bluuebunny/crossref_metadata_2025_split huggingface dataset:
Replacing 5 Inch and 3-1/2 Inch Drill Pipe With a Single String of 4 Inch Drill Pipe
Authors: Mehra Sachin , Smith J. E. 
Published: December 2007

Abstract
Sedco Forex is drilling horizontal and extended reach holes with their Simpler Rig 101 in the Rabi field in Gabon, West Africa. The typical drilling programs call for 17-1/2 in., 12-1/4 in., 8-1/2 in. and 6-1/8 in. bit diameters. Casing sizes are 13-3/8 in., 9-5/8 in. and 7 or 7-5/8 in.. This normally requires the use of two different pipe sizes: 5 in. and 3-1/2 in. The 5 in. pipe is used to drill down to the 6-1/8 in. section because of its torsional strength and fluid carrying capabilities and the 3-1/2 in. pipe is used to complete the hole because the tool joints on the 5 in. pipe are too large for the 6-1/8 in. hole.
A single string of 4 in. drill pipe with double shoulder tool joints can replace the 5 in. and 3-1/2 in. pipe. The 4 in. pipe has the torsional strength and fluid flow capacity needed for the upper portion of the hole, it has better buckling strength than the 3-1/2 in. pipe for more weight on the bit and the tool joints will fit in the lower portion of the hole.
Field Recovery of High Holding Capacity Anchors in 5,000 Feet of Water
Authors: Towns T. K. , Christman S. A. , Ettle R. E. , Bruce P. 
Published: December 2007

Abstract
This paper will review the engineering design and field procedure for recovery of high holding capacity anchors on a moored drilling vessel in 5,000 feet of water.
It will discuss the variables that field personnel can control at the surface and how changing these variables affects forces applied to anchors embedded into a silty-clay bottom. The paper will show how to estimate the resultant force applied to the anchor since there is currently no method available to measure forces at the anchor. The paper will include a discussion of the upgrades to the chain chaser system and a large 450 MT winch used on one anchor handling vessel.
This paper will show how to balance line tensions between the winches on a moored drilling vessel and an anchor handling vessel so that the upward resultant force at the embedded anchor is effectively applied. The pulling procedure can result in lower chase wire tensions at the stern of the anchor handling vessel while reducing the time necessary to recover an embedded anchor. Lower wire tensions increase the factor of safety for the components that make up the chain chaser system and reduce the risk of a failure.
As operators move to deeper waters using moored drilling vessels, thorough understanding of the forces being applied to the chain chaser and anchor can improve recovery of high holding capacity anchors and minimize recovery time. This new technology can help moored drilling vessels operate efficiently in deep water.
PELAUT—A Purpose-Built Semisubmersible Drilling Tender
Authors: Manning F. T. , Pauling J. R. 
Published: December 2007

Abstract
We describe the design, construction and operational experience with the industry's first purpose built semisubmersible drilling tender. In 1987, the Petrodril Company perceived the need for a drilling tender having better wave response characteristics than the barge type derrick vessels used previously. Their need was for a vessel to carry out well servicing operations on platforms installed in water depths of 40 to 400 feet on the north coast of Brunei. Operational capability in seas of up to 20 feet significant height would be a major requirement for the new vessel in order to reduce weather downtime to virtually zero.
The capability for transporting the derrick equipment set (DES) on board and a transfer to or from vessel to well platform in eight lifts was a requirement. This is accomplished by two rotating cranes of 150 and 37 tons capacity respectively. Variable load capacity of 2300 tons for tubulars, consumables and the DES is provided.
The resulting twin hull semisubmersible design was optimized to achieve minimum wave induced motions while maintaining target values of stability, working area and load capacity. Both state of the art computations and model testing were utilized in arriving at a vessel that could achieve these goals.
Construction commenced in March 1993 with delivery in March 1994. Now after two full years of operation, the seakeeping performance has exceeded expectations.
An Overview of Air/Gas/Foam Drilling in Brazil
Authors: Negrão A. F. , Lage A. C. V. M. 
Published: December 2007

