bluuebunny/crossref_metadata_2025_split huggingface dataset:
Laboratory Investigation of the Improvement in Waterflood Displacement Efficiency by the Addition of Finely Divided Coke Particles to Floodwater
Authors: Raza S.H. , Ertekin Turgay 
Published: December 2007

Discussion of this paper is invited. Three copied of any discussion should be sent to the Netherland Section of the Society of Petroleum Engineers, P.O. Box 228, The Hague, the Netherlands. Such discussion may be presented P.O. Box 228, The Hague, the Netherlands. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
Laboratory investigation has been made of a novel approach designed to improve the displacement efficiency of a waterflood. This approach consists of injecting a slurry of finely divided solid particles in water, at a linear advance rates of 3 to 20 ft./day, into 4 to 6-darcy unconsolidated sandpacks saturated with oil and water. The solids used in the slurry preparation are oleophilic coke particles and hydrophilic fluorite particles, in concentrations ranging from particles, in concentrations ranging from 0.02 to 1.2 gm/liter. The sand used in the preparation of sandpacks is rendered either preparation of sandpacks is rendered either strongly oil-wet by prolonged contact with oil containing N-octylamine or strongly water-wet by prolonged contact with water containing a water-soluble surfactant, Orvus-K.
The data presented in this paper show that the addition of coke particles to floodwater results in enhanced oil recovery which is associated with lowered water-oil ratio production in both the oil-wet and the water-wet sandpacks. The increment in oil recovery over the conventional waterflood, generally of the order of 2 to 107, P.V., is directly proportional to the P.V., is directly proportional to the initial oil saturation in the sandpack and to the slurry concentration up to a maximum concentration value. In comparison, the addition of fluorite particles to floodwater does not result in enhanced oil recovery from either the oil-wet or the water-wet sandpack.
The enhancement may be explained by the principle of preferential wettability exchange - a principle used in the benefaction of a mineral from its associated waste matter in the froth flotation process of mineral dressing. It is shown that mechanical drag does not play any significant role toward the enhancement of oil recovery.

Introduction
Primary oil recovery from an oil field depends upon the type and magnitude of the expulsive forces, the permeability of the reservoir rock, the viscosity of the reservoir oil, and to some degree upon the field exploitation. These factors vary not only from field to field but may also vary within a field.
Water Quality In The North Sea And Injection Water Standards For North Sea Oil Fields
Authors: St. John D.H. , Barkman J.H. 
Published: December 2007

Discussion of this paper is invited. Three copies of any discussion should be sent to the Netherland Section of the Society of Petroleum Engineers, P.O. box 228, The Hague, the Netherlands. Such discussions may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
Seawater injection will probably be required to maintain reservoir pressure in most North Sea oilfields. Since there is little published data on North Sea water quality was carried out in the vicinity of the Auk and Brent fields. From these measurements conclusions have been drawn about the filtration and chemical treatment requirements for the seawater that will be injected into the reservoirs of these two fields.

Introduction
Water injection will be needed to maintain initial reservoir pressure in the Auk and Brent fields and will probably be required in most North Sea oil fields. The Auk project will require about 70,000 b/d injection water and each Brent production platform will require about 250,000 b/d. Because of its greater size, the emphasis of the work was directed towards the Brent field. The most convenient source for injection water is North Sea water taken from below the production platforms and in order to design facilities for filtering and treating this water a knowledge of its quality and its effect on the reservoir is needed. At presented there is no published data on the quality of North Sea water with respect to suspended solids, micro-organisms or scaling tendencies. This paper describes the results of a programme of on-site measurements of North Sea water quality which were made in the vicinity of block 211/29, 90 miles northeast of the Shetland Islands. The objectives of the programme were:To determine the type of chemical treatment needed to prevent corrosion, scaling and bacteriological problems.To find the pump intake depth that yields the best quality water.To determine whether the suspended solids level can be substantially reduced by filtration.To estimate the rate of impairment due to suspended solids that would result in the Brent formation from the injection of either filtered or unfiltered seawater.
Parameters Affecting Azimuth and Length of a Secondary Fracture During a Refracture Treatment
Authors: Siebrits E. , Elbel J.L. , Detournay E. , Detournay-Piette C. , Christianson M. , Robinson B.M. , Diyashev I.R. 
Published: December 2007

