bluuebunny/crossref_metadata_2025_split huggingface dataset:
Using GIS as a Data Access and Integration Platform
Authors: Blaha James R. 
Published: December 2007

Abstract
Oil and gas companies around the world are looking for ways to improve efficiency in all aspects of their business. To realize efficiencies, they need to be able to make better decisions faster and cheaper by analyzing all of the relevant data available to them in a systematic fashion. Good decision making starts with quick and easy access to clear and accurate data; no analytical solution, no matter how sophisticated, can compensate for incomplete or inaccurate data. Unfortunately, the data that is needed is very rarely stored in a common format or location and is rarely accessible through integrated, workflow-based, analytical solutions. Instead, users spend a large amount of time tracking down the data they need and loading it into the applications that they use before combining the results to make a final decision.
In the early 1990s, it was believed that monolithic database models and centralized repositories would solve application interoperability concerns. In spite of huge investments and the dedication of leading industry experts, this approach failed. The resulting data models were too complex, and the data conversion costs were too high. Consequently, the petroleum industry data management vision underwent a major transformation during the mid 1990s. A data centric focus was adopted with a resulting shift from the data model to the data itself and the use of meta-data catalogs and middleware to integrate data and applications. To date this approach has yielded some success, but the proprietary nature of the middleware formats and the cost of development of the associated conversion tools makes the resulting solutions expensive and complex to implement and manage.
Over recent years, evolutionary technological advances have presented a more powerful and flexible option for multi-source data access and integration. Data can be managed in its native format and location but is referenced and represented through a de-facto industry standard spatial file structure using the SDE technology from ESRI. This establishes a common data access format that then provides a platform for the integration of information from multiple sources that can be displayed, analyzed, and exported through commercial and customized Web-based or desktop map interfaces.
Water-Based Drilling Fluid for HT/HP Applications
Authors: Tehrani M. A. , Popplestone A. , Guarneri A. , Carminati S. 
Published: December 2007

Abstract
The superior performance of invert emulsion fluids in challenging drilling operations such as HT/HP wells makes them the preferred fluid for such applications. However, there are instances such as drilling in environmentally sensitive areas, or where costs and logistics become prohibitive, where their use is undesirable. In such circumstances, a high-performance water-based drilling fluid is the only option available. A main challenge in developing a water-based fluid for such applications has been to maintain the stability of key fluid properties such as rheology and fluid loss at temperatures in excess of 130°C. Conventional additives, such as biopolymers or synthetic polymers, either become ineffective at such high temperatures or generate too high a rheology when used in quantities needed to curb fluid loss. This paper discusses a novel water-based drilling fluid system in which the synergy of the key fluid components produces a stable rheology and low fluid loss at temperatures approaching 200°C. Furthermore, by balancing the components of the novel system, fluid rheology can be controlled to meet the hydraulics and hole-cleaning demands of the drilling operation.1, 2
Design, Construction, and Optimisation of Big-Bore Gas Wells in a Giant Offshore Field
Authors: Clancey B. M. , Khemakhem A. S. D. , Bene T. F. , Schmidt M. H. 
Published: December 2007

Abstract
An extensive big bore gas well drilling and completions program is in progress to develop the giant North Field, offshore Qatar. Benefits of the big-bore concept, compared to the prior 7-in. monobore design, include reduced development costs by requiring fewer wells, and deferred installation of compression by providing higher flowing wellhead pressures.
This is the widest known application of a big bore design in one single field and involves a large number of wells. Many of these wells are drilled and completed to date and believed to be among the world's most prolific gas producers. These are also the first offshore wells to incorporate big bore well design for large-scale field development and feature industry advances in equipment design and manufacture. An extensive system of detailed design review, equipment performance testing, and quality programs has been implemented to meet challenging project requirements for well reliability.
The wells feature a tapered tubing design known as the "Optimized Big Bore" (OBB). This paper discusses the challenges of planning and executing these OBB wells. It reviews the initial OBB well design, anticipated North Field drilling challenges, critical equipment specifications, and design revisions resulting from optimisation efforts over the past four years.
Achieving Shoe-to-Shoe Drilling Performance in Hole-Opening Application With Rotary-Steerable Systems
Authors: Heisig G. , Hood J. , Okewunmi S. , Robnett E. 
Published: December 2007