Abstract
The air. gas and foam drilling has been used in specific areas in Brazil as an alternative for problems caused by the traditional drilling process. Considering those two-phase flow drilling operations, this work focuses on their benefits and operational improvements. Furthermore, the comparison between the performance of conventional and two-phase flow drilling has been showing this new technique has some advantages: (1) minimum or no damage to sensitive pay zones. (2) immediate and continuous evaluation of cuttings for hydrocarbon shows, (3) avoidance of lost circulation, and (4) higher penetration rates in hard formations.
Two very recent on-shore two-phase flow drilling field cases, one with joint pipe connections, and the other with coil tubing are mainly described. Their results arc analyzed concerning the surface equipment design, appropriate technique for connections when using drill pipe underbalanced drilling, as well as the comparison of predictions of computer programs to real field data.
Future plans for the continuity of the two-phase flow drilling operations in Brazil arc also commented Additionally, potential areas and concrete actions for improving operational feasibility of this emerging technology are identified. The target is a safer and economical air. gas or foam drilling operation.
Stochastic Mapping of Lithology in a Carbonate Reservoir
Authors: Sahin A. , Ghori S.G. 
Published: December 2007

Abstract
Stochastic maps of reservoir lithology are extremely useful for planning during field development, production and management. Moreover, lithology types may have significant controls over porosity and permeability distributions within the reservoir. Therefore, the stochastic mapping of lithology may be considered to he the first step in geostatistical modeling of porosity and permeability distributions during reservoir characterization.
Several stochastic mapping (i.e. conditional simulation) techniques have been developed in recent years to generate equally-probable, multiple realizations of reservoir lithology. Bach realization constitutes a high resolution stochastic image, or map, displaying a realistic level of heterogeneity. It also reproduces the histogram and the spatial pattern of the actual data besides honoring these data at all sample locations.
In this study, the Sequential Indicator Simulation (SIS) technique was employed to generate stochastic maps in a carbonate reservoir consisting of three lithology types (dolomite, limestone and anhydrite). The basic data consisted of lithology indicators representing these lithology types and were derived using several techniques. The simulation provided a total of twenty realizations indicating the presence or absence of one of the three lithologies within cells each having 300m × 300m × 0.5ft dimensions. The results indicate an excellent match between the histogram of the input data and that of the simulated values. Comparison of lithology maps derived from simulation with those of the corresponding well-log porosity fields indicates that porosity does not correlate well with lithology except locally with anhydrite lenses. This is explained by the gradual change of well-log porosity values across lithologic boundaries observed in the input data.

Introduction
Lithologic maps and/or cross-sectional plots of lithology are extremely useful tools for planning purposes during the entire lifetime of oil field projects, particularly for field development, production and management. Classical deterministic or geological maps are generally smooth and do not reveal a realistic level of heterogeneity. Therefore, stochastic mapping or conditional simulation techniques have been employed in recent years to provide stochastic maps of lithology. Stochastic mapping of lithology has also been proposed as the first step in modeling petrophysical properties such as porosity and permeability whenever the lithology types have significant control on distribution of these variables.
Stochastic mapping techniques provide equally-probable, multiple realizations of lithology distribution within the reservoir. P. 183^
POSC and the Emerging E&P Business Perspective
Authors: Ring M.J. 
Published: December 2007

