bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Reservoir Management Model for 26R Reservoir, Elk Hills Oil Field, California
Authors: Echols D.P. , Ezakwe Nnaemeka 
Published: December 2007

Abstract
The 26R Reservoir is a massive sandstone Stevens reservoir in Elk Hills Oilfield. Crestal gas injection was initiated in the reservoir for pressure maintenance immediately after open-up in 1976. Since 1988 the reservoir has been developed extensively with horizontal wells. To date, there are twenty-two horizontal wells completed in the reservoir which accounts for more than 70% of total oil production. A reservoir flow model, referred to as the 26R Reservoir Management Model, was developed with the aid of geostatistics to evaluate alternative management strategies such as full or partial pressure maintenance, termination of gas injection, or drilling more horizontal wells. Prediction results indicate that full pressure maintenance will recover more oil but severely reduce the volume of gas available for sales. They also show that more horizontal wells could be drilled especially in the western half of the reservoir.
Disposal of Crude Contaminated Soil Through Slurry Fracture Injection at the West Coyote Field in California
Authors: Sipple-Srinivasan M.M. , Bruno M.S. , Hejl K.A. , Danyluk P.G. , Olmstead S.E. 
Published: December 2007

Abstract
The first permitted operation in California for disposal by deep injection of crude contaminated surface soils was completed this summer at the West Coyote Field in La Habra, California. Approximately 14,000 barrels of waste material was disposed of from this abandoned oilfield site. The material included crude contaminated surface soil derived primarily from production well cellars, and dried and liquid drilling muds. Waste streams included screened and unscreened soil. The solid waste material was loaded into a hopper and conveyance system, then transferred to a shaker unit. Some liquid wastes were also processed through tubing connected directly from vacuum trucks into the shaker unit. Approximately 50,000 bbls of a slurry mixture of waste material plus fresh water was injected over a three week period into a high porosity (30%), high permeability (500 md) depleted oil sand at a depth of approximately 4100 ft. Average daily injection volumes were on the order of 4,300 bbls/day of slurry, with solids concentration in the slurry as high as 35% by volume.
The permitting phase of this pilot project extended over 18 months and required modification of State regulatory guidelines to accommodate injection of solid materials above parting pressure of the target formation, as well as disposal of surface soils not previously included in the classification of Class II fluids. After demonstration of an acceptable monitoring and analysis strategy designed to ensure containment of the waste material within the target formation, the California Division of Oil and Gas and Geothermal Resources (DOGGR) approved the permit application in early 1997. Final approval from the Regional Water Quality Control Board followed. Close cooperation between DOGGR, the operating company, and the injection service company paved the way for the success of this disposal operation in an environmentally sound and permanent manner with minimal impact to surface land use, and reduced long-term liability to the operator.
Combustion Front and Burned Zone Growth in Successful California ISC Projects
Authors: Garthoffner Egon H. 
Published: December 2007

Abstract
This paper examines the concepts of combustion front, shape, orientation and propagation. It supports the concept of a horizontal combustion surface and a burned zone that has the shape and position similar to that of a conventional gas cap.
Clear direct as well as indirect evidence is presented in support of the claim that combustion surfaces develop and propagate horizontally. The direct evidence comes from the results of coring through the burned interval and from temperature profiles at observation wells and replacement wells. Indirect evidence comes from the analysis of produced gas and gas production rates. We also propose that convection currents play an important role in the growth of horizontal combustion surfaces and their propagation down through the reservoir sands.
The development of horizontal combustion surfaces as a result of air injection is a natural occurrence just as the development of a gas cap is to natural gas injection. In all, it is a highly beneficial activity. It improves volumetric sweep efficiency and allows even irregular well spacing and irregular patterns to be exploited. It also makes it possible to apply ISC to small oil pools that are not suitable for pattern development and to thin reservoirs.
Environmentally Sensitive Flares: No Smoke, Odor or Noise; and No Visible Flame
Authors: Straitz John F. 
Published: December 2007

Abstract
Onshore and offshore, flares are essential safety systems for energy exploration, production, transportation and storage, including ship-board flares on floating production, storage and off-loading (FPSO) vessels. Despite extremely wide variations in the flow of volatile, carcinogenic waste gases or other dangerous offgases, and regardless of the worst weather conditions, including hurricane or typhoon-force winds up to 400 km/hr (250 mph), flares must work right, each and every time, or the consequences can be catastrophic.
The two most important considerations in flaring waste gases or offgases must always be safety and reliability. Protection of the regional and global environment by dependable and complete in-cineration of waste streams is another very important requirement. Burners of various configurations are the heart of all flare systems. Instrumentation and control systems are the nervous system and the brains.
Low-profile enclosed flares and in-ground earthen enclosed flares offer many advantages in comparison to elevated (open-burner) flares. With state-of-art enclosed flares, sometimes called "thermal oxidizer flares", energy recovery from flared streams of gases, as well as liquids and slurries, is possible.
Investigation and Remediation of Hydrocarbon Contamination above Permafrost
Authors: Ratliff M. D. 
Published: December 2007

