bluuebunny/crossref_metadata_2025_split huggingface dataset:
Advanced Reservoir Navigation System and Drilling Technology Maximizes Productivity and Drilling Performance in the Granite Wash - US Midcontinent
Authors: Janwadkar S. , Thomas M. , Privott S. , Tehan R. , Carlson L. , Spear W. , Setiadarma A. 
Published: March 2011

Abstract
The Granite Wash unconventional gas and oil play of US Midcontinent has a multi-trillion cubic feet equivalent upside potential. The condensates and natural gas liquids associated with this gas play make it one of the most prolific and fastest growing unconventional fields in North America. However, efficient extraction of hydrocarbons from the Granite Wash play poses drilling and geological challenges. The Granite Wash deposit has significant lateral variation; in some locations the thickness of the sandstones bodies associated with gas shows are approx 1 to 3 feet thick, and the formations are extremely abrasive. Geological complexity of this field requires precise placement and navigation of the wellbore in real-time to overcome the variable characteristics of the reservoir. To overcome these challenges, logging while drilling (LWD) technology was used in conjunction with geo-steering. The azimuthal gamma ray image was used to determine formation bed dip and stratigraphic complexity within the reservoir. The multiple propagation resistivity measurements were used to correlate position within the reservoir and indicate formation porosity. The LWD data was transmitted in real-time via satellite to a remote reservoir navigation center where the reservoir navigation engineer incorporated the real-time data into the geological model. This strategy has been implemented to drill with excellent results as compared to the offset wells. The initial production rate obtained was 19.4 MMcfe/d. The well was completed 10 days ahead of schedule, resulting in significant cost savings. With the successful implementation of advanced real-time reservoir navigation and drilling technology, the operator has accelerated the drilling program. The results are significant organic production growth, improved drilling performance, precise placement of the wellbore and, significant reduction in rotating hours at lower drilling and production costs.
Thermally Compensated Leak Detection Results in Significant Blow Out Preventer (BOP) Testing Efficiencies
Authors: Franklin C. M. , Sargent T. L. , Brown C. R. , Owen G. W. , Griffith S. , Osmond J. W. , Cully R. 
Published: March 2011

Abstract
Operators, service provides, and drilling contractors established an industry consortium to advance the art of leak detection. The initial development focused on software-based testing of BOPs in deepwater. Upon completion of the pilot program on five deepwater rigs, the results exceeded original expectations. The test results proved the software was effective, efficient, and rig friendly. Once the template was filled out, with the click of the "Start" button, the software was completely automated, up to the time of printing the report.
Through an iterative and collaborative process a unique solution for the Low Pressure (LP) and High Pressure (HP) tests has been developed. Due to the subjective nature of the Circular Chart Recorder (CCR) methodology for validating a test, a small leak may not be identified for up to 30 minutes into the HP test. With this new methodology, objective identification of a slow leak normally occurs during the LP test in less than three minutes; and a good test (no leak) typically validates in the regulatory agency's minimum holding time requirements. The software provides greater assurances, transparency, and reliability as compared to the CCR. The antiquated CCR is easily manipulated in multiple ways, which is now eliminated.
This software provides the industry with a tool for objective, efficient test validation. The software generates simple, clear, concise reports and contains more information as compared to what is currently available. It archives tests in a secure format, and the software allows the users to retrieve and review the tests for any required scrutiny. It also prints the reports to a secured PDF format and archives them.
This paper discusses the current state of the development along with the associated benefits. A vision of the application development pipeline for further pressure analysis opportunities is also introduced.
Kick Tolerance Misconceptions and Consequences to Well Design
Authors: Santos Helio , Catak Erdem , Valluri Sandeep 
Published: March 2011

Abstract
Kick tolerance is a key and fundamental concept used in well design. It defines the appropriate number and setting depth of casing strings that are required to achieve the drilling objectives. It is also used during drilling to determine whether it is safe to continue drilling or if there is a need to run a casing string. Alternatively, it is used to indicate whether it is safe to circulate a kick out of the well or whether bullheading is necessary. During development of a new well control system, a thorough review of the fundamental concepts involved was carried out, and, in relation to kick tolerance, a few misconceptions were identified. Among those misconceptions are issues related to the calculation of the kick volume on bottom when a BHA is present, the effects of friction losses on the wellbore annulus and choke line, and confusion between kick tolerance and maximum allowable pit gain, derived from the additional formation flow into the wellbore after the well is shut in (afterflow). Another important misconception is the assumption that an approach utilizing a single bubble model and ignoring effects of temperature, influx density and gas compressibility (z) factor in the final calculation will always result in a conservative solution.
This paper utilizes four example wells to demonstrate the effect of each component on the final kick tolerance calculation. In order to make it easier to understand, each effect is calculated individually using the same single bubble model that has been historically used. The results show that some components have more impact than others, and the consequence is not always in the same direction. Additionally, the effects on deepwater wells are more dramatic due to the long choke line. Therefore, generalization and simplification of the kick tolerance calculation in well design is not possible.
Interoperability: An Enabler for Drilling Automation and a Driver for Innovation
Authors: Andreas Sadlier , Laing Moray 
Published: March 2011

