bluuebunny/crossref_metadata_2025_split huggingface dataset:
Friction-Based Thermal Desorption Technology: Kashagan Development Project Meets Environmental Compliance in Drill-Cuttings Treatment and Disposal
Authors: Murray A. J. , Kapila M. , Ferrari G. , Degouy D. , Espagne B. J. , Handgraaf P. 
Published: September 2008

Abstract
Friction-based thermal desorption, with temperatures between 260 and 300°C, allows the oil and water phases to be volatilized and subsequently condensed and recovered, leaving dried and cleaned solids that can be disposed. Friction-based thermal desorption reduces the residual oil on the cuttings while recovering oil and other materials for reuse.
This paper presents the novel friction-based thermal desorption system currently deployed in the relatively hostile and remote Koshken area, located on the steppe escarpment above the eastern shore of the Caspian Sea, Kazakhstan. This project is expected to produce 50,000 tonnes of oil-based drilling fluid or "mud" (OBM) drill cuttings annually, which must be treated to below 1% TPH oil before disposal. Any treatment technology utilized in this environment faces operational and logistical challenges, including the severe climate and the need to transport the drill cuttings from an offshore facility to an onshore centralized location. Improvements in friction-based thermal desorption technology were developed specifically for the Koshkani project to ensure health, safety and environmental (HSE) compliance and allow a best-in-class system to operate in this harsh environment.
In this paper, the authors describe the three-year development process, from initial design and equipment construction through installation, commissioning and operation. Analytical data presented includes analysis of discharged material, recovered base oil and air emission analysis. A comparison is made between the application of thermal desorption technology and alternative technologies used in similar projects.
Friction-based thermal desorption met increasingly high performance expectations and technology advancements allowing them to be achieved with assured HSE performance. Given the environmental performance that the Kashagan project required, this technology has proven to be the simplest, easiest and most effective system to implement in this environment with assured success.
Testing of New PDC Cutter Edge Geometry Doubles Penetration Rate and Reduces Torque
Authors: Barton Steven , Setlur Deepthi , Clegg John 
Published: September 2008

Abstract
A new edge preparation of Polycrystalline Diamond Compact (PDC) cutters has been developed to target applications where either weight or torque is limited. This paper describes the geometry, which differs considerably from existing thermostable product.
Initial testing at atmospheric conditions in a drilling laboratory shows a 30% reduction in torque and a 100% increase in penetration rate when compared to conventional cutter geometry. Secondary testing was conducted with drill bit designs at a non-commercial test facility. In this controlled environment, designs with new cutter edge geometry were compared directly to those with conventional cutters. By using the same drill bit cutting structure and parameters, any difference in torque and penetration rate was solely dependent upon the cutter geometry. Additionally, to quantify any effects caused by torsional or lateral vibration, a downhole dynamics recorder was used to gather data at a high frequency sample rate.
Performance studies are presented for a variety of applications from around the world but focusing on applications within the US Rockies. They compare direct offset runs against conventional geometry cutter designs. Results demonstrate that the new geometry delivers footage and ROP equal or greater than the best field offsets.
The increased penetration rate and reduced torque provided by this geometry result from more efficient failure of the rock. This provides reduced Mechanical Specific Energy and improved drilling efficiency, thus reducing drilling costs for the operator. This is a significant step change in PDC cutter technology, dramatically increasing fixed cutter drill bit performance.
Sampling and Characterization of Rocks and Fluids for Heavy Oil Reservoir Management
Authors: Smith C. K. , Wang F. H. 
Published: September 2008