Abstract
The paper discusses a recent remediation project at an oilfield service facility in Deadhorse, Alaska, approximately 300 miles north of the Arctic Circle. The construction of the gravel pad on top of the tundra and the unique environment of performing remediation above permafrost presented significant challenges. This paper will define the problems caused by the northern location ofthe site and the unique movement ofhydrocarbons on the permafrost, and explain how those problems were overcome. The issue of hydrocarbon contamination and its possible remediation is paramount to the continued exploration and production in sensitive arctic regions, such as current operations in northern Russia. Other examples of such regions, which are usually pristine environments, are the Arctic National Wildlife Refuge and the Northwest Territories of Canada.
How clean is clean - Recommended Framework for Rendering an Offshore Installation Clean
Authors: Aabel J. P. , Tibble S. , Helland B. 
Published: December 2007

Abstract
There is a growing concern regarding the fate of oil and gas facilities for which abandonment is programmed as a result of declining production. Different abandonment options have been proposed for consideration in recent years, varying from total removal of all elements of the installations to toppling in place or abandonment in-situ. Any abandonment option that involves abandonment in-situ or temporary or permanent placement of one or several elements of an installation on the seabed could be seen as a potential source of pollution. The probability of pollution depends on the type of installation, procedures for cleaning the platform and the nature and sensitivity of the receiving environment.
This paper presents the objectives and recommended practice for the preparatory works required to render a cold state multi-function steel jacket installation clean. The basis for this framework procedure was an assessment of the technical limitations and relevant legislative requirements and constraints and the findings of a preliminary qualitative risk assessment of the potential environmental implications of the entry into the North Sea offshore marine environment of the residual materials inventory.
An Appendix summarizes the recommended framework procedure developed that was based in part of the following recommendations proposed from the findings of the preliminary risk assessment:
all components containing PCBs should be removed; all components containing halons/freons should be removed; persistent synthetic substances should be removed where practical; production chemicals should be taken onshore for disposal; topside tanks and pipework should be cleaned as far as practical to removed residual sediments containing heavy metals and hydrocarbons; and components/equipment containing radionuclides should be removed.
Environmental Evaluation Systems for Well Drilling and Completion Chemicals -The Present Situation and Future Views
Authors: Berg Erik , Romijn Henk , Wolting Bert 
Published: December 2007

Abstract
This paper describes how chemical hazard and risk assessment systems are being used in North Sea countries. Despite efforts to establish a harmonised chemical hazard and risk system, many countries have developed their own systems. For this reason, three major service companies have been working together to evaluate the CHARM III model (Chemical Hazard Assessment and Risk Management)1,2 and the accepted chemical hazard and risk assessment systems.
Initially implemented by the Oslo Paris Commission (OSPAR), the European regulatory body for offshore environmental issues, CHARM III was a significant step towards developing a simple model that generated consistent hazard/risk evaluation results. During the harmonisation process, the North Sea countries also made attempts to develop a harmonised mandatory control system.3 Currently, four North Sea countries still rely on their own chemical evaluation systems.
The three service companies have used the CHARM III model to perform chemical hazard evaluations on a representative range of cementing, completion, workover and spacer chemicals. The same chemicals were also evaluated with the different pre-screen systems used by the North Sea countries (Tables 1 and 2).
Crude Oil Recovery in Oiler Residual Pits in Boscan Field
Authors: Zabala A. , de Jongh A. , Padron A. 
Published: December 2007

Abstract
The oil industry activities generate a great amount of wastes resulting from oil spills, tanks cleaning and maintenance, drilling, etc., which are dispossed in pits, creating a negative environmental impact. The recoverable crude oil from these pits is estimated to be about 2 MMBBLS. This makes its recoverable economically attractive.
The recovery process is based on fundamental operations like Dilution, Formulation of oil/water Dispersions using Sodium Silicate as natural surfactant active agent present in the oil and Static Dehydration by Heating and Chemical Demulsification Treatment.
In this work, the different phases of the study, beginning from the results obtained on laboratory scale and subsequently industrial application on a pit in the Boscan Field are presented. The oil recovered in this way was later reincorporated into the production line.
Contrasting HSE Approaches by an Oil Company to Concurrent Seismic Operations in a New Country
Authors: Thonger Rod C 
Published: December 2007

