bluuebunny/crossref_metadata_2025_split huggingface dataset:
Driving the Standards Along the Nile
Authors: Refaat H. , Elassar C. , Othman A. , Mourad S. , Hammouda M. , Nabil K. , Nosseir M. , McJarrow S. , El Kordy W. , El Khatib H. , Farouk K. , Nassar M. 
Published: December 2007

Abstract
Egypt has the highest Road Fatality Rate worldwide. Roads claim at least 50% of the lives lost in the Petroleum Industry. During 2004, an initiative was set up to develop a cross industry committee. The aim was to create a strong, collaborative approach on Road Safety across our companies, the wider industry as well as the in community. The objectives were to:
Raise awareness of progress and share lessons learned in monthly meetings. Adopt common industry standards. Influence contractors to adopt safer standards and improved performance. Influence local communities. Influence the issue on a National scale.
Membership has grown to 11 companies including key industry majors plus Joint Ventures. Working groups set out to develop detailed plans in 3 areas:
Impact of High Salinity of Produced Water on the Technical Feasibility of Biotreatment for E&P Onshore Applications
Authors: Baldoni-Andrey P. , Lesage N. , Segues B. , Pedenaud P. , Dehaene P. L. 
Published: December 2007

Abstract
Hydrocarbon production generates aqueous effluents that may contain traces of either hydrocarbon or chemical products, which have to be eliminated according to regulations and to the operator's policy, to reduce the potential impact of their discharge on the environment. These waters could also contain a large amount of salt. The aim of this work is to evaluate the feasibility of the biotreatment of saline (200 g/L TDS) produced water. A Sequencing Batch Reactor (SBR), a trickling filter and a chemostat reactor were compared in terms of total organic carbon (TOC) removal. Results pointed out the biodegradability of the produced water containing high concentration of salt. However continuous operation with SBR could lead to a loss of biomass. TOC removal in the SBR is higher than in trickling filter or chemostat reactor.
A Variational Approach to the Prediction of the Three-Dimensional Geometry of Hydraulic Fractures
Authors: Clifton Rodney J. , Abou-Sayed Ahmed S. 
Published: December 2007

ABSTRACT
A computational method is outlined for modeling the three-dimensional development of hydraulic fractures due to the injection of a non-Newtonian fluid at the well bore. The rock formation is modeled as an infinite, homogeneous, isotropic, clastic solid with in situ stresses that vary with depth. This three-dimensional problem is made two-dimensional by reducing the elasticity problem to an integral equation that relates pressure on the crack faces to crack openings and by neglecting the component of the fluid velocity in the direction perpendicular to the fracture plane. Variational principles are used to derive the discrete form of the governing equations that are used for the computations. Preliminary computations indicate that the essential features of the approach are suitable for use in a numerical method for predicting the three-dimensional geometry of an advancing crack.
Characteristic Behavior of Finite Radial and Linear Gas Flow Systems - Constant Terminal Pressure Case
Authors: Carter Robert D. 
Published: December 2007

ABSTRACT
Gas well rate-time behavior under constant terminal pressure conditions, which is influenced by reservoir boundaries, is treated. It is shown that the variation of the quantity μ(p)cg(p) over the range of average reservoir pressure traversed during depletion influences the rate behavior. Numerical solution results are given in the form of log-log type curves and representative semilog decline curves. It is further shown that the solution for constant pc is a limiting case which may often be used to approximate rate-time behavior adequately during the transient stage of producing history, but which may only be appropriate for late time behavior when the pressure range traversed is suitably small. Results are presented for both real and ideal gas cases and are expressed in terms of a correlation parameter related to the pressure range traversed. The conditions under which this parameter may be used as an exact correlator and those under which it may be used as an approximate correlator are stated. Liquid and rock compressibility effects and turbulent flow are ignored.
Cementing of an Offshore Disposal Well Using a Novel Sealant That Withstands Pressure and Temperature Cycles
Authors: Pedersen R. O. , Scheie A. , Johnson C. , Hoyos J. C. , Therond E. , Khatri D. K. 
Published: December 2007