Adoption of standards in today's business ecology is a strategic decision; most organizations have either embraced them or they will. The strategic need for oil and gas industry standards particularly in the area of integration of business processes and information sharing was the implicit underpinning of the formation of Petrotechnical Open Software Corporation (POSC) in 1990. The business drivers are low oil prices, increasing costs, lower margins, and increasing risks. The oil industry responded by focusing on core business assets, consolidation and restructuring, implementing risk management, increased collaboration with partners, increasing productivity, reducing costs, improving reservoir performance, and a move towards a global business (1).
The use of standards allows for the sharing of data and information across disciplines, functions, companies, countries, partners, through the life cycle of an asset (Figure 1) so that collaborative groups can focus on concurrent, interactive creative thinking and stakeholders can access and respond to pertinent information in real time (Figure 2). Industry standards will imiprove the flow and quality of information throughout an E&P organization; reduce the time, cost and risk of Information Technology solutions; enable new business practices within oil companies and new relationships between suppliers and consumers.
Standards allow better decisions due to improved information resulting from better access to complete data and dramatic improvement in bottom line results (improved work practices, reduce cost and time). Cost savings of 25% are targeted; time savings of 40% have been noted. Improved margins (£/BOE) are being realized by simultaneously decreasing costs (£) and increasing value (BOE).
Industry achievements to date have been significant: drastic cost reductions, outsourcing, partnerships, new team sharing behaviour, new technologies, and the use of de facto standards. But it is recognized that this is not enough; the industry needs to find new ways of working that can reduce costs further and sustain new growth. There are numerous evolving paradigm shifts in the oil and gas industry (Table A). Significant changes are occurring in technology, sociology, geopolitics, business processes, decision processes. Organisations are redefining themselves as the business ecology evolves into the knowledge era.

Knowledge Paradigm in the Oil and Gas Industry
The E&P industry is based on communications of knowledge between people, teams, organizations, etc. Consider the value placed within each organization for the "oil finders"; the drilling team who are able to achieve both the technical and business objectives of the well; the reservoir management team who can optimize reservoir performance or "squeeze the oil from the ground"; the operations team with no injuries; etc. All these teams are characterized by possessing a common shared knowledge which stimulates interactive mental creativity and innovation.
Environmental Cost Criteria for Exploration & Production
Authors: Parums A. M. , O'Leary H. E. 
Published: December 2007

Abstract
BP Exploration (BPX) has completed a study which assembles in a rigorous, comparable format, a wide range of quoted costs for reducing emissions and discharges to the environment. It compares the costs of different improvement technologies for Exploration and Production, and shows how these costs compare with other parts of the petroleum sector or other industries. The study uses two measures (‘capex/annual te’, ‘NPC/total te). Regulators’ expectations of justifiable spends are mapped onto these typical technology costs from studies and actual projects. The environmental issues considered include atmospheric emissions (VOC, methane, NOx and CO2) hydrocarbon aqueous emissions.
These common measures can be used by drilling, petroleum, facilities and production engineers to benchmark environmental spend and by management as an input to decision making in response to environmental challenges.
The simple framework enables the mapping of environmental assessments from a variety of sources enabling site specifics decisions to be considered against a company-wide or industry-wide context.
As well as providing a framework for true economic comparison of environmental improvement options, the paper provides powerful support to the strategy of making simple operational improvements before costly facility change, and for the need to consider the whole scope of environmental impact from any project, not just one narrow goal.
A Mathematical Model for Predicting Wellbore Screenout in FRACPACKs
Authors: Omari Mazen H. 
Published: December 2007

Abstract
The fracturing and gravel packing sand control technique, most commonly referred to as FRACPACK, has recently become one of the most successful and reliable ways to complete low to moderate permeability unconsolidated sandstone reservoirs. In addition to providing a good sand control completion, FRACPACK offers the advantage of stimulating the reservoir and reducing the final skin. FRACPACK treatments are most commonly done with the screen in place where a gravel pack packer is run with the blank pipe and screens placed across the zone of interest. Later, a fracturing treatment is performed through the gravel pack packer and across the screens (Fig. 1)
Although a lot of research has been made in the fracturing area of FRACPACKs, little is known about the nature of slurry flow in the screen/casing annulus below the gravel pack packer crossover ports and before entering the perforations. It is believed that as pumping progresses, deposition of proppant on the screen yields stable nodes that may cause bridging in the annulus that may result in early termination of the fracturing treatment.
This paper discusses the steps involved in mathematically predicting node buildup on the screen during FRACPACK treatments. A simple model was developed that calculates the size of the node deposit at the end of fracturing treatments based upon treatment parameters. FRACPACK case histories from the Gulf of Mexico where wellbore screenouts occurred were predicted by the model.
Development Of An Integrated Reservoir Characterization And Simulation Model For A Heterogeneous Carbonate Reservoir, Arab-D Reservoir, East Flank Of Ghawar Field
Authors: Valle A. , Faulhaber J.J. , Keith T.H. , Hsueh P.T. 
Published: December 2007