Abstract
Detailed analysis of downhole weight-on-bit, torque, bending moment and vibration signals measured between bit and hole opener have provided clear insight into the dynamic response of hole opening BHAs in interbedded formations. Based on transmitted real-time information from an advanced downhole multi-sensor data acquisition and processing system, application-specific drilling procedures and guidelines have been developed to avoid or to identify and overcome critical dynamic situations downhole.
Applying the new procedures, several hole sections in the GOM were drilled for the first time in one run from casing shoe to casing shoe. Here previous attempts had resulted in failures of the drilling equipment or even in twist-offs.
The paper starts with a list of observations made with the downhole multi-sensor tool placed between bit and hole opening device. Log examples with downhole and surface drilling data demonstrate the dynamic response of hole opening BHAs. For the first time, the paper presents downhole measurements showing the changes in weight on bit versus weight on reamer when drilling interbedded formations. Again, log examples are used to document the effect of the drilling procedures that were applied to successfully resolve critical downhole situations. The paper concludes with a summary of the lessons learned in planning and executing hole opening applications with shoe to shoe performance.
Hydraulic Predictions for Polymer-Thickened Foam Flow in Horizontal and Directional Wells
Authors: Chen Z. , Duan M. , Miska S. Z. , Yu M. , Ahmed R. M. , Hallman J. 
Published: December 2007

Abstract
Foam has proven to be effective and economical in underbalanced operations (UBO) and is gaining wider applications in many areas. It provides the desired flexibility in controlling pressure profile and ECD. However, the knowledge of rheology and hydraulics of polymer-thickened foams is still limited. This paper summarizes the significant effects of polymer on foam rheology and presents a hydraulic model that simulates aqueous and polymer-based foam flow in directional and horizontal wellbores.
Experimental studies on the rheology of polymer-enhanced foam were conducted using specially designed a flow-through rotational viscometer and pipe viscometers with different hydroxyethylcellulose (HEC) polymer concentrations. Correlations have been developed for rheological parameters of aqueous and polymer-based drilling foams.
Based on the experimental results of foam rheology and steady-state momentum balance equation, a foam flow hydraulics model was developed to predict pressure profile, ECD, foam velocity and quality along a vertical-inclined-horizontal wellbore. For practical applications, a simulator has been developed and validated by experimental/flowloop data obtained from the Advanced Cuttings Transport Facility of Tulsa University Drilling Research Project (TUDRP). The effects of polymer concentration, back pressure and wellbore trajectory on foam hydraulics were studied extensively using the simulator. Results show significant impact of polymer on foam hydraulics. When 0.5% v/v HEC polymer is added to aqueous foam, Bottom Hole Pressure (BHP) and foam density are significantly increased, while foam quality and velocity are greatly decreased. The polymer effects in vertical wells are more pronounced than in horizontal wells.
Simulation results also indicate that it is possible to use foam to create a pressure profile within the narrow window between continuously changing pore pressure and facture pressure gradients, which is not possible with conventional fluids. Those responsible for hydraulic optimization and well control in MPD/UBO where foam is used will find this paper useful for practical design applications.
Application of Innovative Chemical and Mechanical Processing for Treatment of Difficult Production-Waste Sludge
Authors: Star Jacquelyn F. , Williams Stephen , Sudardjat Isham , Kidder Roger , Gallup Darrell L. 
Published: December 2007

