bluuebunny/crossref_metadata_2025_split huggingface dataset:
Evaluating the Transport of Solids Generated by Shale Instabilities in ERW Drilling
Authors: Martins A. L. , Santana M. , Gaspari E. , Campos W. 
Published: December 2007

Abstract
The problem of cuttings transport in the inclined sections of ERW's is a major concern in the oil well drilling industry. This paper presents an innovative time dependent mathematical model, along with a computer implementation of it, which is based on the well-known two-layer model approach. An innovative feature of this model consists in the consideration of the added amount of solids that comes from the crumbling and cave-in of the well bore. The unstable effects of this added amount of solids is taken into account through a variable representing the added volume of cuttings per unit time and length. A finite volume approach is used to solve the system of differential equations. The paper represents a first step on the integrated analysis of cuttings transport and well bore stability problems.
Modeling Multi-Lateral Wells
Authors: Su Ho-Jeen , Fong William S. 
Published: December 2007

Abstract
A computation scheme was implemented in a general-purpose, finite-difference simulator to model multi-lateral wells. Frictional pressure drop along the wellbore and proper fluid mixing at lateral connection points were included in the calculation of wellbore pressure profile for each lateral. The formulation is general and a lateral can be branched out from any point along the main well path.
Since the production profile of each lateral is influenced by the wellbore pressure distribution, the prediction accuracy depends on a good wellbore flow model. We implemented the Beggs and Brill1 correlation, a homogeneous flow model, and a new model proposed by Ouyang et al2 which included an acceleration term and accounted for the lubrication effect due to radial influx. We compared well performance prediction results using the three models.
We studied the impacts of different tubing sizes on the well performance and the production contribution from each lateral.
Investigation of SAGD Steam Trap Control in Two and Three Dimensions
Authors: Edmunds Neil R. 
Published: December 2007

Abstract
Steam trap production control, i.e. producing fluids to maintain BHT just below the boiling point of water, has been traditionally recommended for SAGD operations. In this work a numerical investigation of the relationships between producing steam trap subcool setting and related parameters of interest such as fluid level, pressure, production rate, and steam/oil ratio is reported for a prototype Athabasca reservoir.
It is found that steam trap dynamics are rather more complex than previously imagined. In three dimensions and the real world, for example, inflow temperature can and does vary significantly along the well according to local conditions, resulting in 3D simulations predicting significantly lower production rates than equivalent 2D cases. The findings have implications to many aspects of SAGD engineering including process optimization, forecasting, completion design and installation, production operations and performance analysis.
The Successful Use of Transverse Hydraulic Fractures from Horizontal Wellbores
Authors: Crosby D. G. , Yang Z. , Rahman S. S. 
Published: December 2007

Abstract
Multi-stage, transversely fractured horizontal wellbores have the potential to greatly increase production from low permeability formations. Such completions are, however, susceptible to problems associated with near-wellbore tortuosity, particularly multiple fracturing from the same perforated interval. A criterion, based on that by Drucker and Prager, has been derived, which predicts the wellbore pressures required to initiate secondary multiple transverse hydraulic fractures in close proximity to primary fractures. Secondary fracture initiation pressures predicted by this new criterion compare reasonably well with those measured during a series of unique laboratory-scale multiple hydraulic fracture interaction tests. Both the multiple fracture initiation criterion and the laboratory results suggest that close proximity of primary hydraulic fractures increases the initiation pressures of secondary multiple fractures by the order of only 14 percent. This demonstrates that transversely fractured horizontal wellbores have limited capacities to resist the initiation of multiple fractures from adjacent perforations or intersecting heterogeneities. Petroleum engineers can use the multiple fracture initiation criterion when designing hydraulic fracture treatments to establish injection pressure limits, above which additional multiple fractures will initiate and propagate from the wellbore.
Systematic Approach Enhances Drilling Optimization and PDC Bit Performance in North Slope ERD Program
Authors: Wolfson Larry , Mensa-Wilmot Graham , Coolidge Robert 
Published: December 2007