Abstract
Refracturing in a plane normal to that of the initial fracture can be beneficial in tight gas fields, even when the initial fracture is deeply penetrating and highly conductive. The magnitude of the benefits will depend on the timing and the penetration of the secondary fracture. The Gas Research Institute has sponsored a project that addresses the conditions required for maximum benefit and the validation of the process with a field trial. This paper addresses the theory and conditions required for maximum benefit.
P. 17
Effect of Completion Geometry and Phasing on Single-Phase Liquid Flow Behavior in Horizontal Wells
Authors: Yuan Hong , Sarica Cem , Brill James P. 
Published: December 2007

Abstract
Horizontal wells can have very complex flow geometries, in part due to interaction between the main flow stream and the influxes along the wellbore, and also due to completion type.
An experimental facility was used to investigate the effects of completion geometries and the density and phasing of injection openings in horizontal wells. Three test sections with perforation densities of 5, 10 and 20 shots per foot and phasings of 360, 180 and 90 were. Four test sections were used for slotted liners, including one single slot case and three multiple slot cases. The numbers of slots for multiple slot cases were 18, 18 and 36 on 4-ft. long sections with slot phasings of 360, 180 and 90, respectively. A total of 1,257 tests were conducted for no fluid injection, no main flow at the test section inlet, and with fluid injection for Reynolds numbers ranging from 4,000 to 60,000 and for influx to main flow rate ratios ranging from 1/5 to 1/2000.
Experimental results show that completion geometry, phasing and density in addition to Reynolds number and influx to main flow rate ratio have dramatic effects on the pressure behavior and therefore the production behavior of horizontal wells.
A general friction factor expression for horizontal wells with multiple injection openings was developed based on the conservation of mass and momentum. A commercial Computational Fluid Dynamics (CFD) computer program was used to determine the length of the flow developing region in a horizontal well after the flow is disturbed due to radial influx. Applying experimental data and the result of CED simulation to the general friction factor expression resulted in new simple correlations for horizontal well friction factors. Very good agreement was found between the friction factor correlations and experimental data. A field example is presented to show the importance of using a proper friction factor correlation to calculate the pressure drop in a horizontal well.
P. 93
Techniques for Solving Torque and Drag Problems in Today's Drilling Environment
Authors: Aston M.S. , Hearn P.J. , McGhee G. 
Published: December 2007

Abstract
Torque and drag minimisation is becoming increasingly important, due to the need to drill more challenging wells and because of tighter legislations restricting the use of highly lubricating oil based and synthetic based drilling fluids. This review compares different mechanical and chemical methods of torque and drag reduction, with reference to field experiences. Results obtained from a new lubricity rig are discussed. These indicate that a wide range of lubricant types can be effective in water based muds. Therefore, lubricant choice needs to be largely based on cost and availability considerations. The rig is found to be suitable for evaluating solid lubricants such as beads, and these are shown to be effective in silicate based fluids.
P. 55
Quantitative NMR Interpretation
Authors: Cannon D.E. , Minh C. Cao , Kleinberg R.L. 
Published: December 2007

