bluuebunny/crossref_metadata_2025 huggingface dataset:
Communication for Public Consultation
Authors: Khan Omayma , Khan Basit , Dennis Paul
Published: December 2007

In 1997, the Ministry of Petroleum and Natural Resources (MOPNR) of Pakistan awarded the exploration license for Dumbar concession to Premier Exploration Pakistan Limited. What makes this concession of particular interest is that the block encompasses the area of the Kirthar National Park (KNP), the Mahal Kohistan Wildlife Sanctuary and the Eri-Sumbak Game Reserves – areas that are protected because of the biodiversity value they house.

As a result of this, the Kirthar National Park became the subject of some controversy between national and international non-governmental organizations (NGOs) and the Exploration Company attempting to gain access to the Park to begin exploration. Despite commitments from the company to use industry best practises and advanced technologies for the protection of the environment and the species within it, NGOs remained adamant that the company's exploration license should be revoked and the opportunity to tap potentially large gas reserves rescinded.

Rather than ignore the protests of the NGOs, the company decided to engage with these very organisations in order to demonstrate to them that the company could manage its operations in an environmentally sensitive manner, and would in fact, contribute to the net betterment of the very area the NGOs were seeking to protect.

As part of the environmental impact assessment (EIA) process; the company developed a public consultation and disclosure plan based on the assesment of key stakeholders and their influence on the project. Communication tools and other inter-active options were used to convey details of the company's activities and its approach to environmental management and community welfare. Devising a communications strategy is perhaps a novel approach for the oil and gas sector to take, but it's one that contributed to the company's subsequent approval for seismic operations in the KNP. One that came after four years of sustained effort during which it became evident that opinion of some of the stakeholders changed significantly as a result of the strategy.
Medical Surveillance of Food Handlers
Authors: Balge Marci Z. , Krieger Gary R.
Published: December 2007

Food handlers potentially represent a specific source of disease transmission in a remote exploration and production environment. Since a food borne epidemic can produce significant morbidity and lost time, it is critical to consider the various sources of disease in the food procurement and delivery system. Food handlers, especially in remote locations that inherently have a substantial underlying disease burden, require special medical attention. A number of strategies exist for implementing medical surveillance programs for food handlers. This paper will include medical exam content and frequency, immunizations, laboratory testing, presumptive disease treatment for parasitic infections, and return to work practices.
Conducting Public Health Risk Assessment in a Remote Drilling Site in Indonesia: An Experience
Authors: Zainuddin Zainal Mubarik , Samad Abu Hasan , Hasyim Irwan B. , Basuni Hanapi , Zampello Frank C.
Published: December 2007

As the Company continues to explore new business opportunities in remote, less developed frontier regions of the world; the challenge of maintaining high safety and health standards is increased. The risks of illness and injury in such operations are not only from the traditional occupational health factors such as chemical and physical hazards but also from the local environmental health factors and endemic diseases. Examples of such diseases are adverse reactions to the different or extreme climate, vegetation, insect and other vectors; diseases transmitted by insects and other vectors (e.g. typhoid, cholera, malaria, Japanese B encephalitis, dengue fever); local public health and hygiene practices (e.g. gastrointestinal diseases related to food and water contamination, sexually transmitted disease). The health risks may further increase due to limited medical resources and facilities, and remoteness of the site for timely delivery of routine and emergency care to the workforce. As these new business opportunities are pursued, maintaining safe operations and healthy workforce remains to be highest priority. Hence, like all other aspects of business, health and safety should be addressed systematically and consistently.

A standard process of conducting public health and medical resource assessments was developed by the Company to professionally and systematically evaluate health risks and level of medical support using Public Health Risk Matrix, Infectious Diseases Matrix, evaluation forms, etc. The results of the assessments are used as the basis for developing risk-based, operation-specific public health risk controls and level of health care support for both routine and emergency.

The paper intends to share our experience in conducting the public health and medical resource assessments using the standard process in a remote drilling site in Cepu, East Java in Indonesia. The results of the assessment, the recommendations, issues and challenges from the exercise will be discussed.
Mass Balance of Production Chemicals
Authors: Aas N. , Knudsen B. , Sæten J. O. , Nordstad E.
Published: December 2007

Estimates of the amount of discharged production chemicals are most often calculated using octanol/water partition coefficients. This is due to the lack of any better methods to predict how much of the chemicals is water soluble and would thus follow with the produced water to sea. Here a laboratory method for determining the partitioning of some typical production chemicals between oil and water is reported. The experimental parameters that influence the partitioning have been examined and partition coefficients for a range of chemicals have thus been established. The validity of this laboratory method has been verified in a field trial in the North Sea. By combining the partition coefficients with production data and putting these into a spreadsheet the so-called ‘Mass Balance Simulator’ is obtained. With this it is possible to predict how much of a chemical is discharged to sea and how much is retained in the crude oil leaving the platform.
Environmentally Acceptable Cement Fluid Loss Additive
Authors: Dao Bach , Vijn Pieter
Published: December 2007

The need for environmentally acceptable cement additives has encouraged the development of new additives based on biopolymers, especially in the North Sea area where environmental regulations are very strict. The main challenge is to develop environmentally acceptable chemicals that meet the relevant environmental legislation and operational criteria, and thus could replace synthetic materials that are currently being used. This paper will describe the development of a cement fluid loss additive that meets the challenges described above.