Abstract
A dedicated injector well, located in the Grane field in the Norwegian North Sea, was chosen as a candidate for application of a novel new sealant. The injector well, drilled for disposal of cuttings and produced water, was selected because of expected temperature and pressure cycling during the injection operation, and the risk of cement sheath integrity failure. This paper will discuss the design, execution, and evaluation of this injector well.
Stress modeling indicated that as wellbore temperature decreased from bottomhole static to injection temperature and as bottomhole pressure cycled between static and dynamic conditions, conventional cement would fail in tension and create a microannulus. In view of these challenges, a redesigned the cement program, which incorporated stress analysis calculations and mechanical-properties testing provided a sealant material that would resist failure due to excessive wellbore stresses. The redesign required three steps;. Firstly, it was necessary to calculate temperature and pressure variations expected in the wellbore during injection. Next, temperature and pressure variations in the wellbore were evaluated using numerical analysis. Finally, a sealant was engineered so that its integrity would be maintained when exposed to repeated temperature and pressure cycles. The chosen sealant material incorporated flexible and expanding materials within an optimized particle size distribution blend. The sealant's mechanical properties were engineered in line with expected stresses to minimize the Young's modulus and improve bonding properties.
The cuttings-disposal injector well was drilled, cased, and cemented using the new sealant material. Since placement, the well has been logged with sonic and ultrasonic tools and these data indicated an excellent bonding response. The well has now been used as an injector for more than two years with no indication of fluid communication in the annulus or loss of cement sheath integrity.
Significantly, since this first application, which incorporated the successful of modeling of the expected stresses and the engineering of a sealant to manage these stresses, further injector wells have been cemented utilizing the same engineering approach.
Hole Cleaning During UBD in Horizontal and Inclined Wellbore
Authors: Zhou L. 
Published: December 2007

Abstract
This paper is an extended work of SPE 90038. Aerated non-Newtonian flow and inclined wellbore section were added to the previous model to study hole cleaning problem while drilling underbalanced well. This new mechanistic model for cuttings transport is developed by combining two-phase hydraulic equations, turbulent boundary layer theory and particle transport mechanism. It is shown that the model is useful for predicting minimum annular velocity and cuttings bed thickness in horizontal and inclined wellbore geometry. Effects of temperature, bottom hole pressure, liquid flow rate, gas injection rate, cuttings size and density, inclination angle and Rheological properties of drilling mud on hole cleaning are analyzed using this mechanistic model. Model is validated by available experimental data. Computer simulation indicates that cuttings bed thickness is very sensitive to the liquid phase flow rate. It dominates cuttings transport efficiency. However, during underbalanced drilling, increase of liquid phase fraction may not always be feasible while trying to keep low ECD. Meanwhile, injection of gas has positive effects on cuttings transportation depending on the flow patterns and drilling mud viscosity. Elevated temperature causes a significant increase of bed thickness and it is important to recognize this negative effect, especially when drilling HTHP wells. The effect of pressure on cuttings concentration is negative. Larger size and heavier cuttings make hole cleaning more difficult and require higher pump rate for low viscosity fluids. Increases of liquid phase density results in better hole cleaning. The range of hole angles from about 35 – 60 deg (from vertical) is the most difficult for cuttings transport. Frictional pressure losses in a deviated wellbore highly depend on cutting bed thickness. Simulation results are compared to available experiment data and show good agreement. In summary, this paper presents a model which is useful for practical hole cleaning during UBD.
World-Record ERD Well Drilled from a Floating Installation in the North Sea
Authors: Hjelle A. , Teige T. G. , Rolfsen K. , Hanken K. J. , Hernes S. , Huelvan Y. 
Published: December 2007

Abstract
The well 34/8-A-6 AHT2 was drilled from the Visund Field Floating Production and Drilling Unit (FPDU) in the North Sea, and set on production in October 2005. The well was drilled to 9082 m/29796 ft measured depth and has an Along Hole Depth (AHD) reach of 7593 m/24911 ft, which is a world record for Extended Reach Drilling (ERD) from a floating installation.
The 34/8-A-6 AHT2 is also the longest Down hole Instrumentation and Control System (DIACS) installation worldwide, with the lower isolation packer set at 8560 m / 28084 ft measured depth. The well includes three hydraulically operated flow valves, which are used as down hole chokes to optimize the production from the separate zones in the reservoir.
Subsea developments in combination with ERD wells can increase oil production and lower total development cost. The drilling progress was 108 m/day from seabed to total depth, according to the Rushmore drilling performance definition, and the payback time for this well was less than two months. Experiences gained on this well indicate that even longer wells can be drilled from subsea locations in the near future.
A Steamflood Experiment in a Utah Tar Sand
Authors: Johnson Lyle A. , Fahy L. John , Romanowski Leo J. 
Published: December 2007

