bluuebunny/crossref_metadata_2025_split huggingface dataset:
Lubricant SSP - The Proven Lubricant To Reduce High Downhole Torque
Authors: Tyldsley D. 
Published: December 2007

Introduction
Most offshore drilling operators have experienced unique physical drilling problems whilst operating in the coastal waters of the British Isles and North Sea areas. The magnitude and effect of each problem is often novel, requiring specific corrective action. Improved physical techniques and chemical treatment are physical techniques and chemical treatment are continually being sought to provide an interim or permanent solution. This paper traces the development and application of a drilling lubricant which has been extensively utilised to overcome the problems of downhole torque and drag encountered in drilling deviated wells. The lubricant, which is based on a vegetable oil derivative, is added to a water based drilling fluid system to provide a significant reduction in torque and friction without creating secondary well problems. A technique which presents several associated problems is drilling directional wells. Directional drilling has problems is drilling directional wells. Directional drilling has been universally applied, and holes with deviated sections greater than 70 degrees have been successfully, completed. This beneficial drilling technique has introduced several undesirable features requiring corrective action, i.e.:downhole torque:drag: . stuck-pipe:
Downhole torque is usually produced by a combination of the drill pipe rotating on the side of the hole. (either open or cased sections) the angle of deviation, the friction at the bit and the general requirement for extra stabilisers and 'dog- legging' of holes after correction runs. In deviated drilling all of these effects cause greater contact of drill stem to hole, and hence greater torque and increased probability of resultant stuck pipe. The standard solution for most of these problems is to incorporate diesel oil or lubricity additives into the drilling, fluid. Diesel oil often does not provide a satisfactory solution to these drilling problems.
Gas Lift Increases High Volume Production From Claymore Field
Authors: DeMoss E.E. , Tiemann W.D. 
Published: December 2007

Introduction
The present production operations on the Claymore A platform are the results of the cooperation of reservoir and platform are the results of the cooperation of reservoir and production personnel. Early in the development of production personnel. Early in the development of Claymore field, reservoir simulations were run to estimate the productivity indexes of the wells and to determine reserve productivity indexes of the wells and to determine reserve estimates. This work exposed the need for a pressure maintenance programme. So, during the first year. water injection into the reservoir was initiated. This was done early to eliminate (or substantially reduce) a big drop in the static reservoir pressure. Without water injection, a 20 per cent drop in static reservoir pressure was expected per cent drop in static reservoir pressure was expected during the first year, and with productivity indexes ranging from 5 to 36 bpd/psi, it was essential that an artificial lift system be selected and implemented into the completion plans as soon as possible. plans as soon as possible. Since the formation GOR of the Claymore was low, gas lift could substantially reduce the flowing bottom hole pressure and increase the Field's production rate. Even pressure and increase the Field's production rate. Even though the formation GOR was low, it was enough to supply fuel for the platform and circulated gas for lifting the wells. The gas for platform fuel needs is taken from the low pressure manifold. As make-up gas was needed for any reason, a gas line from the Piper Field was made available to furnish gas to the compressor suction gas header. At first the Piper was used only at special times. But the need for Piper gas increased each month and a daily requirement was established. In May 1978, the average daily use of Piper gas to the Claymore was about 4,200 mcf/d. The availability of Piper gas, therefore, played an important role in the selection of gas lift to played an important role in the selection of gas lift to produce the Claymore. produce the Claymore. A detailed study of the capability, of gas lift produced the conclusions and design conditions in Table 1. As seen on Table 1. 1,850 psi is the gas lift surface injection pressure at the well. Studied but not selected was 1,600 psi pressure at the well. Studied but not selected was 1,600 psi surface gas pressure.
The Biological Implications For The Filtration Of North Sea Injection Water
Authors: Finch Edward M. 
Published: December 2007

Abstract
As a result of core injectivity tests and alternative filtration trials carried out on Forties platforms it became apparent that certain components of the North Sea biomass have a direct bearing upon the ultimate quality of North Sea injection water. This view is substantiated by the continuous monitoring of the fine filters currently in use in the Forties Water Injection System. This paper discusses those species which according to test data and observations of the fine filters are considered most likely to influence water quality. Their seasonal frequency and lateral and vertical distribution in the North Sea are also commented upon. The conclusion is drawn that filtration of North Sea Water is necessary prior to well injection