Cellulose-type materials have been used for decades as additives to control cement fluid loss. These are PLONOR (pose little or no risk) listed materials, which means they do not have to be subjected to testing protocols. They were agreed upon by all OSPARCOM (Oslo-Paris Commission) countries, and thus, required no further extensive ecotoxicity testing before introduction. However, cellulose-type materials that have been used so far have several limitations: their fluid loss control properties decrease at temperatures above 200°F, their salt tolerance is limited and over-retardation problems can occur at low temperature. Furthermore, the slurry viscosity to fluid loss ratio is unfavorable compared to that of currently available synthetic fluid loss additives. When these cellulose type materials are combined with other additives to help improve their performance, the environmental advantages are compromised, and the resulting substance can no longer be listed as PLONOR.

This paper describes the development of a modified cellulose (HEC) type of cement fluid loss product. It is salt tolerant, it can perform well up to temperatures as high as 280°F and is environmentally acceptable. After extensive laboratory testing, the production has been scaled up for introduction and a successful field trial has been performed in the North Sea area.
CO2 Sequestration in Depleted Oil or Gas Reservoirs
Authors: Le Gallo Yann , Couillens Philippe , Manai Taoufik
Published: December 2007

The reduction of Greenhouse Gases emission is a growing concern of many industries. Following the mitigation solutions recommended by the Kyoto Protocol, underground sequestration of CO2 is a way to meet this goal, as oil and gas fields offer huge CO2 storage capacities, while preserving the environment.

The oil and gas industry has a long commercial practice of gas injection: EOR, natural gas storage. Using a depleted oil or gas reservoir for CO2 storage has several interesting advantages among which the relatively large pressure range available for injection, allowing the storage of significant gas quantities for a low compression power, without altering the cap-rock integrity. Besides, the availability of reservoir dynamical and geological characterization and existing production/injection wells contributes to the optimization of the project, both technically and economically.

This CO2 storage can be permanent in the case of mineral trapping or very long term (several thousand years) in the case of hydrodynamic trapping. The long-term risk analysis of the CO2 behavior and its impact on the environment is a key objective of the project. That is why the selection of an appropriate reservoir is crucial to the success of the sequestration.

Two major steps have been identified while sequestering CO2. The injected CO2 dissolves and diffuses in oil and water and follows the pressure gradient (hydrodynamic trapping). Then, the dissolved CO2 reacts with the minerals within the formation and induces dissolution/precipitation reactions (mineral trapping), that may impair the well injectivity and/or the cap-rock sealing properties.

For the first time, this study investigates both sides using reservoir simulator with improved CO2 thermodynamics (ATHOS) and reactive transport simulator (DIAPHORE) to evaluate the extend of mineral trapping (kinetically controlled reaction) and long term behavior of CO2 within the reservoir and its neighboring geological formations (cap rock, aquifer).

This work is funded by Institut Français du Pétrole (IFP), Geostock, TotalFinaElf and sponsored by the French Ministry of Industry (FSH).
Determination of Practical Minimum Energy Requirements
Authors: Tanzil Dicksen , Schwarz Jeanette M. , Beaver Earl R. , Beloff Beth R.
Published: December 2007

Growing concern regarding greenhouse gas (GHG) emissions and a trend toward higher fuel prices have generated increasing attention on energy conservation in the industries, including the petroleum industry. However, there remains a need for a management tool that would allow industrial decision makers to assess current energy performance relative to recognized benchmarks and to judge the value of pursuing various energy-conservation strategies. This need is addressed in a pilot project on the determination of Practical Minimum Energy (PME), established through funding by U.S. Department of Energy.