Abstract
Advancements in nuclear magnetic resonance (NMR) logging have provided important information on formation productivity, pore size and fluid type. This information has been most easily used as a stand-alone NMR interpretation or as overlays of NMR data on other log data. Attempts at using NMR data quantitatively with traditional porosity measurements have been more difficult. The difficulty originates from the need to combine measurements that are insensitive to pore structure and pore fluid with NMR measurements that are sensitive to those formation properties. For example, even in a perfectly clean freshwater sand, an NMR tool may produce a porosity that is different from density and neutron porosity. The differences have been attributed to either the lack of an early-time signal from small pores associated with silt and clay size grains or incomplete fluid polarization. The lack of an early-time signal has been addressed with the latest generation tools; however, incomplete polarization still needs to be addressed.
Polarization would not be a problem if NMR data were acquired with a sufficient wait time to guarantee complete polarization. The penalty for such a guarantee is long acquisition times and increased costs. In addition, accurate knowledge of the formation's T1 is needed to determine the correct wait time. Such knowledge is often not available.
Current NMR tools include an approximate polarization correction based on the measured T2 and an estimate of T1/T2 ratio. A more rigorous method is proposed that replaces the welisite correction with one dependent on the actual volumes the tool is measuring. To do this, the data are reprocessed without a polarization correction. Calculations are made of NMR tool-response parameters for different pore sizes and pore fluids. These calculations are a function of the hydrogen index and T1 of the individual formation components; inputs to the parameter calculations are pressure, temperature, oil viscosity, water salinity and acquisition wait time. The outputs are the tool's response to fine grain, coarse grain and vuggy porosities; gas; oil; and oil-base mud filtrate. The resultant parameters, NMR data and other log data are entered into a simultaneous solver for the final result.
The advantage of this approach is that it allows the polarization correction to be adjusted according to the individual volumes present. it also allows incomplete polarized NMR data acquired at increased logging speeds to be appropriately corrected. Examples using this approach on formations with light hydrocarbon zones and vugs in water-base and oil-base muds are examined. The results for all cases are self-consistent including resistivity measurements, which are also sensitive to pore size and pore fluids, confirming the viability of the technique.
P. 227
Integration of NMR with Other Openhole Logs for Improved Formation Evaluation
Authors: Minh Chanh Cao , Freedman Robert , Crary Steve , Cannon Darrel 
Published: December 2007

Abstract
The recently introduced measurement of total porosity from nuclear magnetic resonance (NMR) tools can help to identify the hydrocarbon type and to improve the determination of formation total porosity (t) and water saturation (Swt) in combination with other openhole logs. In shaly formations, porosities are difficult to estimate in the presence of hydrocarbons, especially for gas and light oils. Water saturations are even more difficult to estimate because critical parameters such as clay cation exchange capacities per unit pore volume (Qv), formation factors (F) and formation water resistivity (Rw) might not be known. The latter quantities are essential inputs into the Waxman-Smits and Dual-Water model saturation equations.
In the typical case of shaly gas bearing formations, both the total porosity corrected for the gas effect and the gas saturation (Sxgas) in the flushed zone can be derived by combining total NMR porosity (TCMR) and density porosity (DPHI). Adding resistivity logs such as Rxo and Rt helps to differentiate between gas and oil. Furthermore, the flushed zone water saturation (Sxot) computed from 1 - Sxgas can be used in many ways. One procedure uses Sxot in conjunction with the Rxo saturation equation to determine Qv or F. Another technique uses Sxot in conjunction with SP to estimate Qv when Rw is known. Yet, another method estimates Qv directly from the NMR short relaxation time part of the T2 distribution and use Sxot in conjunction with SP to estimate Rw. The new interpretation procedure follows the sequential shaly sands approach: first, determine porosity; second, determine shaliness and third, determine saturation. The new procedure improves on the classical method by offering new ways to compute Qv, F and Rw. The methodology is applied to a number of field examples.
P. 245
The Effects of Faulting on Production form a Shallow Marine Reservoir - A Study of the Relative Importance of Fault Parameters
Authors: England William A. , Townsend Chris 
Published: December 2007