Introduction
Sea Water injection of the Forties oilfield commenced in December 1976 and is currently going ahead at a rate of approximately 125,000 b/d for each of the four platforms. The details of the Forties water injection system have been published and will not be mentioned here in any detail. published and will not be mentioned here in any detail. Suffice to say that the sea water is won from a depth of 200 ft below sea level and is filtered before being pumped down to the aquifer at a well-head pressure of 1,200 psi. An initial coarse filtration of the water is obtained by a 80 um stainless steel screen. Fine filtration down to 5 um is achieved by backwashable. Plenty cartridge filters containing replaceable fibre elements which are positioned upstream of the main injection pumps. The decision to filter the sea water prior to injection was based upon information gained from numerous on-site tests which in turn were followed by filtration trials to ensure the selection of the most efficient fine filter element available for use in the Forties environment. The current paper which is a sequel to one published in 1978 is limited to a discussion of the organic content of the injection water and its relationship to the fine filters.
Determining Average Reservoir Pressure From A Pressure Buildup Test
Authors: Taylor Timothy D. , Caudle Ben H. 
Published: December 2007

Abstract
Results presented in this paper show that significant errors can be obtained by approximating an actual drainage area by a simple geometric shape when determining average reservoir pressure by methods presently available. This paper presents a method for determining true average reservoir pressure from a single well buildup test in a multi-well reservoir of any shape without prior knowledge of drainage area shapes. The method requires one computer run of modest cost to be used with the conventional pressure buildup test on the well.

Introduction
A knowledge of average reservoir pressure, p, is important in characterizing a petroleum reservoir. It is fundamental in computing oil in place or water influx from material balance, determining the pressure distribution for the detection of fluid movement and in predicting future reservoir performance in primary, secondary, and tertiary recovery projects. The purpose of this paper is to present a method for obtaining true average reservoir pressure from a single well pressure buildup test in a multiwell, multi-rate bounded petroleum reservoir producing under unsteady state conditions.
The most commonly used methods for obtaining average reservoir pressure from buildup tests require an estimation of the shape of the drainage area of the well being tested. This shape must then be approximated by one of several regular geometric figures for which solutions of the pressure function are available by the method of images1. Figure 1 shows the pressure function solutions (type curves) for various well locations within some regular drainage areas. A more complete set of these solutions for other regular shapes can be found in the Matthews, Brons, and Hazebroek1 paper and books by Matthews and Russell2 and Earlougher3.
Having selected the most closely resembling available shape, average reservoir pressure is then determined by entering the plot at the dimensionless time of the buildup test, as shown in equation (1), obtaining a value for dimensionless pressure, pD, and calculating p from equation (2).Equations 1 and 2
The pressure extrapolated to infinite shut-in time, p*, and the slope of the straight line portion of the buildup curve, m, are available from the customary plot of shut-in well pressure versus log.

Discussion
Recent developments4 permit bounding of the continuous line source solutions for unsteady state flow in any drainage shape. A computer model has been formulated which can describe the pressure behavior in any shape reservoir containing any number of wells. The model can check the Matthews, Brons, and Hazebroek1 type curves for regular shapes and extend their findings to drainage shapes not capable of being created by image wells.
Forty Years of Steam Injection in California – The Evolution of Heat Management
Authors: Hanzlik E. J. , Mims D. S. 
Published: December 2007

Abstract
Steam injection EOR began in California forty years ago, and has been highly successful. As a consequence, California's thermal recovery operations represent a leading source of EOR production in the world.
The understanding of most early thermal recovery operators was limited to the concept of "heat reduces heavy oil viscosity, and reduced viscosity means more production." Steam injection was attempted in almost any reservoir having viscous oil with little appreciation of other recovery process considerations. Although several early pilot projects were steamfloods, most early applications were cyclic stimulation. During the late 1970's, steamflooding became predominant, and many people considered steamflooding to be a displacement process (hence the term "steam drive’). With this paradigm and high oil prices, there was little impetus to understand efficient use of heat. The predominant philosophy was "If you want more oil, inject more steam." With the later collapse of oil prices, operators returned to review process fundamentals and to determine how to more efficiently operate steam projects. This paper discusses the shift to an override, or gravity drainage, model concept. This helped lead to reduced steam injection and improved thermal efficiency through the use of heat management. This paper discusses the shift to the concept of steam override and gravity drainage as steamflood recovery mechanisms and the subsequent use of heat management practices that improved thermal recovery efficiency.
Effects of the Application of Drill Cuttings and Recovered Oily Sands on Caribbean Pines, Anzoátegui State, Northeastern Venezuela
Authors: Gómez María A. , Sucre Francisco J. , Villarroel Teresa , Robb Albert J. 
Published: December 2007