A methodology was developed to identify successive levels of improvements in energy efficiency. The methodology was applied to evaluate the practical minimum energy requirements in several chemical manufacturing processes. Changes in energy consumption were also found to affect other environmental impacts, and they were studied using sustainability metrics. The combination of the PME tool with a complete suite of sustainability metrics allows managers to measure the added benefits of energy reduction and, in some cases, the trade-offs in impacts that may occur.
Remote Sensing for Environmental Baselining in the Petroleum Industry
Authors: Jackson L. A. , Rubin T. D. , Evans M. E. , Korenaga G. L. , Smart D. R. , Samuels P. A. , Hanrahan F. E.
Published: December 2007

In the present "Age of Transparency" of satellites and the Internet, environmental remote sensing is a rapidly evolving technology with important business applications for the petroleum industry. Much of the current work with remote sensing for biological uses, focuses on agriculture or forest management. This paper specifically deals with hyperspectral and Interferometric Synthetic Aperture Radar (IFSAR) sensors and their multiple applications for the petroleum industry where regional, detailed, and digital environmental information is needed for site and lease management. These technologies can be used to document environmental change, manage existing operations, and evaluate property prior to purchase or relinquishment. Current field applications will be discussed including examples of monitoring environmental change over time, identifying vegetation health, habitat mapping, water quality analysis, and location of hydrocarbon material. Applications still in the research and development stage will also be discussed as well as opportunities to join industry development via global partnerships.
Treatment of waste-water/oil emulsions using microwave radiation
Authors: Vega Camila , Delgado Mayolett , Vega Bolivia
Published: December 2007

Venezuelan E & P industry carries out an important amount of waste-generating processes that make necessary to develop more appropriate methods for disposing of their waste. Some of these waste materials are emulsions formed by a mix of residues of crude oil, water, drilling muds and other agents.

Microwave methods are able to destabilize water/oil emulsions by two means. First by increasing temperature, which reduces the continuous phase viscosity and breaks the outer film of the drops, thus allowing for coalescence; and second by rearranging the electrical charge distribution of the water molecules while rotating them, and moving ions around the drops. These two actions combined result in the breaking of the emulsion without adding any chemical agent.

Aiming to mitigate the environmental hazard that these waste emulsions represent, a base study was carried in order to verify the phenomenon described above. The experimental work consisted on breaking the simplest of the emulsions in terms of content, in order to obtain preliminary data that can help to extend the method to manage actual waste material. The samples consisted in water/oil emulsions (with several W/O compositions) which have commercial lubricant basis as the oil phase. The results of the experimental work are temperature profiles and recovery factors of aqueous phase that describe the performance and efficiency of the method.

The sample emulsions underwent a domestic microwave radiating process at several exposure times. Certain factors, such as aromatic components and sodium hydroxide content, emulsion mixing method and total heat exposure time proved to be the factors that more strongly affect the results. By using the microwave radiation exposure, results showed an aqueous phase recovery that ranged from 60 to 80 %, which is a significant outcome that reveals the study of this technique needs to be taken further.
New Handbook for Guidance in Assessing Impacts of Decommissioning and Disposal of Redundant Offshore Installations
Authors: Nesse Steinar , Lind Even , Jarandsen Bente
Published: December 2007

Decommissioning has really come on the agenda in Europe the last decade. In Norway, starting with the planning of decommissioning the North East Frigg in 1992/93, there were no standards established on issues and methodologies as a basis for impact assessment as part of the decision making. With the Brent Spar situation in 1995 the scope changed at the same time as methodologies were developed (e.g. [1]), improved and new issues were introduced. In 1995 the Norwegian Oil Operators Association (OLF) launched a methodology study to establish a standard set of methodologies to be used in the decision making process [2]. These methods have gradually been improved, as new issues have come on the agenda and as more complex decommissioning projects have been through the detailed planning process. As a consequence of this development OLF has updated the methodology descriptions and now issued a handbook containing descriptions, guidelines and standards for how to carry out Environmental Impact Assessments (EIA's) for offshore decommissioning projects [3]. The handbook contains several methodologies for numerous environmental and societal issues, dealing with installations, pipelines, drill cuttings piles, and the issue of possible reuse of installations.
Behavioural Change in a Oilfield Context and Some References to Grand Prix Motor Racing
Authors: Thonger Rod
Published: December 2007

This paper looks at the application of behavioural change techniques in the context of developing HSE programmes in oil and gas exploration and draws some parallels with improvements in Grand Prix motor racing.

The key to implementing behavioural programmes lies in the culture of the company. It is the essential ingredient that must include everybody from the very top to the very bottom of the management and staff chain, and is something that will be the driver of, and developed in parallel with better engineering and procedural standards

While all companies have managements that have absorbed varying levels of HSE culture and thereby made commitments to their accident programmes, development of the culture within which the behavioural programmes can be applied faces widely differing challenges. Production platforms, drilling rigs, seismic ships and seismic land crews have very different risks arising in terms of a safe place to work, safe equipment to work with, safe procedures and a trained labour force.

