bluuebunny/crossref_metadata_2025_split huggingface dataset:
Heavy Oil Reservoir Mechanisms, Linbergh and Frog Lake Fields, Alberta Part II: Geomechanical Evaluation
Authors: Solanki S. , Metwally M. 
Published: December 2007

Abstract
Field results from many heavy oil reservoirs in the Lindbergh and Frog Lake fields in northeastern Alberta suggest that primary recovery is mainly governed by the processes of sand production and foamy oil behaviour. Sand production leads to the creation of high porosity zones with increased permeability, while foamy oil generation provides the necessary support mechanism to sustain higher production rates.
PanCanadian Petroleum Limited and Centre for Frontier Engineering Research (C-FER) conducted experimental and numerical studies to understand the various reservoir mechanisms contributing to the high primary production recovery observed in the Lindbergh and Frog Lake fields. Laboratory tests were conducted to study the foamy oil behaviour and evaluate its contribution to the enhanced primary production observed in the field. The numerical modelling included a series of idealized models developed and analyzed to determine the most probable shape of the sand-producing zones. The evaluation focussed on matching not only the observed oil production but also the observed sand volumes removed from the reservoir. The analysis from vertical well simulation was also extended to horizontal wells.
The evaluation of heavy oil reservoir mechanisms for Lindbergh and Frog Lake fields is reported in two parts. Part I includes field testing and preliminary reservoir simulation based on the production data. Part II includes analytical and numerical studies for coupling the effects of sand and oil production, and laboratory testing of unconsolidated sand under foamy oil conditions.
Electrical Resistance Tomography for Monitoring Shallow Enhanced Recovery Processes
Authors: Narayan S. , Dusseault M. B. 
Published: December 2007

Abstract
Currently, Enhanced Oil Recovery (EOR) processes are monitored using gas analysis, geophysical logging, observation wells (P&T), well testing methods, seismic velocity tomography, or inversion of deformation measurements. These methods each have their strengths and weaknesses. Most EOR processes involve massive changes in the formation resistivity because of the introduction of a fluid phase with a different conductivity, or a large change in temperature. Threedimensional electrical resistivity tomography may be a way of tracking propagation of fluid fronts with time. We present general requirements for resistivity tomography in EOR, typical electrode installations to reduce noise and seasonal variations, requirements for a general inversion of a 3-D resistivity problem in EOR, sensitivity analyses for a shallow reservoir case subjected to EOR, and a method of rapid design evaluation of resistivity monitoring. We believe that analysis tools and the technology is now adequate to reevaluate and develop electrical monitoring for EOR applications.
Progressing Cavity Pumping System Applications in Heavy Oil Production
Authors: Dunn L. J. , Matthews C. M. , Zahacy T. A. 
Published: December 2007

Abstract
Heavy oil and bitumen wells were traditionally produced with beam pumping systems. However, in the early 1980's, the introduction of progressing cavity (PC) pumping systems presented an alternative to beam pumps that possessed attributes which were ideally suited for heavy oil applications, The functional design of PC pumps facilitates the handling of viscous and abrasive multiphase fluids, and the lower capital and operating costs of these pumping systems makes them attractive for marginally economic operations. Today, primary heavy oil and bitumen applications are almost exclusively produced with PC pumping systems.
To realize the benefits of PC pumping systems for heavy oil production, several issues must be considered. These include flow losses, sand production, rod string and tubing wear, low bottomhole pressures, power transmission/control and pump selection, sizing and reuse. Based on the results from numerical assessments, laboratory testing and field case histories, this paper presents system design, installation and operation guidelines which address these issues.
Numerical Simulation of Horizontal Wells in a Heavy Crude Reservoir in Venezuela
Authors: Zerpa L. B. 
Published: December 2007

Abstract
In 1993, an aggressive horizontal well drilling program started in a Heavy Oil Field, located in the eastern part of Venezuela. The crude oil is characterized by low gravity (8° API). The main objective of this program is to improve oil recovery and control water invasion.
This paper presents the numerical simulation of the first three horizontal wells in the reentry program and sensitivity analysis considering some parameters, such as vertical/horizontal permeability anisotropy, sand thickness, horizontal length, well-bore diameter, number of branches, angles between branches, and friction effects for cold and hot production.
A pseudo-compositional and fully implicit 3-D thermal simulator was used to obtain all the results presented in this study.
The numerical simulation includes the vertical and horizontal history match and the forecast of oil well production performance. Sink-source and well-bore discretization were used as methods for the horizontal well representation.
Simulation results show that a horizontal well reduces water invasion. It also indicates that the optimum horizontal well length for the Jobo area is 800 to 1200 feet. The vertical/horizontal permeability effect is important only for some specific values of the sand thickness and the horizontal length of the well. The well-bore diameter recommended to drill the horizontal wells is seven inches. In addition, drilling of branches at some angles is an option for improving horizontal well production.
The sensitivity analysis, using the well-bore discretization option, reveals that friction has an important effect on the well oil production. The friction effect is more important when the horizontal well length is increased and in some cases it can reduce the cold oil production around 50%.
Cyclic steam injection simulation using horizontal wells shows an oil production improvement of aproximatly 3% for cicle. When this process is applied, the optimum horizontal length is 800 feet.
Cold Lake Project Recovery and the Role of Foamy Emulsion
Authors: Reilly Bernard T. , Scott George R. 
Published: December 2007