Abstract
The first Laramie Energy Technology Center steamflood experiment in a Utah Tar Sand, LETC TS-1S, was conducted in the Northwest Asphalt Ridge deposit located near Vernal, Utah. Following completion of construction in April 1980, steam injection was initiated in the center well of two concentric inverted five spot patterns. The zone chosen for the experiment was a 45 foot (14 m) thick sandstone in the Rimrock Member of the Mesaverde Formation. The pattern area was 0.25 acres (1012 m2) and contained a 12% API (986 kg/m3) bitumen with a viscosity greater than 106 centipoise (103 Pa.s) at reservoir conditions. The average oil saturation was 78.9 percent of the pore volume. During the 160 days of operation, 65,700 barrels (10.4 dam3) of water equivalent steam were injected at 360 to 530 psig (2.5 to 3.7 MPa) and 180 to 650 BPD (29 to 103 m3/d). Total production during the test amounted to 1,150 barrels (183 m3) of oil and 6,250 barrels (994 m3) of water.
New Storage Phenomena in High Drawdown Gas Well Buildup
Authors: Fligelman Haim , Cinco-Ley H. , Ramey H. J. 
Published: December 2007

Abstract
Strange behavior has been noticed in pressure buildup curves for gas wells producing from very low permeability, high drawdown formations. The typical unit slope on a log-log graph of real gas pseudopressure m(p) vs time for wellbore storage-dominated data becomes very steep (greater than unity) before going through a transition to the semilog straight line. A study of this behavior was made by means of a one-dimensional radial mathematical model wherein wellbore storage is treated rigorously. It was detected that buildup cases characterized by moderate to high pressure drawdown before shut-in always exhibit a shift of the conventional log-log graph to a larger value of the dimensionless wellbore storage constant, compared to the liquid solution. The typical unit slope in the wellbore storage control period is still preserved, and after that period, the buildup curve coincides smoothly with the constant physical properties liquid case. In extreme pressure drawdown cases, in addition, a more significant shift is also followed by a steepening towards the liquid solution.
Drawdown Testing for High Velocity Gas Flow
Authors: Fligelman Haim , Cinco-Ley Heber , Ramey Henry J. 
Published: December 2007

ABSTRACT
As the slope and intercept of the conventional semilog graphing are sensitive to gas and well properties, the calculation of conductivity and skin effect for cases of high velocity flowrate can yield erroneous results.
A sensitivity analysis of the transient response of a well located in an infinite medium while a non-Darcy flow caused by high fluid velocity is presented. A rigorous material balance on the wellbore is included.
The analysis of simulated drawdown tests produced several important conclusions. Gas and formation properties such as gas gravity, initial pressure, temperature, and permeability can lead to significant errors if not considered correctly. The rate-dependent pseudoskin factor is not simply an additive term as are the other skin factor components. The radius of invasion of the damaged region around the well remains a significant factor ëven for long times in cases where turbulence is considered. The effect of high velocity is more pronounced in a production case than in an equivalent injection case, and the slope of the conventional semilog straight line may be greater (production) or less (injection) than 1.151. Although wellbore storage was handled in a rigorous manner, for high pressure drawdown cases the shape of log-log drawdown curves of mD(1,tD) vs tD are similar to the liquid log-log graphs. Thus log-log type-curve matching can be a useful technique for detecting the beginning of the semilog straight line. New correlating groups which consider a variety of possible conditions were found. A correction procedure for analyzing drawdown tests when data for only one flowrate are available is suggested.
Recovery of CO2 from Flue Gas for Enhanced Oil Recovery
Authors: Sears John T. , Waltermire Debbie M. , Marcus Steven R. 
Published: December 2007

ABSTRACT
The present study was initiated to investigate the problems associated with recovery of CO2 from flue gases for enhanced oil recovery. In particular, MEA and activated K2CO3 absorbing solutions were evaluated.
In MEA, amine sulfite and amine sulfate are the dominant impurities formed with minor amounts of higher thiosulfates and oxidized amines. In activated potassium carbonate solutions, only sulfites and sulfates ions were found, without higher oxidation products. The absorption rate of CO2 in these solutions decreases with increasing loading of CO2 in almost a linear fashion. The absorption coefficients obtained were linear with respect to active uncombined solution species, in agreement with theory of chemical-reaction control at low CO2 partial pressures. The coefficients ranged from 50 × 10−5 lb mole/ft2-sec for 20% MEA to 2 × 10−5 for 9% K2CO3 (8% K2SO4, 0.9% MEA) at zero CO2 loadings. It was found that addition of EAE rather than MEA as an activator increased the absorption rate by a factor of 2-4. At high CO2 loadings, the absorption rate of EAE-activated potassium carbonate and MEA have almost the same values.
Alternative absorption systems were analyzed in a preliminary cost evaluation. It is recommended that a K2CO3 (EAE activated) solution be the process of choice. The impurity level in the recovered CO2 was estimated to be ≤ 100 ppm non-condensible gases, 20-200 ppm SO2, and &lt; 20 ppm NOX. There is little cost differential between an amine process and a K2CO3 process; the final decision should be based on operating experience, operating ease, and corrosion problem minimization. The estimated cost of recovery was 0.88ȼ/MCF CO2 (available at 1 atm. pressure) for extraction from a large stream of flue gas.
Implementation of Smart Solutions in the Persian Gulf: Optimized Drilling and Completion in South Pars 6–8
Authors: Johannessen B. , Teigen A. S. , Vestvik J. 
Published: December 2007

