bluuebunny/crossref_metadata_2025_split huggingface dataset:
An Overview of Injection Design
Authors: Dunn-Norman S. , May E.A. 
Published: December 2007

Abstract
Recent advances in research have significantly improved the understanding of formation damage induced from injection operations. Specific measures, such as injector half life, and models for predicting injectivity decline have been developed to assist engineers in designing optimum injection operations.
During a similar time frame, Underground Injection Control (UIC) regulations formulated under the Safe Drinking Water Act (SDWA) have been enacted and have served as a catalyst for changes in downhole injection design and operation of injection wells.
This paper provides a concise overview of the state of injection design. The paper includes a review of fundamental injection design, presents research results in formation damage due to brine injection, and discusses the downhole design(s) currently required by law under 40 CFR (US Code of Federal Regulations).

Introduction
Formation injectivity and injectivity decline due to formation damage from inject brines, are principal concerns in waterflood (Class II) injection design. From the operators standpoint, formation damage is the principal concern because increasing damage reduces injectivity, and can affect the longevity of the injection well.
Regulatory compliance aspects of the injection operation and the environmental implications of the wellbore design are also of paramount importance. These issues determine whether an injector can be permitted, the maximum injection pressure which can be sustained, and any risks which the injector may pose to overlying sources of drinking water.
Design Considerations of Waterflood (Class II) Injection Wells.
The design of a Class II injection well must considerFormation injectivity and injection well testingFormation damage, injectivity decline and filteringRegulatory considerations for injection design
Selection of tubulars, injection pumps and surface facilities such as brine filters is made on the basis of design parameters related to these issues.
Formation Injectivity and Injection Well Testing.
Formation injectivity is one of the first parameters determined in injection design. The formation's ability to accept the injected brine will govern the tubulars and surface injection requirements. Injectivity also can affect the selection of the injection pattern and the number of injection wells per producing well in pressure maintenance and waterfloodng operations. Determination of the base formation injectivity also provides a baseline observation from which predictions of the long term injectivity of the well can be made. All of these considerations are important to the economic success of injection projects.
Well tesing techniques have been employed in injection wells to determine reservoir parameters such as injectivity, in-situ permeability and skin factor, formation parting pressure and fracture extension pressure. These techniques include injectivity tests, falloff tests and step-rate tests.
Ultrasonic Instrumentation for On-Line Monitoring of Solid Deposition in Pipes
Authors: Andersen M. I. , Isaksen Ø , Urdahl O. 
Published: December 2007

Abstract
Studies of the fluid- and flow properties of reservoir fluids is important to ensure an effective and safe production and transport of oil and gas. Among the many areas where it is important to gain further knowledge is the formation and deposition of hydrates and wax in pipes transporting reservoir fluids or crude oil. On this background, Christian Michelsen Research A/S (CMR) has studied various measuring techniques over the past few years, and instrumentation for deposit monitoring has, and is in the process of being developed. Recently, CMR has developed ultrasonic laboratory instrumentation for on-line monitoring of solid deposition in pipes.
The system consists of two ultrasonic "clamp-on" transducers operating in pulse-echo mode, two compact electronics units and a PC "control unit" handling all data acquisition, signal processing and presentation of results. The system has been installed on a multiphase flow "loop" at Statoil's Research Centre in Trondheim, and is designed to: 1) – detect the deposition of hydrate on the pipe wall, or 2) – measure the thickness of a possible wax layer.
In this paper, the system, its detection principles, and the results from initial tests are described and presented. The critical factors influencing the operation and robustness of the system are discussed, as well as the conditions which must be satisfied and the challenges to be met for a successful industrial application.
The Evaluation of Two Different Methods of Obtaining Injection Profiles in CO2 WAG Horizontal Injection Wells
Authors: Dollens Kimberly B. , Shoumaker James C. , Wylie Burl W. , Rice Phil , Johannessen Orjan 
Published: December 2007

Abstract
Two different methodologies were employed in obtaining injection profile surveys in two CO2 water-altemating-gas (WAG) horizontal injection wells in the South Cowden Unit (SCU) CO2 project. Both methods were used once during an initial water injection period to establish a baseline profile. Then, the first method was utilized on both of the horizontal injection wells during a CO2 injection period. The first method utilized a coiled tubing conveyed, memory-based logging system, including a correlation gamma ray and collar locator log; injection and shut-in temperature, capacitance, flowmeter and pressure gradient; and interface tag. The second method utilized a logging and injection program wherein coiled tubing and wireline were run in the injection well with a Y-block and coiled tubing side-entry assembly attached to the coiled tubing below the spot valve. The tool consisted of a positive and negative gamma ray and temperature tool, and utilized a slug of more than one gallon of radioactive gel rather than the standard injection volume of approximately 50 cc or 1 cc per station. Actual field results are reviewed, and the two methodologies discussed for application in CO2 WAG horizontal injection systems.
A Practical Technique to Estimate the Formation Thickness in a Kicking Well
Authors: Samuel G. Robello , Engler Thomas , Miska Stefan 
Published: December 2007

