bluuebunny/crossref_metadata_2025_split huggingface dataset:
Critical Properties of Sand-Based Composite Aggregates for Sustainable Performance in Fracturing Applications
Authors: Nguyen Philip , Stephens Walter T. , Sanders Mike , Gashimov Ruslan , Al-Ghamdi Tawfik , AbdulRazzaq Waseem , Khalifa Mohamed 
Published: February 2017

Abstract
In the recent era of increasing oil and gas production, hydraulic fracturing is a proven economical technique to extract trapped hydrocarbons from tight reservoirs. A major factor associated with hydraulic fracturing is the significant quantity of proppant necessary and the high total contributing cost per well. For deep reservoirs, such as in the Middle East (ME), expensive, synthetic high-strength proppant (HSP) is necessary to withstand high closure stresses exceeding 15,000 psi. A new type of propping agent, a composite structure comprising low-performance sand from local sources in the ME, now exists that is capable of operating under these high closure stresses. Transforming low-performance sand into stable sand-based composite aggregates is a significant development, providing an abundant supply of low-cost propping agent that can enhance and sustain well productivity.
This paper demonstrates the sustainable performance of novel thin sheets of the sand-based composite aggregates under application conditions. Analyses of the performance measurements illustrate the unique and necessary properties these aggregates should exhibit to be successful in hydraulic fracturing.
Development of a new type of propping agent requires new techniques to measure performance. Most of these techniques apply common geophysical, chemical, and mechanical methods, while other techniques require considerable adaptation of traditional API testing methods. Performance of sand-based composite aggregates and synthetic HSP using these methods highlights the crucial and necessary aggregate properties.
Laboratory simulation of a post-fracturing scenario showed that low-performance sand, after conversion into sand-based composite aggregates, can withstand high closure stresses up to 10,000 psi. The measured conductivity of the channels is significantly higher than traditional synthetic proppant packs, and the aggregates are sufficiently strong to avoid fines generation. These observations indicate that sand can provide an effective alternative to HSP, which allows successful hydraulic fracturing in regions where synthetic proppants are cost prohibitive.
Finding an alternative to costly synthetic proppant has become more important in recent years. While the natural sand in the ME region is compositionally different and mechanically weaker than synthetic proppants and high-quality sands available in the USA, transforming the sand into composite structures provides unique performance properties. Because the sand is commercially abundant, this novel solution is a viable option.
A Modified Three-Point Contact Approach for Dogleg Severity Modeling
Authors: Gharib Hossam , Kirkhope Kennedy 
Published: February 2017

Abstract
A new approach was developed for modeling the dogleg severity (DLS) of curved wellbores during directional drilling. The approach is based on superimposing a modified three-point contact method with beam bending effects. The conventional three-point contact method provides a quick prediction of the DLS capability of mud motors. However, it is limited with respect to imposing a predetermined location of the three contact points and ignoring the weight on bit (WOB) and hole inclination effects. Moreover, hole enlargement is not considered in a three-point contact method, which can significantly influence the borehole curvature or DLS because of the change in stabilizer/borehole contact.
The new bottomhole assembly (BHA) contact/bending method presented in this paper involves a two-stage solution method. First, a modified three-point contact method is used that assumes a certain number and location of borehole contact points along the lower end of the BHA. This method calculates a preliminary value of the DLS without the loading effects. Subsequently, the effects resulting from WOB and hole inclination are considered to cause bending effects to the lower end of the BHA. These bending effects result in a change to the bend angle of the drill bit, which is used to correct the bend angle initially defined in the modified three-point contact method to obtain a final DLS solution. In addition, the hole enlargement attributable to the formation properties is considered to change the BHA-borehole contact points, thus influencing the achievable DLS range. This superposition approach, between the BHA-borehole contact and bending, results in DLS predictions for slick motors and stabilized directional drilling tools at various WOB and hole inclinations.
The contact-bending superposition (CBS) method is verified by using mud motor field survey data and is compared to the conventional three-point contact method. The CBS results show good correlation with field survey data. A greater rate of change in DLS is observed with slickbore assemblies, wherein the WOB and hole-inclination is more pronounced than stabilized assemblies. The CBS method and results demonstrate that a three-point contact approach with rigid BHA assumption is not sufficient to describe DLS. The bending effects are important considerations, particularly for assemblies with flex collars near the first stabilization point.
This new method provides a simple calculation of DLS for directional drilling tools. It is also useful when the time-consuming numerical models must be avoided, particularly at the conceptual design level, or when an efficient means of analyzing the DLS limitation of an existing tool is necessary.
Enabling Pore Pressure Prediction in Reservoirs by Replacing the Normal Compaction Trend by a Full Rock Physics Model
Authors: Debec Pascal 
Published: February 2017