Abstract
Technological advancements have enhanced operational efficiency in North Slope directional and horizontal drilling applications. These gains result from resolution of technical and economic issues that once seemed insurmountable in extended reach drilling programs. Well profiles have become more challenging because of our need to reach targets, depths and departures that previously seemed unrealistic. Regardless of our current levels of success, there is the urgency to develop methods and processes that will further improve drilling efficiency. As such, it is imperative that a systematic, logical and quantifiable approach for developing and implementing technologies in these types of applications, especially Extended Reach Drilling (ERD) programs be defined.
This paper will show how this approach was used to enhance drilling efficiency in the intermediate section (12-1/4" hole size) of a North Slope ERD program. It defines and quantifies two sets of parameters for the drilling operation: performance objectives and requirements on a "per interval" basis. It evaluates the functional relationships and dependencies among the drilling operation's components. Although effective in directional, horizontal and ERD applications, the method promotes continuous improvement and makes it useful in any drilling environment.
Gannet E Subsea ESP: The Application of Technology in Practice
Authors: Harrall S. J. , Nevelsteen D. 
Published: December 2007

Abstract
The Gannet E single well subsea ESP development has been on stream since January 1998. This is the first such installation in the North Sea, and is only the third development of its kind in the world. At a 14km step-out from the Gannet Alpha platform, Gannet E represents a world record in terms of electrical transmission distance for such developments. Since start-up, flowrates of 18,000 barrels of oil per day have been sustained, whilst valuable operating experience has been acquired in a relatively short time span. During the project planning and execution phases, emphasis was placed upon anticipating potential operational pitfalls which could jeopardize the overall success of the development. Areas of concern lay in the fields of: ESP control and run-life;Control of the platform facilities;Electrical power transmission;Data gathering;ESP flexibility with respect to flowrates and required delivery pressures;Reservoir-related uncertainties;Well completion installation.
The paper describes the technology and techniques applied in order to Maximise the safeguards to the overall system integrity and deliver a robust development. Actual start-up and running experience is discussed in relation to the planning effort. Attention is paid towards the analysis of trips and the evaluation of operability limits over the whole system. The major learning points which are being carried into further projects of this nature are also presented.
Massive Fracture Stimulation in Deep, High-Pressure Athel Formation
Authors: Wong Sau-Wai , Ford Steve , Turner Bob 
Published: December 2007

Abstract
The deep, high pressure Athel reservoirs are located in the South Oman Salt Basin. Due to low permeability, un- stimulated well rates are low. Recently, two wells have been stimulated with the largest hydraulic fractures in the Middle East. The post-frac production lives up to expectation. The well design and stimulation approach has significantly improved the economic viability of the Athel accumulation.
P. 407
Neural Net Identification of Flow Regime using Band Spectra of Flow Generated Sound
Authors: van der Spek Alex , Thomas Alix 
Published: December 2007

Abstract
Multiphase production log interpretation requires that the flow regime along hole in the wellbore is known. Flow regime is the cased-hole analogue of lithology. Knowledge of the flow regime will help to interpret tool signals, will help to evaluate the flow rate on a per phase basis, and will reduce post processing load by at least a factor of 10. Flow regime can be classified correctly by a neural net in up to 87% of all cases using 1/3 octave band spectra of flow generated sound. A neural net trained on commercially available tool data (noise cut's) appears to be too sensitive to the wellbore inclination. Hence, application of automated neural net interpretation of noise logs requires a new generation of noise logging tools.
P. 93
A New Low Risk Technique of Forming A Level 6 (TAML) Multilateral Junction
Authors: Hogg William Clifford , MacKenzie Alan 
Published: December 2007

Abstract
Within the last two years, multilateral systems offering full hydraulic and mechanical integrity have become commercially available in the petroleum industry. Emphasis has now begun to shift toward increasing the flexibility of these systems while minimizing the overall risk associated with the implementation of the multilateral. This paper details the development of a new Level 6 (TAML) type of multilateral that offers mechanical and hydraulic integrity and allows full liner bore access into either lateral, as demanded by the industry. Descriptions of the system and its development are discussed along with an assessment of the risk minimization possible with this new type of multilateral as compared to current state-of-the-art multilateral systems.
P. 289
North Sea Harding Project: A Well Engineering Case History Success
Authors: McLellan W. , Ferguson M. , McKay G. , Hough S. 
Published: December 2007