Abstract
Characterization of formation while drilling continues to be a challenge to the engineers. This paper describes a technique contributing to this objective. When a well kicks while drilling, evaluation of pore pressure and the corresponding kill mud density is of critical importance for the safety of the drilling crew and mechanical integrity of the wellbore. Besides the estimation of these parameters, it will be beneficial to estimate the thickness of the kicking formation prior to drilling. This helps to drill safely and carefully through the potentially active kicking formation. In this paper, it is shown how to calculate the kicking formation thickness with the limited information available at the time of an oil/gas kick. A method of data analysis (obtained on a kicking well) to estimate the formation thickness of the kicking zone is presented. Illustrative examples including actual field cases are described and analyzed.
Rigsite Information Management: Are We Making Use of Modern System's Full Potential?
Authors: Spoerker H. F. , Kroell E. 
Published: December 2007

Abstract
Today's rigsite information acquisition systems are demanding to the operator, costly to install and maintain and hardly friendly to inter-company networking interests. Cost-efficient solutions, integrating rigsite instrumentation with drilling data acquisition through sensor telemetry, daily drilling reporting and all additional related information services /e.g. cement job records, well logs, well tests etc.) are clearly wanted by the drilling community to enhance quality control. The paper lists experiences gained with extensive drilling rig instrumentation and drilling process information gathering systems over a period of 12 months, critically evaluating the quality and usefulness of commonly acquired drilling data as well as the actual application of such information volumes in accelerating the drilling learning curve and enhancing process and quality control. A detailed description of storing "streamed" drilling data into a large-scale multi-user relational database and the additional value of such information volumes available to the user "at his fingertips" is presented. The realization potential of such systems on low-to medium-cost on-shore drilling operations as well as the possible integration of multi-well and multi-rig systems and the buildup of field- and area-databases are presented from a service-company as well as operator standpoint. A definition of the current state-of-the-art in rigsite information management is attempted and the future potential for such systems is assessed.
Illustrations and references at end of paper
Design and Testing of a High-Performance Inflatable Packer
Authors: Eslinger D. M. , Kohli H. S. 
Published: December 2007

Abstract
The marginal performance and reliability of inflatable elements often restrict their use in demanding through-tubing workovers. The development and qualification of a robust, 2.12-in. OD inflatable element are reviewed. The new element has a differential pressure rating of approximately 5000 psi at 2:1 expansion and 2000 psi at 3:1 expansion at temperatures in excess of 300°F. This allows operation in wells that are more hostile than previously possible while increasing job reliability for less demanding applications.
Contribution to reservoir behaviour appraisal by television
Authors: Gay L. , Groult J. 
Published: December 2007

Abstract
Conventional investigation methods, such as logs, core analysis and production tests have been unable to provide data accurate enough for evaluating the Emeraude pool. In order to gather the informations, pool. In order to gather the informations, which in our opinion are essential, we have been led to use a closed circuit television system.
In order to be safely operated in a bore hole, the available television camera had to be adapted to oilfield equipment. A number of preliminary tests was necessary to achieve this goal.
This rather peculiar method provided means to assemble essential and sometimes spectacular data, which successfully completed the partial results available thus far.

Introduction
The Emeraude structure was discovered in 1969 by Elf Congo in the offshore waters of Congo-Brazzaville.
The hydrocarbon in the reservoir is an undersaturated, highly viscous oil. Pay zones are located from 200 to 650 meters (650 to 2.130 feet) and consist mostly of more or less carbonated silts, slightly consolidated or unconsolidated, with indurated limestone breaks. The latter have an average thickness of about a decimeter.
From the first wells on, the conventional formation evaluation methods proved to be insufficient, a striking example being the discrepancy between the permeability values determined from core analysis and the much higher permeability values deducted from the pressure build-up curves recorded on production tests.
Impairment of Producibility Due to Fracturing Fluid Leak-off in Oil Reservoirs?
Authors: Gadiyar B. R. , Gupta A. , Shah S. N. 
Published: December 2007

