bluuebunny/crossref_metadata_2025_split huggingface dataset:
Effects Of Well Placement And Critical Operating Conditions On The Performance of Dual Well SAGD Well Pair In Heavy Oil Reservoir
Authors: Chan M.Y.S. , Fong J. , Leshchyshyn T. 
Published: December 2007

Abstract
The technical feasibility of applying the Steam Assisted Gravity Drainage (SAGD) process to a 10–20 m thick Saskatchewan type of heavy oil reservoir with an overlying gas cap and an underlying aquifer was examined via numerical modeling. The results suggest a potential reduction on SAGD oil recovery and process efficiency in the presence of a gas cap, an aquifer, or worse, by a combination of both. The oil recovery can be reduced by up to approximately 75% depending on the reservoir setting. Oil recovery can be increased by up to 25% by offsetting the injector from the producer from their conventional SAGD well configuration, or by adopting a staggered well pattern. There is diminishing benefit and deterioration in the SAGD process efficiency when the producer drawdown is set at more than 10–20% of the injector pressure and/or when the producer fluid withdrawal rate is higher than around 150% of the CWE steam injection rate. Some of the preliminary results suggest that the SAGD process for such heavy oil reservoirs can be enhanced through steam-gas co-injection, water-alternating-steam injection, or simultaneous steam-gas- bottom water injection.

Introduction
The continued success of the application of the SAGD process at the Athabasca oil sands Underground Test Facility (UTF) in Alberta has lead to a gradual diversification by the Canadian oil industry to application of the SAGD technology from the oil sands environment to heavy oil reservoirs such as those found in the Province of Alberta and Saskatchewan in Canada. Recent reported advancements in a few heavy oil thermal operations had further heightened interest in applying the SAGD technology to heavy oil reservoirs under a wide spectrum of reservoir conditions. This paper examines, via numerical modeling, the technical feasibility of applying the SAGD process to a 12 API heavy oil reservoir with 10–20 m of pay in the presence of an overlying gas cap and an underlying aquifer; the anticipated production characteristics; the issues on well configuration and well placement; key operating parameters; effects induced by the gas cap, aquifer and a combination of the two; and the potential for enhancing the SAGD process in this class of heavy oil reservoirs.
Design Considerations for a Heavy Oil Multi-lateral Well
Authors: Boardman D. W. 
Published: December 2007

Abstract
A generalised methodology is described for the complete modelling of multi-lateral well performance by using a network pressure solver in a numerical simulator to solve for the interaction between well branch inflows and completion pressure drops. The paper illustrates the importance of taking into account well trajectory, completion diameter and the positioning of the artificial lift, for heavy oil multi-laterals. The results of a design study for a multi-lateral well in an 11 API oil reservoir are outlined, and the necessity for economic ranking of results, in light of significant differences in well costs, highlighted.
Candidate Selection for Removal Treatment Based Upon improved Flowback Analysis: A Case Study
Authors: Carr Michelle A. , Yang B. Helena 
Published: December 2007

Abstract
Poor well performance due to permeability and conductivity damage can often be attributed to unbroken gel residue or inadequately reduced filtercake on formation faces. These forms of polymeric damage can negatively impact production rates by restricting the flow of oil or gas from the formation. Remedial treatments have been applied to wells exhibiting this type of damage using acids, oxidizers and enzymes. These removal treatments, when applied to accurately diagnosed polymer damaged wells and effective breaker systems are utilized, have shown to increase well production dramatically. However, polymer damage is only one of many factors that might be responsible for impeding optimum hydrocarbon flow. Therefore, the key to the success of a removal treatment is proper evaluation for polymeric damage when selecting a treatment candidate.
An improved flow back analysis has been recently introduced as a series of tests for polymer damage and for the evaluation of treatment load recovery. The testing procedures involved in that analysis can also be applied in candidate selection for remedial treatments and for monitoring the resulting clean up progress. Samples are analyzed before and after the treatment to determine total carbohydrate content, molecular weight distributions and the standard pH and viscosity measurements. The utilization of this improved analysis can assist in the selection of appropriate candidates and further direct treatment design. Several case histories on low performance wells are presented and include laboratory data to demonstrate candidate selection. Treatments with enzymes were used and detailed results are provided to evaluate the amount of polymer recovered. This paper also presents a guideline for use in the selection of candidates for remedial treatments.
Optimization of Bit Performance for Qatar's Offshore North Field
Authors: Martin Thomas B. , McKinnell Dave , Labrugere Philippe , Besson Alain 
Published: December 2007