Abstract
Heavy oil resources have become a major asset base in the portfolio of many energy companies. Representative sampling and characterization of rock and fluids are essential for efficient and economical development of heavy oil reservoirs. This paper describes the challenges inherent in fluids and rock sampling, PVT and viscosity modeling, and fluid flow property measurements for heavy oil reservoirs.
The key elements in obtaining representative bottom-hole fluid samples from an extra-heavy oil reservoir are described in this paper with examples. Special laboratory techniques are presented for obtaining equilibrium PVT and viscosity data on heavy oil samples. A compositional PVT model that captures the unconventional phase behavior and a viscosity model that quantifies the variations of viscosity with pressure, temperature, and GOR are also presented. Customized equipment and special techniques were employed to measure high-quality relative permeability data and to accurately determine the endpoint saturations such as critical gas saturation, remaining oil saturation, and the corresponding relative permeability. Examples of successful measurements of reservoir conditions steady-sate water-oil relative permeability are presented along with the unique equipment and techniques.
This paper highlights a systematic approach for rock and fluid characterization of heavy oil reservoirs and identifies new technologies that have lead to its successful application.
Use of Multiple-Response Optimization to Assist Reservoir Simulation Probabilistic Forecasting and History Matching
Authors: Osterloh W. Terry 
Published: September 2008

Abstract
This paper describes a straightforward, robust, and easily managed method for assisting reservoir simulation probabilistic forecasting, probabilistic history matching, and process optimization. The method, which is widely used in numerous other engineering fields, is based on design of experiment, Gaussian process modeling (kriging), and multiple response optimization. The method enables a new perspective on probabilistic green-field forecasting - creating a simulation model in which the probability numbers of multiple responses are at the same level (p-number alignment). The method also provides a probabilistic framework for history matching and forecasts made with the matched model. Example applications of p–number alignment and probabilistic history matching are presented for primary production and steamflood EOR pilots.
Highlights of the new method include the following: 1) multiple responses (even those with different units) can be aligned or matched, 2) responses can be weighted to focus the alignment or match on preferred responses, 3) ad-hoc, manual, or trial-and-error adjustments of simulation inputs is largely eliminated, 4) the method can be used with any simulation code, and 5) the method is extensively automated, with all key steps integrated into one commercially-available statistics package.
Pilot Scale Test of a Produced Water-Treatment System for Initial Removal of Organic Compounds
Authors: Kwon Soondong , Sullivan E. J. , Katz Lynn , Kinney Kerry , Bowman Rob 
Published: September 2008

Abstract
A pilot-scale test to remove polar and non-polar organics from produced water was performed at a disposal facility in Farmington NM. We used surfactant-modified zeolite (SMZ) adsorbent beds and a membrane bioreactor (MBR) in combination to reduce the organic carbon content of produced water prior to reverse osmosis (RO). Reduction of total influent organic carbon (TOC) to 5 mg/L or less is desirable for efficient RO system operation.
Most water disposed at the facility is from coal-bed gas production, with oil production waters intermixed. Up to 20 gal/d of produced water was cycled through two SMZ adsorbent units to remove volatile organic compounds (BTEX, acetone) and semivolatile organic compounds (e.g., napthalene). Output water from the SMZ units was sent to the MBR for removal of the organic acid component of TOC. Removal of inorganic (Mn and Fe oxide) particulates by the SMZ system was observed. The SMZ columns removed up to 40% of the influent TOC (600 mg/L). BTEX concentrations were reduced from the initial input of 70 mg/L to 5 mg/L by the SMZ and to an average of 2 mg/L after the MBR.
Removal rates of acetate (input 120-170 mg/L) and TOC (input up to 45 mg/L) were up to 100% and 92%, respectively. The water pH rose from 8.5 to 8.8 following organic acid removal in the MBR; this relatively high pH was likely responsible for observed scaling of the MBR internal membrane. Additional laboratory studies showed the scaling can be reduced by metered addition of acid to reduce the pH. Significantly, organic removal in the MBR was accomplished with a very low biomass concentration of 1 g/L throughout the field trial.
An earlier engineering evaluation shows produced water treatment by the SMZ/MBR/RO system would cost from $0.13 to $0.20 per bbl at up to 40 gpm. Current estimated disposal costs for produced water are $1.75 to $4.91 per bbl when transportation costs are included, with even higher rates in some regions. Our results suggest that treatment by an SMZ/MBR/RO system may be a feasible alternative to current methods for produced water treatment and disposal.
Effect of Brine in Hydrate Anti-Agglomeration
Authors: York J. D. , Firoozabadi A. 
Published: September 2008