Abstract
This paper presents the results and interpretation for return permeability testing following the leak-off of fracturing fluid in reservoir rock samples containing movable oil saturation. The dynamic fluid loss tests were conducted with 2 inch diameter and 10 inch long core samples. The fluids used were linear guar and hydroxypropyl guar (HPG), and borate crosslinked guar and HPG, respectively. Tests were conducted with and without fluid loss additive (FLA) in order to study its effect on return permeability impairment. All tests were conducted at room temperature. The drive pressure during leak-off was 500 psi.
Following the leak-off, the cell was shut-in for a duration of at least 3 hours. In order to obtain the variation of return permeability with time and distance from the fracture face, the return permeability was determined for each 2 inch long section of the core sample. Variation of return permeability for the specified range of fracturing fluids is presented and discussed.
Screening and Design Criteria for Tangleflags Type Reservoirs
Authors: Kasraie M. , Singhal A. K. , Ito Y. 
Published: December 2007

Abstract
Tangleflags project is a highly successful example of a Steam Assisted Gravity Drainage (SAGD) process operated by Canadian Natural Resources Limited. The original reservoir conditions were unfavourable for steam injection : the reservoir has a small gas cap and an active bottom water, which made the primary production very unattractive. However, a judicious application of steam injection with horizontal producers made it a show case project.
This study examines the Tangleflags type of projects from the point of view of future applications (screening and design) of the SAGD process. A thermal simulator (STARS) was used, to achieve a history match of six-years' performance. Predictions for 15 years showed continued encouraging operations.
The second phase of the study involved examination of reservoir parameters and operating conditions that would lead to a successful project. For example, it was found that without using conditions of a steam trap, the steam-oil ratios would be high. Pools with oil viscosities higher than 35,000 mPa.s, and oil zone thicknesses less than 15 m were found to be unattractive. Vertical injectors (rather than horizontal), appeared to be more desirable, with an improvement in performance as the injectors are placed farther from the horizontal producer. Optimal well spacing in such a scheme, seemed to be dependent on the mobility of oil in the reservoir. Presence of an active aquifer below the formation results in severe water coning after a few years from the start of steam injection.
The results of this study are expected to be helpful in planning a Tangleflags type operation in heavy oil pools containing mobile oil, where vertical steam injectors are used around horizontal producers.
A Practical Method for Modeling Bit Performance Using Mud Logging Data
Authors: Xu Hong , Tochikawa Tetsuro , Hatakeyama Takashi 
Published: December 2007

Abstract
Using mud logging data, this paper presents a practical method for modeling ROP and bit life, and therefore modifying the value of Cost-Per-Unit-Depth (CPUD) calculated by using the conventional formula. For illustration, this paper shows how to identify the best bit type, the best IADC code and the best bit name/model number for a particular formation. The results appeared to be practically interprétable and physically valid. This method can be used to assist with bit selection, optimizing drilling parameters and diagnosing drilling problems.
Strength calculation on a semi-submersible drilling platform
Authors: van Holst M. 
Published: December 2007

1. Abstract
The paper describes the motions and overall strength analysis as used for the design of the semi-submersibie drilling platform Norrig, fig. 1, with an emphasis on the calculation of the loads on the structure in floating condition.
The motions are treated as a linear problem according to a method described by Hooft. Experiments and full scale measurements have shown that this method gives acceptable results. For the determination of the waveloads on the floating structure no attempt at linearization has been made. The most important non-linear feature is that the waveloads run the length of the actually submerged part of the construction.
The loads and internal forces are determined at certain points of time and cannot be expressed as amplitudes and phase angles. Consequently the step to a probabilistic approach of the strength problem cannot be made and the strength analysis has been performed using a design wave.
The construction of a system of forces in dynamic equilibrium at the points of time under consideration is a notable feature of the described method.
When the loads have been determined the strength analysis is performed using the frame analysis program STRESS.
The internal forces are transformed to stresses and checked using the AISC rules.
Taking Advantage of 3-Dimensional Visualization in Drilling Operations
Authors: Guerrero J. Victor 
Published: December 2007

Abstract
This paper illustrates the benefits of utilizing 3-dimensional visualization as a tool to integrate engineering analysis in drilling operations. Studies reveal that integrating new and existing technologies in advanced graphics with engineering analysis results in improved drilling operations which:–Increase well planning effectiveness and accuracy–Maximize reservoir exploitation and drainage–Significantly lower the risk of collisions, thereby reducing the overall exposure to economic and social catastrophes–Elevate the confidence level of drilling each well productively and safely
Some notable features to include in this integrated environment are:–Automated collision avoidance–3-D visualization with powerful viewing features–Graphically interactive 3-D well planning with modifiable and fixed constraints–Links to petrophysical, geological, survey and drilling data
Today there is not yet a system that combines the full 3-D description of reservoir shape and properties with modern directional drilling software. Case studies presented in this paper will demonstrate the need to commercialize and further develop such a system.
P. 759
A New Approach to Mechanized Tubular Handling and Running as a Safe and Cost Effective Alternative
Authors: Kinzel Holger , Lorenz Jörg 
Published: December 2007