Abstract
This paper describes the contrasting approaches taken by Enterprise Oil in their two new Greek licenses during 1997. Seismic operations were set up for the northern, mountainous, heli-supported dynamite project with a major international contractor. The southern prospect involved vibroseis in mostly flat countryside with the purely domestic geophysical division of the state oil company.
Co-operation between client and contractor was given the highest priority, and expert assistance provided where needed. This included safety management training and the provision of helicopter and mountaineering experience in addition to the normal schedule of training. The inclusion of sub-contractors was a key necessity.
The objective was to ensure that both contractors were as ready as reasonably practicable to start work before going to the field and in the early stages of production. A major problem in starting seismic crews has frequently been the short lead time between award of the work and the start of operations. HSE matters are often left behind in the rush to the field so the paper offers a solution to this problem which should satisfy both the client and the contractor.
This paper will show how each crew was approached from the Client point of view on HSE matters, give field results, give a comparison of additional HSE investment up front and actual production against budgeted production under usual start-up methods. A key point will be to show that by getting the management and the work procedures right at the beginning in order to control the HSE aspects, there were time and financial gains made over the whole project.
HSE Management of Geophysical Operations: The Client's Role
Authors: Dolezal Alan L. 
Published: December 2007

Abstract
Over the last ten years, most exploration and production companies have discontinued the use of company seismic crews, and now these companies depend on contractors to acquire their geophysical data. The increased use of contractors has resulted in a shift of the majority of the effort to manage risk of incidents from the company to the contractor. However, there are significant benefits for companies, clients, to work with their contractors in preparing a sound Health, Safety and Environmental (HSE) plan for each geophysical project.
This paper describes Exxon Exploration Company's approach for working with contractors to lower the risk of HSE incidents during the acquisition of geophysical data. Exxon uses a structured process that consists of written guidelines and checklists to ensure that key elements of the contractor's HSE plan are in place before the project begins and functioning during the project. The key action items or activities required by the structured process are described for the four main project phases: Pre-Bid, Pre-Survey, Survey and Post-Survey.
Highly Inhibitive, Low-Salinity Glycol Water-Base Drilling Fluid for Shale Drilling In Environmentally Sensitive Locations
Authors: Brady M. E. , Craster B. , Getliff J. M. , Reid P. I. 
Published: December 2007

Abstract
Water-base drilling fluids containing glycol additives have become established for cost-effective drilling of many reactive shale formations. Existing fluids function most effectively when the glycol is used in conjunction with moderate to high levels of salt; potassium chloride is most commonly used, although this can sometimes be replaced by sodium or calcium chloride or by more expensive acetate or formate salts.
In many onshore locations, discharge of saline drilling wastes poses environmental problems because of contamination of groundwater and soil which may make the water unsuitable for drinking or irrigation and agriculture. In these situations, either expensive pollution control measures or low-salinity drilling fluids are required. Unfortunately, the glycols in common use for shale control do not function well in salt-free or low-salt fluids, so their benefits cannot be fully exploited in these environmentally sensitive areas.
This paper discusses the technical performance and environmental benefits of a new class of glycol inhibitors, specifically designed to provide high levels of shale inhibition in freshwater and low-salinity water-base drilling fluids. Waste disposal implications are considered and inhibitive properties are compared with other currently available fluids.
Aquila Oil Field: Safety and Reliability in the Development of Deepwater Field
Authors: Rizzi W. , Priotti W. 
Published: December 2007

Abstract
The development of marginal fields in deepwater and hostile environmental conditions represents a technological challenge which to be winning, must conciliate competitive with safety and environmental protection. For this reason, since the beginning of Aquila Project, Safety Dept. was called to join the Project Task Force internally established, to sum up resources with experiences in the main technological areas. These specialists have not been permanently part of the Task Force but they were the reference individuals throughout the project life. From this point of view, Aquila oil field could be considered as a model: since from the early engineering phase, safety analysis, as HAZID and HAZOP and other studies have been done and the results were implemented into the detailed engineering. The risk assessment considered the overall development system as well as the certification; from downhole completion up to the offloading operation, equipment, operations and procedures have been considered.
This paper highlights the most significant studies and recommendations issued in the HAZOP works with the aim to increase the safety conditions during installation and production phase.
In particular the following were considered:
Dropped Object Study: to establish the probability of damage to the subsea equipment resulting from objects potentially dropped from surface; Use of well fuel gas (sour) in the engine room: to minimise the potential presence of sour gas in the vicinity of the Living Quarter especially in case of leakage from pipes carrying gas to Boiler, or in case of any gas emergency; Probabilistic analysis of incidental sequences concerning the leakage of production pipes in the turret area.
Safety FPSO Consideration for Girassol Deepwater Development Project
Authors: Tonda Henri 
Published: December 2007