Abstract
Due to availability, as well as economical and environmental considerations, natural gas is projected to be the premium fuel of the 21st century. Natural gas production poses risk of flow-line hydrate blockage from co-produced water and hydrate-forming species. Common industry practice is the use of large doses of thermodynamic inhibitors such as alcohols; aside from undesirable environmental consequences, sufficient quantities of such thermodynamic inhibitors induces salt precipitation from co-produced water. Thermodynamic inhibitors affect bulk phase properties and inhibit hydrate formation. An alternative is changing interface properties by polymers and surfactants, effective at 3 to 0.5 % (or less) by weight of co-produced water. One group of low dosage hydrate inhibitors (LDHI) are kinetic inhibitors, which affect nucleation rate and growth. A second group of LDHI are anti-agglomerants, which prevent agglomeration of small hydrate crystallites. Despite great potential, work on hydrate anti-agglomeration is very limited. This work centers on the effect of NaCl and MgCl2 in mixtures of two vastly different anti-agglomerants. We use a model oil, water, and tetrahydrofuran as a hydrate-forming species. Results show that both salts—added in sufficient quantities—may result in the agglomeration of hydrates. Our results reveal a non-monotonic agglomeration behavior at low salt and/or large surfactant concentrations. Specifically, dissolved MgCl2 results in agglomeration more than the dissolved NaCl. Our measurements also show that the quaternary ammonium salt—i.e., quat—is more sensitive to dissolved salt than the nonionic rhamnolipid biosurfactant. In this work we show that the rhamnolipid biosurfactant is effective to a low concentration of 0.05 wt. %, yet quat has effectiveness down to 0.01 wt. %. The biosurfactant—with less toxicity and higher biodegradability—is an attractive alternative to chemical surfactants in anti-agglomeration. Results on the model systems show the promise for testing in real fluid systems and the field testing of the ideas.
Utilizing Modern Frac Baffles Improves Completion Efficiencies
Authors: Arispe Michael , Mueller Randy , Meaux Chris , Green Todd , Rojas Daniel 
Published: September 2008

Abstract
As hydrocarbon production costs rise, the need for greater completion and production efficiency is becoming increasingly important. The Haley Field in the Delaware Basin of West Texas has begun utilizing frac baffles in order to improve the overall efficiency of the multi-stage completion process. The frac baffles, which are strategically placed within the casing string, allow for zonal isolation by means of dropping a frac ball that seats on the frac baffle at the specified depth. The isolated zone is then ready to be perforated and fractured.
The process of utilizing frac baffles has proven to be more efficient compared to the traditional method of setting composite bridge plugs for zonal isolation. First, the need for wireline is reduced because there is no need to set composite bridge plugs. Additionally, the challenges experienced with setting and milling the composite bridges plugs are completely eliminated. Finally, the processes of perforating, stimulating, and coiled tubing milling have been dramatically improved.
In particular, coiled tubing milling of the frac baffles / balls has improved in the areas of milling speed, coiled tubing cycling, and circulation of milled particles returned. Most important, is the significant operational time savings, which allows the well to be brought on production faster.
Since October 2006, approximately 30 wells have been completed with this method. This paper provides an introduction to the frac baffle technology and shows how the utilization of frac baffles has improved the efficiency of the completion process. Specifically, the improvement with coiled tubing milling of the frac baffles / balls over the traditional composite bridge plugs is compared and discussed.
Well Test Analysis in Volatile Oil Reservoirs
Authors: Sanni M. , Gringarten A. C. 
Published: September 2008

