bluuebunny/crossref_metadata_2025_split huggingface dataset:
New Solutions To Extend the Application Window of Horizontal Openhole Gravel Packing
Authors: Pedroso C. , Sanches E. , Oliveira N. , Fernandes L. , Mickelburgh I. J. , Coelho G. S. 
Published: December 2007

Abstract

Introduction
Open hole gravel packing using the alpha/beta wave placement technique, has become the completion of choice for many operators developing fields with horizontal wells in unconsolidated sands. The interrelationships of the gravel placement parameters in these wells are well understood, and the process can be effectively modeled. However, for completions in deep and ultra deep water, difficulties limit the use of this technique.
New solutions are required to overcome the challenge of successfully packing through shale intervals, and to reliably overcome the gravel placement limitations imposed by low frac gradients. This paper presents the solutions currently in use and provides an application example using a new solution.

Horizontal Open Hole Gravel Pack (HZ-OHGP) Techniques
Successful gravel packing of long horizontal open holes has been achieved with two alternative gravel placement techniques – alternate path (A/P) and alpha/beta (A/B).
Fracturing for Sand Control: Screenless Completions in the Yegua Formation
Authors: Ellis V. R. , Cormier G. , Adams G. , Santos F. 
Published: December 2007

Abstract
Natural completions in the Yegua formation have resulted in failures caused by formation-sand production and wellbore collapse. In the past, the most popular remedy was small fracturing treatments with gravel-pack screens to control the production of formation material. Designing the completions specifically for wellbore stabilization, sand control, and maximizing the conductivity endurance, has resulted in techniques that eliminate the need for gravel-pack screens, helping to simplify completion operations and minimize cost. Field data, including logs and production history, have been used extensively for the purpose of verifying this technique. The completion technique includes several key components: Perforations—The interval length, along with perforation phasing and orientation, have shown to be the most important aspects of a successful completion.The use of resin-coated proppant and conductivity endurance modifiers (CEMs) are used to aid in stabilizing the proppant pack and demobilizing fines.The fracturing treatments are designed to maximize fracture width and decrease the pressure drawdown near the wellbore during production.
Several wells have demonstrated the effectiveness of this technique (frac-pack stimulation without gravel-pack screens) by producing no formation fines or proppant. These results are documented by several case histories comparing previous techniques to current techniques.
The application for this technique reaches further than the Yegua formation of east Texas to include any formation with similar properties. This technique provides extra benefits for wells with multiple zones by reducing the completion cost and minimizing the complexity of the wellbore for future entries.
In summary, by properly designing the completion of the Yegua Sand formation and applying curable resin-coated proppant or CEM's, sand control has been achieved without the use of screens. This technique has reduced the overall completion cost, simplified the wellbore configuration, delayed or eliminated casing collapse in Yegua producers, improved total gas recovery, and reduced well down-time.
Multiproduct Pipe Transport Conversion of Abandoned Single Product Pipelines
Authors: Davis C. , Fagan J. 
Published: December 2007

Abstract
This paper explores the potential of utilizing large diameter steel pipelines, that are no longer in use, to simultaneously transport small batches of different products. These pipelines were originally created in the United States to transport gas from the south to the north. As Canada emerged as a gas supplier to the northern states, these pipelines were no longer needed for their original purpose. Many of these pipelines were completely abandoned because an alternate usage was not identified for transporting large quantities of a single product. With these pipelines obsolete, building new smaller diameter pipelines was the only solution considered to accommodate the present need.
To accomplish the necessity of economically transporting small batches of product, multiple pipes are inserted into these large diameter steel pipelines. Polyethylene (PE) was selected as the piping material for this application because of the flexibility and tensile strength required during the insertion process. A method was developed to insert 10-mile sections of the PE pipes into the steel pipeline. Once these PE pipes are installed, a method of controlling and monitoring the flow is required. The control system allows the outputs to be maximized without causing failures such as bursting or leaking. Furthermore, to assure economical feasibility, performance benchmarks were proposed by industrial partners.
The model produced from this study analyzes steady state operation as well as transient effects such as opening/closing a valve or starting/stopping the pipeline. New formulas are derived to calculate frictional pressure drop for fluid flow in pipes containing internal pipes. National Instruments Lab-View, a graphical programming language, was used to transform the mathematical model into a real-time operational tool that can be directly connected to the pipeline system.
Successful Stimulation of Sandstones in the Dulang Field, Malaysia, Using Surfactant-Based Diverter: A Novel Solution for Mature Fields
Authors: Ali A. , Hashim A. H. , Hashim F. , Said R. , Nair D. S. , Chan K. S. , Samuel M. 
Published: December 2007

