bluuebunny/crossref_metadata_2025_split huggingface dataset:
TOTALFINAELF Experience and Strategy in Downhole Processing
Authors: Gay Jean-Claude , Minebois Jean-Loup , Lacourie Yves , Lecoffre Yves 
Published: December 2007

Abstract
Water is very often associated to the oil production, for geological reasons, but also because it is the most frequent mean of secondary recovery. However all fields are not comparable in their behaviour. In the best cases water is effectively contributing to the oil sweeping and the bulk of the oil reserves can be produced at low water cuts. In other cases, it can be said that water is inevitable to the oil and huge volumes of high water liquids must be lifted from an early stage to produce the oil.
In some cases, mechanical or chemical water shut off techniques can help to reduce the water production however, depending on the specific conditions, they are not always cost effective, their implementation can be tricky, and their efficiency may be limited in time.
Therefore the operator is often left with the standard solution of upgrading its field and process facilities to cope with the produced water constraints. However, due to the increase difficulties resulting from the drastic new environmental regulations, the operators tend to focus more than before on the produced water associated cost.
A typical offshore field production history and capex and opex breakdown was analysed to highlight the impact of the water on a field economy.
The new interest linked to the emerging technology of downhole separation and re-injection has motivated the testing of a DOWS unit on the well LA-90 in the Lacq Superieur field in France and results of this operation are presented.
Considering the shortcomings in the existing static cyclone technology which is implemented in the down hole separation systems, TFE has undertaken since three years a R&D program based on an innovative concept of rotary cyclone. The base of the theory and its implementation are presented along with the promising preliminary results.
Plant Integrity Management Reviews
Authors: Oliver Michael H. 
Published: December 2007

Abstract
A major concern of companies operating refineries, gas and chemical plants is continued assurance of plant integrity. Plant integrity is loosely defined as assurance that there will be no "loss of containment", that all safeguarding systems act in the desired manner at the proper time and that the equipment is being operated within predefined limits, not necessarily design limits, that are necessary to assure continued operation from one major shutdown to the next. There are two approaches to managing plant integrity, the first being a reactive approach which tends to correct threats to integrity as they occur and the second being a "business process" approach. The business process approach to managing integrity is a proactive way of managing integrity in which failure modes are anticipated and the proper safeguards are put in place to prevent degradation or failure. In most cases, a combination of the two approaches is necessary to bring a plant back to the original level of integrity. The reactive mode is for correcting known problems and then business processes must be implemented in order to prevent future deterioration of plant integrity. Typically, an integrity review for a plant is carried out over 2 – 3 weeks by a multi-discipline team of technical experts well versed in the development and application of business processes
Typical business processes that have been developed for managing integrity include the following: Risk Based Inspection (RBI) which defines the interval between inspection of vessels and piping thus assuring that the more critical pieces of equipment are inspected over shorter intervals and less critical pieces over longer intervals.Defect Elimination, which is a process that captures incidents, determines the root cause with a structured root cause analysis and then based on business premises, establishes the best solution for the problem.Competency Assurance, which assures that personnel who operate and maintain the plant meet minimum standards of competency appropriate for the job they are doing.Integrity Operating Windows, which is a process, associated with RBI that defines the allowable limits of operating variables (not mechanical design limits) for critical equipment such that operation within the limits assures integrity for the interval between inspections.
A thorough understanding of the fundamentals of Risk Management forms the basis of most of these business processes and is therefore also a critical ingredient of modern integrity management.
An Integrated Approach for the Design of Squeeze of Mineral Scale Inhibitors
Authors: Bazin B. , Kohler N. , Broseta D. , Le Gallo Y. , Delaplace P. , Longeron D. 
Published: December 2007

Abstract
Inorganic scaling is the process of mineral scale deposition that may occur in the well tubing, and/or in the near well-bore area of both production or injection wells. Scale formation is usually the result of poor compatibility between the brines injected into the reservoir and the minerals in the formation. It may also be the consequence of abrupt pressure and temperature variations to which production fluids may be submitted between the reservoir and the surface. The precipitation of mineral deposits (carbonates, sulfates …) may create significant permeability impairments due to plugging of pore throats and thus induce large well productivity or injectivity losses. In most cases, precipitation cannot be avoided and preventive treatments are recommended. One of the most efficient treatment consists in squeezing a scale specific inhibitor into the formation.
This paper presents an original integrated methodology aiming at defining the best chemical inhibitor formulation for a given application and at optimizing its implementation into the corresponding reservoir. Both experimental and numerical approaches are used to select the inhibitors, to evaluate their performance at both core and field levels and to define the best strategy for the squeeze process. Laboratory tests include the classical inhibitor selection methods based on jar tests and tube blocking tests but also on more sophisticated testing procedures recently developed. Numerical simulations of the treatment are performed using a in-house reservoir simulator to upscale the squeeze life time of the treatment from laboratory scale to well geometry.
Sour Gas Injection Project
Authors: Miwa Masahiro , Shiozawa Yuji , Saito Yoshiharu , Tarmoom Ihab Othman 
Published: December 2007

