bluuebunny/crossref_metadata_2025_split huggingface dataset:
Testing Methodology for the Preliminary Assessment of Mechanical Performance of Materials for Expandable Applications
Authors: Bufalini A. , Morana R. , Nice P. I. , Nasvik H. , Kjørholt H. , Bailey B. M. , Adam M. K. , Jiral D. G. , Ross R. C. , Smith R. C. 
Published: February 2011

Abstract
While the introduction on the market of expandable casing has undoubtedly been successful, the full potentiality of this technology seems not yet accomplished. Uncertainties related to the reliability of expandable applications prevent the full exploitation of expandable tubular technology to reduce well construction costs and improve well productivity.
One key limiting factor is the incomplete knowledge of the mechanical performance after expansion of the materials used for the expandable casing. This is partially due to the lack of industry consensus on the most appropriate methods to measure post-expansion material performance. Also constraining is the availability of materials expanded by the methods used downhole.
As a consequence, an extensive experimental program was started by Statoil with the goal of identifying suitable testing methodologies to predict the post-expansion mechanical properties by analyzing a material only in its initial conditions. This paper describes the testing methods developed and compares the results obtained on as received materials with the results of tests carried out on the same materials after laboratory expansions performed specifically for this program.
The results show that it was possible to obtain a good estimate for post-expansion material properties like tensile yield, compressive yield and strain aging effect, enabling the prediction of post-expanded pipe performance ratings. The calculations of post-expanded collapse pressure were then compared with the results of actual collapse tests on expanded samples, showing good correlation both for expanded material and, when appropriate, for expanded and aged material. A procedure to perform a quick assessment of materials for expandable applications, based on the tests identified, is then proposed and discussed.
Real-Time Reservoir Characterization and Geosteering Using Advanced High Resolution LWD Resistivity Imaging
Authors: Al-Musharfi Nedhal , Bansal Radhey , Ahmed Mahbub , Kanj Mazen , Morys Marian , Conrad Chris , Chemali Roland , Lotfy Amr , Bayrakdar Mohammed , Parker Tim 
Published: February 2011

Abstract
A recently introduced azimuthal resistivity LWD imaging tool has been upgraded with advanced high resolution sensors that are capable of differentiating reservoir and borehole features down to a size of 0.4 in. when drilling in well consolidated formations. The high vertical and azimuthal resolution, along with 100% borehole coverage, yield an image quality comparable to that of wireline service for applications that include fracture characterization and formation evaluation.
This paper describes a field test of the high resolution tool in 5 7/8" and 8 3/8" holes in Saudi Arabia and shows the application of LWD images for estimating carbonate reservoir producibility involving the characterization of secondary porosity. The LWD imager provides significant economic and logistic benefits, especially in slim horizontal sections; in addition, it can identify fractured zones with mud loss potential shortly after penetration. The real-time resistivity provides a good basis for accurate dip calculation and geosteering in general.
In its default configuration, the high resolution tool is equipped with six high resolution sensors arranged in two rows. One of the benefits of the multi-sensor configuration, demonstrated by the field test, is the ability to validate the image quality by comparing data from various sensors. Another benefit is the depth correction achieved by correlating images from identical sensors located at various depths.
The paper also discusses the fundamental principles behind high resolution resistivity imaging in conductive mud and makes extensive use of modeling techniques to characterize the sensor performance in various practical situations.
Comparison of Chemical and Hysteresis CO2 Trapping in the Nugget Formation 2
Authors: Behzadi S. H. 
Published: February 2011

Abstract
The Moxa Arch Anticline is a regional-scale northwest-trending uplift in western Wyoming and it has been chosen for CO2 capture and storage. The Nugget Sandstone is a deep saline aquifer that has been a candidate for CO2 storage. In this paper we compare the amount of mineral and solution trapping in comparison with dynamic hysteresis trapping based on compositional simulation. To the best of our knowledge this is the first paper to computationally assess the chemical trapping in the Nugget formation and to compare these three trapping mechanisms against each other.
Reaction-path and kinetic modeling of CO2–brine–mineral reactions in the Nugget formation was investigated to probe the factors that affect capacity for CO2 chemical trapping. The geochemical simulation of this system was explored in order to assess how mineralogy might change and the relative importance of mineral and solution trapping phenomena through time. Mineral trapping is simulated with both GWB and GEM-GHG. The maximum mineral trapping is 5 g of CO2 per ton of reacted rock, and solution trapping is 3.47 g/kg rock. In comparison, a recent computational study of the Rose Run sandstone, Ohio indicates a much higher mineral trapping capacity, mainly because of reservoir pressure in addition to the presence of glauconite as an iron source for siderite formation.
These results reveal that mineral trapping in the Nugget formation is not significant but that total chemical trapping might be much more than that of hysteresis trapping. Therefore, the contribution and importance of chemical trapping in CO2 sequestration should be taken into account for assessment of CO2 sequestration.
Case History Using ESP's to De-Water Horizontal Wells
Authors: Bassett Lonnie 
Published: February 2011