Abstract
The ability to anticipate pressure in the reservoirs and shale is a critical point for safety and well control.
Shale compaction is mainly driven by effective stress. In "normal" (i.e. hydrostatic) pressure conditions, shale velocity is fortunately a "simple" function of effective stress: the Normal Compaction Trend (NCT). Many different methods exist for predicting shale Pore Pressure, in which velocity deviations from the NCT are directly attributed to stress variations and hence pore pressure variations.
Unfortunately, those approaches fail in case of facies, mineralogy or porosity changes (cementation, organic matter, smectite, sands, carbonates, etc.) since the NCT is only calibrated on shale. Pore pressure Prognosis in reservoirs classically has to be based upon other considerations, mostly made "by hand" (basin analogs, regional knowledge, reservoir size and connection to aquifer, etc.).
This paper presents a new approach predicting Pore Pressure in both shale and reservoirs. Replacing the NCT by a full RPM allows to take onboard petrophysical parameters (mineral fraction, porosity), and thus to estimate pressures in shales, but also in clastic reservoirs: Compressional Velocity (Vp) = f°(Pore Pressure, clay fraction, quartz fraction, calcite fraction, dolomite fraction,effective porosity…).
Evaluating the Performance of Advanced ESP Motor Technology in a Steam Assisted Gravity Drainage SAGD Field in Canada
Authors: Graham John , Coates Bryan , Montilla Carlos , Padilla Oscar 
Published: February 2017

Abstract
A significant percentage of all ESP failures are electrical failures and this becomes even more noteworthy in harsh, high temperature applications such as Steam Assisted Gravity Drainage (SAGD). For this reason, it is extremely important to continue the enhancement of ESP motor technologies that are specifically designed to address the challenging and unique SAGD environments that include wide bottom hole temperature ranges, abrasives and gas rich fluids. Through experience and testing, it has been learned that for these types of applications it imperative to design not only to a high temperature limit, but also to withstand extreme temperature cycles experienced on steam injection facility shutdown.
A combination of historic evidence with controlled laboratory evidence yielded improvement areas for a new high-temperature ESP motor development. The new high ultra-temperature motor breaks paradigms and opens a new generation of motors that looks towards above 300°C downhole temperatures. This paper will review the performance of the motor at Suncor's Firebag SAGD field where 92 units have been installed since January 2015 in bottom hole (BHT) temperatures reaching 240°C. Description of the laboratory qualification, major design characteristics and field results will also be discussed on the paper.
Implementing a Scientific Perspective and a Pragmatic Approach to Optimizing Perforated Completions
Authors: Zuklic Stephen , Satti Rajani , Myers William , Bale Derek , Sampson Tim 
Published: February 2017

Abstract
A truly optimized completion requires a wide range of understanding and activities. Starting with a thorough understanding of the reservoir, each completion element must be fully addressed from connecting to the reservoir, to enhancing the reservoir through proper treatments, to conducting hydrocarbons to surface for optimal efficiency. By considering the cause-and-effect interactions between these activities, each individual process can be designed and performed better, ultimately delivering the best overall solution. This overarching philosophy is also fully applicable to perforated completions.
Providing a perforating solution that is truly optimized for the reservoir is challenging, requiring advanced laboratory testing capabilities, reservoir specific products and systems, robust analysis and modeling tools, and a thorough process to insure solutions are designed, executed, and reviewed for continuous improvement and optimization. Recent advances in in-situ perforation testing techniques provide significant insights into dynamic events during perforating as well as enabling more reservoir specific equipment designs. Furthermore, state-of-the-art computational models complement testing methods by correlating dynamic perforating events and inflow analysis to actual productivity. Numeric modeling techniques also allow results from lab testing to be better translated into field scale environments. And finally, rigorous procedures can be followed to practice this process across a wide variety of completion types to provide well optimized perforated completions.
This study will detail the techniques used to employ the philosophy, and multiple case histories of such applications with results and lessons learned. In these cases, a comprehensive consideration of the overall completion was critical in optimizing the perforating process. The use of laboratory testing, customized products and systems, integrated modeling and analysis tools, and a disciplined process have led to the successful application of this scientifically engineered philosophy. This unique perforating philosophy is also aimed towards integration with other completion methods like hydraulic fracturing & stimulation, sand control and management and above all, enhancing reservoir productivity.
Beginning With the End In Mind: Shaped Charges Designed for Reservoir Conditions
Authors: Satti Rajani , Betancourt David , Harvey William , Zuklic Stephen , White Ryan , Ochsner Darren , Sampson Tim , Myers William , Gilliat Jim 
Published: February 2017