Relating this to the motor racing world, the number of drivers and spectators killed during race meetings since the 1950s has been significantly reduced by the commitment of organisers, teams, circuit owners and sponsors in an industry where the objective is specifically and aggressively to be first.

This paper looks at different situations as behavioural programmes are used more extensively.
Predicting the Properties of Sour Gases and Condensates: Equations of State and Empirical Correlations
Authors: Elsharkawy Adel M.
Published: December 2007

Compressibility, destiny and viscosity of natural gases are necessary in most petroleum engineering calculations. Some of these calculations are gas metering, gas compression, design of processing units, and design of pipeline and surface facilities. Properties of natural gases are also important in calculation of gas flow rate through reservoir rock, material balance calculations and evaluation of gas reserves. Usually the gas properties are measured in laboratory. Occasionally, experimental data become unavailable and estimated from equations of state or empirical correlations.

This paper presents the results of using various equations of state, corresponding state methods, and correlations to predict the volumetric and transport properties of sour gases and gas condensates. Capabilities of PR-EOS, SRK-EOS, and PT-EOS to predict gas compressibility and density of 2100 gas samples under various schemes of binary interaction number are thoroughly investigated. This study also reports a comparison between modified PR-EOS and other methods to estimate the viscosity of highly sour gases and rich gas condensates.
Image-Dip Calculation Using New-Generation LWD Density-Porosity Tools
Authors: Labat C. P. , Doghmi M. , Tomlinson J. C.
Published: December 2007

A new generation of LWD density-porosity tools azimuthally measure bulk density (RHOB) and photoelectric effect (Pe) in 16 sectors around the borehole in holes from 5 ¾ to 10 5/8 inches. They can provide formation images with a pixel size of 1.2 inches. These tools can function in conductive water based or non-conductive, oil or synthetic-based drilling muds.

The density images could be used to identify lithology and allow computation of dips for structural analysis. This application is demonstrated in deviated and complex wells in near-shore Gulf of Mexico. Field examples will illustrate the successful application of the density images for structural analysis, basic dip computation, and identification of large stratigraphic features such as folds, unconformities, fractures, and nodules.

Although these tools do not have the same resolution as some wireline deployed imaging tools, they provide an alternative method particularly when operators rely only on LWD for formation evaluation. Thus, they can save rig time associated with wireline runs and their respective wiper trips. They also measure while drilling so that if hole conditions negate the use of wireline tools, the information is already collected. Additionally, these multi-sector tools can be run in highly deviated holes which so often require electric line tools be drill pipe conveyed reducing costs exponentially.

These new LWD tools have also proven that they can deliver image-based information on borehole conditions such as shear and/or tensile fracturing, stress direction, borehole breakout, and borehole shape greatly aiding wellbore stability studies. In brief, the services provided by these new-generation tools are applicable to drilling, geological, geophysical, and petrophysical departments for formation evaluation, borehole stability study, and geo-steering.
Natural Gas Network Optimization and Sensibility Analysis
Authors: Martínez-Romero Néstor , Osorio-Peralta Oscar , Santamaría-Vite Iván
Published: December 2007

In the past few years, the numerical solution of non-linear equations for natural gas network optimization has proven to be useful. This paper presents: (1) a sensibility analysis for the most important flow equations defining the key parameters in the optimization process, and (2) a software "GasNet" based in the Stoner method, improved with several techniques to solve the equations system, allowing until an error of 50% in the initial values which avoids the divergence and accelerates the convergence.

GasNet is a powerful tool for design and optimization because it has advantages such as many routines for handling the specific gravity of the natural gas mixture composition; in addition it includes correlations used to obtain other properties. It also has graphic utilities that make easier the detection and solution of problems.

With information from the network as: flow rate, input and/or output pressures, features of the pipelines, compressors, valves and regulators, etc., we perform a sensibility analysis in order to get which flow equation: Weymouth, Panhandle, AGA, etc., is best at predicting the natural gas flow behavior in the pipeline (also this adjustment is applied to the PVT correlations and the equations of state by determining the Z-factor). The variation between the predicted and measured values with two parameters was estimated using the coefficient of multiple correlation and the X2-distribution.

The optimization process is performed with two criteria: the maximum operational permissible pressure and the gas flow velocity. These criteria allow for security in the facilities and suppress the harmful bottle-neck.

Two field examples are considered to illustrate the applicability of the proposed algorithms: distribution of a high pressure natural gas network in the Mexico Valley, Mexico and a network in Michigan State, USA.
Advanced Completions for Injection Applications
Authors: Gajraj Allyson , He Chuanping , Betancourt Soraya , Li Ruijian , Jalali Y.
Published: December 2007

We present results of modeling studies of injection schemes with wells using new completions technology, and address how these are applied or envisaged for the fulfillment of field development strategies in offshore environments.
Producing Sand for Sand Control: A Novel Approach
Authors: Underdown David R. , Sanclemente John
Published: December 2007

The Boscan Field, Maracaibo, Venezuela is using a unique approach to sand control. The completions use a combination of premium sand control screens and artificial lift that are designed to have a controlled level of sand production.