Abstract
This paper describes the methodology and the results of a successful partnership between operator and service companies that improved the drilling performance and economics for the development of the North Field in Qatar. Fifteen high rate gas wells were delivered within designated directional targets, ahead of schedule and under budget.
The systematic use of a new methodology for bit selection, linked with an excellent level of communication and confidence between different parties involved in the drilling operations, was a major reason for the drilling success.
The different sections drilled were mainly made up of limestone, marl, and shale, but also anhydrite in the top portions of the well. In the lower sections, hard and soft limestone alternates withhighly compacted shales and dolomites. Penetration rates were greatly enhanced and bit performance improved by more than 100% in some instances.
The optimization of the performance took into consideration three aspects:A very tight schedule, where the optimization phase had to be performed within a limited time frame: Four wells were planned to be drilled back to back with two jack up rigs from two production platforms. After this short phase, batch drilling was expected to be performed for more than 20 deviated wells.The formations to be drilled presented a high complexity and heterogeneity where hard stringers alternate with a soft or a very compacted rock, and where in the lower section of the hole, a typical pseudo plastic behavior of the rock has to be anticipated.The well designs, casing depths, and bit types had to be in harmony with the drilling environment, the formation, and provide effective performance. New bit designs, more adapted to the technology available had to be developed or identified.
The use of roller cone bits and motors was planned and used in the top hole sections. The use of PDC bits associated with extended steerable motors and/or turbines was considered as potentially providing the best performance in the intermediate and bottom sections.
The early bit designs were modified based on wear patterns of dull bits. These enhancements and modifications were one of the major reasons in improved drilling performance and helped reduce the total drilling time from 75 days to 56 days per well. The challenges were met successfully, the most economical options selected and earned out ahead of time and under budget.
Environmental Regulations for Drilling Operations in Saudi Arabia
Authors: Abu Khamsin S. A. 
Published: December 2007

Abstract
There are several environmental regulations that any drilling and workover contractor must follow when working in Saudi Arabia onshore and offshore areas. These regulations are corporate, national, regional and global in nature. These environmental regulations are established to control drilling operations to minimize its impact on the environment.
The purpose of this paper is to summarize the requirements listed in the environmental regulations that pertain to drilling operations. AH these requirements must be followed and adhered to by operators when working for Saudi Aramco in its operating areas. Also discussed are the plans of implementation by operators to insure compliance of the regulations.
These regulations pertain to (1) discharge to marine environment from drilling operation, (2) waste water treatment re-use and disposal, (3) protection of marine life, (4) pollution control and environment protection, (5) waste management for mud, cuttings and rubbish.
Drilling Optimisations in Yibal Field, Oman
Authors: Koole Koos , Verwey Piet 
Published: December 2007

Abstract
In Yibal, a mature oil field in Oman, a number of optimisations have been implemented as a result of constantly challenging historically accepted procedures and by aligning the objectives of PDO, the Drilling Contractor and Service Contractors through the use of incentives. Although these may not include any step changes in technology, in combination they have realised a 25% reduction in drilling costs over a 2 year period (see fig. 1).

Introduction
The Yibal field, situated in the desert of North Oman, was discovered in 1962. The main oil reservoir is located within the Upper Shuaiba formation at 1370m TVD. The oil column attains a maximum thickness of 100 m with no primary gascap present and hydrostatic pressures. The STOIIP is estimated at 550 million m3 with an expected ultimate recovery factor of 55 %.
Since coming on production in the early 1970's the field has produced approximately half of its ultimate recoverable reserves but it is still responsible for almost one third of the current production target of 135,000 m3/day.
Since the middle of 1994 additional horizontal drainage points in the field have been provided by drilling side-tracks instead of new wells (see figure 1), and with 438 wells present in Yibal and the rapid production rate decline there are many side-track candidates available. Any new Yibal well requires 5 or 6 casing strings (due to the presence of shallow gas, artesian flow, requirement for sweet aquifer isolation, and isolation of a gas reservoir) and costs in the order of US$ 1.6 million with an average duration of 30 days. In comparison, a side-track takes on average 18 days and costs just under US$ 1.0 million. In the first half of 1996, 15 horizontal sidetracks were drilled, each producing initially 500-1000 m3/day.
Although the wells are shallow their complexity is increased by the horizontal design and the frequent presence of total losses and unstable shales. In this environment of repetitive but complex and very intensive work, it is a continuous challenge to obtain increased optimisation of the drilling operation. However this challenge must be undertaken in order to reduce or even maintain the UTC per barrel of oil for PDO.
Deep Water Riser System Design and Management
Authors: Thorogood J.L. , Train A.S. , Adams A.J. 
Published: December 2007