Abstract
Historically, the performance of shaped charge jet perforators has been evaluated using concrete targets under ambient conditions, thereby failing to clearly characterize their performance in downhole conditions. In recent years, testing using sandstone targets (API RP-19B Section 2) and various numerical models have been adopted as a better means of quantifying shaped charge performance. However, it is important to note that such testing and modeling methods do not still account for the complex shaped charge physics in downhole conditions, which includes pressures (wellbore to pore to confining), rock properties (bedding plane orientations, porosity, permeability, UCS, etc.), cement and casing material characteristics, etc. In fact, the results from standard tests or numerical models have been proven to be misleading while designing and optimizing shaped charges for reservoir conditions.
As a result, the advent of perforation flow laboratories and advances in shaped charge research and engineering has been the key motivation for this work. In this work, we have employed a scientifically engineered approach to determine and optimize shaped charge performance. A comprehensive test program in conjunction with computational modeling was utilized to design, test and improve shaped charge performance under reservoir-specific conditions. For this purpose, methods relating to API RP-19B Section 4 testing and advanced hydrodynamic solvers were integrated into a scientific workflow.
The results from this study demonstrate the following: First, pore pressure does influence shaped charge performance. Second, the best way to characterize the performance of a shaped charge is to conduct a laboratory test under true reservoir conditions. Third, designing a shaped charge around performance at true downhole conditions has enabled significant performance and productivity improvements.
Utilizing advanced numerical modeling and extensive testing, we have achieved significant increase in shaped charge performance (penetration and flow area) in some of the most challenging reservoir conditions. The new class of reservoir-driven shaped charges is aimed towards increasing production or injection by deeper formation connectivity with the wellbore as well as ensuring perforation contribution efficiency.
Surfactant-Polymer Flooding: Chemical Formulation Design and Evaluation for the Raudhatain Lower Burgan RALB Reservoir in Kuwait
Authors: Al-Murayri M.T. , Hassan A.A. , AlAbdullah M.B. , Abdulrahim A.M. , Marliere C. , Hocine S. , Tabary R. 
Published: February 2017

Abstract
Surfactant-Polymer (SP) flooding is an Enhanced Oil Recovery (EOR) process that can lead to incremental oil recovery through two mechanisms: reducing oil/water interfacial tension (IFT) to decrease residual oil saturation and increasing the viscosity of the displacing fluid to improve overall sweep efficiency. IFT reduction allows better oil recovery by overcoming capillary effects while the increased viscosity of the displacing fluid allows a more homogeneous sweep of reservoir oil. Implementing chemical flooding in reservoirs with relatively high temperature and in-situ salinity (&gt; 200 g/L) is somewhat challenging. This paper describes the extensive laboratory work performed for the light oil Raudhatain Lower Burgan (RALB) reservoir (180°F/82°C) in Kuwait.
Reservoir fluids were thoroughly characterized to preselect the most suitable chemicals for the SP process. Reservoir crude oil was analyzed and recombined with gases (C1-C3) based on reported Gas-to-Oil (GOR) ratio to reproduce the oil in-place at original reservoir conditions in terms of pressure, temperature and oil composition. A shift of the live oil Equivalent Alkane Carbon Number (EACN) was noticed compared to dead oil EACN.
Numerous surfactants were screened based on three main criteria: solubility in the envisioned injection brine, ultra-low oil/water interfacial tension and chemical adsorption on reservoir rock. Different brine types were considered and the use of adsorption inhibitors was also investigated. Furthermore, polymer screening, involving temperature resistant polymers, was conducted by means of viscosity, long-term aging and adsorption tests. Polymer compatibility with the selected surfactants was also evaluated. The selected SP formulation was further evaluated through a series of coreflood experiments mainly based on chemical adsorption on reservoir rock and incremental oil recovery and an injection strategy was designed thereof.
Laboratory results obtained thus far are encouraging and provide a systematic methodology to design surfactant-polymer injection in high temperature, high salinity and light oil reservoirs that are similar to the RALB reservoir. Additional techno-economic evaluation is in progress in preparation for field-scale deployment of surfactant polymer injection at the RALB reservoir in Kuwait.
An Innovative ICD Design Workflow to Balance Flux Equalization and Well Productivity in Horizontal Wells
Authors: Lee Byung , Faizal Syed Abu , Galimzyanov Artyom 
Published: February 2017