Abstract
This paper discusses the Well Engineering successes of BP's current North Sea Harding Project and the intrinsic reasons behind them, with particular reference to the management philosophies and engineering technologies utilised to ensure maximum performance, productivity and efficiency. The key contributory areas are discussed in both overview and detail format as appropriate.
P. 387
Cuttings Flow Meters Monitor Hole Cleaning in Extended Reach Wells
Authors: Naegel M. , Pradie E. , Delahaye T. , Mabile C. , Roussiaux G. 
Published: December 2007

Abstract
This paper presents an innovative solution to monitor hole cleaning in Extended Reach Wells. It was successfully used while developing marginal oil and gas reserves offshore TIERRA DEL FUEGO (ARGENTINA) by TOTAL AUSTRAL operator and partners DEMINEX and PAN AMERICAN ENERGY.
Keeping the hole clean in Extended Reach Wells is a key issue as cuttings accumulation will result in increased torque, pressure losses and will create a high risk of getting a stuck pipe.
Cuttings Flow Meters (CFM) continually measure and record the flow of cuttings at the outlet of the shale shakers. This measurement allows an enhanced understanding of hole cleaning process and status, which in turn permits to optimize the main drilling parameters such as flow rate, rotation, circulation times, reaming time at connections and rate of penetration.
It has been observed on those wells that the volume of cutting returns always fits with the actual volume of hole, over extended periods of time. By comparing on a permanent basis the volume of hole drilled with the volume of cuttings returned to surface, one can monitor the cuttings accumulation in the hole, one can thus better diagnose an increase in hole friction, adjust mud rheology parameters and circulating rate in order to minimize the surface and bottom hole circulating pressures while ensuring a good transport, all factors which are essential to further extend the drilling envelope.
P. 401
Breakthrough Well Suspension Operations in West of Shetland Horizontal Wells
Authors: Elliot G. , Makin G.D. , Ferguson S.E. , Moyes P.B. 
Published: December 2007

Abstract
Foinaven is the first field to be developed in the deep water, West of Shetland. A sub-sea development, in 500 metres of water, Foinaven will have fourteen production wells. Most of these wells will have extended reach horizontal sections, completed with sand control screens. The challenging weather conditions mean that a number of the wells are suspended once the screens are in place, with the upper completions being run when the weather is less severe.
The suspension operations required plugs to be set using drill pipe or coiled tubing, from a semi-submersible rig capable of operating in the West of Shetland environment. The high day rates associated with these vessels mean that a major cost saving can be realised by eliminating these interventions.
This paper describes the planning, development, and field deployment of a deep-well barrier system which is installed as part of the sand control completion. The clear understanding of the well objectives led to the creation of a system whose benefits exceeded simply reducing the cost of the completion operations, namely:–deep well suspension without well intervention;–protection against fluid losses immediately after completing the reservoir section;–improved well productivity;–less operational risk during the completion phase;–reduced personnel exposure to harm due to less rig-up operations;–shorter well clean-up times;–ability to run the completions underbalance.
At the time of writing this abstract, four Foinaven wells have been completed in this fashion. The learning from these first applications has led to such systems gaining increasing acceptance throughout the industry.
P. 409
Multiphase Transportation: A Kinetic Inhibitor Replaces Methanol to Prevent Hydrates in a 12-inc. Pipeline
Authors: Leporcher E.M. , Fourest J.M. , Labes-Carrier C. , Lompre M. 
Published: December 2007