Abstract
Drilling automation promises to reduce costs, increase safety margins, and improve the overall efficiency of drilling operations whilst maintaining a high-quality wellbore. However, realizing this vision necessitates that components which acquire, process, provide intelligence for "situational awareness," and automatically execute instructions, share complete information. Effective decision support capabilities and the automated control of the drilling process can only occur with seamless communication based on standards that provide interoperability through an event-driven architecture.
Many standards already exist in both the oil and gas and other manufacturing process industries. Yet, the lack of adoption of these standards and best practices is predominantly due to the fear of intellectual property being compromised. We have witnessed through message-based standards the mobile handheld market's unprecedented proliferation of applications that will automate just about anything for your PDA (think Apple Inc.'s "There's an app for that"). Independent software vendors provide solutions that work seamlessly to interconnect business processes and other software systems enabled by the standards developed and adopted as a result of the Internet and the service-oriented architecture (SOA) movement. Key to this development has been the protection of individuals’ intellectual property through the encapsulation of processing and control logic. Harvesting innovation from these next-generation solution developers requires standardized messaging architectures and communication protocols.
This paper will examine several industry segments to highlight how standardization at the level of interconnectivity has affected both their interoperability and innovation. Business models that promote and reward open innovation will ultimately drive solutions for automation. But interoperability will drive more than just automation; it is the key to shattering the myth around service complexity. Protecting intellectual property (IP) requires encapsulation of process and control logic and the adoption of appropriate interface standards. Standards enable the prospect of greater interoperability, reduce system complexity through modular packaging, and drive innovation.
Well Construction Hydraulics in Challenging Environments
Authors: Martins A. L. , Aragão A. F. , Aranha P. E. , Folsta M. G , Waldmann A. T. 
Published: March 2011

Abstract
Hydraulics plays a major role in well construction, especially in narrow operational window scenarios, where the difference between pore and frac pressures approaches zero. Besides, special geometry wells, where annular friction losses contribute expressively to downhole pressures, are becoming attractive alternatives to enhance production. Efficient drilled cuttings transport, minimization of contamination during fluid substitution operations and gravel packing are critical operations to be performed. The hydraulic targets for such projects require multidisciplinary technological development, including real time monitoration of downhole pressure, density and friction reduction concepts, chemicals and equipment, rheology optimization and reliable multiphase models. This article focuses on the application of latest design, chemicals, software, and equipment technology for drilling and completing (including sand control) in challenging scenarios, such as ultra deepwater exploratory wells, extended reach offshore wells, 2000 m horizontal section in shallow water carbonate reservoirs, 1200 m horizontal section gravel packing in deep water non consolidated sandstone reservoirs, managed pressure drilling onshore experiences, extended reach onshore wells for offshore reservoir exploitation, including slant rig drilling and open hole gravel packing with synthetic low viscosity fluids. Finally, the hydraulic challenges for the future will be highlighted.
Improving the Quality of Ellipse of Uncertainty Calculations in Gyro Surveys to Reduce the Risk of Hazardous Events like Blowouts or Missing Potential Production through Incorrect Wellbore Placement
Authors: Ekseth Roger , Weston John , Ledroz Adrian , Smart Barry , Ekseth Astrid 
Published: March 2011

Abstract
Wellbore position uncertainty estimation (error modeling) is a key element in safe and cost effective drilling. The quality of error modeling has improved a lot over the last 10 – 15 years through the publication of SPE papers like SPE-67616, 90408, 103734 and 105558. These papers taken together form a good framework for error modeling calculations with one exception. None of these papers supplies the drilling industry with realistic publicly documented uncertainty estimates for gyroscopic survey tools. It has been left to the gyro service providers themselves to supply the rest of the industry with the necessary gyro model inputs, mainly without any external review/audit process. This is not an ideal situation, and represents a potential safety hazard. The gyro service providers do not only compete on price, but also on survey accuracy. This paper is an attempt to start a process to close this safety gap by presenting the actual derivation of a brand new set of realistic uncertainty estimates for some of the existing gyroscopic tools based on real downhole data and guidelines given in the above mentioned SPE-papers.
Quality Assurance of Wellbore Stability Analyses
Authors: Aadnoy Bernt S. 
Published: March 2011