Abstract
For deep water field developments as Girassol in Angola, a Floating Production System and Offloading (FPSO) unit provides a good economical and production facility. However is such FPSO as safe as a standard fixed unit ?.
Due to its concept, a FPSO has three main functions: oil processing, floating storage and offshore terminal. By consequence, the FPSO main hazards are, at least, the hazards related to these functions when they are implemented onto different supports. In addition, the concentration of these hazards onto the same support leads to increase the risk on both the frequency and the consequence sides, due to the possible functions’ interactions.
The paper presents the risk assessment performed at the Girassol pre-project phase. Due to the little field experiences of FPSO's, the study was mainly based on the adaptation of historical data relating to fixed offshore platforms, trading tankers and ports.
It appears that the risk to loose a FPSO based on a standard tanker without any dedicated design precautions is roughly estimated to be 28 times higher than the risk of total loss of a North sea platform.
The study was formally integrated into the conceptual activities of FPSO. The practical issues relating to the concept selection is presented as well as the assessment of the possible risk reducing
Operational Lessons from the UKCS Hydrocarbon Leaks Database
Authors: Bonn Robert J.C. 
Published: December 2007

Abstract
Since 1992, Operators in the UK sector of the North Sea have been reporting all hydro-carbon leaks to the Health and Safety Executive (HSE). The resulting data-base is the most detailed of its kind in the World. The HSE and the Operators Association (UKOOA) are to produce analyses of the data for use in Quantified Risk Assessments and for bench-marking safety performance.
There are other lessons which this valuable data can teach us. This paper will identify areas where improvements to design and operational practices can have a significant benefit, not just in terms of the number of releases, but also in terms of risk.
This paper will focus on the causes of high risk incidents, with the causes grouped into categories of: Design, Equipment, Operations and Procedural failures. The analysis has revealed lessons which can be used to make significant reductions in the frequency of releases for new and existing sites. This in turn will, improve safety performance and reduce environmental impact of E&P operations around the World.
The Adoption of Technical Safety Assessment Tools in Oil and Gas Development Projects
Authors: Wright G. J. , Newton M. A. 
Published: December 2007

Abstract
BHP Petroleum operates 3 Floating Production and Storage Offloading Units (FPSOs) and two onshore plants in Australia, offshore facilities in Western Europe with a number of global projects in various stages of development that will take the company into the year 2000 and beyond. In 1995, the company embarked on a safety improvement programme, to integrate technical safety assessment within the operating and design processes. This demanded the development of comprehensive and detailed safety study plans for all new projects, and the preparation of safety cases for our existing facilities. The plans set out the technical safety related work required during the course of a project's life time, and are primarily used to programme the development of safety cases. The objective of this strategy is to ensure that the safety study work keeps pace with, and has an effective input to the design, and ultimately, that the operating safety risk levels are as low as is reasonably practicable, that is ALARP. This paper includes a description of the development of offshore safety cases and their application, for example, to the effective targeting of competency based training efforts, and risk based strategies for maintenance, inspection, and testing programmes for operating facilities. The adoption and use of standardised QRA rule sets and assumptions is also discussed together with the processes used to determine the tolerability of a facility's risk levels. And finally the use of benchmarking, audits, and reviews for sustained improvement in safety performance is examined.
New Strategy of Controlling Risks in Development of Oil & Gas Fields with Hydrogen Sulfide
Authors: Koutsyn P. V. , Gendel G. L. 
Published: December 2007

Abstract
As a result of analysis of long standing experimental investigations, objective laws were discovered and mathematic models of technogenic risks were formed. The author investigated the risks associated with possible emergency releases of H2S-containing vapours of gases when developing oil & gas fields.
Criteria were substantiated and evaluation methods were created for the level of dangerous H2S intoxication with due regard for the time of its impact to a person and dynamics of air contamination level in conditions of real emergency situations. Efficiency of already known and new proposed measures was evaluated theoretically and experimentally. Such measures envisage "passive" protection of people and environment as well as active influence to an emergency release of gas.
New strategy of technogenic risk control was proposed. It is applicable to typical targets of oil & gas industry. It is based on rational organizational measures, computer programs and other technical means, technologies and devices for operative prevention, protection and liquidation of emergency.
Unlike earlier applied emergency programs, new technologies of active impact to the source of emergency gas release and to the spreading clowd of toxic gas-air mixture were recommended for practical usage as the most efficient and rational ones. Results of practical tests of proposed methods at the largest oil & gas producing complexes in Russia have been considered in this paper. The achieved efficiency allows to recommend the proposed methods for practical usage at chemically dangerous targets of various industries in order to provide safety of people and to protect environment against emergency contamination of air.