Abstract
Dulang is the major oilfield in the Malay Basin. Owned by the Malaysia national oil company, Petronas, it is located in the South China Sea, about 130 km offshore the east coast of Peninsular Malaysia in water depths of about 76 m. This field, consisting of sandstone formations, was discovered in 1982 and developed fully in 1991 resulting in 48 wells being drilled and produced. Currently, the reservoirs in this field are nearly depleted, having many idle wells with high Gas Oil Ratio (GOR) and water cut (up to 95%).
An attempt was made to revive the idle wells with potential recoverable reserves. A collaborative team was formed to devise a solution. The main focus was given to idle wells with high water cut. The objective was to increase oil production and reduce water cut. A number of options were reviewed, with one of the strategies being to increase oil production by shutting the water/gas production. However, due to various operational challenges that these well possess, (i.e. difficulty in mechanical isolation due to dual completion and availability of multiple water/oil zones) no direct approach could be employed.
In order to keep the drive and market of idle wells afloat, a different strategy was proposed and marketed which focused on increasing the oil production with little or no water increase. The water cut in response to this strategy would be expected to be either maintained or decrease resulting in higher oil production. The introduction of matrix acidizing utilizing a high temperature viscoelastic surfactant-based diversion system has made it possible to achieve such results.
A high temperature viscoelastic surfactant-based diverter was engineered to selectively plug the zone with high water saturation, allowing the treatment system to enter the zones with high oil saturation. Another advantage over the conventional particulate diverters is that it contains only a surfactant and does not have any solids or polymers. This paper discusses application and results of using high temperature viscoelastic surfactant-based technology in the Dulang fields.
This paper will also cover candidate selection, pre-job laboratory testing, execution and evaluation challenges in order to properly execute the job. Candidate selection, which is the most crucial task in this project, determines the right and potential candidates for the treatment. Extensive laboratory experiments, such as crude oil and acid compatibly (emulsion and sludge tests), and core studies (SEM, XRD, core flow, etc.) have been carried out to develop the most effective acid recipe. Previous treatment results will also be discussed in this paper. The success of the treatment in Dulang has proven the potential success of the application of this high temperature viscoelastic surfactant-based diverter for selective stimulation of high water cut oil wells.
Offshore Safety Division's Response to Concerns About Installation Integrity on UKCS
Authors: Cutts S. 
Published: December 2007

Abstract
This paper outlines the delivery of a key programme (KP3) being undertaken by the Health & Safety Executive's Offshore Safety Division (OSD) to address integrity concerns offshore. The approach and findings of the structured inspection programme are discussed, together with an analysis of both weaknesses and strengths. The participation of industry stakeholders is acknowledged as key to achieving an upturn in integrity performance and so minimising the potential for accidents.
Ultraslim Rotary-Steerable System Enhances Brownfield Production
Authors: Kholy K. E. , Kuyken C. , Kleverlaan M. , Saul D. , Andersen S. , Kirkemo E. 
Published: December 2007

Abstract
Schlumberger has worked collaboratively with Shell U.K. Limited (Shell), BP and Statoil to develop a 3 ¼-in. ultra slim through tubing rotary steerable system (RSS) with the objective of extending the production profile of offshore maturing fields. Through tubing rotary drilling (TTRD) is a very attractive option for enhanced reservoir development at low cost. Current methods use motor bottomhole assemblies (BHAs) in TTRD applications, but these have limitations. The introduction of the RSS will extend the reach of TTRD to pursue more distant targets, enhance production through precise directional control, improve drilling performance, reduce drilling cost, and improve ultra slimhole hydraulics. The tool has entered its field test stage and has two successful downhole runs to date.
This paper provides a brief overview of TTRD as a method of sustainable development of mature oilfields (brownfields). A detailed overview of the tool development is given, including the main milestones and a system description. The joint RSS development project is presented as a best practice in industry collaboration and a good example of a collective visionary approach to future brownfield development.
An Integrated Transport Model for Ball-Sealer Diversion in Vertical and Horizontal Wells
Authors: Li X. , Chen Z. , Chaudhary S. , Novotny R. J. 
Published: December 2007