Abstract
This paper describes how a kinetic inhibitor has been selected and then deployed in a gas pipeline in operation. Elf has performed a lot of research about new alternatives for hydrate inhibition in order to extend the area of multiphase transportation. Kinetic inhibitors can act at much lower concentration than thermodynamic inhibitors (alcohols). These new chemicals do not prevent the nucleation but significantly delay the growth of hydrate crystals. The duration of inhibition, which determines the chemical efficiency depends on the rate of sub-cooling. The understanding of these key parameters allows to contemplate multiphase transportation in the thermodynamic domain of hydrate formation. Within the family of kinetic inhibitors issued from research programs and proposed by manufacturers, three chemicals were pre-selected. Hydrodynamic conditions of the liquid phase were assessed on a pilot laboratory loop 1" × 22m. A lot of specific tests including compatibility with the field injected chemicals, modification of physical properties of the liquid phase were performed in order to anticipate any operational disturbance. From this test program, the overall most efficient chemical was selected.
Then this chemical was injected instead of methanol during three weeks. The onshore gas pipeline 12" × 17km was continuously monitored with eight pressure transducers located along the pipeline. The conditions of deployment, hydrodynamic observations and induced consequences on the downstream process are presented. The main conclusion is that a kinetic inhibitor injected at a rate of 170l/d in a pipeline carrying 1 MSm3/d of gas (with its condensate and condensed water) replaced methanol, with sub-cooling conditions up to 8 C.
P. 455
How do Anions in Water-Based Muds Affect Shale Stability?
Authors: Carminati S. , Del Gaudio L. , Zausa F. , Brignoli M. 
Published: December 2007

AbstractThe effect of different anions on shale behavior has been studied. Viscosity effects, pore blocking mechanisms and osmotic phenomena have been evaluated by pressure transmission tests under high pressure and high temperature conditions. Parallel to this short term experiments, mechanical (indentation) tests on cuttings aged for 12 days at 80°C have been run. In addition to organic and inorganic sodium and potassium salts, two commercial glycols (with and without Cloud Point) have been selected and analyzed. All the experiments have been carried out at alkaline pH. It is shown that different anions induce different shale hardening and different unbalance (related to osmotic phenomena) between pore and drilling fluid pressures. Besides that, some conclusions on the role of glycols have been drawn.
Gel Treatment Optimization by Rheological Measurements
Authors: Broseta Daniel , Marquer Olivier , Baylocq Pascal , Féry Jean-Jacques , Zaitoun Alain 
Published: December 2007

Abstract
This paper gives some recommendations of the pertinent rheological measurements for an efficient gel screening in water shut off and conformance improvement treatments. The proposed methodology is based on measurements of gelation time and final yield stress, which are related, respectively, to the pumping time and to the maximum differential pressure the gel can withstand in the reservoir (matrix or fracture).
A laboratory study has been carried out with two polyacrylamide/chromium (III) formulations, one of which, involving a high-molecular-weight polyacrylamide, is adapted for plugging fractures, and the other one, involving a low-molecular-weight polyacrylamide, is usually employed for plugging porous matrices. These formulations have been used in some specific field applications. A series of viscosity, storage modulus and yield stress measurements on the gelling solutions are presented in this paper, with the purpose of quantitatively characterizing the gelation kinetics and final strength of the gel formed. The proposed methodology is utilized for investigating in detail the influence of shearing on the gelation time and final gel strength. In practice, the gel formulation is in fact subjected to hours of strong shearing in the surface facilities (i.e., pumps, tubings….) and in the near-wellbore part of the formation before being left under quiescent conditions (well shut-in).
The results demonstrate that shearing has for effect to restrain gelation and, in particular, to limit the viscosity rise due to the formation of aggregates of crosslinked polymers (microgels). The gelation time, defined in relation to this viscosity rise, strongly increases with shear rate for the high-molecular-weight (non-Newtonian) formulation, but is unaffected by shear for the low-molecular weight (Newtonian) formulation. Experiments have also been conducted in which an extended initial period of strong shearing was followed by another extended period of rest. The final gel strength of both formulations, evaluated from yield stress measurements, turned out to be independent of the shear rate history.
Optimization of Hydrogen Sulfide Scavengers Used During Well Stimulation
Authors: Al-Humaidan A. Y. , Nasr-El-Din H. A. 
Published: December 2007