Abstract
East Kalimantan Indonesia has a history of challenges and difficulties in the management and treatment of emulsions, slop oils, slurries and tank bottoms which accumulate in process vessels and tanks. These unresolved production streams, collectively termed "sludge" incorporate strong oil and water emulsions, chemically bound by metal-carboxylate soaps and various mixtures of stabilizing fine sand, scale, and wax.
Previous disposal methods used or considered for use range from very crude methods such as open burning and land-spreading to sophisticated techniques such as slurry fracture injection. However, such options did not provide for oil recovery and posed severe environmental or regulatory problems. The process proven most viable in treatment of sludge employs an aggressive system of heat, customized chemical demulsification, settling, and various means of mechanical/centrifuge separation. In the last several years, more than 500,000 barrels of sludge have been successfully reclaimed at Lawe Lawe and Santan Terminals. Whilst the sludge treatment program overall has been successful, there have also been serious technical challenges and cost-impacts. These difficulties have provided significant lessons learned for both operator and contractor in terms of optimization of key physical, chemical and mechanical separation techniques; as well as for minimizing costs.
A case study of a recent treatment program for over 220,000 barrels of sludge at Santan Terminal will be used to highlight significant implementation and management experience including: Critical equipment selection and design parameters,Chemical treatment requirements,Successful (and unsuccessful) methods for optimization of treatment rate and improving oil recovery,Mechanical challenges for the removal of stabilized fine solids,Key parameters for project tracking, andA realistic assessment of treatment costs.
The results to date illustrate how an effective sludge treatment and reclamation program can provide commercially and environmentally superior results in terms of cost and impacts.
Clustering and Corridoring Project and Challenges
Authors: Elabed Amjad , Ur Rahim Ihtisham 
Published: December 2007

Abstract
By late 90's, Abu Dhabi Company for Onshore Oil Operations (ADCO) started facing increasing surface congestion and related potential operating hazards caused by haphazard laying of new surface assets/facilities in ADCO concession areas due to the implementation of aggressive field development plans. ADCO Management realized very early the need to reduce congestion and reduce the risk to the equipment and personnel while coping with the increased number of surface equipment as business needs expanded. As a result, the Clustering and Corridoring (C&C) Project was launched in 2003 and was divided into three studies phases. Phase I and II studies defined the optimum configuration of the facilities to control congestion and reduce the surface facilities footprint. The studies outcome was the development of four main design concepts:
Exclusion Zones, Well Pairing, Corridors Design, and Radial Corridors Layout.
Phase III studies resulted in the re-defining of Production Pad concept in order to meet the long term field development requirements. To date a total of 97 flowlines have been laid in the corridors in all ADCOs' major fields and a total of 24 wells were clustered since May 2005 in line with the Clustering and Corridoring Project guidelines.
Effect of Length: Diameter Ratio on Collapse Test Results and Frame Design
Authors: Pattillo P. D. 
Published: December 2007

Abstract
The current version of ISO 10400 TR requires a length:diameter ratio of at least seven for sizes larger than 10-3/4. This bound was instituted to account for end effects in a collapse test frame. The requirement currently, however, does not justify the selection of the value of seven, nor does the TR discuss the effect of varying end conditions. This study reviews both experimental and theoretical studies aimed at quantifying the effect of length and end constraints on collapse resistance. The results are intended to (a) justify (or dispute) current ISO 10400 requirements and (b) offer guidelines for adjusting collapse test results when the sample diameter is so large that a length sufficient to satisfy the ISO requirement is impractical.
Gas Blending for Miscible Gasfloods in South Oman
Authors: Deinum G. , Dindoruk B. , O'Dell M. 
Published: December 2007