Abstract
Ball sealer diversion has been proven to be both an effective and economic way to selectively stimulate low permeability oil and gas reservoirs in hydraulic fracturing and matrix acidizing treatments. However, the design and implementation of a successful ball sealer diversion treatment is still a challenge. Often the designer depends on experience, and lacks the knowledge of accurate ball transport and sealing behaviors. An integrated model for selecting operating factors such as fluid and ball properties, as well as predicting the ball sealers transport and hydraulic behavior prior to pumping is needed for optimizing the stimulation process.
In this paper, an integrated transport model is presented to describe the relationships among the ball sealer transport sealing behavior, wellbore deviation, wall effect, perforation density and size, fluid properties, pumping rate and ball properties. In addition, the smoothness of ball, perforation phasing, and velocity profile inside the wellbore during ball seating are also taken into consideration. Recommendations are provided for determining the number of ball sealers per job for either single or multiple stage treatment, the designed pumping rate, and the physical properties of the fluid and ball sealer. A hydraulic analysis model is presented for the overall fluid dynamics starting from surface, through wellbore, to reservoir. This analysis describes the effects of reservoir condition, pressure drop on perforations, and actual sealing efficiency on the surface treatment pressure profile. This paper will investigate the effects of the diversion factors on the ball transport behaviors such as transport time, ball sealer efficiency and surface pressure.
Breakthrough Drilling Performance in Horizontal Deep Gas Wells with Application of Geo-steering Technique in Saudi Arabia
Authors: Thomas S. , Al-Thuwaini J. , Petrick M. , Nwabor D. 
Published: December 2007

Abstract
Saudi Aramco attempted to drill horizontal deep gas carbonate wells without utilizing the Geo-steering technique in Hawiyah/ Uthmaniyah (HWYH/UTMN) field. In both 8-3/8" and 5-7/8" horizontal sections, much time was lost due to low ROP, sidetracks due to drilling in an unwanted pay zone and a stuck BHA, drilling with TCI and PDC bits (originally designed for vertical application).
A new approach was required to deal with this problem. The reservoir engineers and drilling engineers, together with service companies, analyzed each problem in detail and found the solution, utilizing LWD/Geo-steering technique. An improvement in casing design led to reduced MW across the pay zone. A geo-mechanical study was conducted and implemented its recommendation of drilling in the direction of maximum horizontal stress. This approach utilized PDC bits designed for horizontal drilling. This approach reduced drilling costs for over five laterals; compared to the previous five laterals in this carbonate reservoir (costs do not include the additional bits and pipe conveyed logging in these wells).
Utilizing the Geo-steering Technique in the carbonate reservoir increased the length of pay from 6,360 ft to 15,400 ft, an increase of 142% over a five-well average. It reduced the number of days required to drill five laterals from 364 days to 129 days, a reduction of 65%. Total lateral footage drilled for these five laterals reduced from 24,251 ft to 19,898 ft, a reduction of 18%. The average ROP improved over five wells from 6.11 ft/hr to 12.67 ft/hr. The average footage drilled per day increased from 66 ft/day to 154 ft/day and average number of bits used per well reduced from 13.4 bits to 3.6 bits per well. No sidetrack was required. One of the recent wells was drilled in record time for a HWYH/UTMN horizontal well and was also the longest single-lateral horizontal well in the field. One of the 8-3/8" PDC bits achieved record performance by drilling 4,475 ft in 261.5 hrs with an average ROP of 17.11 ft/hr, representing one of the longest intervals drilled by any 8-3/8" PDC bit in Khuff-C carbonate reservoir.
The Material Issues Involved in the Discussion Surrounding the Virtues of the SPE/WPC Definition of Proved Oil and Gas Reserves vs. the Corresponding Definition Set Out by United States Securities and Exchange Commission (SEC)
Authors: Cline W. B. , Rhodes B. C. , Hattingh S. K. 
Published: December 2007

Abstract
Among the more contentious issues discussed within the oil & gas industry recently are: Are the United States Securities and Exchange Commission (SEC) definitions of Proved oil and gas reserves obsolete, too narrow and/or unrealistic for today's oilfield technology?Are the SPE/WPC definitions of Proved oil and gas reserves much more realistic and responsive to today's comparable reporting needs?Has the meaning of the word ‘Proved' changed over the last twenty-five years?Has the meaning of the expression ‘Reasonable Certainty’ changed over the last twenty-five years?
The contention here is that the answers to each of these four questions is ‘No’. This paper advances the idea that there are no material differences between the Proved oil and gas definitions promulgated by the two organizations if the original common cornerstones are honored within the true spirit of the words engaged in those definitions.
The allegation that the SEC definitions for Proved oil and gas are in some way out-of-date in terms of the application of modern oilfield technology is examined and found to be without legitimate foundation. The distinctive variation between the two organizations is discussed; the SEC as a regulatory authority with responsibilities for ensuring comparable reporting by listed corporations within its jurisdiction versus the SPE as a Technical Society without such responsibilities or the structure for offering guidance regarding definitional compliance.
As the ‘interpretation drift’ in the application of the SPE/WPC Proved reserve definition continues unabated, the search for an International Standard by other organizations (particularly the United Nations) only further complicates the matter. The question is posed as to whether the lack of proactive contributions in this regard from the SPE, as an organization, places the very integrity of the Society's broader reserve definitions at stake. The SPE membership are reminded that very few years ago, the SPE/WPC/AAPG definitions were very credibly put forth for adoption as the essential International Petroleum Industry Standard.
Real-Time Asset Management: From Vision to Engagement—An Operator's Experience
Authors: Unneland T. , Hauser M. 
Published: December 2007