Abstract
Cyclic steam injection stimulates an effective foamy emulsion expansion drive at Imperial's Cold Lake Project. Projected bitumen recovery is 25% of the Clearwater bitumen-in-place on developed pads. Ultimate recovery is estimated to be 232 million cubic metres of bitumen from the development area accessible from the current plants.
Milne Point Schrader Bluff: Finding the Keys to Two Billion Barrels
Authors: Bidinger C. R. , Dillon J. F. 
Published: December 2007

Abstract
Milne Point, North Slope Alaska, contains in excess of 2 billion barrels original oil in place (OOIP) in the shallow, Late Cretaceous, Schrader Bluff Formation. This resource is part of a larger accumulation in excess of 26 billion barrels OOIP overlying many of the deeper producing fields. A small waterflood pilot presently produces 3300 barrels of oil per day (BOPD) of 19 API oil from 2650 acres in Milne Point. Initial average well productivity's of 350 BOPD, low by North Slope standards, coupled with current cost, performance, and fiscal conditions, render the resource uneconomic. A multi-pronged approach dealing with well productivity, drilling and facility costs, and development incentives is underway to save this resource from abandonment. Technological and contractual innovations are considered keys to success. Which keys fit the lock will determine the development of billions of barrels of recoverable oil.
High Temperature Naptha to Replace Steam in the SAGD Process
Authors: Palmgren Claes , Edmunds Neil 
Published: December 2007

Abstract
World-wide experience indicates that thermal methods are the only effective methods for the in-situ recovery of heavy oils. Furthermore, the steady progress within horizontal well technology increases the applicability of thermal methods in conjunction with horizontal wells. The steam-assisted gravity drainage (SAGD) process is the prominent example of the synergism of horizontal wells with steam injection.
The major portion of the dollar per barrel operational cost for steam injection is currently attributed to the generation of steam and water handling requirements. In the future, more stringent environmental regulation might further prohibit the use of water for the recovery of heavy oils.
Naptha is present at the site as a diluent for pumping and pipe line transport of the produced heavy oil. The injection of naptha vapour instead of water vapour combines an effective thermal process with the diluent mechanism of the naptha. We present the results of simple analytical calculations, demonstrating the applicability of naptha-assisted gravity drainage (NAGD) compared to the SAGD process.
Numerical simulations have been performed on a two-dimensional cross section perpendicular to the horizontal well pair. We discuss in detail the reservoir mechanisms present during NAGD. For the conditions studied naptha circulation rates are some 14 times the bitumen production rate. Evaluation of the process shows that it will be economic with naptha recycling and by minimising the naptha remaining in the reservoir.
A Practical Thermal Well Testing Method Including Heat Loss Effects
Authors: Sheng James J. , Ambastha Anil K. 
Published: December 2007

Abstract
Monitoring of swept volume over time is important for assessing the success of a thermal project. Falloff tests are commonly used to estimate swept volume for steam injection projects. Steam-injection falloff test data can be significantly affected by heat losses. A well test analysis method to include the effects of heat losses was published in Reference 1. However, one of its shortcomings is that the method requires a knowledge of the rock permeability to analyze test data.
This paper presents a practical method to overcome the proceeding and other shortcomings of the method presented in Reference 1. In our proposed modified method, we rely on pressure derivative graphs to identify the flow regimes, and to improve the analysis accuracy significantly. Numerically-simulated steam-injection falloff test data are analyzed using the previous methods and the modified method of this paper, showing the practicability and improvements resulting from the modified method of this paper.
The modified method presented in this paper should be of considerable help in analyzing falloff test data affected by significant heat losses. The modified method of this paper is also capable of demonstrating whether the effects of heat losses are significant for a given test data set.
Influence of Inelastic Rock Properties on The Stability of a Well-Bore
Authors: Daemen J.J.K. , Fairhurst C. 
Published: December 2007