Abstract
This paper describes a sensitivity study in which a variety of fault patterns was superimposed on a set of realistic heterogeneous sedimentary models of a near-shore marine environment. Using an experimental design technique, 32 faulted models were upscaled to a 40 acre (420m) water flood from which recoveries at water breakthrough and 1 MPVI were estimated by flow simulation. Statistical analysis of these data allowed us to study the relative effects of the various fault pattern parameters. We also studied the effects of adding faults to the same set of unfaulted reservoir descriptions.
In summary, fault plane seal was found to be the most important fault plane seal was found to be the most important fault parameter influencing recovery at water breakthrough. Recovery at 1 MPVI was influenced by cross fault presence and fault plane seal. The stacastic noise in the modeled recoveries was increased significantly when faults were added. The influence of the sedimentary parameters was not eliminated by the addition of faults, although some significant reductions did occur for recoveries at 1 MPVI.
An important effect appears to be the reduction in sweep efficiency when injector wells are placed near to sealing faults. Conversely, in layered (hydraulically sealed) sedimentary models, faulting can increase recovery by improving cross communication.
P. 279
Inflow Performance Relationships of Horizontal and Multibranched Wells in a Solution- Gas-Drive Reservoir
Authors: Retnanto Albertus , Economides Michael J. 
Published: December 2007

Abstract
In predicting and optimizing the performance of single and multiple wells, or complex well architecture, within a drainage or flow unit, we have favored benchmark analytical or semianalytical models. Recently. a general productivity model has been constructed and presented that allows for the performance prediction of any single- and multi-well configuration within any reservoir geometry in both isotropic and anisotropic media. Such an approximation is known to have limitations when applied to two-phase reservoir flow. This work used a numerical simulator to generate IPR's for horizontal or multibranched wells producing from a solution- gas-drive reservoir. First, a base case is considered with typical fluid, rock, and reservoir properties. Then, variations from the base case are investigated. These variations cover a wide range of fluid, reservoir, and well characteristics. The effects of numerous reservoir and fluid properties on the calculated curves are investigated. Bubblepoint pressure and reservoir depletion have a significant effect on the curves. A generalized dimensionless IPR based on nonlinear regression analysis of simulator results is developed. This IPR curve is then used to predict the performance of horizontal and multibranched wells in a solution-gas-drive reservoir combined with our productivity model. For relatively low bubblepoint pressures, the curves coalesce on Vogel's classic relationship. For higher pressures they deviate substantially.
P. 239
Application of Interpolation In-Field Referencing to Remote Offshore Locations
Authors: Williamson H.S. , Gurden P.A. , Kerridge D.J. , Shiells G. 
Published: December 2007

Abstract
A method for modelling the crustal magnetic field vector from total intensity data has been used to determine the magnetic field snapshot required for Interpolation In-Field Referencing (IIFR). The method has been validated in a number of ways, including comparison of magnetic and gyroscopic survey data in three UK fields.
P. 387
Case History of the Implementation of a Fast Track Gas Production SCADA Project
Authors: McLean Dan , Alvis Vern 
Published: December 2007

Abstract
Field Automation systems comprising EFM and SCADA Technology continue to improve the profitability of oil and gas producers through increased visibility of remote wells and improved accuracy and delivery of production data. The installation of SCADA forms the backbone for other departments within the enterprise to enable pro-active business decisions. The direct benefits of SCADA can be realized as soon as the systems are in service. To achieve the benefits as soon as possible a fast track approach to the retrofitting of wells and compressor plants was taken. The case history presented will describe the SCADA system and installation plan, and indicate the benefits realized from a business management perspective.
The implementation of the SCADA system for PanCanadian Petroleum Ltd. was termed the Gas Production Inquiry Reporting System (GPIRS) and comprised automation of approximately 500 wells and 35 compressor stations/gas plants throughout southern, central, and north-western Alberta. The 1993 budget of $25M CDN for the retrofit work was staged in two parts with Phase I measurement implementation completed in 8–9 months, the Phase II automation implementation completed over 9–10 months the following year. The main topic of this case study is the nature of the implementation, including interfacing and coordination of many disciplines in order to achieve a fully installed and commissioned system. Numerous contractors, sub-contractors and PanCanadian internal groups participated in the project. It will be shown that the resultant improvements in gas deliverability and improved marketing substantially justified the capital cost.
P. 291
Identifying and Meeting the Key Needs for Reservoir Fluid Properties A Multi-Disciplinary Approach
Authors: Moffatt B.J. , Williams J.M. 
Published: December 2007