Abstract
During the last decade, inflow control device (ICD) technology has rapidly developed and widely been used in horizontal wells due to its effectiveness in flux equalization and mitigation of unwanted fluid breakthrough. An ICD completion achieves flux equalization and manages water breakthrough by introducing an extra pressure drop in the ICD and redistributing the drawdown across the sandface between high and low permeable intervals of a horizontal well. This additional pressure loss in the ICD completion will cause reduction of effective productivity of the well, in other words it will require lower flowing bottom-hole pressure for a well with ICD completion to produce the same liquid rate compared to a well with a barefoot completion. The higher the pressure drop across the ICD completion, the better will be the equalization effect and water mitigation. Subsequently, the reservoir pressure has to be used wisely during field development as expensive pressure maintenance programs are utilized in many fields as part of the field development plans.
This study tries to answer an important question: What should the optimum pressure regulation in an ICD completion be to realize the benefits of ICD without excessive reduction of well productivity? The effect of ICD regulation on flux equalization and well productivity reduction for various cases of well productivity index (PI) and permeability variation were studied through numerous static near wellbore simulation runs. Dynamic reservoir simulation was conducted to verify the results from the static simulation and dependence of the degree of flux equalization along the horizontal section on water breakthrough deferment and the oil recovery factor.
An ICD design workflow is presented, which can be used to select an optimum ICD design, which maximizes the benefits of ICD with the least reduction in well productivity. A trade-off chart between well productivity and the degree of influx equalization has been built, which helps to determine the optimum pressure drop across an ICD completion in the presence of various levels of permeability variation along the wellbore. This approach can provide quick and simple calculation for the required ICD strength or number of ICD joints along the wellbore to maximize recovery of hydrocarbons. A real field case is used to illustrate the effectiveness of this workflow for optimum ICD design.
Unique Approach to Bit Design Coupled with Innovative Rolling PDC Cutter Sets New Performance Benchmark Drilling Extremely Abrasive Sandstone Formations, Usinsk Region Russia
Authors: Pak M. , Gumich D. , Zinnatullin I. , Mukkisa S. , Bits Smith , Gaynullin I. 
Published: February 2017

Abstract
Developing reserves in the North Russia, Usinsk requires the operator to drill extremely abrasive sandstone formation at bottom of 8.625-in. reservoir section. Drilling with PDC bits has been challenging due to severe cutter wear. Heavy-set standard PDC cutter bit would last on average from 45 to 100 meters depending on field. With the goal of increasing production and reducing costs, reservoir section can be from 170 up to 350 meters long.
With standard PDC bits, it would take from three to four bits to finish the interval. The operator required new type of PDC bit that could efficiently drill abrasive sandstone at high ROP and cutting structure that would remain sharp over longer interval.
To develop a durable bit solution, engineers used an FEA-based modeling system to implement an innovative bit by positioning new shearing elements (rolling cutters) to address cutter wear. Several designs were implemented that hold the cutter securely in place and allow full cutter rotation. Rolling cutter PDC shearing element utilizes the entire 360 degree of diamond edge to shear the formation while reducing frictional heat and, by strategic positioning of these rolling cutters in the high wear areas of the bit, provides longer footage and higher ROP.
New design 8-bladed PDC bit with rolling cutters was tested and compared against direct offsets in two different fields in Usinsk, Russia. In first field, rolling cutter bit drilled entire reservoir section 335 meters with 4.6 m/hr ROP improving 140% meterage and 44% ROP. In second field, two rolling cutter bits drilled reservoir section and replaced four standard PDC bits saving three days.
New concept of PDC bit utilizing rolling cutter expands the limit of PDC bit durability drilling extremely abrasive sandstone formations. New type of bit can efficiently drill in those challenging geological conditions improving the drilling time and cost.
Geological Modeling in Structurally Complex Settings Using a Depositional Space and Cut-Cell Unstructured Grids
Authors: Levannier A. , Chabbert A. , Neumaier M. , Benabbou A. , Viard T. , Macé L. , Santoshini S. , Lepage F. , Malvesin E. , Laverne T. , Daly C. , Buchholz C. , Wang Y. 
Published: February 2017

Abstract
Historically it has been a challenge to rapidly produce a geomodel that can honor the detailed form of complex faulting and folding, while enabling sensible property modeling and that is tailored to fluid flow simulations. In structurally complex areas, the construction of accurate 3D geological models is often impeded by the complexity of the fault framework, the resulting layer segmentation, "multi-z" horizons in compressive settings and steeply dipping to overturned layers. In particular, standard geocellular models, such as pillar grids, may fail to honor complex structural features.
To address those issues, methodologies using a mapping between the geological space and a 3D parametric space — often referred to as depositional space — have been described in the literature for geological grid construction and property population. Using case examples of structurally complex settings, we illustrate a depositional unstructured grid construction workflow. Compared to known methodologies, the depositional space is computed using a geomechanically-based approach. We illustrate that the methodology allows for complex structural configurations to be effectively modeled and transformed into a geocellular model honoring the full structural complexity. Our depositional unstructured model can then be populated with properties and used directly for flow simulations.