bluuebunny/crossref_metadata_2025_split huggingface dataset:
Experience With Operation Of Smart Wells To Maximise Oil Recovery From Complex Reservoirs
Authors: Snaith Nigel , Chia Richard , Narayasamy Devarajan , Schrader Kirby 
Published: December 2007

Abstract
Selective completions have been used in BSP's Iron Duke and Bugan fields to allow commingled production from multiple reservoir intervals, in some cases across fault blocks. Typically, the oil rims in Iron Duke and Bugan are overlain by large gas caps within heterogeneous sandstones. Recent PLT results have indicated that gas breakthrough occurs in high permeability sand streaks. As a result, selective production offers the potential to increase ultimate recovery by improved reservoir management. For example, specific simulation models built to investigate the benefits of a smart well have estimated 20% increase in UR in the Iron Duke. In addition, smart completions offer the potential of accelerated production.
The benefits of smart completions are discussed with particular reference to the well Iron Duke 19. This was completed with a 5 zone selective completion. Although the production performance of 3 of the 5 zones was worse that expected, the smart completion has demonstrated considerable value in allowing both production rates and expected ultimate recovery to be increased. This shows that much of the value of selective completions can be in providing flexibility to respond to reservoir surprises.
Some of the challenges that have been encountered with the operation of multi-zone selective completions and the solutions that have been put in place to optimise well and reservoir deliverability are also discussed. This experience builds on that described earlier for the much larger Oseberg field in Refs. 1 & 2.
Hybrid Testing Technique Results in Successful Well Test and Completion of Low Permeability, HP/HT Sour Crude Reservoirs - A Case Study from Kuwait
Authors: Reji E. C. , Al-Awadi Mohammed , Al-Medhadi Fahed , Kaura Jiten , Clayton Robert 
Published: December 2007

Abstract
The development of light-oil reservoirs in Kuwait has become increasingly more important for maintaining the quality of exported crude. This is due to the fact that producing light-oil reservoirs has proven to be not only a necessary link for maintaining the oil production from this area but also for increasing it. As a result, efficient testing of the light-oil reservoirs has become paramount in importance for overall well and field development.
The reservoirs in Kuwait are low permeability, high pressure/high temperature (HP/HT) and sour. In earlier wells, the strategy had been to perforate these formations balanced or slightly overbalanced, in mud, with through-tubing guns. Results from testing in several wells indicated that if they could be perforated under-balanced, the formations would yield better results since this method would allow better penetration and perforation cleanup. A number of reservoirs are stacked horizontally and range from typically conventional to fractured limestone.
In view of the corrosive nature of the fluids present, one of the primary efforts in the testing of these wells had to be directed toward keeping the number of wireline and coiled-tubing operations to a minimum without compromising the testing objectives. Since it was necessary to test multiple objects in the exploratory wells individually, special effort was focused on determining methods that could effect a reduction in the testing period for each object. By reducing individual testing times, Kuwait Oil Company felt that the overall savings would be significant.
Several areas were identified that would require special consideration. This paper will discuss these areas (listed below) and how the challenges they presented were addressed: Modifications to retrievable completion test (RCT) tools and tubing-conveyed perforating (TCP) equipment that would be required to test these zones efficiently.The challenges associated with designing and carrying out the tests.Ongoing modifications in the testing methodology to overcome the testing challenges.The operation of the test-string, annulus-pressureresponsive components in the heavy oil-based mud and the difficult wellbore conditions.How the problems of shaped charge performance in the naturally fractured formations with unusually high compressive strength and very low matrix permeability and porosity were resolved.
The modifications to tools and methods allowed the goals of the operator and service provider to be met.
Laboratory Investigation and Field Use of a Novel Sand Cleanout Fluid System for High Temperature Applications
Authors: Xiao Zhijun , Shahin Magdy , Hosein Paul , Dellorusso Paul , Lungwitz Bernhard , Samuel Mathew 
Published: December 2007

Abstract
Cleanout of proppants, cuttings and fines in well construction and production phases are typical of oilfield operations. To make these processes successful, extensive research efforts have been done on the development of (i) equipment such as concentric pipe, tubing-operated pump-to-surface bailer and coil tubing with jetting; (ii) engineering operation control and software simulation such as conventional high-rate circulation, reverse circulation, three-segment hydraulic modeling; and (iii) carrier fluids with suspension capabilities. The development of equipment is generally expensive, and often operation limited. Software simulation and control of operation parameters are normally not able to achieve the expected cleanout effectiveness due to the process complexity. Development of novel fluid systems is the only way forward to simplify the cleanout puzzle, and extensive research has been done to improve the efficiency of carrier fluids. The most commonly used fluids are brines, drilling fluids, foams and viscous polymer fluids.
The paper describes the laboratory development of a novel viscoelastic surfactant-based cleanout fluid system and its successful field application. This fluid has several advantages over conventional polymer systems. Viscoelastic surfactant systems are non-damaging to the reservoir, has excellent suspension capacity, adjustable density for hydrostatic head and low friction.
Application of a New Class of Surfactants in Stimulation Treatments
Authors: Nasr-El-Din Hisham A. , Samuel Elsamma , Samuel Mathew 
Published: December 2007