The rock around a well-bore is subjected to a stress field which can-be considered to be composed of four parts:
the virgin stress in the rock the change in this stress field caused by creating the opening the fluid pressure inside the well the pressure caused by the flow of the fluid towards the hole.
An additional component can also be developed if oil withdrawal causes compaction of the oil bearing formations, leading to subsidence of the overlying rock mass. Whether the well will be stable or not depends upon the behaviour of the rock in this stress field.
The stress distribution around a circular well-bore has been calculated by Paslay and Cheatham for an elastic system with radial symmetry and steady state fluid flow into the well-bore. They showed in particular that the rock strength required around the hole can be influenced very significantly by a change in permeability of the rock in the immediate surroundings of the hole. permeability of the rock in the immediate surroundings of the hole. Rock failure is most likely to occur in this zone. Once the rock strength is exceeded it is necessary to include the behaviour of the broken zone in the analysis.
As an initial step we can consider the situation of a vertical cylindrical hole with internal fluid pressure Pi in a rock mass where the virgin stress in the horizontal plane is P in all directions. The radius to which the rock will break* can be calculated from the equilibrium equation:
(Equation 1)
and the expression for the behaviour of the broken rock :
(Equation 2)
Mechanisms of Formation Damage and Permeability Impairment Associated With the Drilling, Completion and Production of Low API Gravity Oil Reservoirs
Authors: Bennion D. B. , Thomas F. B. , Bennion D. W. , Bietz R. F. 
Published: December 2007

Abstract
The economic production of heavy oil reservoirs requires an indepth understanding of the specific mechanisms of formation damage which are unique to these types of formations. This paper will provide a brief description of some of the dominant mechanisms of permeability impairment which can occur in low API gravity oil-producing zones. These include:
Drilling induced damage solids entrainmentfines migrationrock/fluid incompatibilitiesfluid/fluid incompatibilities Reactive clay induced damage Formation of emulsions (water-oil, oil-water) Foamy oil phenomena Sand control and consolidation issues Completion induced damage, acidizing, solvent injection, etc. Thermally induced formation damage mineral transformationsmineral and formation dissolutionwettability alterations Biologically induced formation damage issues Formation damage issues peculiar to the drilling and completion of horizontal wells in heavy oil producing zones.
This paper provides a general overview of many of the potential types of formation damage which drilling, production and reservoir engineers as well as geologists and geophysicists should be aware of when planning exploitation programs for heavy oil plays.
Investigation of the Asphaltene Precipitation Process from Cold Lake Bitumen by Confocal Scanning Laser Microscopy
Authors: Li Hongqi , Wan W. K. 
Published: December 2007

Abstract
The equilibrium asphaltene particle shape, size and size distribution were investigated by Confocal Scanning Microscopy (CSLM). Using CSLM, better quality images of asphaltene particles were obtained. The 3-D reconstruction from 2-D images capability of CSLM was used to visulaize the shape of the asphaltene particles. They were found to be highly non-spherical. With the CSLM operating in the fluorescence mode using incident light of 586 nm, it was found that freshly precipitated asphaltene particles gave strong fluorescence. However, if the sample was exposed to air, the fluorescence intensity quenches over a period of 24–48 hours indicating chemical changes, possibly oxidation, was taking place. Contrast to this, in a dry nitrogen atmosphere, the asphaltene particles maintained their fluorescence over the entire period when the experiment was carried out. Fluorescence emission by asphaltene particles provides yet another alternative for its size and size distribution determination especially for samples with a dark background. Imaging of such system would be less dependent on the incident light intensity. Asphaltene samples prepared at the industrially more relevant low bitumen to solvent ratios are being investigated by this method.
Sustaining the Viability of the UKCS in the New World Environment
Authors: Kemp Alexander , Stephen Linda 
Published: December 2007

Abstract
This paper examines the issue of how the viability of activity in the UKCS may best be maintained in the context of the new world environment. This environment is personified by (1) continued relatively low but volatile oil prices, (2) keen competition among producing countries with OPECs market power considerably reduced, (3) strong, global competition for investment funds with much of the world including the FSU now attempting to attract private investment, (4) modest oil demand growth, and (5) increasing environmental concerns and associated regulatory pressures. These features will be illustrated.
Activity in the UKCS is likely to continue to take place within this context over the next few years. How can a mature province best adapt to this environment? Considerable opportunities are still available because the actual and potential reserve base is still attractive. To maximise the opportunities appropriate actions are required by all players. Government should attempt to ensure that (1) regulations do not add unnecessarily to costs nor delay projects, (2) taxes do not inhibit projects (3) agreement and relations with other countries (including EU) take into account the needs of the UKCS and (4) R and D in the petroleum sector is fostered Appropriate Government behaviour can reduce the perceived political risks. Examples where Government initiatives are desirable will be given.
Oil companies and the major supply and contracting companies will continue to have competing calls on their limited budgets. Success in the UKCS will depend upon continued innovations in both technology and managementVwork practices, particularly directed towards cost reduction. The continued role of CRINE (with the associated technique of partnering in particular) will be discussed. The issue of how innovations and cost reducing techniques developed in the North Sea can be deployed elsewhere will be raised.
Captain Innovative Development Approach
Authors: Etebar S. 
Published: December 2007

