bluuebunny/crossref_metadata_2025_split huggingface dataset:
Data Driven Analytics in Powder River Basin, WY
Authors: Maysami Mohammad , Gaskari Razi , Mohaghegh Shahab D. 
Published: June 2014

Abstract
In the past few years, we have observed the introduction of smart technologies that adapt themselves to the specific needs of individual users. There are many mobile and web-based services with learning capabilities that play the role of a personal assistant in our daily life. The foundation of this new class of services is a paradigm shift from intensive computational modeling and simulation of complicated phenomena toward data driven analytics. The oil and gas industry with the uncertainties convoluted into our measurements and understanding of the subsurface should not be excluded from this recent paradigm shift. Data driven analytics have proven to be a powerful alternative to conventional numerical and analytical solutions. In their advanced form, data driven technologies may be used as comprehensive management tools of oil and gas assets.
In this paper, we study Hilight field in Powder River Basin, a mature field with large number of wells. Lack of sufficient dynamic data such as flowing pressure for mature fields is common among these types of fields. Conventional data analyses impose a challenge in the absence of time-variant field measurements in addition to production history. Acquisition of a comprehensive data set for oil and gas assets, in general, is a costly luxury that is not financially feasible for all investment budget ranges. Data-driven approach along with pattern recognition techniques can introduce a potential solution to this challenging task and extract practical and valuable insights which can be vital to identification, planning and developments of assets and plays.
In this work, data from nearly 400 wells has been analyzed. Data from completion and workover was partially available. Well logs for only 15 wells is accessible providing less than 10% petrophysical data attributes over the entire well sets. Available production rate history for 185 wells starts from June 1969 and extends until April 2012. The information value of this dataset is investigated through a multi-step workflow. The workflow includes reservoir delineation and geological modeling, volumetric reserve and recovery factor estimations, production decline curve analysis, fuzzy pattern recognition (FPR) analysis and key performance indicators (KPI) analysis. FPR analysis provides time-laps spatial patterns, enabling us to qualitatively study the reservoir depletion and fluid flow in Hilight field. The result of these analyses has been used to identify the depletion distribution over time and sweet spots for infill locations. KPI analysis identifies relative influence of different parameters on hydrocarbon production. Top-Down Model is developed and used for field development planning and economic analysis on proposed new wells. The workflow has a minimal computational footprint compared to conventional methods. It has been demonstrated how these data driven techniques can be employed as a guide toward an improved reservoir management and planning.
All in One for Casing while Drilling Technology: Numerical, Analytical, and Experimental Results and Field Observations
Authors: Salehi S. , Karimi M. , Shahri M. P. , Aladsani A. , Ezeakacha C. 
Published: June 2014

Abstract
Casing while Drilling (CwD) is an efficient method by which to increase the fracture gradient in narrow pore-fracture pressure sedimentary basins and deep offshore applications. It offers hydraulic improvements and the ability to plaster cuttings to the wellbore wall, which can enhance the wellbore's hoop stress by wedging the created fractures. Although successful field applications of increasing wellbore integrity have been reported, uncertainties remain regarding the mechanisms and how to operationally capture the maximum attainable wellbore pressure. These uncertainties include the hydraulic complexities of fluids, role of Particle Size Distribution (PSD) and how it relates to the plastering effect, type of drilling fluids, borehole shape, role of lost circulation materials (LCM), and casing eccentricity.
This paper presents numerical, analytical and experimental methods to study the contributing factors in CwD applications. Laboratory experiments were conducted to evaluate the Particle Size Distribution (PSD) and filtration rate of the mud mixed with cuttings from a recently drilled well. Several tests were conducted using Permeable Plug Testing (PPT) equipment to evaluate the role of different LCMs, to fill the PSD gap and to capture the strengthening effect.
In addition, advance finite-element methods were used to model the near wellbore area and hoop stress changes with consideration of the formation's poro-elastic properties. Furthermore, the frictional pressure lost during the CwD operation was evaluated using Computational Fluid Dynamics. Analytical models were used to investigate different boundary conditions when applying finite-element analysis.
The numerical simulations and laboratory experiments in this work were based on a recently drilled well in South Louisiana, where severely depleted sections were drilled successfully. Previous drilling records in this area report multiple problems with lost circulation, tight holes and other wellbore stability issues. Results from the numerical models and laboratory experiments agree well with field observations. The analysis presented in this paper indicates that an optimum PSD can significantly mitigate lost circulation and minimize the need to add LCM.
Rubble Zone Below Salt: Identification and Best Drilling Practices
Authors: Saleh S. , Williams K. E. , Rizvi A. 
Published: June 2014