Abstract
Over the past 20 years, the evolution of de-watering unconventional gas wells has gone from simple vertical to more complex horizontal wells. Each has had it learning curve and each has had its own challenges to overcome. No application has been more challenging that getting results for de-watering horizontal wells.
This paper will focus on real case histories of this learning curve and discussion on what has worked best and what has not worked at all. We will discuss methodologies that were used to overcome specific challenges and although it is recognized that each application is different, these two case histories will show the commonalities that can be seen in all horizontal unconventional gas wells. No claim can be made that all wells are alike and this paper will not make this claim. However, these two examples will show that there are similarities that can be universally addressed and if nothing else it gives a better starting point without having to reinvent the wheel.
The paper will cover specific wells, each with a different completion technique and the challenges faced by each. This paper will cover new information not yet submitted under any review and showcase methods used to solve these challenges.
Specific examples will be shown how the initial attempts to draw the well down and subsequent gas production was hampered by old techniques and what was developed that let to a fourfold increase in gas production by being able to de-water below the bend.
1. Electric Submersible Pumps (ESP's) best practices for a horizontal well: A horizontal well is a place an ESP's flexibility can really shine. This paper will identify the key areas that drastically improve the chances of success. The paper will identify the operational differences and the different options in running in a horizontal well compared to a vertical well. It will cover the preplanning required to avoid negative operational issues including gas locking, solids intrusion and optimized draw down.
This paper will concentrate on horizontal wells and highlight techniques that will increase the effectiveness of utilizing ESP equipment for dewatering.
Development of a Steam-Additive Technology to Enhance Thermal Recovery of Heavy Oil
Authors: Srivastava P. , Sadetsky V. , Debord J. , Stefan B. , Orr B. 
Published: February 2011

Abstract
Steam assisted gravity drainage (SAGD), cyclic steam stimulation (CSS) and steam floods are widely employed in the industry to extract heavy oil. These techniques use steam to lower the viscosity of bitumen, which translates into improved production. Sustainability of the enhanced production is primarily dependent on the ability to generate large volumes of steam. Steam generation consumes large amounts of natural gas and leads to higher CO2 emissions, which impacts profitability of the SAGD operation and the environment in a negative way. This problem, a technological void, calls for a solution with higher oil production for the same level of steam consumption, and thus higher profit margins. This paper reports how adding a chemical to the steam enhances production rates and recovery factor from the Alberta Oil Sands. The steam pumped into the reservoir serves as a carrier for the chemical additive. The additive allows condensed water to retrieve more bitumen by allowing higher mobilization of the bitumen deposits. Laboratory-scale simulations were conducted using a gravity-driven displacement process. Steam at 200°C and 2000 kPa was passed over an unconsolidated oil sands core sample. The results of the experiment were highly encouraging. An additive dosage rate of 1000 ppm resulted in a 13.5% increase in heavy oil recovery compared to the baseline (no additive, pure steam). This enhanced production at a low dosage rate of 1000 ppm prevents the need for any economically driven recovery of the chemical additive.
Wellbore Strengthening: The Less-Studied Properties of Lost-Circulation Materials
Authors: Kumar Arunesh , Savari Sharath , Whitfill Donald L. , Jamison Dale E. 
Published: February 2011

Abstract
Lost circulation is one of the major issues that lead to unwanted non-productive time (NPT) while drilling with a narrow mud weight window and it requires engineered solutions to address the problem. In several instances in the past, wellbore strengthening was achieved by treating the drilling fluid with lost circulation material (LCM), utilizing Stress Caging or Wellbore Strengthening theory. Small fractures were propped and sealed with a proper size distribution of particles that isolates the fracture tip from fluid pressure and controls the fracture propagation, effectively increasing the near wellbore hoop stress.
Laboratory data and field experience indicate limited success may occur if a single material such as sized calcium carbonate is used alone for wellbore strengthening. This is possibly due to size reduction that may occur while drilling or due to fracture closure stresses (FCS) acting on the particles. However, using calcium carbonate in conjunction with resilient graphitic carbon (RGC) material has shown to be effective in increasing the formation integrity.
The effect of mechanical properties of LCMs on wellbore strengthening has been investigated using compression/crush tests at different confining pressures simulating a wide range of FCS. Crush test demonstrated compaction and significant crushing of the ground marble and ground nut shells at high confining pressure (~ 5000 Psi). Considerable improvement in the crushing resistance and resiliency of these materials was observed with small additions of RGC. Knowledge of deformation and failure behavior of different LCM materials may result in better design. In this paper recommendations are made on different combinations of LCM that may be used more effectively to provide wellbore strengthening.
The Late Miocene Coalbed Methane System in the South Sumatra Basin of Indonesia
Authors: Mazumder Saikat , Sosrowidjojo Imam B. , Ficarra Alessandro 
Published: February 2011