The Boscan formation is considered unconsolidated due to the lack of cementing agents, and the nature of the mineralogy. Lab studies have shown that low drawdowns will initiate sand production, and field experience shows that the drawdown caused by the artificial lift techniques used does induce sand production. Several other factors such as the crude which has a 10 API gravity and a viscosity that ranges from 300 to 2000 cps also affect the completions in the Boscan Field. In addition, the productive intervals range from 300 to 600 ft in length with large shale breaks between zones in many cases.

There have been several types of sand control implemented in the Boscan Field. The major methods of sand control prior to 1996 were stand-alone and gravel packed slotted liners. Since 1996 the completions have included open hole and cased hole completions using a variety of sand retention methods that include 12 & 16 gauge all weld and pre-packed screen, stand alone low profile screens, and premium all metal screens.

This paper discusses a lab study that evaluated several types of sand control screens for stand-alone and gravel packed completions using a technique developed by ChevronTexaco Exploration & Production Technology Company (EPTC) (8). The mineralogical characteristics of the formation that contribute to the sanding potential of the field are described. The rational for using a sand control technique that allows a certain amount of sand production is discussed in detail. In addition, production data including sand production for several types of completions are compared.
Collaboration between Corporations, Non-Governmental Organizations, and Indigenous Communities: The Bridge Strategy to Pursue Sustainable Development in the Oil & Gas Industry in Latin America
Authors: Garcia Percy , Vredenburg Harrie
Published: December 2007

Corporations investing in Latin America are facing problems including opposition from indigenous communities and environmental non-governmental organizations (ENGOs)1, and the activities of guerrillas and drug cartels2 that are making it difficult for them to operate. Collaborative alliances are seen as a strategy that organizations can use to deal with the turbulence and complexity of their environments3. Strategic bridging has proved to be effective to approach collaboration in sensitive areas of operation. The main conclusions are: (a) the complex environment in which corporations operates in Latin America requires collaboration among all stakeholders to achieve common goals of sustainable development; (b) indigenous communities have the potential to collaborate with MNCs; however, they need certain level of education and training; and (c) NGOs possess the necessary expertise to act as a bridge, their participation is essential to explore opportunities of collaboration between indigenous communities and MNCs.
Self-Sufficient System For Continuous Gas Lift In A Very Harmful Sour Gas Environment
Authors: Lozada Aguilar Miguel A. , Ramos Hipólito Peregrino , Inestrosa Ariel Ramos , Hernández Ramiro Acero
Published: December 2007

The Mora Field is located 60 kilometers from Villahermosa Tabasco in the southern region of Mexico. A project of self-sufficient system for continuous gas lift in a very harmful sour gas environment was performed. The gas lift infrastructure is not going to be installed in a short time due to many problems such as logistic issues.

The self-sufficient system separates the gas from the liquid. Then, it is compressed and injected into the well, similar to an artificial gas lift. This system uses special coiled tubing for sour gas handling. In addition, a continuous chemical inhibitor is injected to protect both the tubing and the coiled tubing from either cracking failure or corrosion, (because the H2S and CO2 content in the mixture is too high).

The goal of this work is twofold: (1) present a facility design and (2) present a process to choose the equipment for this particular application based on the well productivity. Because the probability of both cracking and corrosion is high, sizing the equipment and selecting the appropriate material are special issues for the success of this application.

Based on this pilot test, a major project is being implemented to install this system in those fields with high content of sour gas and without gas lift infrastructure.
Coiled-Tubing-Conveyed Perforating for Maximizing Underbalanced in Hard Rock
Authors: Gorian S. , Rodriquez J. , Loboguerrero S.
Published: December 2007

This paper describes a variety of Coiled Tubing perforating approaches and techniques which have been evaluated, planned and implemented during the development of the Cusiana and Cupiagua Fields. A synopsis has also been prepared which outlines the advantages/disadvantages of each of these approaches. In addition, several detailed case-histories are included which provide the actual Operating characteristics of each approach.

The particular operational advantages, of Coiled Tubing Perforating, for Cusiana and Cupiagua have also been summarized. These include, the long intervals, deep wells, complex well trajectories, large gun-size, pre-frac requirements and poorly understood pore-pressures. An assessment has also been made of the additional benefits, IOR, cost savings, etc. that these techniques have potentially provided.