Abstract
Three dimensional geocellular and simulation models were developed for an area on the eastern flank of the Ghawar Field in the Arab-D carbonate reservoir that displays anomalous flood front advance and the potential for by-passed oil. Results were achieved through the integration of openhole log data, well performance data, production log data, well test and pressure build up data, core descriptions, 3-D seismic structure, and 3-D seismic influenced permeability distributions. The final products were simulation and geocellular models that were consistent with each other and with all of the available engineering and geologic data. This approach has constrained the resulting models towards a more unique solution that can now be used with greater confidence for reservoir management and the identification of areas of lagging flood front or bypassed oil.
This study was built upon a previous study which showed considerable success through innovations in model layer selection, mapping of very high permeability areas, horizontal and vertical permeability distribution, grid size and relative permeability assignments. However, the incorporation of other data sets, particularly newly acquired 3-D seismic, demonstrated that the predicted distribution of by-passed oil is dependent upon an accurate description of structure, faults and related fractures as well as rock porosity and permeability. The fully integrated modeling approach utilized here was recognized as a superior way to develop a useful simulation model.
This project was accomplished through a multidisciplinary team approach. The team varied in size and membership as the project developed through its various phases. This project integrated the work of reservoir engineers, reservoir simulation engineers, petrographers, geologists, geophysicists, petrophysicists, and geocellular modelers.

Introduction
This paper discusses the development of an integrated reservoir characterization and simulation model for a very heterogeneous segment of the Arab-D carbonate reservoir of the Ghawar Field in Saudi Arabia. The referenced reservoir segment is roughly 15 km wide by 15 km long and is being depleted by peripheral water injection. Waterflood advance in this area of the reservoir has been extremely rapid. There is therefore the potential of losing oil reserves due to by-passed oil (Fig. 1).
Moore discussed reservoir management issues, well completions and production strategies for this area of Ghawar. In his paper, Moore correlated the fast flood front advance to the preponderance of superpermeability (layers which generally exhibit specific flow rates of 500 BPD per foot or greater). He ascribed the main source of this superpermeability in this part of the reservoir to vugs created after the stick-like organism, Cladocoropsis was leached out from a cased-hardened dolomitized rock at the middle of the reservoir, Zone-2B (Fig. 2).
P. 195^
Production Water Management in Oman
Authors: Al-Muscati A. , Huijskes J. , Parker D.H. 
Published: December 2007

Abstract
This paper describes the development of the Production Water Management Plan for Petroleum Development Oman (PDO) and its subsequent implementation. It outlines the current water production and disposal practices, the existing Omani legislation on waste water disposal, and trials carried out by PDO, all of which resulted in the development of the plan and an implementation strategy agreed by PDO and the Government to achieve a produced water management operation that is sound both in environmental principle and practice.