Abstract
As a part of an overall waste reduction initiative, beneficial reuse of materials otherwise considered oilfield waste were evaluated as an environmentally responsible and business practical method of handling theses materials. Heavy oil production by the Cerro Negro Project, within the Orinoco River region of the Anzoátegui State of northeastern Venezuela, is surrounded by Caribbean pine plantations. During 1999 and 2000, decanted drill cuttings and recovered oily sands were mixed with virgin soil (mostly sandy loams) and an agglutinate in order to produce an asphalt mixture for use as a substrate stabilizer and road base. The mixture was prepared to comply with Venezuela Ministry of Environment requirements before being spread as a road base on internal roads within the pine plantations as a stabilizer.
Studies were conducted to evaluate numerous quantitative and qualitative parameters potentially associated with impact to pine trees and the surroundings environment. These possible effects were evaluated from the following key assessment sectors: Caribe pine plantation areas near the initial mixing sites (borrow pits),Plantation areas adjacent to roadways or firebreaks where the mixture was applied, andPlantation areas where the mixture is used directly as a substratum.
The results of this study, designed to evaluate the effects of the application of the mixture of drill cuttings and recovered oily sands on the forestation species and their surrounding environment, document that the application of this mixture represents a cost-effective waste reduction option with natural resources re-use and erosion stabilization benefits. Results potentially demonstrating enhanced growth and productivity of surrounding pine plantations further document a "win-win" solution between the Cerro Negro Project operator and the plantation owners for the handling of these materials that would otherwise be considered a waste.
Collaboration in Deep-sea Biodiversity - Expanding the value from Deepwater E&P Operations
Authors: Hudson Ian R , Putt Russell , Wigham Benjamin D. , Young Sean 
Published: December 2007

Abstract
Oil and Gas Exploration relies heavily upon the use of Remotely Operated Vehicles and data collection in many deep-water production areas. Through collaboration projects between scientific instiutions and production companies it has been possible to gain great ecological value from existing data and new data routinely collected as part of normal offshore exploration activities.
The Issue Of Access: Confronting Community Expectations
Authors: Shrimpton Mark 
Published: December 2007

Abstract
Oil companies seeking to access new regions are often confronted by communities and governments that know little about the petroleum industry, its activities and their impacts. Their expectations are commonly based on stereotypes that are problematic, not least because various factors lead to an emphasis on negative impacts, rather than a balanced picture of potential costs and benefits. From a petroleum industry perspective, this can increase the costs of having exploration and development programs approved and implemented, and it may result in arduous conditions and even moratoria on activity. From the perspective of local communities, employment, business and other benefits may be delayed or foregone. These misconceptions are best countered through collaborative processes that educate about the industry, its activities, their effects, and how they can be managed. While these processes should use information about the impacts of upstream petroleum activity in other regions, such comparative study must be undertaken with care if it is to address, rather than reinforce, negative expectations.
First ISO 14001 Environmental Certification of a Danish Offshore Installation
Authors: Valeur Jens Rosendal , Hollen Ivar Helge , Clowers Michael 
Published: December 2007

Abstract
In October 2002, the Amerada Hess operated oil and gas producing installation, South Arne, had its Environmental Management System (EMS) certified according to the ISO 14001 requirements. The paper describes how the requirements were implemented in the existing management system, making the installation the first in the Danish sector to obtain certification.
Internal resources were used in order to ensure an in-depth implementation. The South Arne asset manager sponsored the certification initiative and had overall responsibility for the EMS. Training was carried out by internal HSEQ staff.
Environmental aspects were identified, evaluated and ranked with respect to their impact were done depending on the extent of the impact. Aspects with global or regional impact (mainly emissions to air) were compared with the overall emissions from the Danish society. Aspects with local impacts (mainly discharges to sea) were evaluated based on chemical risk assessment. Flaring and discharge of produced water have been identified as two of the major aspects, and environmental improvement plans covering these are ongoing.
Flaring during the last two years caused about 20% of the total CO2 emissions from South Arne. A new gas recovery system is planned to be installed in 2004 as a main environmental improvement regarding emissions to air. This "zero flare" system can recover essentially all of the gas that previously had to be flared resulting in significant reduction in flaring and its associated air emissions.
As the life of the field matures, the production of water will increase. With no improvement plan this would result in significant increases in produced water, with its oil and chemical content, being discharged to the sea. Re-injection of the produced water into the reservoir was successfully tested in 2003, and full-scale re-injection is planned to take place starting in 2005.
Examining the Role of Occupational Health Management in the Safety and Well-being of the Offshore Worker
Authors: Hope Lorraine , Mearns Kathryn 
Published: December 2007

