizations of all sizes and magnitude.

The purpose of this paper is to highlight major aspects of strategic management and its importance for the long-term success of an organization in a competitive and ever changing business environment. Furthermore, the application of a strategic management process in ADCO's Budget & Contracts Department will be briefly discussed.

2. THE EVOLUTION OF STRATEGIC MANAGEMENT

The concept of strategic management has been around for a long time and originated from the Greek word STRATEGO meaning to be a general.

Effective Greek generals needed to lead an army, win battles, vanquish the enemy, win and hold territories, protect a city from invasion and treat the people nicely as to gain their support and be less resistive to their presence.

Each of the above objectives required a different deployment of resources. In this context an army's strategy could be defined as the actual pattern of actions taken in response to the enemy.

The Greeks also knew that strategy was more than fighting battles. Effective generals had to determine the right lines of supply, decide when to fight and manage the army's relationship with citizen's, politicians and diplomats, therefore they had to plan and act.

In many respects, business strategy is like military strategy and what military strategists have learned over the centuries can benefit business strategists today. Both business and military organizations try to use their own strengths to exploit competitors' weaknesses. Military conflict and business competition are so similar that many strategic management techniques apply equally to both.

Strategy may be defined as the direction and scope of an organization over the long term and can be viewed from two perspectives:What an organization intends to do - the concern here is to engineer a program for defining and achieving an organization's objectives and implementing its mission.what an organization eventually does - the concern here is with the pattern of the organization's response to its environment, over time.

P. 694
Phase Behaviour of Fluids in Multiple Contact Processes with CO2, N2 and their Mixture
Authors: Abrishami Y. , Hatamian H.
Published: December 2007

The thermodynamic behaviour of hydrocarbon fluids in multiple contact processes with nonhydrocarbon gases (N2, CO2 and their mixtures) has been studied experimentally. A gas condensate PVT cell has been used to simulate the process of multiple contact gas injection in the vicinity of an injection well. Measured quantities at each contact include volumes and compositions of gas and liquid phases at cell conditions of pressure and temperature and the number of moles of each component in the discharged gas. Attention has mainly been given to gas condensates, although the results are equally applicable to oil fluids. The tested fluids are well defined mixtures of paraffinic hydrocarbons and the injectant gases were pure CO2, N2 and their mixtures. Dynamic miscibility was achieved by CO2 injection, while the process with N2 injection was of the immiscible evaporating type, vaporizing light, intermediate and fractions of heavy hydrocarbons. Lean mixtures of CO2 in N2 (5-15% by mole), similar to those in flue gases, had the same evaporation behaviour as the N2, but caused liquid phase swelling effect due to the CO2 solution.
Deploying and Recovering Long and Heavy BHAs in Live High Angle Wells
Authors: Engel Steve , Sehnal Zdenek
Published: December 2007

Until recently, the length of BHAs run into live wells has been limited by surface lubrication length. A tool string deployment system (TDS) has been developed over the past two years and now has a proven record. The case study presented involves running 140m of 3 3/8" guns along a horizontal well. The guns were conveyed on 2" coiled tubing with a cable installed.

These large assemblies require careful engineering and programming to enable coiled tubing to deploy them in highly deviated wells. The paper discusses techniques that have been employed to reduce the drag of the BHA and coil. A clearer understanding of modeling and job planning is evolving and the paper addresses the pitfalls of working coiled tubing to the material limits.
Real-Time Treatment Optimization
Authors: Acock A. M. , Sanders A. H. , Fry L. A.
Published: December 2007

This paper presents recent case studies where down-hole pressure and temperature sensors, run on coiled tubing, provided real-time measurement of matrix acid treatments in the Gulf of Mexico. The information obtained during these jobs allowed on-site design and execution changes to the treatment. Four case studies are presented to demonstrate how the sensor information was used to optimize the treatment of each well.
New Thru-Tubing Sand Control Technology Returns Oil Wells To Productivity
Authors: Holder G. M. , Hadeed J. E. , Crow W. P.
Published: December 2007

Two coiled tubing conveyed concentric gravel packs were performed to repair screen damage of existing open hole gravel packs. Both completions were initially drilled and underreamed to 1!" with a polymerized calcium carbonate drill-in fluid and gravel packed using water pack techniques. Case histories are presented with pre/post production data for this remedial operation which utilized recent technological developments of the circulating gravel pack packer and sand screen. A risk sharing alliance was employed to meet the needs of the operator while providing incentive to the service sector for the first operation of its type in Trinidad.

Cumulative production gain of 500 BOPD from both wells was obtained at a cost savings of approximately $1.8 MMUSD when compared to conventional rig repair options. The payout time for each well was approximately 4 months. These two operations were major achievements in coiled tubing sand control technology for the following reasons:Well E-ll: Longest circulating gravel pack assembly (480’) installed to date.Well E-19: Most sand placed through the gravel pack packer (12,800 lb.).Clarified xanthan gum was used for the first time in this type of operation as a carrying agent due to its shear thinning properties to reduce friction pressure under circulating conditions and provide gravel suspension when static.
Economic Benefits of Advanced CT Life Monitoring
Authors: Brown P. , Pursell J. , Emerick S.
Published: December 2007

The past few years have seen several important developments in the related areas of coiled tubing (CT) fatigue prediction and life monitoring [1-8]. These include:A move away from the Running Feet method, particularly for complex and high risk applications, in favor of theoretical or statistical fatigue models.Calculating and maintaining fatigue records for shorter tubing increments, down from typically 500 feet when depth and pressure data are logged manually, to as small as 5 feet through use of built-for-purpose tracking software and databases.Accounting for factors affecting the working life other than fatigue, such as diameter growth, ovality, welds, surface damage and corrosion.Use of data acquisition systems, providing more frequent and accurate data plus the option of real-time fatigue calculations (especially valuable for CT drilling).