Abstract
The risk of a fatigue failure of a critical weld in a marine riser employed in deep water, harsh environment operations is judged to be high. This paper describes how the dynamic excitation caused by vortex shedding can be quantified and used to predict fatigue accumulation while drilling. Estimation of the initial riser fatigue state is of considerable importance, for this good record keeping by the rig owner is required.
The paper concludes that wells can be drilled in harsh environments without the use of vortex suppression devices so long as fatigue accumulation is monitored. Drilling contractors play a key role in maintaining accurate records of riser fatigue history and managing an appropriate inspection programme. The fatigue accumulation predictions are only as good as the models used in the analysis, which at this stage must be treated with some care.
P. 25
Innovative Rotary Closed Loop System - Engineering Concept Proven by Extensive Field Application in the Adriatic Sea
Authors: Donati Franco , Oppelt Joachim , Trampini Alessandro , Ragnitz Detlef 
Published: December 2007

Abstract
The Rotary Closed Loop Drilling System (RCLS) was developed as a joint venture project between a major oil company and a leading service company. A long term research and development program within the service company was supported by the Italian oil company over the past five years. The resulting drilling system is capable of steering a wellpath while the drill string continues to rotate, so penetration rates are not sacrificed while slide drilling, as is necessary when using conventional steerable technology. Furthermore, this unique system has several integral downhole sensors, enabling two-way communication between the downhole system and surface, while also providing FEMWD data. In addition, several automated drilling functions enable the system to steer independently. During this operation, surface personnel are able to intervene at any time through direct control using a downlink signal. This paper will provide a detailed insight into the project's engineering strategy during the development. The paper also presents a review of the first year of field application, mainly in the Adriatic Sea offshore Italy, which concluded the prototype period. The philosophy of the pilot field application program is briefly described and an overview is given of the ongoing engineering efforts, as well as the considerable future development potential.
P. 305
Using Suction Technology for Deep Installation of Structural Pipe in Deepwater
Authors: Faul G.L. , Audibert J.M.E. , Hamilton T.K. 
Published: December 2007

Abstract
Suction technology has the potential to enhance structural well casings, foundation piles, and caissons in deepwater. The enhancements should provide increased integrity as well as cost savings for future deepwater projects. Suction technology provides an attractive alternative to the current methods of jetting, driving, or drilling and Cementing. The application of suction to install large diameter, shallow set anchors and foundation caissons has already proven to be valuable. Extending this technology to relatively small outside diameter, deep set tubes can provide significant cost savings for deepwater well and foundation construction.
P. 417
Innovative Way To Cement a Liner Utilizing a New Inner String Liner Cementing Process
Authors: Fuller M.S. , Littler M. , Pollock I. 
Published: December 2007

Abstract
It has long been recognized that the conventional process of running an inner string when cementing liners provides for protection of the liner inner diameter from cement during the installation of a well bore liner. Over the years, this process has created concern about being able to verify the location of the cement, accidentally cementing the inner string in place inside the liner, leaving the inner string full of cement upon pulling, or not being able to circulate the liner clean after cementing.
A new inner string liner cementing process has been developed that addresses these concerns and offers solutions to the potential problems. The new process incorporates ways to prevent these problems from occurring. Since the inner string volume will be more consistent than the total liner volume, the volume of cement can be accurately calculated to insure that the shoe track is not over displaced. This is very important since the standard shoe track length can be greatly reduced. In addition, this new system allows you to clean the liner I.D. and displace the well prior to tripping out of the hole with your hanger setting assembly. A cost savings is realized due to the elimination of a separate trip in the hole to clean and circulate the well.
This paper will describe the conventional liner cementing process along with the improvements that have been incorporated into the new system.
P. 501
Outsourcing Can Be Used Successfully Within an Existing Well Construction Organization
Authors: Harder C. , Drennon P. 
Published: December 2007