AbstractThe Digital Oil Field is rapidly gaining attention within the oil and gas industry. Several oil and gas operators are working to develop their vision for an oil field of the future, testing new technologies, setting up programs and participating in industry events. The vision is an integrated approach allowing more real-time control of asset management. Many different names are used in the upstream industry to describe this trend; Smart Fields, Digital Oil Field, Next Generation Oilfield, Field of the Future, e-field, Instrumented Field and Intelligent Energy. However, there is still uncertainty as to what needs to be done and what value it will actually bring to the industry. Several operators and service companies are transitioning from the initial envisioning and abstract phase to projects creating measurable value for the company. In this paper, Chevron's efforts within the Digital Oil Field domain, including concept, business case, corporate governance, technology development, partnerships, deployment and field experience are presented.
Simple, Robust NMR-Based Indicators for Detection of Hydrocarbon Gas or Oil, Borehole Contamination, and Vugs
Authors: Chen S. , Munkholm M. , Hursan G. , Georgi D. , Gillen M. 
Published: December 2007

Abstract
NMR logging techniques have proven to be useful tools for a variety of formation rock properties and fluid typing applications. In the last decade, numerous improvements have been made both to multi-frequency NMR logging instruments and to data acquisition methods that have significantly enhanced the data quality and expanded the NMR logging applications envelop. On the other hand, these more versatile acquisition methods collect a large quantity of data that may seem overwhelming to most non-expert NMR users. To overcome the complexity of NMR logging and facilitate the wellsite decision-making, we have developed a number of simple, robust NMR log-based indicators for identifying hydrocarbon gas or oil, for detecting borehole rugosity contamination, and for recognizing vugs in carbonate reservoirs.
Reservoir Simulation and Reserves Classifications—Guidelines for Reviewing Model History Matches To Help Bridge the Gap Between Evaluators and Simulation Specialists
Authors: Rietz D. , Usmani A. 
Published: December 2007

AbstractAs the scrutiny on oil and gas reserves continues to increase, the subject of evaluating reservoir simulation models has come to the forefront. Regulatory bodies, such as the U.S. Securities and Exchange Commission, do not provide detailed criteria on the use of reservoir simulation models in the reserves estimation process, other than their stated position that the model must have a "good history match". A great deal of high quality, highly technical research has been conducted in the field of history matching and of late in "automatic" history matching, and the paper reviews some of this research. While much of this research is useful, it is not clear that any particular quantitative assessment can be made of history match quality, or if such a method really helps to understand the applicability of the history matched model. It is easy to understand why reservoir simulation specialists and reserves estimators may be at odds as to the use and utility of a particular model. It is well recognized that, in general, only a limited amount of time is available to review models; thus, only a fraction of the time devoted to the original model construction can usually be devoted to the review process.The authors have been on both sides of this dilemma, and this paper is intended to provide some suggestions for a systematic review of models (for whatever ultimate use) and start a dialogue to discuss how history matches should be evaluated with respect to reserves. It is noted that, for the most part, model reviews do not need to address whether a model is "perfect" overall, rather a review should address whether a model is fit for a particular purpose. The authors propose that the applicability of the model, and the quality of the history match can always be qualitatively assessed if one views the model as an analogy for a particular property. Therefore, the "analogy" approach suggested by the authors provides a specific methodology for incorporating simulation model results in the reserves estimation process.
A Well Test for In-Situ Determination of Relative Permeability Curves
Authors: Chen S. , Li G. , Peres A. , Reynolds A. C. 
Published: December 2007

Abstract
We propose a novel well-test for in situ estimation of relative permeabilities under two-phase (oil-water) flow conditions. The test consists of three periods, (i) injection of water into an oil reservoir operating above bubble point pressure, (ii) a falloff test and (iii) a producing period. The producing period is critical as it yields production data that reflects changes in sandface mobility and thus is highly sensitive to the parameters used to model relative permeability curves, whereas, our results indicate that injection/falloff pressure data by themselves are not as reliable for defining relative permeability curves. We have developed optimization code based on the Levenberg-Marquardt algorithm and coupled it with a commercial reservoir simulator to obtain a procedure for data analysis where the reservoir simulator is used as the forward model. By matching data by minimization of a weighted least squares objective function, we generate estimates of absolute permeability, relative permeabilities and the well skin factor. We show the method can be applied with either power law models or B-splines. We introduce a variable transformation that can be used to ensure that the estimated relative permeabilities are monotonic and concave up when B-splines are used.