Finally, there is some discussion as to the future direction of Coiled Tubing perforating for the Cusiana and Cupiagua Fields. Issues include a clearer definition of the Opportunities/Requirements and the additional Techniques/Systems which will be necessary to allow these to be realized.
Stratigraphic Architecture and Sedimentology of the Main Oil-Producing Stratigraphic Interval at the Cantarell Oil Field: the K/T Boundary Sedimentary Succession
Authors: Murillo-Muñetón G. , Grajales-Nishimura J. M. , Cedillo-Pardo E. , García-Hernández J. , Hernández-García S.
Published: December 2007

Detailed stratigraphic and sedimentologic analysis of the main oil-producing stratigraphic interval at the Cantarell Oil Field suggests a general graded stratigraphic architecture for the Cretaceous-Tertiary (K/T) boundary carbonate sedimentary succession. Extensive well log data, core description and petrographic analysis, as well as comparison with contemporaneous outcrop analogs, indicate that this interval is dominated by a thick carbonate breccia genetically related to the Chicxulub meteorite-impact event occurred in northern Yucatan. The carbonate breccia deposit is consisting with a base-of-slope apron.
Thin Laminated Gas Bearing Sequences, Gas Finder A New Approach Of Petrophysical Evaluation, In México
Authors: Frass Manfred , Saldungaray Pablo , Jimenez Ricardo
Published: December 2007

Traditional petrophysical well evaluation, is able to show an integrated analysis where the log information is transformed into a lithology, water, oil, gas saturation curves, along a specific interval of a well. This method, is not able to predict how much the production of those intervals could be, when completed.

With this new methodology the same approach is used, but magnetic resonance and pressure data, is integrated.

As magnetic resonance, allows the discrimination among irreducible and moveable fluid saturation and also indicating the better permeability zones, it is used as a guide for the point selection for the modular dynamic formation tester. Based on this data set, the pressure, a skin factor is determined and the relative permeability to the reservoir fluid, is defined.

In low resistivity reservoirs, were the traditional calculation could show high water saturation, the new technology will allow the engineer to discriminate if the water is going to flow or not, maximizing the reservoir potential.

Having defined the lithology, pressure, permeability, fluids distribution and fluids saturation a synthetic production flow profile log, can be generated for each selected interval, allowing an optimized selection of the best possible intervals or overlooked zones, maximizing the final production of the well.

In conclusion, new technology and power full computer calculation have a big impact in the well completion and production maximization of reservoirs.
Underbalanced-Undervalued? Direct Qualitative Comparison Proves The Technique!
Authors: Pia Giancarlo , Fuller Tom , Haselton Thomas , Kirvelis Ringys
Published: December 2007

Underbalanced Drilling (UBD) techniques have been evolving since 1989 and have been justified and documented, mostly from a drilling engineering point of view, on the basis of improvements in drilling performance. Enhancements such as increased rate of penetration, reductions in lost circulation and virtual elimination of differential sticking have all been shown to have a significant impact on the associated costs. However, to date, there has been a comparative lack of documentation of the improvements attainable from a production optimisation and reservoir engineering aspect. Very little material has been published on well data enhancement, such as productive capacity, reservoir life and net present value, which proponents of UBD maintain should be major drivers towards its consideration in the early phases of the analysis of reservoir economics and modeling of well construction.

This operator has committed to a campaign of drilling onshore wells, using UBD techniques for both drilling and completion, in a well-cemented, abrasive Cambrian sandstone reservoir. This formation is characterized by relatively poor porosity and horizontal permeability and a comparative lack of fracturing that would normally preclude it from consideration as a good candidate for UBD, though it does have a depleted reservoir pressure.

The results obtained, in a safe and economic manner, have far exceeded operator expectations. By comparing two wells, one drilled using standard overbalanced drilling methods, the other, a very close offset well, drilled with UBD techniques, this paper will document an increase in well productivity in the order of twenty-five fold. It will go on to discuss the production increases obtained over multiple wells, 6 in total at the time of this publication, which have been limited only by the surface handling capabilities, highlighting the changes in field development planning that have resulted from the successful application of UBD techniques.
Design, Specification, and Construction of a Light, Automated Drilling System (LADS)
Authors: Dunn M. D. , Archey P. J. , Opstad E. A. , Miller M. E. , Otake T.
Published: December 2007

A "typical" North Slope well is a thing of the past. Twenty years ago, a rig would sit on a Prudhoe pad and drill dozens of 10,000 bopd wells. Today, a rig might drill multi-laterals one month, and exploration wells 60 miles from infrastructure the next. Diverse well types and changing economic drivers warranted a new look at North Slope rig designs.

In 1997, BP Alaska began researching what the drilling machine of the future should look like. Conceptual drawings were drafted and several new design tenets emerged. First, the rig had to be safer and more automated. Second, it had to reduce well costs. Third, it had to be lighter and smaller. Fourth, it had to be better suited for cross-tundra rig moves.