AbstractDifferent acid systems have been used to stimulate production and injection wells for more than a century. Several chemicals are added to the acid to enhance the efficiency of the acidizing treatments, including various types of surfactants.Surfactants play a key role in many well treatments because of their unique properties. Surfactants are used to reduce surface tension, change wettability, mobilize residual oil, and disperse corrosion inhibitors. They are also used as anti-sludge agents, emulsifiers in acid-oil emulsions, and demulsifiers. This wide spectrum of applications is due to the ability of surfactants to adsorb on various surfaces and associate in the bulk of solutions and form micellar structures. The properties of surfactants depend on the size of the head, tail length, and configuration of the tail, surface charges, ionic strength and temperature.Recent advances in surfactant technology have introduced a new class of surfactants with special characteristics useful in oilfield applications. This new class of surfactant has the ability to form viscoelastic systems, which can be used to increase viscosity of the treating fluids, without causing formation damage. These surfactants have been used in Saudi Arabian fields to enhance diversion during matrix acid stimulation, reduce leak-off during acid fracturing and to minimize losses (well control) during workover. The system proved successful to provide fracture extensions in acid fracturing applications of low temperature seawater injectors and high temperature gas wells. These surfactant systems are non-damaging and do not require sized solids to control losses, which eliminates the need for remedial acid treatments.
Innovative Inflatable System Enables the Underbalanced Deployment of Sand Control Screens
Authors: Arnold George , Suwandi Enrico 
Published: December 2007

Abstract
A recent project in the Asia-Pacific country of Brunei required the underbalanced deployment of sand control screens into two wells immediately following the completion of their underbalanced drilling. An inflatable system was specially developed for use in this application to overcome the challenge of maintaining well control while deploying the screens. After serving as a primary barrier while the screens were run into the well, the inflatable tool was then released by the run-in string, and pushed to bottom; a task that would pose a significant challenge to existing inflatable technology. The new system integrated specialized accessories with fieldproven inflatable tools and techniques to enable the innovative procedure.
The paper will summarize the system design process, showing how project engineers addressed the limitations of previous methods with new, inflatable accessories and running procedures. The authors will also present a detailed description of system components including running tools, inflatable tools, releasing tools and their operation. Finally, the paper will review the implementation of this new technology by summarizing the application from the pre-job planning process through the installation of the equipment at the well-site.
The Alphabet Soup of IOR, EOR and AOR: Effective Communication Requires a Definition of Terms
Authors: Stosur George J. , Hite J. Roger , Carnahan Norman F. , Miller Karl 
Published: December 2007

Abstract
The purpose of this paper is to call attention to the need to establish a mutually acceptable definition of the terms Enhanced Oil Recovery (EOR) and Improved Oil Recovery (IOR). It is hoped that the SPE will take note of the need to define the terms and use them as guidelines in reviewing of manuscripts for publications and presentations at its worldwide SPE meetings. A workable definition of the terms is necessary not just for improved communication, but also for recoverable reserves, contract negotiations, Government incentives, taxation purposes, and regulatory authorities when looking at fiscal issues. To get the discussion started, the authors propose workable definitions of the IOR and EOR terms based largely on an informal survey within the SPE EOR/IOR Technical Interest Group (EOIO TIG).
First Successful Implementation Of Expandable Sand Screen (Ess®) Technology In An Open Hole Horizontal Well Located In Baram Field, Offshore Malaysia – A Case Study
Authors: Kabir Mir Rezaul , Awang M. Zaki , Umar L. , Norjusni Omar , Khazimad Yusof 
Published: December 2007