Abstract
How to ensure that miscibility of oil and gas is achieved in each reservoir is a fundamental issue for miscible gasfloods involving different oil reservoirs with varying fluid properties. This paper reports on all the work done to help decide on how to optimally blend available gas such that miscibility can be achieved in all reservoirs with appropriate focus on the first reservoirs to be flooded. These studies have resulted in an investment decision to undertake a miscible gasflood already in 2005, whereas initial production from four reservoirs had only started in March 2004. Main components of this paper are: (1) Design of experiments for a wide spectrum of fluids (from near-critical systems to black oil systems) using miscible sour gas-blends while minimizing cost and the time spent on the experiments. (2) Acquisition, interpretation of the data (3) Utilization of the data for reservoir engineering/design calculations using a consistent approach for a cluster of sour reservoir fluids, (4) Recommendations based on the experimental data and calibrated simulation models.
Smart Wells Experiences and Best Practices at Haradh Increment-III, Ghawar Field
Authors: Al-Arnaout Ibrahim H. , Al-Zahrani Rashad M. , Jacob Suresh 
Published: December 2007

Abstract
Haradh Increment-III is Saudi Aramco's latest and most advanced developed area in Ghawar field. The area was developed with 32 multilateral wells utilizing advanced drilling technologies to reduce the number of wells and provide maximum reservoir contact at a lower cost per barrel. The complex array of 113 laterals dictates the necessity for individual lateral control for better reservoir management strategy.
Twenty eight smart completions were run in Haradh Increment-III totaling in 87 downhole choke valves installations for flow regulation from different laterals. Throughout the project progress and as more smart completions are installed, Saudi Aramco's experience was ramping up through its learning curve and first-hand knowledge was being gained. The company's experience with smart completion and best practices for ensuring proper functionality of smart completions were being developed with each additional installation.
Detailed project and operational planning is critical to the success of such innovative projects. Operational planning begins before the equipment is manufactured and carries through to equipment assembly, testing and surface tests prior to completions.
The paper presents the experience of Saudi Aramco and the supplier in the installation of 28 intelligent wells, with reliability of 97%, through the adoption of best practices. The development stages of smart completion best practices will be illustrated citing various history cases and addressing important operational concerns.
The learning discussed in this paper will provide an insight into how a large scale application of smart completion technology can be handled in a systematic way to achieve a successful conclusion.
Lessons Learned from Repickling Old/Sour Gas Wells
Authors: Nasr-El-Din H. A. , Garzon F. , Al-Mutairi S. H. , Al-Driweesh S. , Al-Harith A. M. 
Published: December 2007

Abstract
Saudi Arabia has embarked on developing its gas fields. Some of these fields produce sour gases with hydrogen sulfide content that can reach 10 mol% and carbon dioxide of 4-5 mol%. The carbonate formation is very tight and acid fracturing treatments were used to enhance the productivity of these wells. All tubulars were pickled before the acid fracturing treatments. Pickling was needed to remove mill scale (iron oxides) and pipe dope. Invasion of these contaminants into the formation would cause severe formation damage, which might adversely affect the productivity of these wells.
Some of the gas wells have been on production for several years. There was a need to stimulate these wells to perform various workover operations. The question raised was whether there was a need to pickle the tubulars before performing acid treatments to these relatively old wells given the fact that these wells were pickled when the lower zone of the formation was fractured for the first time several years ago. Unlike new wells, the tubulars of old wells are typically covered with various corrosion products, condensate, and pipe dope.
To address the question of pickling of old well tubulars, an acid formulation was designed to remove various contaminants that might present in the wellbore, while maintaining the integrity of the tubulars. The acid treatment was bullheaded in seven wells. Wellhead samples were collected every two minutes during the well flow back and analyzed for key elements.
Similar to new tubulars, field data indicated that there is an absolute need to pickle old tubulars. High concentrations of total iron were detected in the well flow back samples. Manganese concentration was relatively low, indicating the acid pickling treatment did not affect the integrity of the low-carbon steel tubing. This paper describes in detail the laboratory work, treatment design, and field application. It will give conclusive evidence on the importance of pickling old tubulars and highlight the need for such treatments.
New Cement Formulation that Solves Gas Migration Problems in Iranian South Pars Field Condition
Authors: Pour M. Mohammadi , Moghadasi J. 
Published: December 2007