Abstract
In close collaboration with Abu Dhabi National Oil Company (ADNOC) and Supreme Petroleum Council (SPC), Abu Dhabi Oil Co., Ltd. (Japan) (ADOC) has been instrumental in introducing, for the first time to the Arabian Gulf region, the challenge of sour and acid gas injection technology. The objective of the Sour Gas Injection Project is to capture excess daily flared gases at ADOC's offshore operation site, which in turn reduces toxic emissions into the atmosphere, and re-inject it into oil reservoirs at an injection pressure as high as 6, 000 psig for enhanced oil recovery. This paper discusses ADOC's historical mode of operations, adopted process description, lessons learnt during the project implementation and commissioning, and the project impact on the local environment and oil recovery.
Solar Dew® – The Prospect of Fresh Water in the Desert
Authors: Verbeek Paul , Straccia Joe , Zwijnenberg Harmen , Potter Marinus , Beek Arno ter 
Published: December 2007

Abstract
Solar Dew® technology is a novel way to purify water produced from oil fields, contaminated with traces of oil, metals, noxious gases and potentially high levels of mineral salts. Water purification is enabled by non-porous membrane distillation combined with renewable solar energy. Access to fresh water in the desert would have far reaching benefits, i.e., it provides sustainable development opportunities for local communities whilst it provides the producer with more diverse options for water re-use as an alternative to disposing water into deep aquifers as a waste.
The paper describes qualification trials of the Solar Dew system using water produced from an oil field in south Oman. Trials, executed in 2001 at small scale in the laboratory and in the field, demonstrated that the performance in year-round weather conditions consistently met targets set for quantity and quality of fresh water. Scale-up trials in 2002 aim to demonstrate that a hectare flowing system can be run, that polymer membrane materials are durable and that the system can compete with alternative means of water purification. Trial results indicate that up to 90% of the volume may be extracted as pure water, meeting international quality standards, at a rate of over 50m³ per hectare per day.
Introduction of Oil Spill Crisis Management System
Authors: Okayasu Kunio , Sato Akihiko , Sasaki Chikara , Al Minhali Ahmed A. , Bensahraoui Mohamed , Radhwan Ali M. , Keogh Michael 
Published: December 2007

Abstract
A crisis response exercise, "EXERCISE GHAZAL", was conducted in 1999 to give the ADNOC Crisis Management Team (CMT) practice in dealing with a realistic oil spill scenario in real time. The debriefing of this exercise clearly recognized the importance of sharing information through proper means of communication. Sharing information is essential for the Emergency Response Center (ERC) to effectively manage emergencies. It was also recognized that a useful computerized tool to assist in the management of an emergency was not available in Abu Dhabi. As ADNOC intends to introduce a common emergency management system to its Group of Companies, JODCO/CRC have been working with ADMA-OPCO to develop a PC based system called "InfoBook".
How to Etimate the Maximum Achievable Drilling Rate without Jeopardizing Safety
Authors: Akgun Ferda 
Published: December 2007

Abstract
Recorded drilling times may show significant variations from well to well even for the same total depth in the same field. Apart from the formation characteristics, engineers' technical ability plays an important role in determining drilling time.
A drilling performance is usually compared with respect to the performances of previously drilled wells. This approach has two major drawbacks. One, in newly developed fields, there may not be sufficient number of drilled wells to make a healthy comparison. Two, past drilling practices may not represent good engineering practices.
In this paper, a different approach is introduced in assessing drilling performance. The new approach suggests a comparison of drilling performance with respect to what is called ‘technical limit of drilling rate’, a maximum achievable drilling rate without risking drilling safety.
Using Statistics To Evaluate A History Match
Authors: Uldrich David , Matar Saad , Miller Hugh 
Published: December 2007