Abstract
The purpose of this paper is to provide a view on the South Sumatra basin CBM development potential. The basin ranks as one of Indonesia's most prospective coalbed methane (CBM) basins, but well testing is still in the earliest stages. In S. Sumatra basin there are three distinct identifiable sub-basin evolution periods. First, a period of horst-graben development controlled by major localized extensional faults that initiated the basin architecture. This episode was followed by rapid to moderate sedimentation controlled by normal faults resulting in deposition of Oligocene Talang Akar alluvial, fluvial and deltaic deposits. Secondly, a period of decreased fault activity along with regional subsidence coinciding with the deposition of the post-rifting Miocene Air Benekat and Muara Enim Formations. The third period is marked by regional uplift resulting in wide spread basin inversion over the entire region. Coal seams in the Muara Enim Formation are thickest and most numerous in the SW half of the South Sumatra basin representing key target for CBM development. This is the axial region of the basin where the subsidence has been most pronounced and the formation is thickest. While the coals are quite thick and laterally extensive in the broad synclines, most of the Miocene Muara Enim Formation has been eroded out along the anticlines. The Lematang Depression and the Central Palembang sub-basin are considered the most prospective CBM areas on the basis of coal thickness, depth, and gas kicks on mud logs. The Muara Enim formation comprises more than 3500 ft of paralic sandstones and mudstones, with thick intercalated coal seams. Typically some 10 to 15 individual coal seams are present.
The coals are of sub-bituminous rank and characterized by low vitrinite (huminite) reflectance (VRr = 0.35 – 0.46%). These low rank coals are dominated by huminite (34.6 – 94.6 vol. %). Less abundant are liptinite (4.0 – 22.5 vol. %) and inertinite (0.2 – 43.9 vol. %). Minerals are found only in small amounts (0 – 5 vol. %); mostly as iron sulfide. Kaolinite occurs as cleat fillings at some places. The coals are characterized by high moisture content (4 – 21 %) and volatile matter content (&gt; 40 wt.%, daf), and less than 80 wt. % (daf) carbon cotent.
CO2 and CH4 sorption isotherms on six different coal samples were carried out at reservoir temperature. Given the uncertainty around the gas content measurements, the coals tend to suffer from some serious under saturation. The sorption capacities of the coals tend to decrease with increasing depth. This behavior can either be related to the increasing moisture content of the coal with depth or with the significant variation of the vitrinite content of the deeper seams. The high CO2 adsorption capacity and the low rank tend to make these coals ideal targets for CO2 sequestration.
Advanced Sand-Face Completion Design and Application in Gas and Gas-Condensate Fields
Authors: Al-Khelaiwi F. T. , Davies D. R. 
Published: February 2011

Abstract
Sand-face completion technology for gas wells has evolved to overcome problems associated with sand and water production. Frac-packs, gravel packs, screens and oriented or selectively perforated completions have all been applied to gas wells to maintain wellbore integrity and control expected, late-life production challenges. However, none of these completion designs are capable of managing variable productivity, pressure or sanding tendency when producing multiple reservoir layers into a single wellbore. The result is premature water and (often) sand production. Intelligent completions employing Interval Control Valves (ICVs) can successfully manage these problems. However, not only are there limitations on the number of zones that can be separately controlled, but the hardware is also susceptible to the increased erosion potential of the high flow velocities associated with gas production.
Inflow Control Devices (ICDs) are an alternative Advanced Well Completion (AWC) technology. An ICD employs a passive flow restriction mounted on each joint of tubing or sand-control screen. The Autonomous Inflow Control Device (AICD) adds an "Active" water shut-off element to the flow equalisation provided by the standard ICD. An (A)ICD completion consists of multiple joints of (A)ICD equipped tubing separated into the required number of zones by Annular Flow Isolation (AFI). Such completions have the ability to equalise the gas inflow from many more layers (or even separate reservoirs) than is possible with an ICV or separated conventional completion.
This paper will present a critical evaluation of the ICD and AICD technologies together with a novel design methodology for their application to gas fields. This will be complemented by two case studies based on real data from both a gas and a gas- condensate field. These studies will be used to illustrate the application of the design workflow along with the potential advantages and added value derived by installing (A)ICD completions.
This design methodology and the field studies provide the basis for an extension of the (A)ICD's application envelope.
Henry Subsea Development - Challenges and Solutions
Authors: Henzell Stephen , Glucina Andrew 
Published: February 2011