Introduction
PDO currently produces some 330,000 m3/day of water as a by-product of its oil output of about 135,000 m3/day. The volume of this production water has been steadily increasing over time and is predicted to rise to about 650,000 m3/day by the year 2005.
The disposal of large volumes of production water presents PDO with important environmental and economical challenges. In order to manage these challenges, the PDO Production Water Management Plan was developed and agreed with the Government and private shareholders.
In resolving the best technical solution for disposal at any of PDO's production sites, PDO has fully evaluated the principles of the PDO Production Water Management Plan by testing and then implementing the latest state-of-the-art technologies. Studies and trials have been carried out in order to achieve improved cleanliness of production water, and to identify economically attractive usage alternatives for the water. In particular field trials to test various deoiling equipment have been carried out, as well as a detailed study and field trial into the use of disposal water as irrigation water for an agricultural project. As a pre-study for the agricultural conceptual work, other alternative water disposal methods, such as the use of evaporation ponds, ocean discharge and production of potable water, were evaluated but found to be economically less attractive than the agricultural alternative.
Having completed these trials and studies, plans have been put in place to bring production water disposal in all production centres into line with the principles of the Production Water Management Plan. The main outcome has been the implementation of Deep Water Disposal for most production centres in the South of Oman.

Water Production
The disposal of large volumes of production water presents PDO with an environmental and water resources conservation issue of considerable importance, in terms of both quality and overall quantity. The volume to dispose of is expected to rise over the next decade, with no significant increase in the volume of water that can be profitably utilised either for reservoir pressure maintenance or for other purposes.
High water production is caused by bottom or edge water drive, high oil viscosity and low density contrast. Well over half of PDO's Oil initially in Place (STOIIP) is in reservoirs with conditions resulting in high water production due to natural water drive.
P. 265^
Slim Hole Drilling In Kuwait (4 1/2" Hole Size)
Authors: Al-Khayyat Bader , Al-Azmi Bader 
Published: December 2007

Abstract
Slim Hole Drilling in Kuwait Oil Company (KOC) is not a procedure that is planned for in initial well designs. The complexity of drilling conditions in Kuwait has forced KOC to plan and drill such hole sizes as a contingency. First, one must appreciate the drilling conditions that forces the need for slim hole drilling in Kuwait. Highly fractured, extremely weak zones near surface and below or between several productive field horizons are followed by a pressure transition that ends with a salt/anhydrite section with porous layers interbedded, containing H2S gas and water. In order to control the fluid within such layer, mud weight, in excess of 19.0 ppg is required. Below this section is a slight pressure reversal which includes fractured carbonates. Due to such pressure differences between layers and the position of lost circulation layers within productive zones, numerous casing strings are required to isolate pay zones from weak zones, normally pressured zones from high pressured zones and weak zones from other normally pressured zones, to maintain circulation for drilling and well control. Kuwait Oil Company Deep well programs end with 5½" casing set on bottom which requires that the well starts with 42" conductor at surface and 30" as surface casing. Unanticipated hole conditions or well problems that require setting a casing string at an earlier depth than what was actually planned for in the well casing design, will result in slim hole drilling on bottom in order to reach the objective of the well. Often very little allowance is available for problems by the very nature of drilling conditions.
Slim hole drilling in Kuwait is drilled in a hostile environment. The slim hole sections are typically in deep, hot hole sections. This environment often finds high pore pressures virtually near frac strengths. The wells are often either flowing or losing mud. To make matters worse, H2S accompanies any influx or drill volume gas.
The paper will cite case histories of wells that have included 4½' slim hole sections at depths from 19300 to 20774' in EXW-1 and over long intervals of 15704 to 18683' in DW-01 and in mud weight ranges of 16.0 to 19.3 ppg. Slim hole sections have been drilled using downhole motors as well as with rotary drilling. The case histories will additionally describe the down hole tool selections used along with kick and lost circulation handling. Also, discussions will touch on side tracking and completion on DW-02 where the the original 4 1/2" hole was drilled from 12,620' to 13,800' with 16.0 ppg mud and was side tracked from 12,821' to 13,560’. At the end of the side tracking, 3 1/2" liner was run and cemented as the completion liner and 2.6" bit was run on 1 1/2" coil tubing to clean out inside the liner.