Abstract
This paper discusses characterization of volatile oil reservoirs using well test analysis. For this purpose, typical well test behaviors were simulated with a one-dimensional single well compositional reservoir model, for different production rates; fluid composition and relative permeability curves, with bottomhole pressures above and below the bubble point pressure. It was found that, when the bottomhole pressure falls below the bubble point pressure during a drawdown, a high gas saturation zone is created around the wellbore with two-phase (oil and gas) flow, whereas single phase (oil) with the initial gas saturation remains away from the wellbore. During the subsequent build up, the gas created around the wellbore during the preceding drawdown condenses into the oil and the saturation in the near-wellbore region returns to the initial gas saturation. The log-log pressure-derivative behaviors below the bubble point correspond to a two-zone radial composite model, with decreasing mobility during drawdowns and increasing mobilities during build ups. The log-log pressure derivative plot of the build up reflects oil mobility distribution of the reservoir at the end of the preceding drawdown.
Knowledge obtained from the study was applied to the analysis of a well test in an actual volatile oil reservoir. Analysis results were validated with compositional reservoir simulation that included the effect of capillary number and non-Darcy flow.
Numerical Investigation of Gravitational Compositional Grading in Hydrocarbon Reservoirs Using Centrifuge Data
Authors: Ting P. D. , Dindoruk B. , Ratulowski J. 
Published: September 2008

Abstract
Fluid properties descriptions are required for the design and implementation of petroleum production processes. Increasing numbers of deep water and subsea production systems and High-Temperature-High-Pressure (HTHP) reservoir fluids have elevated the importance of fluid properties. Like rock properties, fluid properties can vary significantly both aerially and vertically even within well-connected reservoirs.
In this paper, we have studied the effects of gravity using experimental data available for five live oil and condensate systems (at high pressure and temperature) considering impact of fluid characterization effects. Under isothermal conditions and in the absence of recharge, gravitation will dominate. However, gravitational effects are not always significant for practical purposes. Since the predictive modeling of gravitational grading is sensitive to characterization methodology for some systems, experimental data from a specially designed centrifuge system is essential for calibration and as well as for quantification of these forces.
Numerical studies were performed using a calibrated EOS description based on the fluid samples taken at a selected point of each reservoir. Comparisons of measured data and calibrated model show that the EOS model quantitatively (within desired limits) and qualitatively described the observed equilibrium fluid grading behavior of the fluids tested. First equipment was calibrated using synthetic fluid systems as shown in Ratulowski et al.1 Then real reservoir fluids were used ranging from black oils to condensates (properties ranging from 27 API/1,000 scf/stb GOR to 57 API/27,000 scf/stb GOR). Diagnostic plots based on bulk fluid properties for reservoir fluid equilibrium grading tendencies have been constructed based on interpreted results, and sensitivities to model parameters estimated. The potential use of centrifuge data was investigated as an additional fluid characterization tool to construct more realistic reservoir fluid models for graded reservoirs (or reservoirs with high grading potential) have also been investigated.
Evolution of Single-Trip Multiple-Zone Completion Technology: How State-of-the-Art New Developments Can Meet Today's Ultra Deepwater Needs
Authors: Clarkson Brad , Grigsby Tommy , Ross Colby , Sevadjian Emile , Techentien Bruce 
Published: September 2008