Abstract
During the second quarter of 2002 Petronas Carigali, the State Oil Company of Malaysia, embarked on a campaign to utilize Expandable Sand Screen (ESS®) in unconsolidated multi-zonal sandstone completions in the Baram and Alab fields, offshore Malaysia. The primary objective of the application of ESS® technology was to control sand in conjunction with minimum skin damage without encountering operational problems/constraints which are inherently associated with gravel packing as a means of sand control. A total of five deviated cased holes were equipped with ESS® with mixed results which have been documented in details in a previous publication by the authors (SPE paper # 80449). Further investigation revealed that the wells completed with ESS® have achieved satisfactory improvement in productivity. ESS® technology has now proven to be one of the best available sand control techniques for the Baram field.
This paper will focus on Petronas Carigali’s experience in ESS® technology implemented in a deep horizontal open hole section of a sandy well which is to be equipped with a gravel pack assembly in the upper section inside the cased hole section, thereby providing an excellent source of comparison between the performance of gravel packing and expandable sand screen technology. Installation of ESS® in well BA-47, being the first deep horizontal open hole application in Malaysia, was an operational challenge with a few lessons learnt which may be shared by other operators.
The primary objective of the well has been successfully realized as evidenced by better than expected sand free production. The execution of ESS® installation was successful with some problems encountered while initiating the expansion process. After some modifications on the expansion string and mud/brine system, the expansion process was carried out smoothly.
The secondary objective of the ESS® application was to assess/evaluate the enhancement/impairment of productivity of the well using ESS®, in comparison with the technique of gravel packing. The well is presently in the process of being cleaned up. Preliminary data indicates higher than expected production. PI and PBU tests are planned for the well as soon the well has cleaned up and/or stabilized.
Stimulation Through Back Surging In Horizontal Wells In Mumbai High Field
Authors: Siddiqui N. A. , Roy K. K. , Kumar O. V. , Hazarika A. K. 
Published: December 2007

Abstract
The CTU based stimulation jobs practiced for the horizontal oil wells completed in the, LIII limestone reservoirs of giant Mumbai High field in the Western Offshore basin of India was gradually losing its desired efficacy due to the falling reservoir pressures. As an alternative, the back surging technology used for post gravel pack perforation tunnel cleaning operations in sandstone reservoir was recasted with minor modifications and applied for stimulating the horizontal wells in the saturated, multilayered LIII reservoir Wells IQ-9H and S16-P1H located in the downdipside and crestal part and of the field respectively, were identified for pilot tests so that the field trials are subjected to widely differing geological and petrophysical environment. While Well IQ-9H is placed in the thin uppermost layer of LIII limestone overlain by a huge shale sequence, well S16-P1H is placed within an intermediate layer of the same limestone formation overlain by a large gas cap in the upper eight layers and underlain by a shale band. Encouraging results in both these wells prompted more extensive use of the technology elsewhere in the heart of the field, and results of around twenty 8–1/2" horizontal sections and forty-one 6" drain holes completed in the last three years have been deemed to be successful without exceptions, both in terms of effective stimulation and rig-time savings to US $ 30,000 /well , thereby proving to be a cost effective substitute over conventional bulldozing and CTU based jobs.
The surge tool is tailormade for instantaneous drawdown across the formation face thereby removing all post-perforation fines. The assembly is run on a lock mandrel to an appropriate landing nipple profile. The tool is surface dressed with shear screws, number and type chosen to suit the pressure likely to be created across it. After the horizontal well is completed with packer, the dressed back surge assembly is installed over the landing nipple through slick line. The tubing volume above the back surge tool is knocked out for creating the differential pressure. The preinstalled shear pins gives way to the formation fluids. The back surge tool is ultimately retrieved once the stabilised flow is attained.
The paper details the design of the surge tool, its preference over other existing systems in practice and the performance enhancement profile alongwith the financial indices in the 61 wells it has been tested in the LIII reservoir of Mumbai High field.
Fastest Deep Marrat Well in North Kuwait: Case History of Raudhatain 206
Authors: AL-Saeedi M. , AL-Mutairi B. , AL-Khaldy M. , Sheeran T. 
Published: December 2007

Abstract
For the last 20 years, exploration in Kuwait has focused on finding commercial quantities of high quality oil in the deeper high pressure/high temperature (HTHP) Jurassic formations (13,000–17,000 ft), and for gas within the Triassic formations (17,000–21,000 ft). The HPHT conditions, the presence of H2S and CO2, the narrow pore pressure/fracture pressure (PP/FP) window to work with, and the high mud weights (18–20 ppg) required have made deep drilling conditions in Kuwait some of the most challenging in the world.
This paper discusses the outstanding drilling performance achieved in drilling Ruadhatain 206 (RA-206) as the fastest deep Jurassic well to date in North Kuwait. New practices were incorporated and several firsts accomplished through optimum utilization of local built-in experience, combined with the latest technology and practices developed by International Operating Companies (IOC's) and service companies.
Optimum bit selection resulted in a world record bit run in the 28" section, and record firsts for Kuwait in the 22" and 16" sections. Careful analysis of offset data and in selecting mud weights resulted in improved hole stability with minimum mud losses, and enabled the bottom two hole sections to be commingled. Extensive cement design and optimization resulted in an excellent CBL being achieved in the production casing.
The excellent performance achieved in well RA-206, has now opened the possibility of efficiently drilling similar wells in 100 days (technical limit) instead of the 170–200 days normally taken. (Fig-1) The improved drilling practices significantly reduced the drilling time and well costs, and provided a step-change forward in KOC's understanding of drilling limits when applied to deep exploratory/development wells.
New Contracting Relationship Improves Drilling Performance with New Technologies and Aligned Goals
Authors: Forbes David , Mencer Glenn , Hartono Slamet , Russell Richard , Stymiest John 
Published: December 2007

