bluuebunny/crossref_metadata_2025_split huggingface dataset:
Multivariate Fracture Treatment Optimization for Enhanced Gas Production from Tight Reservoirs
Authors: Rahman M. M. , Rahman M. K. , Rahman S. S. 
Published: December 2007

Abstract
An excessive high treatment pressure may be required to execute a production enhancing hydraulic fracture treatment in a tight-gas reservoir, particularly if the treatment is designed with inappropriate values for treatment parameters: fracturing fluid viscosity, injection rate, injection time and proppant concentration. Such a high treatment pressure may not only exceed the delivering capacity of specified surface equipment (pump, pressure rating devices and downhole tubing), but may also cause multiple fracture initiation. Multiple fracture initiation may cause near-wellbore tortuosity complexities and large fluid loss, and thus may damage the formation irreversibly that results in productivity lower than even unfractured wells. This paper presents an integrated model for multivariate fracture treatment optimization with adequate trade-offs between production enhancement, equipment capacity and formation compatibility requirements. The model considers both fracture geometry (length, height, width etc.) as well as treatment parameters as free design variables. Compatibility relationships between reservoir properties, treatment parameters and fracture growth are formulated using a modified pseudo-3D fracture model. Design constraints are formulated to ensure that the final optimum design is compatible with specified equipment and formation characteristic to avoid the above-mentioned fracture complexities. The optimal design of fracturing treatments to maximize cumulative production is demonstrated in the paper by a series of applications of the model to a tight-gas reservoir. Sensitivity results of various parameters are also presented in the paper.
Severity of Water Coning in Gas Wells
Authors: Armenta M. , Wojtanowicz A. 
Published: December 2007

Abstract
Theoretical study, reported in this paper, qualifies unique mechanisms of water coning in gas wells. Water coning in gas wells has been understood as a phenomenon similar to that in the oil wells. It is shown, however that both the water inflow mechanism and its impact on well's productivity are substantially different. It is shown, for example, that, after water breakthrough, the oil-water interface at the well's completion would continue to cone, while the gas-water interface reverses at the top of the cone.
Analyzed in the paper are the results of a conventional simulation of water coning in gas wells showing that water could affect productivity only at the very late stage of well's life. However, field data, shown in the paper, evidence early and severe water problems. This contradiction is explained in the paper by including the effects of Non-Darcy flow, perforation density and the ratio of vertical-to-horizontal permeability in modeling of water coning in gas wells. Results from numerical simulation combined with analytical models show that an early water breakthrough and a considerable increase in water production may result from combined effects of increased vertical permeability, lower density of perforation and high-velocity gas flow around the wells.
Application Of The Ion Exchange Process To Reservoir Preflushes
Authors: Griffith T. David 
Published: December 2007

Introduction
The ionic environment of a reservoir is important in micellar flooding and in any other process where ion sensitive agents, such as caustic process where ion sensitive agents, such as caustic or wettability alteration fluids, are flooded through a reservoir. Ton exchange can have a major, if not the controlling influence on the composition of brines in petroleum reservoirs.
Ion exchange operations are chemical reactions between an electrolyte (the ions) in solution and an insoluble electrolyte (the clays) contacted by the solution. Clays in reservoirs behave as ion exchangers. Normally, they are in equilibrium with the reservoir brine. When fluids of a different composition, not in equilibrium with the clays, contact the clays, an exchange of ions between the clays and the fluid takes place until the two are in equilibrium. The exchange is primarily with cations (positively charged ions) primarily with cations (positively charged ions) with little, if any, anion (negatively charged ions, such as chloride) exchange occurring. To preserve electrical neutrality, the exchange is preserve electrical neutrality, the exchange is stoichiometric with respect to the charges of the ions. Material balances show that two monovalent cations (sodium) are exchanged for one divalent cation (calcium).
A relatively hard though fresh Madison water has been injected during the waterflood of the Second Wall Creek Reservoir of the Salt Creek Field. The reservoir is working as a large water softener, exchanging the calcium and magnesium from the injected water for sodium on the clays. The result is that the clays near the injectors have been hardened by the Madison water, while the clays near the producer can still remove the divalent ions and soften the injected water. This hardening process can be reversed by injection of a soft brine containing low levels of calcium and magnesium. This process is analogus to the regeneration of a water softener. Injection of a micellar fluid more saline than the Madison water would reverse the process causing high concentrations of hardness which could be detrimental to an ion sensitive micellar fluid.
The purpose of this paper is to present experimental data and model studies showing how the ion exchange process has affected and will affect the Second Wall Creek reservoir. A method for preflushing the reservoir to remove the divalent ions is also presented. Additional insights into the ion exchange process and the nature of the ion equilibrium are discussed.