Abstract
Many water injectors and oil producers are damaged due to the accumulation of iron sulfide deposits near the wellbore area. For example, iron sulfide is present in water supply and injection wells as a product of sulfate reducing bacteria (SRB). Hydrochloric acid can be used to remove iron sulfide, however this process can result in the release of hydrogen sulfide, a toxic and corrosive gas. Moreover, hydrogen sulfide reacts with ferric ions and precipitates elemental sulfur. Elemental sulfur is insoluble in acids, practically impossible to dissolve, and can damage the formation. The objectives of this study are to screen hydrogen sulfide scavengers, which can be used during well stimulation, and assess the performance of the selected chemical in the field.
A simple, fast procedure was developed to evaluate hydrogen sulfide scavengers. Several types of scavengers, all aldehyde-based chemicals, were examined. The concentration of hydrogen sulfide scavenger was varied from 0 to 10 wt%. Reaction temperature was kept constant at 25°C.
A simple, fast procedure was developed to screen hydrogen sulfide scavengers used during well stimulation. The efficiency of capturing hydrogen sulfide was found to be a function of scavenger type and concentration. At scavenger concentrations greater than 0.5 wt%, a polymer-like material was observed with most scavengers examined; this material adversely affected acid reaction with iron sulfide and could cause formation damage. Low sulfide concentrations were obtained in the acid returns when S-1 was added in the acid formulation.
Improvement of Low-Permeable Cement for Zonal Isolation at High-Temperature Conditions
Authors: Dubois N. , Noik Ch. , Rivereau A. , Vernet Ch. 
Published: December 2007

Abstract
The development of new drilling technologies and the increase of severe operation conditions related to deep water applications lead to enhance the performance of drilling fluid and cement formulations. Success of cementing operations depends on slurry placement and then on the material properties under temperature and pressure conditions. A novel cement developed for high temperature wells is proposed. This material issued from civil engineering is composed of classical Portland cement and silica particles. The major problem in these formulations was to manage with the compacity of dry powders by a better choice of the particle size distribution of cement and silica grains. At least two types of silica were used, one was a crushed sand and the other a silica fume. The control of the initial homogeneity of the dry mixture allowed to adjust the rheology of the granular media in water. The slurry fluidity is finally adjusted by an optimum in the concentration of the dispersant additive leading to a minimum in viscosity.
Other additives such as retarders and fluid loss reducer were selected according to the temperature range of use. Properties of the setting material were evaluated by compressive tests on crashed core and water permeability measurements. Test results indicated good relation between mechanical properties and initial compacity of the cement systems.
Application of Multiphase Flow Methods To Horizontal Underbalanced Drilling
Authors: Smith S. P. , Gregory G. A. , Munro N. , Muqeem M. 
Published: December 2007

AbstractMultiphase flow can be present in all aspects of underbalanced drilling. This paper outlines the ways in which multiphase flow pressure loss calculations can be used by drilling engineers in the design and optimization of underbalanced drilling operations. Then, detailed field measurements for several horizontal wells drilled underbalanced with coiled tubing are used to evaluate the application of existing pressure loss calculation methods to this unique application.
A Massively Parallel Reservoir Simulator for Large Scale Reservoir Simulation
Authors: Dogru A. H. , Li K. G. , Sunaidi H. A. , Habiballah W. A. , Fung L. , Al-Zamil N. , Shin D. , McDonald A. E. , Srivastava N. K. 
Published: December 2007

Abstract
A Massively Parallel reservoir simulator (POWERS) has been developed and fully integrated with Suadi Aramco's pre and post processing graphical environment. The simulator has been validated against published results and other industrial simulators. Three different giant oil field studies using million grid blocks were carried out by using the new simulator. Benchmark runs indicated near linear performance improvement with linearly increasing number of processors. With the current capabilities mega cell construction, preprocessing and post processing is quite fast. History match runs involving over million grid block and 30-50 years of history is obtained in less than one hour on a low cost parallel computer.