In May 2000, BP chose Phoenix Alaska Technology (PAT) to finalize the design, construct, and operate the rig. In March 2001, PAT began constructing a state-of-the-art, fully automated drilling rig that is expected to commence operations on the North Slope in early 2002. The rig weighs less than half that of a conventional North Slope rig of equivalent horsepower. A single operator controls all drilling, tripping, and horizontal setback operations from a computerized control station.

This paper discusses the first four stages of this project: 1) The conceptual design phase by the operator, BP, 2) conceptual design phase by the contractor, PAT, 3) final engineering and specification by PAT and its subcontractors, and 4) rig fabrication. This case study also explores the basis for the design and the features of a light automated drilling system (LADS) that is expected to meet the objectives.
Target Design Based Upon Multidisciplinary Uncertainty Information
Authors: Haarstad Ivar , Lotsberg Oddvar , Torkildsen Torgeir , Munkerud Per Kristian
Published: December 2007

Target design is an important element in planning wells. It is a multidisciplinary and interactive process between geoscientists, reservoir/production engineers and drilling engineers to define the combined uncertainty constraining the size of the target. A methodology and tool for target analysis and quantification of target intersection probability based on drilling and geological input has been developed to promote interdisciplinary communication and help designing realistic drilling targets.
Project Management and Technology Provide Enhanced Performance for Shallow Horizontal Wells
Authors: Sander M. , Norgaard R. , Kern K. , Warren T. M.
Published: December 2007

Seven rigs were employed in the Hay Project to drill eighty-three laterals - 22 triple laterals, 4 dual laterals, and 9 single laterals for oil production, water injection and water source during the 2000/2001 winter drilling season. These laterals were typically longer than 3,300 ft, with laterals as long as 4,060 ft being drilled at a TVD of 1,065 ft. The overall drilling project was completed 21 days ahead of schedule and significantly under budget. Project organization, the application of technology, and agreeable weather conditions were the main factors contributing to this outstanding performance.
Using Predictive Testing to Circumvent Blowout Prevention Equipment Downtime
Authors: Montgomery Michael E.
Published: December 2007

Pulling the blowout preventer (BOP) stack or Lower Marine Riser Package (LMRP) on a floating drilling rig has always cost everyone involved a significant amount of money. However, when operating in the ultra-deepwater theater, those costs regularly exceed $1,000,000 per event. As a result, developing and utilizing methods to ensure operative BOP equipment and systems continues to grow in importance to avoid this downtime cost.

The first known field predictive test on BOPs was conducted on ram locking systems in the North Sea in 1987. Since that time, the tests have been refined to identify other modes of failure so they can be corrected while on the surface, providing increased assurance of their ability to function when they are needed on the wellhead. Additionally, predictive tests have been devised and their effectiveness demonstrated on ram locking systems, connectors, annulars, failsafe valves and control systems.

This paper will outline each of the predictive tests developed and validated from field testing and working with equipment manufacturers, describe the principles upon which they are based, and provide case study examples where they have proven to identify pending failure.
Emulsion-Based Fluid Used to Optimize Casing-Cleaning Operations
Authors: Berg Erik , Nabati-Shoghl Farzad , Saasen Arild , Sedberg Stian
Published: December 2007

The removal of drilling fluids from the cased well prior to installation of critical completion equipment often involves use of special fluids to ensure a complete removal of both the drilling fluid itself and particles attached to the casing wall. This is a critical operation where failure can lead to excessive complications in the subsequent completion operation with stuck packers or formation damage due to particle invasion into the formation as a consequence. Furthermore, these operations have the highest attention from the environmental authorities because casing cleaning operations are considered as highly polluting operations during drilling and completion of a well. Modern drilling fluids used in the North Sea region are designed to meet occupational hygiene requirements and environmental criteria. These drilling fluids are relatively difficult to remove from the casing surface.

The current paper describes in detail a well cleaning fluid system designed to meet these technical objectives with special focus on reducing environmental impact. The casing cleaning fluid system is designed using a partly unstable emulsion, where the surfactants are partly dissolved in the water phase and partly used as emulsifiers. Since the emulsion is unstable, the individual components can be separated after the operation. This allows for re-use and recovery of the fluid components at the same time as the fluids has optimized the well cleaning efficiency. The removed base oil can be used to formulate new drilling fluid or re-used in casing cleaning fluid systems.