Abstract
It has become clear that many wellbore stability studies suffers from various inconsistencies. These lead to incorrect results, or results that may not be extrapolated to other well configurations.
In this paper typical wellbore fracturing and collapse models are investigated with respect to the accuracies in the input data. It is shown that the cumulative uncertainty is considerable. To reduce this uncertainty, constraints on the in-situ stress states are invoked. The paper further advocates the need for model calibration. In addition to using leak-off, breakout and wellbore image data, methods such as establishing bounds on the in-situ data, data normalization and inversion methods are proposed to improve accuracy and to provide quality assurance. Examples are provided in the paper.
Which Material is Less Resistant to Buckling: Steel, Aluminum or Titanium Drill pipe?
Authors: Bensmina S. , Menand S. , Sellami H. 
Published: March 2011

Abstract
Access to reservoirs in ultra-deep and extended reach drilling projects leads the industry to develop new resistant and higher-strength materials. Drilling equipments manufacturers and drilling contractors have to meet higher requirements of operators to manufacture and operate quality tubulars in these severe environments. However, with the increasing complexity (deep, long, high-pressure/high-temperature, sour service) of drilled wells, steel may become a limiting drill pipe material. A non-steel alternative material may exist such as aluminum, titanium or composite materials.
Buckling of steel, aluminum and titanium tubulars inside wellbore has been the subject of researches and articles in the past. According to some authors, the light Young Modulus of lightweight drill pipes does not affect their buckling response: the relative low stiffness of the pipes would be balanced by reduced contact forces with the wellbore.
This paper presents a full study discussing clearly the buckling response of steel and lightweight drill pipes in both experimental bench and real field conditions.
This paper shows a full comparative study between steel, aluminum and titanium drillstrings in Extended Reach Drilling (ERD) wells and studies the opportunity to use aluminum and titanium drillstring in ERD wells while the buckling, drilling efficiency and drillstring integrity stay acceptable. Critical buckling loads for each drill pipe material and dimension is reviewed and presented, using our numerical model and in the form of charts which could be used by drilling engineers. Along this comparison, we also focus on drillstring rotation, tool-joints and dimensions effects on buckling loads.
Finally, this paper should give a better comprehension of the mechanical behavior of lightweight material for drill pipe, which can improve significantly well planning to drill wells with an increasing depth, length and complexity.
Pre-perforated Liner Design and Coiled-Tubing Acidizing of Maximum-Reservoir-Contact (MRC) Wells Offshore Abu Dhabi
Authors: Jorden John , Jackson Alfred , Keller Stu , Shuchart Chris , Alvarez J. Oliverio , Quigley Scott 
Published: March 2011

Abstract
This paper describes the design and installation of the lower completion and acid stimulation of two 20,000-ft-measured-depth extended-reach (ER) wells in a major oil field offshore Abu Dhabi. The wells each had 10,000-ft horizontal completion intervals in a carbonate reservoir. One well was a producer, and the second well was a parallel water injector. The wells were each completed with an engineered, pre-perforated liner run with ten swell packers. The acidizing was performed using a specially-designed 2.375-inch coiled tubing string run with a spiral jet nozzle bottomhole assembly.
About 180,000 holes were pre-drilled in each 6.625-inch completion liner using a special hole pattern based on computational fluid dynamics and finite element design. The liners were run to total depth; these are believed to be the longest high-hole density pre-drilled liners ever run. Pre-stimulation logs were run to determine the inflow and outflow and pressure profiles. Blank pipe placed above and below the swell packers helped determine the contributions from each reservoir unit. These data were used to optimize the design of the acid stimulation treatments. The acid treatments were placed by varying the pulling speed of and the pump rate into the coiled tubing. Simultaneous annular water injection was used to help divert acid away from the heel portion of the injector well.
These wells serve as pilot wells to help confirm the feasibility of developing the field using maximum-reservoir- contact (MRC) wells rather than the current practice of using much shorter (e.g., 3,000 ft) openhole completions. The use of MRC wells is expected to significantly reduce development costs over the life of the field.
Turbodrill BHA Solves Build Section Challenges, Anadarko Basin
Authors: Staley Craig , Bruton Greg , Natanael Mark , Kelley Jason , Milne Ross 
Published: March 2011