Abstract
Three methods are proposed for quickly evaluating the history match of a numerical simulation to actual reservoir performance. All of the methods rely on computing a set of deviation values, each of which is defined to be a calculated simulator result minus the corresponding surveillance measurement value.
For any particular type of surveillance data, such as rates, watercuts, or gas-oil ratios, the deviation values can be grouped by well, by area, or combining all measurements in the database. The first two proposed methods rely on simple graphical presentations of each group of deviation values to show how well the simulation results match the surveillance data. Plotting together the results from more than one simulation run allows a quick comparison of the match for each run, which is useful during the history match process.
The third method converts each deviation value to a quantity called Match Factor, which is a relative measure of the confidence that the simulator actually reproduced the particular reservoir performance at the time the surveillance measurement was made. Weighted-average Match Factors can reveal the degree of match by well, by area, and by data type.
These techniques are especially valuable when matching reservoirs with a large volume of surveillance data. They can help focus the history matching process by identifying areas less well matched. They can identify when the history matching process is not significantly improving the match and can stop.
Modeling of Simultaneous Proppant Fracture Treatments in the Fruitland Coal and Pictured Cliffs Formations in the San Juan Basin
Authors: Bazan Lucas W. , Larkin Sam D. , Jacot R. Henry , Meyer Bruce R. 
Published: December 2007

Abstract
Limited entry design techniques have proven successful for the simultaneous fracture stimulation of the Fruitland Coal and the Pictured Cliffs sandstone in the T28N-R7W Federal Unit of the San Juan basin, Rio Arriba County, New Mexico1. Optimization of this completion technique is dependent upon determining and placing the required effective propped fracture length in the coal and sandstone formations.
This manuscript addresses utilizing limited entry techniques and a 3D fracture model. The model is then used to design N2 foam proppant fracture treatments in the coal and sandstone formations. This completion methodology allows reserves to be recovered from the Fruitland Coal at a significant cost reduction.
With the different mechanical and reservoir properties of the two formation types, created fracture geometry will vary in each formation. Methods used to model these varied fracture geometries are discussed. Net pressure and production data analysis provide estimates for the effective propped fracture lengths in each formation.
Radioactive tracer and production logs are presented as supporting evidence to validate the well completion design, the fracture modeling inputs and the stimulation of both formations simultaneously.
Using this fracture modeling technology leads to increased reserve recovery and cost effective proppant fracture treatments.
Case History: Horizontal Well SAGD Technology is Successfully Applied to Produce Oil at LAK Ranch in Newcastle Wyoming
Authors: Grills Tracy L , Vandal Bryan , Hallum Frank , Trost Paul 
Published: December 2007

Abstract
Several attempts have been made in the past to apply enhanced oil recovery ("EOR") techniques to the Newcastle Sandstone formation at LAK Ranch in Eastern Wyoming. Solvent flood, steam stimulation, and chemical flooding have all been tried without significant success. Utilizing horizontal wells and the Steam Assisted Gravity Drainage ("SAGD") process, Derek Resources was able to successfully produce in excess of 5000 barrels of oil during two short (three-month) sessions of initial pilot production testing.
The Newcastle formation is an alluvial channel with a pay thickness of 25 to 100 feet, averaging 25 to 30 feet. It differs from conventional formations in that formation beds dip at up to 20 to 25 degrees. To further complicate drilling, the reservoir forms a synclinal basin, resulting in constantly changing bedding orientation; and a series of inter-bedded shale stringers make drilling horizontally along strike a challenging process.
The initial SAGD pilot consisted of a single well pair drilled for Derek Resources by Sperry Sun Drilling Services in July of 2000.
This paper will discuss the application of the SAGD process in a non-traditional reservoir, requiring non-traditional well pair geometry. The paper will cover the background to LAK Ranch. This paper will review planning phases for the project, drilling problems encountered, drilling results, and lessons learned from the drilling operation. Startup problems, production results, lessons learned about a project of this type, and future plans for LAK Ranch will also be discussed.
Project Scenarios for Bitumen Upgrading
Authors: Koppel Paul E. , Mazurek William L. , Harji Abdulla 
Published: December 2007

Abstract
The size of Alberta’s heavy oil resource has been well documented with all the superlatives regarding its size. It is truly enormous with established reserves of 178 billion barrels and potential recoverable reserves of 315 billion barrels. However, the logistics of recovery, upgrading, and transportation to market are daunting.
Even after the challenges of production, utilization of the produced bitumen is far from straightforward. It is too viscous to transport by pipeline and not processable by the vast majority of existing refineries. Thus in order to develop a mass market, the bitumen must be upgraded to a quality that can be processed by the existing North American refinery market.
The intent of this paper is to analyze the factors impacting which method of upgrading to follow and give some illustrative examples.
Novel Cement System for Improved Zonal Isolation in Steam Injection Wells
Authors: Dean Gregory D. , Torres Ricardo Sadovski 
Published: December 2007