Abstract
Gas migration through cement columns has been a problem of the oil and gas industry for many years. The most problematic areas in Iranian South Pars Field operations for gas migration are in gas wells; which causes failure of about 30 % of the primary cement jobs. Gas migration in these gas wells occurs when drilling through the Kangan and Dalan formations. To control gas influx, cement densities required to successfully cement this zone could be as high as 120 pcf. Specially designed cements were used to "zone isolate" the high pressure coming from the formation. High density/low fluid loss cements were used in the past with limited success. The objective of this study was to develop an effective cement formulation to control deep gas migration during primary cementing. To measure major slurry properties lab equipments were utilized for this study. A static gel strength analyzer (SGSA) is used to determine the static gel strength of formulated well cements to confirm the data from previous experiments on the slurry (rheology, filtration, and free water). Results from the SGSA were utilized to reduce the gas migration problem. This study also discusses the individual components necessary for gas-leak elimination. In addition, clearly addresses the gas migration problems related to cementing operations.
Support Vector Machines Framework for Predicting the PVT Properties of Crude-Oil Systems
Authors: El-Sebakhy E. , Sheltami T. , Al-Bokhitan S. , Shaaban Y. , Raharja I. , Khaeruzzaman Y. 
Published: December 2007

Abstract
PVT properties are very important in the reservoir engineering computations. There are many empirical approaches for predicting various PVT properties using regression models. Last decade, researchers utilized neural networks to develop more accurate PVT correlations. These achievements of neural networks open the door to both machine learning and data mining techniques to play a major role in both oil and gas industry. Unfortunately, the developed neural networks correlations have some limitations as they were originally developed for certain ranges of reservoir fluid characteristics and geographical area with similar fluid compositions. Accuracy of such correlations is often limited and global correlations are usually less accurate compared to local correlations. Recently, support vector machines have been proposed as a new intelligence framework for both prediction and classification based on both structure risk minimization criterion and soft margin hyperplane. This new framework dealt with kernel neuron functions instead of sigmoid-like ones, which allows projection to higher planes and solves more complex nonlinear problems. It has featured in a wide range of medical and business journals, often with promising results. The objective of this research is to assess the benefit of support vector machines as decision making tools in the field of oil and gas industry.
To demonstrate the usefulness of the support vector machines technique in petroleum engineering area, we describe both the steps and the use of support vector machine modeling approach for predicting the PVT properties of crude oil systems. A comparative study will be carried out to compare their performance with the performance of the neural networks, nonlinear regression, and the empirical correlations algorithms. A preliminary results show that the performance of support vector machines will be accurate, reliable, and outperform most of the existing approaches. Future work can be achieved by using this new framework as a modeling approach for solving oil and gas industry problems, such as, permeability and porosity prediction, identify liquid-holdup flow regimes, and other reservoir characterization.
Overcoming the Loss of a Primary Barrier in an HP/HT Well—Investigation and Solution
Authors: Humphreys Alan , Ross Robert 
Published: December 2007

Abstract
The failure of a primary barrier on a completed HPHT well in the West Franklin field in the UKCS in 2005 resulted in a significant pressure increase in the production annulus requiring a complex well kill operation to resolve. Following this incident an investigation programme was undertaken to determine the root cause of the failure and, thereafter, to develop a solution. The failure investigation looked at all aspects of the well design and operations and found no clear cause. A ‘failure test’ was then carried out which recreated the exact downhole conditions on surface. This test demonstrated that very small irregularities in the internal casing profile would cause packer to casing seal failure under severe bottom hole conditions. A programme was then undertaken to develop a packer seal system, suited to the severe well environment, that could withstand a specified degree of casing irregularity. A rigourous qualification programme was also developed to verify the new systems capability in irregular casing.
The programe was completely successful and new packer seal systems have been qualified to these enhanced standards and deployed in the field.