The improvement of new designed fluid has been verified in both laboratory tests and North Sea field experiences. Field experience from approximately 30 operations show that the average operation time has been significantly reduced. The paper compares field experience obtained using different casing cleaning operation techniques.
New People, New Rig; Managing Performance
Authors: Blank Bob
Published: December 2007

Long-term business relationships and working teams are difficult to maintain in a cyclical business where activity levels can quickly change. Starting rigs up and building new working relationships is time consuming and can be tedious and unproductive if not properly managed. Both informal and formal processes can be utilized to good advantage in order to maximize safety and productivity. This paper will discuss some of the systems and processes used by one offshore drilling contractor with their customers to focus efforts toward meeting these goals.
Managing the Operator/Supplier Relationship on the Mad Dog Project - The Supplier's Perspective
Authors: Fulks Robert , Cook Allen "Rusty"
Published: December 2007

In mid-2000 BP invited a group of suppliers and drilling contractors to become involved in a deepwater development project in the Gulf of Mexico named "Mad Dog". This project involved building and maintaining unique relationships among the drilling contractors/suppliers, BP and its partners on the Mad Dog field. BP employed a process not used before in the deepwater Gulf known as "Lean Drilling™"1 to foster these critical relationships necessary to the early success of the project.

This paper will detail how BP selected the drilling and completion suppliers during the conceptual stage of the project and how these suppliers were organized and empowered for success. The paper will examine the Lean Drilling process from the supplier's vantage and comment on the effectiveness of this process in terms of technology transfer and other criteria.
Shallow Geohazard Risk Mitigation; A Drilling Contractor's Perspective
Authors: Reed David
Published: December 2007

The introduction of the Offshore Installations (Safety Case) Regulations 1992 and the Offshore Installations and Wells (Design and Construction, etc) Regulations 1996 to offshore operations in the UK North Sea require risks related to the drilling of wells to be kept As Low As Reasonably Practicable (ALARP). The responsibility of the rig owner in this regime is to identify safety critical elements associated with the rig and ensure that these risks are maintained to within ALARP principles. This responsibility also recognises that wellbores attached to the rig may also present a threat to the installation and those onboard. Additionally, the rig owner must take into account well-related safety critical elements.

By using examples, this paper examines why and how a drilling contractor has implemented a Shallow Geohazard Review process in order to mitigate shallow geohazard risks. This paper reviews the operator - geotechnical contractor relationship and identifies where drilling contractor involvement has strengthened the risk analysis process. Finally, this paper summarises the positive outcomes of this process as well as challenges the drilling and geotechnical contractors to bridge the information gap.
Optimizing HTHP Cementing Operations
Authors: Shaughnessy John , Helweg John
Published: December 2007

Successful cementing jobs are critical to economically completing HTHP wells. BP and Schlumberger Dowell have consistently been successful cementing wells at total depths between 22,000′ and 23,000′ and maximum temperatures of 400°F. The proof of successful cement work is demonstrated with record production rates for the state of Louisiana and achieving isolation in sands with over 10,000 psi depletion. The optimization methods and approach will be discussed along with problems experienced and subsequent solutions. Over 15 such wells have been drilled in Louisiana during the last 5 years. This paper will also address the philosophy and procedure of cementing production tieback casing to the surface by reverse circulating.
Evaluation of Deepwater Drilling Prospects Using New Concepts to Identify, Quantify and Mitigate (IQM) Risks for Well Design
Authors: Holasek Fred R.
Published: December 2007

The detailed analysis of a drilling prospect is crucial for a successful well. As the geological events vary dramatically from well to well, the drilling characteristics and risks will also vary. This difference between wells is easily the difference between a successful well and a well fraught with significant safety and financial problems.

An overview has been presented of the steps for the evaluation of a drilling prospect to produce a unique set of drilling characteristics and well design for a proposed well. This evaluation is founded in the fundamental concept of projecting from the known to the unknown.

Wells in the same micro-basin of the proposed well are analyzed in a new way to allow the properties to be projected to the proposed well. This unique analysis allows quantitative comparison of drilling parameters such as shallow flow potential, overburden profile, pore pressure profile, fracture gradient profile, and penetration rate profile. This new concept has it roots based in the fundamentals of micro-basin fluid migration gradients and reservoir seal capacity limits.

Once the analysis of the key wells has been prepared a detailed 2-way time-depth correlation is made from the key wells to the proposed well. Using this detailed correlation along with micro-basin fluid migration gradients and reservoir seal capacity limits, the drilling parameters can be projected to the proposed well bore.

Once this has been done, risks can be identified, quantified and mitigated. A well design and plan can be prepared that has significantly reduced risks. Reducing the risks directly reduces the times that the drilling rig and personnel are exposed to potentially hazardous situations. This means fewer accidents and a safer working environment. As a secondary concern, identifying, quantifying and mitigating risks will significantly reduce the finding costs of hydrocarbon reserves.