Background

Theory
The ion exchange reaction is described by Equation 1
(1)
as a reversible chemical reaction between free ions (Na and Ca) in solution and ions adsorbed on the clays where X is an ion exchange site. To preserve electrical neutrality, two monovalent preserve electrical neutrality, two monovalent (sodium) ions exchange for one divalent (calcium) ion. The clay ion exchange sites can be thought of as a separate chemical species involved in the reaction.
Fracture Stimulation Optimization in the Redevelopment of a Mature Waterflood, Elk Hills Field, California
Authors: Walker Tom , Kerns Shawn , Scott Dick , White Paul , Harkrider John , Miller Craig , Singh Tarlochan 
Published: December 2007

Abstract
This paper is a case history describing fracture optimization of low-permeability highly-stratified stacked turbidite sandstone reservoirs of the B interval of the Elk Hills Field. The occurrence of high-permeability, high-pressured water saturated sands immediately above and/or below the objective oil sands poses a major challenge.
Integration of improved petrophysical understanding, geoscience techniques, hydraulic fracture model calibration and on-site, real-time execution has achieved a two-fold oil production increase in the south east nose area of the field while limiting water production to a 40% increase. Downhole tiltmeter measurements are incorporated to calibrate the fracture model and limit fracture height growth, thus regulating fracture conductivity to the oil saturated reservoirs, and minimizing contact with the adjacent wet zones.
To date, results from surface tiltmeter1 measurements completed during twenty six fracture stages have been used with the downhole tiltmeter2 data and reservoir characterization to optimize the ongoing redevelopment from a peripheral waterflood to a pattern flood.
Rapid Seismic Screening and Probabilistic Economic Methodologies for Prioritization of Targets
Authors: Toelle Brian E. , Chi Dah-Ruey David 
Published: December 2007

Abstract
The current energy environment has refocused attention on many exploration areas in Alaska. The resulting flood of new data for these areas will require rapid evaluation for the bidding rounds. New innovative approaches can help companies rapidly screen 3D seismic and prioritize prospects. Aided by the preliminary risked reserves and economic analysis, management can gain insights into the monetary worth of an area in order to make investment decisions.
The QuickSEIS 3D seismic screening process has been applied to a number of areas in the Gulf of Mexico. In an integrated process, seismic attributes are generated and blended in various combinations, and examined with modern visualization technology that allows the major structural and stratigraphic features to be identified and defined in terms of their geometry and attribute anomalies.
While Alaska’s geology is significantly different from the GOM, this technique is applicable. Combined with probabilistic economic methodologies leads to an overall reduction of project cycle time. This is especially important for areas like Alaska where a huge amount of capital is often involved.
Multiscale Reservoir Description Models for Performance Prediction in the Kuparuk River Field, North Slope of Alaska
Authors: Scheihing Mark H. , Thompson Ron D. , Seifert Dirk 
Published: December 2007

Abstract
Reservoir engineering studies of the Kuparuk River Field require reservoir description models at multiple scales. Kuparuk reservoir types range from relatively low permeability, vertically stratified and imbricated lower shoreface sandstones (A Sands) to "thiefy", glauconitic and sideritic shallow marine sandstones with complex permeability structure (C Sands). The field is also heavily faulted, having over 5200 mapped faults with throws typically between ten and several hundred feet.
Geocellular models built for type curve modeling of waterflood and enhanced oil recovery (EOR) processes capture a range of A and C Sand reservoir types. These models are 2600x2600 feet with cell dimensions of 50x50x0.5 feet. Cored wells provide a robust facies and petrophysical model. Both object- and pixel-based techniques are used together with a flow unit-scale zonation to capture key heterogeneities. In the A Sands, this requires capturing the interstratification of sandy and shaly facies using object-based methods. In the C Sands, this requires capturing permeability heterogeneities caused by facies changes and siderite diagenesis using pixel-based methods.
A geocellular model was built to evaluate options to improve throughput rate in the A Sands. This model is 24,000×20,000 feet with cell dimensions of 150x150x0.5 ft. It incorporates 237 faults and 11 flow units. Both object- and pixel-based techniques were used to distribute facies and petrophysical properties. A challenge in this model was in representing reservoir compartmentalization due to faulting of thinly bedded sandstones.
These examples demonstrate the need for "fit-for-purpose" models that best represent key heterogeneities for a given reservoir-modeling/reservoir engineering objective.
Thread Sealant Selection for the Alpine Miscible Injection Project
Authors: Erwin Michael , Ruschau Greg 
Published: December 2007