Abstract
More than 30% of total rig time is spent on drillstring tripping and casing and tubing running operations. Tripping operations always have been the cause of heavy accidents. The easiest way to reduce the safety hazard is to reduce the number of people involved in unsafe operations. The number of people involved in manual operations on the rigfloor is directly related to the safety of the drilling rig's operation. The reduction of total personnel on board is significant for the costs. This requires the mechanization of processes now done manually.
Traditional automation concepts often required the complete re-design of rig components such as power tongs and handling equipment. Even derrick structures had to be modified to fulfill the requirements of a completely automated process. This made several of these technically interesting concepts very expensive and not many of them were actually put into operation.
A new approach to rig mechanization is based on existing technology. System components with proven designs such as hydraulic power tongs for drillpipe, tubing and casing running are modified for mechanical and remote controlled operations and are combined in a modular system.
This system includes a new technical solution to move the hydraulic power equipment towards the string and to pull it back into park position. The device is based on zipping chains guiding the equipment on a pre-defined line. It can be attached to any existing derrick structure in an elevated position not consuming any valuable rig space.
A New Environmentally Safe High-Temperature, Water-Base Drilling Fluid System
Authors: Thaemlitz Carl , Patel Arvind , Coffin George , Conn Lee 
Published: December 2007

Abstract
A new, environmentally safe water-based polymer system has been developed for drilling applications with temperatures up to 232°C (450°F) and high pressures. The system components are newly developed synthetic polymers that do not contain chromium or other environmentally harmful materials. These new synthetic polymers are designed to perform specific functions at high temperatures and the innovative designs of these thermally stable polymers allow for the use of a minimum number of products in the formulation of high-temperature fluids.
The new system consists of two basic polymeric components for rheology and filtration control at high temperatures. High-temperature fluid formulations are greatly simplified utilizing this new system, with only the two polymeric components being required, along with a pH control additive, weight material, and small amounts of clay for filter cake quality. This simplicity is a significant advantage over "traditional" high-temperature systems, which normally require use of a large number of additives to control or limit the effects of thermal degradation.
The new system may be formulated with fresh water or sea water, providing flexibility for a variety of drilling environments. Excellent resistance to common contaminants, such as calcium and magnesium hardness and solids accumulation, is another important characteristic of this new system.
This paper will review the previous state of the art with respect to high-temperature, water-based muds and will generically discuss the unique chemistry of the newly developed polymer system components. System formulation and application will be discussed.
Drilling Through Mature Production Zones
Authors: Kenney N. R , Kilchrist Joseph 
Published: December 2007

Abstract
This paper is a case history which describes the six wells of a drilling program fostered by 3-D seismic data. The challenge of this project was significant, and the early wells did not reach target depths due to stuck pipe in depleted zones. Importantly, success was realized on the final three wells through the creative application of existing technology. The ultimate success of this drilling program may be attributed to the application of real time dynamic filtration technology on the drilling fluids of the successful wells.
The Role of a Worldwide Drilling Organization and the Road to the Future
Authors: Boykin G. F. 
Published: December 2007

Abstract
After struggling for the past few years with the question "How can we get the highest return for our drilling expenditures?", major operators have arrived at very different answers. Some have responded by moving the drilling function to business units, some by retaining a mixture of centralized and decentralized drilling staffs, and some by outsourcing the function almost entirely.
The purpose of this paper is to describe why one major operator has chosen to keep drilling management as one of its core competencies, and how it continues to use a centralized drilling group to meet its exploration and production customers' needs. Also discussed is the deliberate strategy employed by this operator to meet the challenges posed by the changing exploration and development environment. This strategy included elements to manage people, business and technical processes, and to ensure that the drilling organization captured and shared its experience. This paper describes this strategy, the organization's successes and remaining challenges, and how this organization plans to address these challenges.
The Destruction of PDC Bits by Severe Slip-Stick Vibration
Authors: Fear M. J. , Abbassian F. , Parfitt S. H. L. , McClean A. 
Published: December 2007

Abstract
Surface mud logging systems have detected a severe form of torsional vibration that causes rapid destruction of polycrystalline diamond compact (PDC) drill bits. These failures can occur when combining a limber bottomhole assembly (BHA) with a PDC bit lacking some form of anti-whirl stabilisation. On the basis of experience to date, these vibration-induced failures occur only in larger hole sizes.
This paper describes the nature of these bit failures, their dependence on operating conditions, and practical recommendations for avoiding failure. Experience from one operation, in which revised drilling practices and bit selection criteria eradicated the failures, will be presented.