Abstract
The Henry and Netherby gas fields are located in Victorian waters in South East Australia. They have been developed by extending the Casino production system which comprises two subsea wells in the Casino field producing by offshore and onshore pipelines to an onshore gas plant. The entire Henry and Netherby development is subsea, connecting to the Casino pipeline in 70 metres of water.
During the Casino design, provisions were made for future extension of the production system. This paper discusses the provisions made and their effectiveness during the expansion project. The paper also discusses some of the challenges encountered by the project team and how they were overcome.
Specific project challenges included dewatering the pipeline extension without direct access to a production facility, pressurization of the pipeline extension and safe removal of nitrogen from the pipeline extension. The paper also covers the hydrate management of the extension wells, pipeline hydraulics and commercial issues that affected the project development.
Living in Harmony—Gas Production and the Attwater's Prairie Chicken
Authors: Haut Richard C. , Bergan James F. , Judy Jared , Price Liz 
Published: February 2011

Abstract
Over a century ago, one million Attwater's prairie chickens graced the coastal grasslands of Texas and Louisiana. Today, less than 1% of their native habitat remains and in 2009, it was estimated that only 90 remained in the wild at three different locations. The remaining nearly 260 Attwater's prairie chickens are in captive rearing facilities throughout Texas. One of the last remaining locations where the Attwater's prairie chicken is found in the wild is the Texas City Prairie Preserve that was set aside near Texas City and is owned by The Nature Conservancy (TNC). The Conservancy has leased oil and gas production on the Preserve and works to balance production with the conservation and recovery of the Attwater's prairie chicken.
The Houston Advanced Research Center (HARC) is leading an industry consortium effort, the Environmentally Friendly Drilling Systems (EFD) Program, to investigate the development of cost-effective, low impact drilling and production systems and to reduce the environmental tradeoffs associated with operations. The work originated in 2005 when co-funding was obtained by the U.S. Department of Energy and industry. Additional funding for the effort was obtained through the Research Partnership to Secure Energy for America (RPSEA).
The paper documents how HARC and TNC partnered to investigate if and how noise from production operations affects the Attwater's prairie chicken. An electrical submersible pump (ESP), powered by a 500 kW diesel electric generator, was installed in a gas well to increase production. Attwater's prairie chicken locations and movements were monitored prior to, during the workover, and following the installation of the pump (operation of the diesel generator). Noise measurements for the operation of the diesel generator were recorded. Locations of Attwater's prairie chickens were compared to the before, during and after time periods relative to the ESP installation.
History Matching With Learned Sparse Dictionaries
Authors: Khaninezhad Mohammad-Reza M. , Jafarpour Behnam , Li Lianlin 
Published: February 2011

Abstract
History-matching of heterogeneous hydrocarbon reservoirs is carried out to construct predictive reservoir models that: i) provide accurate predictions of fluid displacement and future reservoir production behavior; ii) honor all existing measurements; and iii) preserve prior knowledge about geological continuity. Estimating individual gridblock heterogeneous reservoir properties from limited static data and spatially averaged dynamic production measurements inherently leads to an ill-posed inverse problem that can have several non-unique solutions. Many geologic formations consist of a finite number of continuous rock types (facies) with distinct hydraulic properties and spatial distributions that constrain the global fluid displacement patterns. In such cases, a feature-based history-matching technique (instead of gridblock property estimation) is more appropriate. In this paper, we present a novel and geologically motivated feature estimation method for solving history-matching problems more effectively and consistently. Using an ensemble of prior geologic models, we apply a sparse learning algorithm to generate a large number of geologically relevant model elements (similar to "words in a dictionary"). The sparsity of the constructed dictionary implies that only a small set of dictionary elements (i.e., "words") are needed to construct, according to the information in the static and dynamic production measurements (i.e., "intended meaning"), a history-matched model (i.e., "a sentence"). The sparse learning method used to generate the geologic dictionary is a recently developed machine-learning algorithm known as K-SVD. The K-SVD algorithm builds a "sparse dictionary", with flexible dimensionality, from a prior model library. An important property of the geologically learned dictionary is that only a small set of its elements is needed to reconstruct the history-matched model (i.e., solution sparsity). To achieve solution sparsity, we implement an iteratively reweighted (sparsity) regularized least-squares algorithm to selectively combine and weigh a small subset of relevant model elements from the learned dictionary that explains the observed data. We use several examples from fluvial formations with channel features and Tarbert-like formations resembling prograding near shore depositional environments, to illustrate the validity and effectiveness of the proposed history matching approach.