Abstract
Thread sealants in oil field service are routinely selected based on a variety of requirements including cost, lubricity, and tenacity. Early in the design stage of the Alpine Miscible Injection program concern was raised about thread sealant longevity when exposed to miscible injectant (MI). Previous experience in offsetting North Slope fields has proved that miscible injectant is an aggressive and pernicious leak finder which removes hydrocarbon based lubricants, dopes, greases and sealants from any and all exposed surfaces in wellheads, flowline valves, fittings, lubricators and threaded connections. This paper will describe the laboratory testing and selection process leading to identification of a suitable thread lubricant.
Application of Innovative Strategies and PDC Bit Technology in the Cook Inlet Basin
Authors: Smith Bobby , Langeler Mike , Penrose Bill , Perry Carey , Smith Lee 
Published: December 2007

Abstract
The paper describes recent advances in techniques for rotary drilling interbedded formations of Alaska's Cook Inlet using PDC drill bits. Until recently, use of PDC drill bits in the Hemlock formations in Cook Inlet was inconsistently successful at best. The advent of new drill bit technology that incorporates natural diamond impregnated cylinders to back up the conventional PDC cutting structure has resulted in consistent, best-in-class performance in these punishing drilling environments, as documented by case histories.
In addition, this new PDC bit technology was combined with an innovative dual penetration directional strategy which allowed the operator to maximize exposure to the target Hemlock formations. Developed by the operator in combination with the drilling crew and contractors, the U-shaped dual penetration trajectory has allowed economic commercial development of applications previously not considered PDC-drillable.
Implementation of Intelligent Well Completions Within a Sand Control Environment
Authors: Moore W. R. , Konopczynski M. R. , Nielsen V. Jackson 
Published: December 2007

Abstract
Intelligent well completions have introduced a step-change technology that improves project economics by permitting the operator to actively manage the reservoir. This aspect of asset management is especially important in those wells requiring sand control, often located in remote geographic locations or extreme operating environments, such as deepwater and ultra-deepwater, where the reserves base is high and the subsurface complex. Combining sand control technology with intelligent well technology can be a significant challenge, particularly when producing fluids from multiple, unconsolidated, high productivity zones.
To-date, the successful intelligent well completions that have been completed with sand control have been limited to a maximum of two productive intervals with full time monitoring and control. The limitation has been a result of the architecture of a gravel packed completion, requiring that the interval control valves (ICVs) and pressure and temperature gauges be placed above the zones of interest. While valuable to the asset where employed, some operators have expressed a need to have the control and monitoring equipment placed at or in the completion itself, or to have the capability of adding additional sand control completions to the wellbore.
Design solutions exist that may permit the operator to stack three or more gravel packs in a single wellbore and achieve full intelligent completion functionality. This paper will discuss those solutions and present several examples and case histories.
Revised BOP and Well Control Policies in the Kingdom of Saudi Arabia
Authors: Al-Shammari Hamoud A. , Nordquist Darrell G. 
Published: December 2007

Abstract
Effective blowout preventer (BOP) requirements and well control policies are crucial in maintaining safe drilling and workover operations. These requirements/policies generally are tailored to the individual oil and gas operator’s specific drilling environment. Changes in well profile, depth, temperature, pressure, hydrogen sulfide concentration, and safety margin may require changes in BOP equipment and well control. Saudi Aramco has recently revised their equipment requirements and well control policies in an effort to further optimize drilling safety and efficiency in the Kingdom of Saudi Arabia.
This paper discusses changes in BOP stack arrangements, kill/ choke line requirements, replacement part criteria, elastomer application limits, and use of variable bore rams and shear blind rams. Also included are requirements for number of isolation barriers, pressure testing/maintenance, and minimum overbalance. A new tripping policy and shut-in procedure are also discussed, with the introduction of a new trip sheet and kill sheets. Specific well control policies are provided.
The Use of Self Erecting Tender Rigs for Improving the Economics of Marginal Fields
Authors: Leland Anders 
Published: December 2007

Abstract
Self-Erecting Tender Rigs (SETR’s) have been used in South East Asia, West Africa and the Middle East for 30 years for drilling development wells from fixed platforms.
Inherent in the SETR concept is that equipment required to support the drilling operation such as power, living quarters, etc, is located on the tender, while only equipment actually needed for drilling such as the derrick, topdrive, BOP, etc are installed on the platform. Compared to the use of a platform rig the design load and required deck area of using an SETR is thus only about 1/4 of that needed for a platform rig of comparable capacity.
So far tender rigs have mainly been used for development drilling in water depths down to 800 ft. And this will most likely remain their main application also in the near term.
However, with increased focus on use of dry completions in deep water with the Xmas trees installed on a floating platform like a TLP or SPAR - the self-erecting tender rig concept will present many benefits for field development also in deep water, particularly for marginal field development, where the field economics may depend on solutions using small, remote controlled wellhead TLP’s.
The Legendre Field Development and Geomechanical Program: From Exploration to Drilling to Production
Authors: David Castillo , Ryles Phil , Kirsty John 
Published: December 2007