Abstract
This paper will cover the drilling and completion optimizations implemented in the South Pars field, which has resulted in more than two years of saved rig time compared to the budgeted time.
Improvements introduced to the drilling process and the technologies and equipment utilized to achieve the success will be discussed, as well as the decision to change the "standard South Pars completion solution" commonly used by all other operators in the same field.
The previous best drilling and completion times by the other operators in the field have all been surpassed, and the total operational time spent on each well have been reduced to almost half of the original budget estimate of 72 days per well (Figure 1). We will try to shed some light on the planning process and the fit for purpose technical solutions that have lead to the best overall well times so far in the South Pars field.
Lifting of Heavy Oil with Inert-Gas-Operated Chamber Pumps
Authors: Dewan John T. , Elfarr John 
Published: December 2007

Abstract
Lifting of heavy oil is currently carried out almost exclusively by rod pumps. Severe problems are often encountered, such as rod floating and overloading due to high fluid viscosity, pump sticking and erosion with high sand production, heavy crude plugging, and gas locking under steam flood conditions. Special rod pumps alleviate some of these problems but installation and maintenance expense typically remains high.
This paper describes an unconventional gas lift system which can replace rod pumping for shallow (&lt;3,000 ft.) heavy oil production. It circumvents all of the aforementioned problems and in addition has advantages in adjusting to variable production rates, in steam injection and in ease of well cleanout.
The heart of this system is an insert chamber downhole, whose only moving parts are two standing valves. Produced fluid entering the chamber is periodically expelled into a production annulus by pressurized gas injected from the surface down a small injection string. Natural gas, inert gas, or even air can be used for pumping. This paper analyzes the operation of the chamber lifting system and shows how to optimize the system design and the operating variables to obtain maximum production at minimum cost.
With the close spacing of thermal wells (2-5 acres), the combination of a single inert gas generator and associated compressor to supply a large number of wells equipped with chamber pumps is feasible. Several types of inert gas generators are described. Capital and operating costs of chamber and rod pumping for a 170 well system are compared. The economic return is far greater for chamber pumps when bottomhole conditions are such that steam locking of rod pumps occurs.
High-Speed Drillstring Telemetry Network Enables New Real-Time Drilling and Measurement Technologies
Authors: Reeves M. , Macpherson J. , Zaeper R. , Bert D. , Shursen J. , Armagost K. , Pixton D. , Hernandez M. 
Published: December 2007

Abstract
A real-time, bi-directional, drill string telemetry network has been proven reliable over the course of seventeen field trial wells, including seven wells within the U.S. The network has demonstrated simultaneous upward and downward data rates of up to 57,000 bits per second, with reliability comparable to current mud pulse telemetry technology.
The network utilizes unique inductive coupling coils and armored coaxial data cables embedded within premium double-shouldered drilling tubulars to provide high bandwidth telemetry without impacting drilling operations.
U.S. field trials have included multiple vertical and directional gas wells drilled to depths exceeding 14,000 feet in the Arkoma region of southeastern Oklahoma. The drilling environment has involved extremely harsh vibrational conditions, including air hammer drilling and multiple jarring events.
During these trials, a leading oilfield service company has deployed a number of different downhole measurement-while -drilling (MWD) tools interfaced directly to the drill string telemetry network. This interface allows real-time surface control and interrogation of the downhole tools and transmission of high-density, low-latency drilling dynamics, formation evaluation and directional MWD data at previously impossible speeds.
In a recent well, the operator elected to eliminate their usual mud pulse transmission tool, utilizing the telemetry drill string network and compatible MWD tools as the primary downhole data source.
This paper builds on prior publications and provides details of the latest field trials, including, for the first time, information on the development and performance of network enabled MWD tools. A summary of the mechanical and electrical design considerations associated with tool conversion is offered.
Observations regarding mud-pulse and drill string telemetry performance, including operational differences, rig time impact, added value and deployment issues are provided.
Finally, this paper provides details, and value propositions, of downhole measurement and drilling applications that are enabled by the availability of a reliable telemetry drill string network.