Abstract
Previous research in the offshore environment indicates a positive relationship between good health management practices and safety performance (Mearns, Whitaker & Flin1). The current research seeks to examine the nature of this relationship and explore whether investment in occupational health, can lead to improvements in organizational climate and, in particular improvements, in safety climate and safety behaviour. The research was conducted by means of a questionnaire survey incorporating 31 offshore oil and gas installations on the UK Continental Shelf. To investigate the hypothesis that investment in health builds worker loyalty in areas such as safety behaviour, 1,928 offshore employees were surveyed using measures of health and safety climate, employers' commitment to health, colleague social support, safety behaviour and employees' commitment to the organization. Additional data was collected in relation to health surveillance and use of PPE for occupational hazards such as chemical and vibration exposure. Respondents were also required to indicate personal health behaviour in terms of diet, exercise and smoking activity. In addition to data on the frequency of sickbay visits for injuries and medical purposes, installation medics provided details of additional health checks offered and health promotion activities. Details of occupational health training undertaken (and offered) to both medics and the workforce in areas such as stress, manual handling, skin problems and HAVs were also collated. Preliminary results indicate that investment in occupational health offshore fosters greater organizational commitment, more positive health and safety climates, improved safety behaviour and more positive perceptions of employers' commitment to the workforce.
Controls on Vertical and Horizontal Flow in a Carbonate Reservoir that Impact Gasflooding and Waterflooding
Authors: Thawer Roxy , Alhendi A. , Al Mazroui Y. , Boyd Doug , Masuzawa T. , Sugawara Y. , Hollis C. , Lowden B. 
Published: December 2007

Abstract
Identifying the location and quantification of flow units is critical to managing a reservoir's production and achieving maximum recovery. Gas injection is planned in a limestone reservoir offshore Abu Dhabi. To understand the benefits of future full field gas flooding, a pilot covering three reservoir units is underway. Ten wells were drilled and significant log/core data acquired. Interference tests within a reservoir unit in single wells and between-wells have revealed useful insights into the vertical and lateral continuity of barriers and conduits to flow. Recovery efficiency is driven by these contrasts in the reservoir sublayers.
Significant variations in permeability occur over short vertical distances due to local facies and diagenetic changes, including dissolution events, distorting associations between porosity and permeability. Porosity cannot predict permeability to better than 1.5 decade on a logarithmic scale in this reservoir. Experimenting with NMR, Stoneley wave responses on one well, we were able to improve our predictive capabilities by combining the strengths of each tool. Predicted values fell mostly within half a log cycle of the whole core measurements. Vertical interference testing with a multi-probe Modular Dynamic Formation Tester (MDT*) used in a totally new way and using single well numerical models, proved useful in defining vertical barriers to flow. Cross-well interference testing proved that some of these barriers are discontinuous and act as baffles. Mobilities obtained from the MDTs, mimicked permeability contrasts measured in core. These contrasts confirmed the rapid response time seen in the cross-well interference tests. A full field simulation model with local grid refinement was able to match the cross-well interference test data.
The integration of core description, whole core/plug physical properties, downhole electrical images, NMR, conventional logs, mobility, down-hole vertical as well as cross-well interference tests is presented and their impact discussed.
Large-Scale Produced Water Re-Injection Under Fracturing Conditions in Oman
Authors: van den Hoek P. J. , Sommerauer G. , Nnabuihe L. , Munro D. 
Published: December 2007

Abstract
This paper describes the concept, initial field case studies, and observations to date on Deep Water Disposal (DWD) in one of Petroleum Development Oman's (PDO) larger mature oil assets. The concept of DWD by fractured injection on a large scale has been quite successful. Current concerns relate to the size of injected fractures, and pressure build-up within the disposal zone.
Initial simulation studies were carried out with dedicated in-house produced water re-injection software to asses the size and containment of the induced hydraulic fractures as a function of relevant injection parameters such as water quality, injection rate, injection volume and injection depth. This was essential as fractures are not allowed to break through the cap rock shale layer of the disposal zone into the overlying sand body which has communication with shallow potable aquifers. Based on stress data (minifracs, logs) and simulations it was concluded that fracture containment within the disposal zone was only guaranteed if fractures were initiated of the order two hundred metres below the cap rock.
Simulations of produced water injection were carried out also to assess well injectivity in the long-term, and to estimate the required injection pressures for the injection pumps. The simulations indicated that no injectivity decline long-term would be expected to take place. Field observations to date are in line with these simulations. Currently, each DWD well is injecting ca. 15,000-20,000 m3/d of unfiltered produced water with wellhead pressures of approx. 140 bar.
Fracture monitoring programmes are currently being carried out. Hydraulic Impedance Testing (HIT) was applied to measure fracture dimensions. It was found to be restricted to small fracture sizes due to the insensitivity of the reflected wave amplitude in the applied frequency range. Improved methods to measure fracture size such as tiltmeter surveys and downhole geophones are currently under investigation.
Pressure monitoring within the disposal zone via observation wells has shown little pressure increase to date. Characterisation of this pressure response is a key reservoir driver in deciding how much water could be disposed at each of the disposal sites.