Abstract
Since the first drilling department was formed many years ago, sizing drilling organizations has been a constant challenge. Fluctuations in drilling activity create a moving target for optimizing drilling personnel requirements. Recent changes in industry patterns have altered both organizational structures and job descriptions. When properly implemented, total outsourcing of well construction, whether on a project or geographic basis can effectively maximize the flexibility of an organization.
Four years ago a well construction organization was formed combining company personnel and a fully integrated, outsourcing engineering firm in-house. The outsourcing arrangement was made to address varying activity levels. To date a total of 144 projects and 57 million dollars of expenditures have been outsourced. The work was performed on a project management basis which required very little supervision by the operator.
The expected benefit of buffering manpower requirements during cyclical activity was not the only advantage experienced with outsourcing. As drilling activity increased, well construction projects were prioritized so that complex projects were handled by company personnel while the engineering firm worked on lower risk projects. In addition, since the outsourcing firm had other clients this opertator continuously benefited from the firm's external experience and perspective, and allowed a continuous competitor analysis approach to evolve throughout the entire organization.
Variations in Multilateral Well Design and Execution in the Prudhoe Bay Unit
Authors: Aubert Winton G. 
Published: December 2007

Abstract
Declining volumetric rates characterize hydrocarbon production from the Prudhoe Bay Unit (PBU) of Alaska's North Slope. Economics of declining production forces Prudhoe Bay operators to seek ever-decreasing well bore construction costs. Multilaterals are designed to reduce well costs on a "per barrel" basis, as multiple producing branches access greater reservoir volume or more than one reservoir.
This paper describes various multilateral well configurations currently in use in the PBU. Descriptions are substantiated by multiple multilateral well case histories. Included are geologic and targeting considerations, operational details, and details of specialized hardware used in drilling new and sidetrack multilateral wells at PBU. Oil production data are also presented.
Open junction multilateral technology is shown to be viable and applicable at PBU. Multilaterals have been executed successfully, and well production performance has been excellent. PBU asset business interests are shown to be well served by application of multilateral technology.
P. 807
Data Integration and Automated Stress-Profile Zonation Enhance 3D Hydraulic Fracture Design
Authors: Boonen P. , Frisch G. , Storozhenko K. 
Published: December 2007

Abstract
A new method is presented to compile all the available data from wireline logging or logging-while-drilling in a format suitable for direct input in 3-D hydraulic fracture models. Because of the differences in format and data density, log data are not always used optimally in 3-D hydraulic fracture modeling. They do provide however the most comprehensive and continuous parameters for borehole stress profile, permeability index, elastic moduli, lithology, porosity and fluid saturations. An automatic zoning technique divides the data into consistent intervals based on stress contrast. The representative design parameters are then computed for each zone. The outputs are a blocked stress profile and zoned fracture design parameters.
The availability of a stress profile based on rock mechanical analysis from wireline logs, microfrac tests and core data specifically designed for use in 3D hydraulic fracture simulators has stimulated the use of these data in the selection of candidates for stimulation treatment. Post-frac radioactive tracer logging has shown that the automatic zone selection identifies natural barriers to hydraulic fracture extension. This new product provides a synergistic approach to hydraulic fracturing in which wireline logs and rock mechanical analysis are fully utilized together with microfrac tests, core data and production history to optimize the execution and economics of the field development process.
Improved candidate selection (wells and reservoirs) for stimulation treatment in a South Texas gas field increases production while reducing the number of fracture treatments and total stimulation cost. Pre- and post fracturing logs are compared to show adequate stress profile compilation.
P. 327
Mapping Hydraulic Fracture Growth and Geometry Using Microseismic Events Detected by a Wireline Retrievable Accelerometer Array
Authors: Warpinski N.R. , Branagan P.T. , Peterson R.E. , Wolhart S.L. , Uhl J.E. 
Published: December 2007

Abstract
Technology has advanced to the point where microseismic monitoring of hydraulic fractures can provide critical information for fracture optimization. Important elements of a monitoring system include the receivers, the telemetry system, and automatic processing of the vast amounts of - data. Procedures and additional data requirements are discussed and examples of the important results which can be obtained are illustrated.
P. 335
Waterflooding Heterogeneous Reservoirs: An Overview of Industry Experiences and Practices
Authors: Gulick Karl E. , McCain William D. 
Published: December 2007

Abstract
This paper reviews waterflood management practices, highlighting key industry papers. It is intended to move readers up the "learning curve" and provide a road map for implementing and operating a successful waterflood project. It will assist reservoir engineers, production-operations engineers, and development geologists who are involved in or are contemplating waterflood operations.
The paper addresses operating philosophy, well spacing (density), pattern development (selection), completions, injection water, and surveillance. Although these factors are presented from a west Texas perspective, they are applicable to reservoirs having a high degree of vertical and areal heterogeneity.
In addition to a brief history of waterflooding, the paper reflects "lessons learned" through years of experience in waterflooding and CO2 flooding carbonate reservoirs, principally in west Texas. This experience has been gained through work in both a major and a large independent oil company, through interfacing with outside operators of all sizes, and through consulting for small, independent oil companies.