Abstract
A joint-industry project (JIP) from 2005 through 2009 involved acquiring, analyzing, and documenting more than 100 subsalt wells in the Gulf of Mexico (GOM), from shelf to deepwater. The result of this unique study culminated in the compilation of a large and comprehensive database of pertinent petrophysical, geophysical, and drilling data. This database was used to develop a set of suggested best practices for pore-pressure estimation below and around salt bodies. An analysis of the wells in the subsalt JIP indicated that the majority (64%) of the wells studied demonstrated evidence of a subsalt gouge or rubble zone. Sufficient data for this analysis was obtained from 87 JIP wells. Statistical analysis of this large database allowed a wide range of correlations to be established for the subsalt rubble-zone occurrence with salt body structural and geological features. An early diagnostic of rubble zones using logging while drilling (LWD) tools can trigger certain drilling practices to be employed.
This paper presents the diagnostic criteria for a subsalt rubble zone and several other confirmatory criteria. The diagnostic identification for a subsalt rubble zone is small-scale discordance between the gamma ray and the resistivity log in the interval immediately below the salt. The relationship between rubble-zone occurrence and salinity changes is discussed.
Drilling subsalt rubble zones can be challenging. This paper documents current industry methods for drilling subsalt wells based on the analysis of multiple sources of data. In addition to the subsalt database, data was compiled from an industry questionnaire designed to capture current practices for drilling subsalt wells, a survey and reviews on subsalt drilling-related published literature, and personal interviews with industry professionals.
This paper focuses on the following key subsalt (with and without a rubble zone) drilling issues of interest to well-construction professionals: the drilling window, casing setting, loss of circulation, wellbore stability, mud-weight scenarios, and leakoff tests. Highlights of each of the aforementioned drilling issues are presented along with well examples.
A Dynamic Imaging Particle Analysis System for Real-Time Analysis of Drilling Muds
Authors: Brown Lew , Duplisea Matthew , Bowen Steve 
Published: June 2014

Abstract
This paper details a novel new system for real-time analysis of drilling muds. The system uses in-flow digital imaging to capture images of all particulates in drilling mud. Sophisticated image processing algorithms are used in real time to segment each particle from the background, and record over 30 size, shape and gray-scale measurements for each particle. Particle size and shape distributions are produced in real-time, and are used for trend analysis.
This system can be integrated into any part of the drilling flow loop for analysis at any point in the process. Using a unique auto-dilution system, the concentration is automatically adjusted for optimum presentation of the particulates to the imaging system. Since every particle image and its measurements are saved by the system, it creates an ironclad audit trail for how particle size distributions are derived.
While the basic system architecture is very robust and could be used in many different applications, the system presented here has been fully optimized for the analysis of particulates in drilling mud.
Real-world data collected in the field is shown illustrating typical results from the system. A brief description is provided on how the system works in real-time, including how the particle images are acquired and measurements made. Finally the results of the analysis are shown, detailing how the system can be used to monitor particle size and shape distributions from any part of the flow loop. This resulting analytical data becomes an integral part of the real-time operation of the drilling platform, ensuring continuous optimization of the drilling mud particulate content. This optimization is critical to the performance of the drilling mud, for cooling and lubrication of the drill bit, interacting with the surrounding geology and maintaining proper rheological characteristics.
This system represents a new way of proactively monitoring drilling mud content in real-time, and provides more information than prior systems because the system can measure particle size as well as shape. Particle shape information can be used by the system software to automatically classify particulates into different component types.
Modeling Wellbore Transient Fluid-Temperature and -Pressure During Diagnostic Fracture Injection Testing in Unconventional Reservoirs
Authors: Nojabaei B. , Hasan A. R. , Kabir C. S. 
Published: June 2014