Abstract
Designing a development drilling program for the Legendre Field required a systematic approach that incorporated the lessons learned during the exploration and appraisal drilling phase. A significant part of the planning endeavor focused on arriving at a geomechanical solution that would prevent many of the instabilities and lost circulation events from being repeated. Detailed image analysis for wellbore failure, and a systematic stress and rock strength analysis was performed to identify the optimal well trajectories and mud weights to successfully drill and complete the production wells. The results of this geomechanical analysis indicated that the stress state in the Legendre Field area is associated with a strike-slip stress regime. Horizontal wells drilled sub-parallel to the maximum principal stress are optimally oriented to ensure wellbore stability in the overburden, while using a lower mud weight within the reservoir reduces the risk of massive lost circulation.
Gas Hydrates as a Resource and a Mechanism for Transmission
Authors: Makogon Yuri F. , Holditch Stephen A. 
Published: December 2007

Abstract

Gas Hydrates as a Resource
During the past century both the world population and energy consumption have increased substantially. The population has grown four-fold in one hundred years, and now exceeds 6 billion. The energy consumption has grown 9.5 times, from 0.9*109 T.O.E. (tons of oil equivalent) to 8.55*109 T.O.E. The information in Fig. 1 reflects the dynamics of consumption of different energy sources in the world. From 1850 to 1950, the main source of energy has been coal. In 1920, the percentage of coal in the world energy balance reached 74 %. In spite of rapid development of the petroleum industry, the percentage of oil has never exceeded 47 % (1972). The proven reserves of oil of 142.1*109 tons [1] is sufficient to last 40 years. At present,, the percentage of oil and gas in the world energy balance is approximately 65 %. The percentage of natural gas in the energy mix is approximately 25%, about the same as coal.
Fig. 2 illustrates the producible quantities of coal, oil, natural gas and gas from hydrate deposits, as presented earlier by Makogon.1 The data in Fig. 2 are based upon proven reserves of hydrocarbons.2 Excluding the possible discoveries of new energy sources, natural gas will be the primary fuel for the coming century for two reasons. First, natural gas is abundant in nature. We know where much of it is located. Second, burning natural gas is much cleaner than burning coal or oil. The world's proven reserves of natural gas at 1/1/2001 were 150.2*1012 m3 (135* 109 T.O.E.). Proven reserves of coal were 498*109 T.O.E.2 At the current level of consumption, the world has enough oil to last for at least 40 years. Known natural gas resources should be sufficient for 60 years or more. However, there could be much more natural gas that is trapped in the deep waters of our oceans and in the arctic in the form of gas hydrates. There are possibly enormous reserves of natural gas in the solid, hydrated state, with an estimated volume of gas-inplace of 14* 1012 T.O.E. If only 10% of that gas could be recovered, it would provide the world with gas for 180 years at the current level of energy consumption.
Rapid Assessment of 3D Seismic and Its Economic Impact
Authors: Roopa Gir , Chi Dah-Ruey David , Tushingham Keith , Xue Jack 
Published: December 2007

Abstract
New innovative approaches are now available that enable three dimensional (3D) seismic data to be rapidly screened, evaluated, and interpreted in a period of weeks, rather than months. This provides a quick and effective way to identify and define prospective targets to help optimize exploration and production (E&P) activities leading to a major impact on the net present value (NPV) of the field.
The rapid seismic screening process identifies major structural and stratigraphic features, blends the major stratigraphic features with 3D attributes, and locates amplitude anomalies via 3D Voxel screening. This process applied to 3D data from the Gulf of Mexico has revealed numerous large undrilled structures in the deeper section below and adjacent to existing fields associated with sand-prone low-stand facies. This approach for screening 3D seismic data sets reduces the risks normally associated with conventional evaluation methods. Its use significantly reduces 3D seismic evaluation time and increases information quality, helping asset managers find and evaluate drilling opportunities quickly and accurately.
Improvements on project economics through the use of this process are demonstrated in a number of economic impact analyses. Typical values of production, commodity prices, and costs from a Gulf of Mexico region are used in various cases to quantify the economic benefits of the rapid seismic screening process. The economic impact of this rapid seismic screening and interpretation approach can be clearly shown.