Abstract
Over the past several years much interest has been generated in the industry of late in the development of ductile cements, exhibiting high values of tensile and flexural strength. There has been a great deal of field information suggesting that hydraulic isolation from cement is not what it should be or is believed to be. In other words many cement jobs are failing. Conventional cement systems used in oil wells exhibit high compressive strengths, yet are limited in tensile and flexural strength development. Recent field experience and research has shown that in the majority of cases, the mechanism of cement sheath failure is radial tensile cracking, causing a loss of hydraulic isolation.
Flexible cements are more able to withstand the tensile forces generated by fluctuations in downhole pressure and temperature caused by drilling, production and workover operations. Also affecting the cement seal are factors such as hydraulic fracturing treatments, high drawdown pressures, steam injection, and subsequent drilling operations.
This paper reviews the application of a flexible cement designed to address problems with loss of hydraulic isolation encountered in steam injection wells. The paper also reviews the basic principles for estimating the cement tensile strength requirement and describes the process used in selecting the final cement slurry formulation, including the use of a mathematical simulator. Also described is the introduction of a novel mineral fiber, which imparts higher tensile strength to the set cement and results in slurry that is better able to withstand the high temperatures induced by steam injection operations. The new flexible cement is also able to provide the required characteristics at lower slurry densities. A summary is presented of the results of the first 4 wells cemented with this technique in the Mossoró area of Northern Brazil.
Comparison of CSS and SAGD Performance in the Clearwater Formation at Cold Lake
Authors: Scott George R. 
Published: December 2007

Abstract
Data are available for four SAGD projects and two CSS projects operating in the Clearwater formation at Cold Lake. This paper uses these data to compare the energy efficiency and recovery performance of SAGD and CSS.
For the conditions outlined in this paper, field data demonstrate that: Bitumen recovery using SAGD is generally uneconomic in the Clearwater formation.Bitumen recovery using CSS in the Clearwater formation:Produces as much as 50% or more bitumen/m3 external gas consumed than SAGD; andWill result in significantly higher overall bitumen recoveries (as a percentage of OBIP) than SAGD.
These observations are consistent with industry experience in non-Clearwater SAGD and CSS operations.
In addition, operating and design data for commercial SAGD and CSS projects is used to demonstrate that: Due to differences in steam quality, SOR is not an appropriate indicator of energy efficiency. Energy efficiency comparisons are more appropriately based on the quantity of external gas required to produce 1-m3 of bitumen.To convert SOR data to an external gas requirement, the following conversion factors are proposed: 1-m3 wet (80% quality) steam requires approximately 60-m3 gas.1-m3 dry (100% quality) steam requires approximately 75-m3 gas.The use of project specific EBIP, versus OBIP, in calculating recovery makes meaningful comparisons difficult.
Conditional Stochastic Moment Equations for Uncertainty Analysis of Flow in Heterogeneous Reservoirs
Authors: Li L. , Tchelepi H. A. 
Published: December 2007

Abstract
We consider permeability as a random space function defined by its mean and covariance. The stochastic nature of the permeability description leads to uncertainty in flow-related quantities such as pressure, saturation and production rate. We extended our statistical moment equation (SME) approach to accommodate conditioning. The conditional stochastic moment equations (CSME) framework is a direct approach for quantifying the uncertainty in flow performance due to uncertainty in the reservoir description. It is quite different from Monte Carlo Simulation (MCS). In MCS, the performance uncertainty is obtained through a statistical post-processing of flow simulations, one for each of a large number of equiprobable realizations of the reservoir description. We developed a CSME computational tool for flow in heterogeneous domains. We employ an approach analogous to the deterministic streamline-based method in order to solve the equations that govern the first (mean) and second (variance and covariance) moments of interest. This numerical CSME tool allows for quantifying the value of existing and future information, and that helps evaluate existing projects and steer future development plans. We present several examples that demonstrate how to choose the best sampling locations to obtain maximum reduction in prediction uncertainty. We compare our results with high-resolution MCS.
A Strategy for Rapid Quantification of Uncertainty in Reservoir Performance Prediction
Authors: Subbey Sam , Christie Mike , Sambridge Malcolm 
Published: December 2007

Abstract
This paper will describe a strategy for rapid quantification of uncertainty in reservoir performance prediction. The strategy is based on a combination of streamline and conventional finite difference simulators.
Our uncertainty framework uses the Neighbourhood Approximation algorithm to generate an ensemble of history match models, and has been described previously. A speedup in generating the misfit surface is essential since effective quantification of uncertainty can require thousands of reservoir model runs.
Our speedup strategy for quantifying uncertainty in performance prediction involves using an approximate streamline simulator to rapidly explore the parameter space to identify good history matching regions, and to generate an approximate misfit surface. We then switch to a conventional, finite difference simulator, and selectively explore the identified parameter space regions.
This paper will show results from a parallel version of the Neighbourhood Approximation algorithm on a Linux cluster, demonstrating the advantages of perfect parallelism. We show how it is possible to sample from the posterior probability distribution both to assess accuracy of the approximate misfit surface, and also to generate automatic history match models.