Abstract
Diagnostic fracture injection testing or DFIT has gained widespread usage in the evaluation of unconventional reservoirs. The DFIT entails injection of water above the formation-parting pressure, followed by a long-duration pressure falloff test. This test is a pragmatic way of gaining critical reservoir information, such as the formation-parting pressure, fracture-closure pressure, and initial-reservoir pressure, leading to fracture-completion design and reservoir-engineering calculations.
In typical field operations, pressure is measured at the wellhead, not at the bottomhole, because of cost considerations. The bottomhole pressure (BHP) is obtained by simply adding a constant hydrostatic head of the water column to the wellhead pressure (WHP) at each timestep. Questions arise whether this practice is sound because of significant changes in temperature that occur in the wellbore, leading to changes in density and compressibility throughout the fluid column. The paper explores this question and offers an analytical model for estimating the transient temperature at a given depth and timestep for computing the BHP. Furthermore, based on the premise of line-source well, we showed that the early-time data can be represented by the square-root of time formulation, leading to the new modified-Hall relation for the injection period.
The Development of a Geopolymer-Based Pill as an Engineered Solution to Lost Circulation
Authors: Miller Matthew L. , Scorsone Jason T. , Whitfill Donald L. , McDonald Michael , Miller Neil 
Published: June 2014

Abstract
Lost circulation is a common and highly varied drilling challenge. Whole fluid loss can be the result of entry into a highly permeable zone, vugular formation, or natural or induced fracture. Losses are further impacted by variables such as engineering practices, wellbore conditions, type of fluid (drilling, completion, cement, etc.) and formation properties. A variety of materials and techniques have been developed to stop lost circulation and stabilize the wellbore. One of the more common fluid solutions is the use of a dedicated pill formulation. These technologies may be comprised of particulate and/or fibrous material that is completely inert, or may be a chemically reactive solution that is triggered to form a sealant throughout the thief zone. Historically, these pills have proven highly effective, but most function under a narrow set of conditions. Another technical limitation for the materials used as a pill treatment is lack of structural integrity (strength) and a reduced tolerance to higher temperatures.
This paper presents a comprehensive summary of the development of a new type of chemically reactive pill based on aqueous alkali alumino silicate as the key component. The aqueous alumino silicate is a low molecular weight, low viscosity solution that is sometimes referred to as a "geopolymer". Set times can range from several minutes to several hours based on the type and concentration of setting agent. By controlling the type, size and quantity of particulate material in the chemically reactive pill formulation, properties such as density, temperature resistance, strength and flexibility can be regulated to suit a wide range of lost circulation challenges.
Models were developed on factors affecting set times, as well as properties of the uncured and cured formulas. These results are utilized to design a lost circulation pill that could be easily pumped through a bottomhole assembly over a wide range of loss rates and downhole conditions. The alumino silicate pill can provide strength properties approaching those of cement with a corresponding tolerance of high downhole temperatures. The environmental characteristics of the system and the economics of its application are also presented.
Production Gains through Reuse of Frac Fluids for Hydraulic Fracturing: A 10-Year Study
Authors: Monroe S. , McCracken D. , Dawson K. , Mouallem S. 
Published: June 2014

Abstract
The rapid expansion in the use of hydraulic fracturing to unlock unconventional hydrocarbons over the last five years has created significant challenges in the management of water. The US Environmental Protection Agency (EPA) estimates that 3.3 billion barrels of water were used in 2010 for fracturing in North America. Costs associated with the management of water, from sourcing through disposal, have been estimated to comprise as much as 15% of the overall cost of a well (Slutz et al. 2012).
Reuse of produced and flowback water to reduce costs has been an area of focus within the industry, but has yet to become the standard practice. While cost-effective technical solutions exist to treat these waters for reuse as an alternative to fresh water, a more fundamental question remains: What is the long-term impact on production by changing from the accepted practice of freshwater use to the use of produced water for hydraulic fracturing?
This paper details a 10-year production analysis from a 48-well project completed in 2001 (Gupta and Hildek 2009). Comparing results using fresh water against those using flowback water for hydraulic fracturing suggests that reuse results in better initial production as well as equivalent production over 10 years.
Mangala Well and Reservoir Mangement: The Journey to 150,000bopd
Authors: Kumar Verma Sumil , Prasad Dhruva , Tandon Rohit , Kumar Pankaj , Kumar Singh Aditya 
Published: June 2014