Abstract
Dubai Petroleum Company (DPC) operates a number of offshore fields in the emirate of Dubai in the United Arab Emirates. The fields have been producing for over 30 years and the structures now require some of the most innovative and complex well designs that are currently being drilled in the industry today. In order to successfully achieve such designs it has been necessary to introduce new processes and technologies. DPC recognized that traditional contracting relationships were not the appropriate environment to encourage the use of such technologies to improve the drilling performance.
In 2002 a new contracting relationship was established between Dubai Petroleum Company and Halliburton for the provision of directional drilling, MWD, LWD, drill bits and Surface Data Logging (SDL) services. Whereas previously these services were provided by four different suppliers, it was recognized that they are all related in terms of the provision of data and performance during the drilling process. It was therefore determined that synergies would be realized by having these services provided from the same source. More importantly a fair and equitable remuneration scheme was established whereby overall compensation was based on agreed key drilling performance factors, in addition to meeting agreed well objectives. These are designed in such a way to allow the service supplier to realize the benefits of introducing new technologies which in turn would actively encourage their introduction.
To date the new contracting relationship has been in place for over a year and it is now possible to compare drilling performances under the new contract with those under the previous contracts. In addition during this period a number of new technologies have been utilized in the drilling of these wells.
This paper will examine the traditional contracting relationship between operator and service supplier and describe the new contracting relationship established in 2002. Previous and current drilling performances will be compared and the new technologies introduced described along with the benefits they bought to the overall drilling program.
Field Study in Kuwait
Authors: Al-Zanki Khalid , Al-Anzi Nayef , Cox Gene , Al-Mohailan Mohannad , Al-Khaldy Ali 
Published: December 2007

Abstract
After the liberation of Kuwait, a large number of wells were blown up by the Iraqi troops, and some needed to be worked over before re-producing them. Around 100 wells were intact and were put back on production shortly after the liberation. Those wells are originally 40 to 50 years old, and the wellhead equipment on those wells were not changed or reconfigured with the current API standards until this date. Workover operations were delayed due to several issues concerning the wellheads. A project was assigned by KOC management in 2002 to inspect those wellheads and submit a report with the current status of the equipment, problems, and solutions.
As a result of a full research made on those intact wells, the wells were segregated into 4 categories depending on the integrity and operational issues of the wellhead equipment. It was decided that some of those wellheads would only be reconfigured using a combination of the old and new equipment. Others will require total wellhead replacement.
This paper will discuss results and recommendations on the report submitted. It will cover the integrity issues of old wellheads concerning safety, control, and effect of time on the equipment. It will also cover the operational issues on those wellheads that prevented safe and controlled workover operations. Improved technology was the ultimate solution, and a detailed comparison between the old and the new types of wellheads will be discussed in the paper.
Drill Cuttings Disposal, Balancing Zero Discharge and Use of Best Available Technique
Authors: Paulsen John E. , Omland Tor H. , Igeltjørn Hilde , Aas Nina , Solvang Steinar Aabye 
Published: December 2007

Abstract
The new OSPAR regulation (OSPAR 2000/3) on drill cuttings is due to be effective by January 2005 at the Norwegian continental shelf. Drilling operations planned to be performed from to date and onwards therefore have to take into account that the forthcoming regulation has important implications with respect to selection of adequate and compliant technology.
Drilling will commence at a new HTHP Statoil operated field offshore middle Norway, by late summer 2003. Ahead of the spudding in, a detailed and comprehensive review of technological solutions has been carried out to resolve the issues of zero discharge and use of best available technique.
The paper describes the challenges associated with the forthcoming zero discharge regulation and the different technological scenarios that have been reviewed. Waste minimisation methodology has been of major importance in the decision process. Treatment of oily drilling waste, applying new technology at the rig, was studied in detail. The respective energy budgets, environmental impacts and risks associated with the different solutions are also presented, as well as a suggested best technique.
The paper offers a study of how operators may comply with a zero discharge in drilling operations, with reference to BAT (best available technique). On a general basis the ultimate goal of environmental legislation is discussed with reference to the forthcoming discharge regime and how to decide BAT; achieving the right balance between technology and value.