Abstract
Drilling the difficult build section in the Granite Wash play in Washita County, Oklahoma can present a number of challenges. The formation contains multiple reservoirs within complex sequences of sandstone, siltstone and shale interbedded with granite/limestone wash. This hard and abrasive matrix is uniquely challenging and unpredictable which makes conventional drilling with positive displacement motors (PDM) combined with rollercone TCIs and/or PDC bits difficult due to the lack of desired durability.
The operator required a new technological solution to minimize the flat time in this particular section by reducing bit trips and/or improving penetration rates (ROP). In normal situations, a turbodrill paired with a diamond impregnated bit is a viable option to tackle this challenge. However, the conventional steerable turbodrill BHA was incapable of achieving the target build rates required by the customer in their deviated section.
The challenges in the build section of the well were evaluated by the engineering team. A review of the run data and use of mathematical-based predictive analysis software identified the changes needed to achieve the required doglegs needed to meet the challenge. The study indicated that using a steerable turbodrill with two bends and a specific stabilization setup coupled with a diamond impregnated bit with a shorter gauge length could yield up to 65% higher build rates.
This new turbodrill BHA has been successfully field trialed in numerous wells in Washita County, Oklahoma and surrounding areas and has achieved the goal of consistently building a curve with a plan of 14°/100ft and has set numerous new field performance records. Drilling time has been consistently reduced by 45% (from 8.0 to 4.3 days) and bit runs reduced from 2.5 to 1.0 while achieving 40% higher ROP. The authors will present case histories that illustrate performance achievements in the build sections and provide details that contributed to the success of this unique BHA.
Development of an Automated System for the Rapid Detection of Drilling Anomalies using Standpipe and Discharge Pressure
Authors: Reitsma Don 
Published: March 2011

Abstract
The requirements for the early detection and the control of kicks, losses and other anomalous conditions while drilling are becoming increasingly important as the industry drills in more challenging environments both onshore and offshore due to greater challenges with respect to equipment stresses and pressure regimes. This paper will present the design and testing of a high fidelity and high certainty system for the early identification of anomalous conditions while drilling such as kicks, losses, washouts, drill string plugging and hole bridging without the need for traditional delta flow equipment and interpretation methods. An explanation of how the system minimizes false alarms and how visual and audible methods inform the operator of the different anomalies as they are detected will be included. Installation of the equipment on the rig will also be presented and compared to current delta flow methods both for managed pressure drilling operations and conventional drilling operations. Maintenance and reliability issues will also be discussed. Full scale testing and tests using collected field data will be presented to demonstrate the system operation. Further development and field testing will also be discussed.
The Successful Evolution of an LWD Rotary Steerable System for Air Drilling
Authors: Hartley Chris , Weisbeck Denis , Robert Scott , Smith Mark 
Published: March 2011

Abstract
This paper will present the evolution of a third-generation, point-the-bit rotary steerable system (RSS) and its successful application for air drilling of directional wells and lateral intervals.
There are a number of applications for air drilling; the primary one is obviously to drill hydrostatically underbalanced where extremely low bottomhole formation pressures are encountered. In certain circumstances, the requirement to have a very small rig footprint makes drilling with air preferable to drilling with mud systems.
The engineering requirements for drilling with air obviously differ from more conventional drilling fluids. Pressure integrity of the mechanical components of the RSS device has to be sufficiently robust to withstand more extreme differential pressures. This paper will describe the steps in the evolution of the RSS design to accommodate this requirement and other functionalities of the system.
Transmission of downhole information drilling with dry air necessitates effective communication of data via electromagnetic (EM) wave in the absence of the medium for conventional mud pulse telemetry (MPT). The timeline over nine years to integrate basic EM with more high-end LWD and steering devices is illustrated (Fig. 1). Optimization of controllable constraints to extend the reach of acceptable EM transmission is addressed.
Results of successful deployments on over twenty bit runs so far will be demonstrated, along with a step-change in tool reliability delivered. Performance improvements were achieved using the surface output of the existing rig fleet without modifications. Lateral reach capability was extended, largely due to improved hole quality over the air motor drilling system used previously. This delivered greater production footage from fewer wellbores as well as the increased ability to reach topographically constrained payzones.