ABSTRACT
The Mangala field in the Rajasthan state of western India was the first major oil discovery in the Barmer Basin having a STOIIP of over 1.3 billion barrels in multiple stacked fluvial clastic reservoirs. It contains medium gravity (20-28 °API), waxy, viscous crude (9-17 cp) in high permeability (1-25 Darcy) clean sandstone reservoirs. Mangala field is on production since 2009 and is currently producing at 150k bopd.
The field has a comprehensive reservoir Management plan (RMP). As per the RMP, an active reservoir surveillance plan of data acquisition and analysis is being continuously executed in the field. The key data acquisition included Pressure surveys, Production and injection logging, well and network modeling, Reservoir saturation logging, Interference testing, well & artificial lift parameters.
Several challenges and production and injection problems were identified and were addressed in a step wise manner. The well and reservoir performance for ∼ 2 years suggested higher production capacity. Detailed well modeling and surface network modeling was carried out and it was seen that after the installation of Artificial lift, the ongoing production enhancement efforts, continuous reservoir surveillance and management, the field had capacity to produce at a plateau rate of 150k bopd. Simulation studies suggested no detrimental effects on the ultimate recovery.
The plateau rate of the field was increased from approved FDP rate of 125k to 150k bopd, after due approvals and the field has been producing at this rate since April 2012. This paper presents the summary of:
Data acquired during the production phase of 125k bopd Major problems identified in the field and there mitigation Well and Network Modeling Study History of field post plateau rates of 150k bopd. Challenges being faced to maintain 150k bopd
A Successful Trial of Special Downhole Completion for Optimizing Injection Profile in a Highly Fractured Horizontal Well
Authors: Al-Abdulmohsin Yousif A. , Al-Mosa Muhanad A. , Al-Jandal Ahmed A. , AL-Ghafli Hashem A. , Al-Mulhem Abdullah , Kamal Ramy , El-Tonsy Mohamed 
Published: June 2014

Abstract
Uniform injection profile is a reservoir management goal for better sweep efficiency and uniform flood front displacement. Natural and thermal induced fractures in tight reservoirs are difficult to avoid, especially when drilling horizontal wells. Evolving well completion technology has introduced several completion types to delay premature breakthrough by isolating fractures in horizontal wells. In the targeted area where tight rocks and natural fractures exist, several of these completion technologies have been tested on horizontal oil and water wells.
This paper will detail a recent successful trial of a special downhole completion design that provides improved capability for controlling fluid distribution in highly fractured horizontal wells. Also, it will provide information on the reservoir performance after full implementation of this design. The completion design integrates two field proven technologies, inflow control device (ICD) and inflow control valve (ICV) technologies, for maximum reservoir management and control. This unique design was specially tailored to suit a well case in the largest onshore oil field in Saudi Arabia. The primary objective of this completion is to achieve formation compartmentalization and fracture control and isolation in very heterogeneous formations. The completion is also designed to provide intervention capability for future coiled tubing (CT) operations to stimulate or isolate any well section. This functionality will ensure maximum completion performance to achieve even fluid distribution into the induced thermal and natural fractures, thereby optimizing injection profile along the well path, especially for seawater flooding wells.
Environmental Risk Arising From Well Construction Failure: Difference Between Barrier and Well Failure, and Estimates of Failure Frequency Across Common Well Types, Locations and Well Age
Authors: King George E. , King Daniel E. 
Published: June 2014

Abstract
Do oil and gas wells leak to the environment? The great majority of wells do not pollute. The purpose of this paper is to explain basic concepts of well construction and illustrate differences between single barrier failure in multiple barrier well design and outright well integrity failure that could lead to pollution, using published investigations and reviews from data sets of over 600,000 wells worldwide. For US wells, while individual barrier failures (containment maintained and no pollution indicated) in a specific well group may range from very low to several percent (depending on geographical area, operator, era, well type and maintenance quality), actual well integrity failures are very rare. Well integrity failure is where all barriers fail and a leak is possible. True well integrity failure rates are two to three orders of magnitude lower than single barrier failure rates.
When a series of barriers fail and a leak path is formed, gas is the most common fluid lost. Common leak points are failed gaskets or valves at the surface and are easily and quickly repaired. If the failure is subsurface, an outward leak is uncommon due to lower pressure gradient in the well than in outside formations. Subsurface leaks in oil wells are rare and are routinely exterior formation salt water leaking into the well towards the lower pressure in the well.
Failure frequency numbers are estimated for wells in several specific sets of environmental conditions (location, geologic strata, produced fluid composition, soils, etc.). Accuracy of these numbers depends on a sufficient database of wells with documented failures, divided into: 1) barrier failures in a multiple barrier system that do not create pollution, and 2) well integrity failures that create a leak path, whether or not pollution is created. Estimated failure frequency is only for a specific set of wells operating under the same conditions with similar design and construction quality. Well age and era of construction are variables. There is absolutely no one-size-fits-all well failure frequency.