The purpose of any CT life monitoring method is presumed to be to maximize the working life of the pipe while minimizing tubing failures in the field. All of the above developments contribute towards that goal. However, the problem is usually more complicated than this suggests because the criteria vary with the circumstances. Consider two quite different scenarios.
The Feasibility of Using an Electric Downhole Motor to Drill with Coiled Tubing
Authors: Newman K. R. , Stone L. R. , Wolhart S.
Published: December 2007

A study has been performed to determine the technical and economic feasibility of using an electric drilling motor to drill open hole with coiled tubing. An historical review of electric motor drilling was performed, a conceptual design was developed and a market analysis was performed. This paper summarizes the findings from this study. For more details on this study see reference 1.
Improving the Reliability and Efficiency of Coiled Tubing Operations
Authors: Bigio D.
Published: December 2007

This paper will discuss how a simple to operate, personal computer (PC) based data monitoring and recording system can improve the reliability of Coiled Tubing (CT) operations by providing onsite information of real-time key operational parameters like tubing life, tubing forces, operating limits and design versus actual data. It will also describe how the efficiency can be improved by simplifying the repetitive tasks of connecting the data sensors, configuring the system, storing the CT life information with the string itself and generating a customizable report during or after the job.
Frictional Pressure Loss during Turbulent Flow in Coiled Tubing
Authors: McCann R. C. , Islas C. G.
Published: December 2007

Full scale flow experiments were conducted using coiled tubing without a weld bead having 1.75", 2.00", and 2.375" outer diameters on a 98" diameter reel. Experimental results for water agree well with values calculated using previously published formulas. A formula derived by the authors for non-Newtonian fluids gives pressure losses that are in excellent agreement with experimental data for the six fluids considered.
Analysis of Coiled Tubing Welding Techniques
Authors: Newman K. R. , Brown P. A. , Van Arnam W. D. , Wolhart S.
Published: December 2007

As the use of coiled tubing (CT) in workover services, drilling services, coiled completions and coiled pipeline increases, the need for improved field welding techniques increases. This paper summarizes the results of a weld analysis research project in which failed welds were analyzed, welding procedures were reviewed and alternative welding techniques were considered.
Coiled Tubing Drilling Case History
Authors: Mix K. , Bell G. , Evans S. J.
Published: December 2007

This case history outlines a recent North Sea Coiled Tubing Drilling Project (CTD). The Project consisted of 2 main phases – Onshore Testing and Offshore Operations.

The objective of the Project was to drill a 1000 ft sidetrack from an existing water injection well via a window cut in 7 inch casing. If the operation were to be unsuccessful, the well would be returned to its original configuration.

The existing perforations were successfully abandoned using a gel plug and a cement abandonment plug. A separate cement kick off plug was spotted above the cement abandonment plug. A pilot hole was drilled in the kick off plug and a window cut in the casing. Eighty feet of formation was then drilled.

Following a bottom hole assembly change access to the window was lost. Subsequent attempts to re-enter the window were unsuccessful. The drilling bottom hole assembly continued past the window into the original wellbore. Attempts were made to re-cement to allow a new window to be cut. These operations were unsuccessful.

The Project was terminated after 52 days on location. All cement was underreamed from the well, the perforations treated with an acid wash and the well successfully returned to injection.
High Penetration Rates and Extended Bit Life through Revolutionary Hydraulic and Mechanical Design in PDC Drill Bit Development
Authors: Taylor M. R. , Murdock A. D. , Evans S. M.
Published: December 2007

PDC drill bit developments have been made to achieve higher penetration rates and longer life, involving a compromise between open, light set, bits for speed and heavy set ones for durability. Developments are described which provided the benefits of both in a revolutionary hydraulic and mechanical design.

The hydraulic design causes mud to flow first towards the bit centre and then outwards. It was extensively flow tested using high speed photography to ensure that bit balling was prevented. It includes features to address bit whirl which were demonstrated in full scale laboratory testing to reduce the bit’s vibration level.

The mechanical design maximises open face volume, known to benefit penetration rate, by using very high blades. However, the heights attainable can be limited by the bit body’s mechanical strength. Steel was chosen to maximise blade strength and was coated with a newly developed hardfacing to improve erosion resistance. A programme of fatigue testing assured adequate strength.
Low-Cost Short-Radius Re-Entry Horizontal Drilling Program Revitalizes Aging Northern Michigan Niagaran Oil Fields
Authors: Lanier G. H.
Published: December 2007

This paper highlights recent experience gained while developing a low-cost drilling program in Northern Michigan’s Niagaran reef trend based upon modern short-radius, horizontal drilling technology to re-enter existing wellbores. Since the program’s beginning in September 1994, it has evolved significantly and cost performance has steadily improved from over $600M to less than $350M per well. Greater than three-fold production increases and as high as ten-fold reductions in GOR (gas-oil ratio) along with decreased water production have been observed upon completion.

Key to the program’s success has been a team approach to well planning involving the combined efforts of a multi-disciplined engineering staff, production and drilling operations, and quality service company support. In order to lower costs and maximize the pool of potential re-entry candidates, the program’s focus has been to emphasize a simplified well design relying primarily on production test data and minimal evaluation logging. A discussion of specific remedial, drilling, and completion procedures is summarized with overall program performance measures and evaluation data results from a three-well evaluation program completed in 1994 and a 20-well program completed in 1995.