Abstract
The paper will describe how a field discovered in 1977 moved from being an unattractive prospect, to the top of the Texaco North Sea UK Company portfolio by the twin drivers of new technology and a fresh look at development strategy leading to reduced development costs.
Although it was expected from an early stage that there was significant (approx. 1.5 billion bbls) oil in place, the reservoir characteristics were such that recoveries were anticipated to be low, and early conventional development plans called for over 200 development wells in more than 10 drilling centres. Unconventional thinking, an extensive appraisal programme and an extended well test in 1993 demonstrated that the field could be exploited using 6000ft horizontal wells and electric submersible pumps (ESP).
In parallel to the appraisal programme, the engineering and construction industry were solicited for ideas on how best to develop the first phase of the field. Three concepts were selected for front end engineering by three different contracting groups. The effort resulted in three different designs that were competitively tendered.
A phased economic development plan was devised to minimise drilling and facilities costs. Company sanction and final development option selection took place in the Autumn 1994 and detailed engineering began in October of the same year.
First oil is scheduled for late 1996, with revenues generated from the first phase to be used to develop a second area of the field at the end of the century.
The Feasibility and Construction of the Landfall at the Liverpool Bay Development, Point of Ayr, North Wales
Authors: Smith Michael 
Published: December 2007

Abstract
This paper describes the feasibility and construction of the landfall of a 20" gas pipeline and two 3" piggy-backed condensate pipelines at Point of Ayr, North Wales from BHP Petroleum's Liverpool Bay Development.
The 4,340 metre long pipeline was constructed from pipeslrings, each approximately 600 metres long using a construction site at Point of Ayr. The pipeslrings were pulled into position by the bottom pull technique using an 800 tonne capacity winch spread on a marine barge.
On completion of the pulling operation the pipelines were buried in the seabed using a submarine trenching machine operated from two work barges. The utilisation of the TM4 trenching machine was in preference to an extensive dredging and backfill operation.
An International Perspective on Risk/Reward Contracting: Comparison of U.S., Middle East and U.K. Alliances
Authors: Farrell Susan , McDermott J. Ray 
Published: December 2007

Abstract
The purpose of (he paper is to compare the structure of six contracts considered by clients and contractors to be partnering or alliance arrangements. Two are in the U.K., three in the U.S. and one in the Middle East. Particular emphasis is placed on the management structure and risk/reward elements found in the contracts.
Basic project characteristics such as total value, work scope and length of agreement highlight the impossibility of applying a simple checklist to identify a likely partnering candidate. Each client determines if its project is best served through a partnering arrangement with a risk/reward structure.
The management of the agreements has more similarities than differences, with four of the six projects being managed via Integrated Teams. While only two contracts studied are termed alliances, there nevertheless appears to be a trend to alliances by companies with some partnering experience.
The risk/reward structure of the six contracts shows a great deal of variability. The sharing of upside potential is most frequently on a 50/50 basis between the client and the contractor. However, as multiple contractors are introduced into an alliance, the percentage sharing changes. One alliance treats all contractors equally for reward sharing, while another rewards in relation to relative value in the contract.
The sharing of downside risk is highly dependent on the amount of perceived risk in the contract. One contract shows zero downside for the client, several share 50/50 with the contractors, while another places most of the downside risk on the client.
The offshore industry is still at an early stage of implementing partnering, alliancing and risk/reward elements. One would expect an increasing number of alliances and more complex risk/reward structures as companies gain experience with the concepts.
E & P FORUM Health, Safety and Environmental Management System Guidelines
Authors: Downey I. L. 
Published: December 2007

Abstract
Introduction
During the last decade management of safety has progressively moved from reaction to an incident towards prevention of the incident occurring.
Safety management has moved from being a side-issue to being an integral part of the business to be managed in the same way as other critical issues. Incidents which in the past may have been viewed as unfortunate events are now recognised as costly and avoidable events.
The principles of the management of safety risks are similar to management of health and environmental risks. Indeed the considerations am often overlapping. A combined system for management of health, safety and the environment is both more efficient and more effective than tiying to manage the elements separately.