Abstract
In the 1980s, economic conditions in the oilfield were demanding improvements in economic and completion efficiency, and all phases of the industry were requiring that strategies to improve cost be revisited. Sand-control completion methodologies were no exception; they were no longer capable of meeting the economic and completion-efficiency required to complete the long stacked intervals being attempted. To address this problem, a single-trip multiple-zone gravel-pack system was developed. The concept was successful for the targeted formations, but as with all new technologies, certain shortcomings concerning rathole intervals, complexity of the systems, and longer, more deviated wellbores prevented its use in all types of reservoir scenarios.
An improved version that was introduced in the early 1990's attempted to address these shortcomings. This system was successfully deployed and is still being run in the Far East today. However, limitations that were still experienced with the single-trip multiple-zone systems have prevented their wide spread adoption, causing them to remain a niche completion technique predominately used in the Far East and Italy.
Industrial drivers for deepwater development have again caused operating companies to revisit the viability of multiple-zone systems. Once considered too complex and risky for offshore operations; the development of the ultra deepwater lower-tertiary play in the Gulf-of-Mexico has provided the impetus for renewed interest in multi-zone concepts. This interest has been driving the development of the latest generation of the cased-hole multiple-zone system as well as an openhole multiple-zone frac-pack-compatible completion system.
The intent of this paper is to chronicle the development of cased-hole single-trip multiple-zone completion systems with a focus on the latest generation of these systems — the systems developed for deepwater applications. The paper will also discuss why previous systems have not proliferated globally to become an accepted mainstream sand-face completion technique.
The improved functionality of the newest system will be described and compared to the previous generation of systems. The integration testing to qualify the new multiple zone system is included in the discussions. Several installations have been planned, and the case histories will be included if available by paper time.
Employing Flow Assurance in an Offshore FEED Study
Authors: Grove Gary , Saether Geir , Estrada Giovanni P. 
Published: September 2008

Abstract
Flow assurance has taken on a primary role in FEED studies as of late and has become a standard tool to test design ideas, design changes, and operating strategies. The expectation from such studies is to lower the risk of flow assurance related problems, thereby minimizing both capital expenditures and operating costs. This discussion includes both the methodology and the results of the flow assurance study.
Production is located offshore and is made up of two platforms with a 25 kilometer flowline between them. The production stream is the combination of production from 5 wells and contains oil, water, and gas. This combined fluid presents primarily two flow assurance related problems: slugging and wax deposition.
In the case described herein, simulation tools incorporated the various data to create an understanding of the three typical operating scenarios: normal production operations and the respective flowline characteristicsplanned and un-planned shutdowns with resultant fluid cool-down behaviorstart-up methodology and subsequent transient behavior
A review of the methodology of the FEED study includes a discussion of what constitutes the necessary input data, how that data was used, how design changes were treated, and how other engineering aspects utilized these results for the final design.
The resulting simulated operations of the production system are presented. This includes the thermal behavior of the flowline, the changing fluid characteristics, and the associated temperatures and pressures with respect to the operating methodologies and mitigation techniques.
Finally, what makes this study possible is the use of state of the art dynamic simulation technology to delineate complex behavior in flowline systems. A discussion of the computing power and the software capabilities required for such an involved set of variables is provided.
Numerical Inversion of Laplace Transforms in the Solution of Transient Flow Problems With Discontinuities
Authors: Al-Ajmi N. , Ahmadi M. , Ozkan E. , Kazemi H. 
Published: September 2008

Abstract
Laplace transformation provides advantages in the solution of many pressure-transient analysis problems. Usually, these applications lead to a solution that needs to be inverted numerically to the real-time domain. The algorithm presented by Stehfest in 1970 is the most common tool in petroleum engineering for the numerical inversion of Laplace transforms. This algorithm, however, is only applicable to continuous functions and this limitation precludes its use for a wide variety of problems of practical interest. Other algorithms have also been used, but with limited success or popularity. A recent algorithm presented by Iseger in 2006 removes the restriction of continuity and provides opportunities for many practical applications. This paper exploits the useful features of the Iseger's algorithm in the inversion of continuous as well as singular and discontinuous functions that arise in the solution of pressure-transient analysis problems. The most remarkable applications are in the problems that require the use of piecewise continuous and piecewise differentiable functions, such as the use of tabulated data in the Laplace transform domain, deconvolution algorithms, and solutions that include step-rate changes as in the mini-DST tests.