Abstract
With emphasis on fast-track developments often involving small fields or harsh conditions, reliable reservoir fluid properties are becoming increasingly important. However pressure on staffing levels can lead to inadequate expertise within operating companies for identifying needs, for justifying sampling analysis costs, and for validating results.
The work involved an investigation of physical and chemical fluid property requirements within the entire Exploration and Production organization of an operator. The information obtained was used to rank key properties and was compiled in a suitable format to assist less-experienced staff in identifying areas of primary concern. Field sampling and laboratory analytical practices were also investigated, and a series of Best Practices developed. An additional investigation was performed to quantify typical financial risks on the basis of experience. It is demonstrated that even relatively poor- accuracy measurements, if made at an early stage of a development, can have very significant information value. Once fully implemented, this work should have a major effect on reducing the risks of unexpected production problems, of improper facilities design and of out-of-specification sales product.
The paper reports the key fluid characteristics identified by a wide range of disciplines, and the risks associated with inadequate fluid property data are quantified in terms of the dollar cost of failures or missed opportunities. Best Practices for sampling and analysis of well test fluids are made available.
The methods presented can be used widely by petroleum industry professionals to identify and satisfy needs for reservoir fluid properties.
P. 315
Practical Analysis of Drilling Mud Flow in Pipes and Annuli
Authors: Zamora Mario , Lord David L. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
New numerical and graphical techniques permit practical assessment of drilling mud hydraulics. Developed from a sound theoretical analysis of power law fluids, they are extended by power law fluids, they are extended by a generalized model to approximate Bingham plastic and power law with yield stress behavior. Applicable equations are expressed in terms familiar to the field engineer.
A proposed geometry factor reduces the hydraulic equations to a single set describing pipe, parallel plate and annular flow. It also defines a generalized Reynolds number for different geometries and flow regimes found in the circulating system.

Introduction
Drilling muds are non-Newtonian fluids. As such, the equations describing their rheological behavior are both complex and bulky. This is true even under assumptions of isothermal, steady-state flow in circular pipes or stationary concentric annuli.
There is a gap between theoretical work in mud hydraulics and its application in the field. This is unfortunate because theory and laboratory data must eventually be correlated to actual behavior in the well. Major efforts to eliminate this gap include extensive simplification of the rheological equations and use of wellsite computers. Approximations for field use are necessary; however, oversimplification can lead to errors. Most wellsite mini-computers (or programmable calculators) have limited core, making it difficult, if not impossible, to do justice to present rigorous solutions.
This paper presents a practical approach to calculate surge/swab and other wellbore pressure losses. pressure losses.
A Novel Approach to the Exploitation of Deepwater Gas Fields - The FPLSO Difference
Authors: Stephens K.R. , Ronalds B.F. , Piermattei E.J. 
Published: December 2007

Abstract
The introduction of regulations prohibiting the flaring of natural gas, the increase in demand for a clean burning fuel, the improvements in liquefaction and offloading technologies, and the potential for mobility of a floating natural gas processing, liquefaction, storage and offloading vessel which could exploit several smaller reserves over its effective operating life, will permit the development of smaller fields located in deeper water, further offshore and lacking in existing infrastructure; fields once considered marginal. The FPLSO vessel is the key for the exploitation of these fields. The focus of this paper is the motions response of the Floating semi-submersible natural gas Processing, Liquefaction, Storage and Offloading (FPLSO) vessel when subject to wave loading from the head seas direction in Australian North West Shelf Conditions. This is of particular interest due to the fact that the length of the vessel is unprecedented, 478 metres.
P. 131