bluuebunny/crossref_metadata_2025_split huggingface dataset:
Ensuring Systems Compatibility for Deepwater Chemicals
Authors: Frostman L. M. , Gallagher C. G. , Ramachandran S. , Weispfennig K. 
Published: December 2007

Abstract
Efficient production of oil and gas generally relies on the use of specialty chemicals to prevent solids deposition, inhibit corrosion, and control fluid phase properties. While performance testing is an important step in selecting appropriate chemicals for such applications, the compatibility of the chemicals with materials used in the production system is critical to the successful implementation of any chemical treating program. Extensive formulation work, laboratory testing, and field verification are required to ensure that production chemicals will be compatible with system metals and polymers used in pumps, umbilicals, and capillaries. In offshore applications, particularly in deepwater where many components of the production system are not readily accessible, the systems compatibility of any production chemical is an essential part of the flow assurance process. This paper will focus on compatibility of production chemicals typically used in deepwater applications with system materials, and the deliverability of these chemicals through umbilicals and capillaries. Materials commonly used in deepwater installations were chosen, including mild steels, stainless steels, Nylon 11, elastomers, and thermoplastics. Standard test procedures including documentation were implemented. The results of a comprehensive study of corrosion, paraffin, asphaltene, hydrate and scale inhibitors will be discussed. Using material compatibility data for performance chemicals enhances the selection process for existing production, optimizes material selection and design in the development stage for new production, and facilitates formulation of new products.
Field Evaluation of Downhole Corrosion Mitigation Methods at Prudhoe Bay Field, Alaska
Authors: Hsi Daniel C. , Woollam Richard C. 
Published: December 2007

Abstract
Increasing downhole corrosion failures are observed in large number of carbon steel (CS) completion wells at Prudhoe Bay field in Alaska. The main corrosion damage mechanism was identified as CO2 corrosion (sweet corrosion), caused by relatively high temperature (200 - 220 °F) and high CO2 content (12%) in the reservoir gas.
Different downhole corrosion mitigation methods, including corrosion inhibitor batch treatments, gas lift corrosion inhibitor treatments, chemical treater strings, internally plastic coated tubing, and 13Cr tubing were evaluated in the field.
The relative effectiveness and economics of different downhole corrosion mitigation methods were compared based on extensive corrosion monitoring data from weight loss coupons, downhole and surface electrical resistance (ER) probes, caliper surveys, and well completion/ workover records.
Study results show that corrosion inhibitor batch treatments have limited treatment life (&lt;10 days) in higher water cut wells. Inhibitor film persistency (treatment life) is inversely proportional to the daily water production rate. Except for very low water cut wells, quarterly or monthly corrosion inhibitor batch treatments are not cost effective at Prudhoe Bay field. Gas lift corrosion inhibition, on the other hand, can potentially provide cost effective protection against downhole corrosion in higher water cut gas lift wells.
Study results also show that chemical treater strings and 13Cr tubing have excellent corrosion resistance performance and they are recommended for future new completion if high water production rates and/or long completion service life are expected.
An Investigation of the Stability of Colloidal Asphaltene in Petroleum Reservoirs
Authors: Alkafeef Saad F. 
Published: December 2007

Abstract
Asphaltene precipitation from petroleum fluids has proved to be a difficult problem to define and study. Asphaltene problems may occur deep in the reservoir formation and cause permeability reduction as well as contribute to serious plugging problems in oil well tubing and surface facilities. The stability of a dispersion in colloid science terms refers to the resistance of the particles to flocculation. The degree of this resistance is a measure of stability. Asphaltene colloidal dispersions in petroleum reservoirs are considered physically stable if free from any changes in physical properties. This paper first examines theoretically particles (asphaltene) in crude oil to determine, if they are electrically charged, how important it is to their inter-particle repulsion (stability). The theoretical result is then compared with the surface potential and steric effect of asphaltene and/or solid in petroleum fluids. Both theoretical and experimental results indicated that the electrical charge effects of asphaltene were found to play an utterly negligible role in the interaction between asphaltene particles and either surface or other particles. The stability of colloidal asphaltene in oil was investigated and determined to be caused by the steric effect of high molecular weight material (resins) adsorbed on asphaltene particles. The aggregation kinetic rates of asphaltene were also investigated using a laser back-scattering technique and determined to be influenced by the resin chemical potential concentration and the dispersion medium solvency. The latter needs to be a "good solvent" for the resin so that the aliphatic chains can be extended and move freely, thus enhancing the steric repulsion force.
Iron Sulfide Formation in Water Supply Wells With Gas Lift
Authors: Nasr-El-Din H. A. , Al-Humaidan A. Y. , Mohamed S. K. , Al-Salman A. M. 
Published: December 2007

Abstract
Iron sulfide scale is present in sour gas, oil and water wells. It is present in various chemical species with different iron to sulfur ratios. Iron sulfide species with high iron content is soluble in acids, whereas those rich in sulfur are almost insoluble in acids. Iron sulfide scale was detected in several water supply wells where a sour gas is used for gas lifting operation. The objectives of this study were to determine the mechanism that led to the formation of this type of scale, to characterize this scale and determine the most effective chemical treatments to remove and prevent reoccurrence. Lab work included characterization of the scale, and examine various acids and non-acids formulae to remove various iron sulfide species.
Several wells in a sandstone aquifer are used to supply water needed for the operation of gas oil separation plants (GOSPs). The reservoir pressure is low, therefore the water is produced using gas lifting. The gas used is an associated gas that is produced with the oil from a carbonate reservoir. The gas is sour with a hydrogen sulfide content of 2 mol%. In addition, the supply water contains total iron at 5–10 mg/L. Hydrogen sulfide reacts with the iron present in the aquifer water and precipitates iron sulfide on the well tubulars and gas injection nozzles. Accumulation of iron sulfide has caused many operational problems.
Lab results indicated that iron sulfide scale deposited on the inside wall of the well tubulars. The scale was uniform with a thickness that increased from 0.025" above the gas injection point to 0.25" at the well head. The composition of the scale changes with the length above the gas injection point. Just above the gas injection point, the scale was identified as FeS whereas close to wellhead, the scale was identified as FeS2. Acid solubility varied across the length of tubing. In areas where there is FeS, acid solubility in 20 wt% was 85–90 wt%. On the other hand, acid solubility was only 3–5 wt% in areas where FeS2 was present. Experimental results showed that 20 wt% could be used to remove a portion of the scale, however a suitable hydrogen sulfide scavenger should be added to the acid. Several non-acid formulae were tested and some of them were effective in dissolving acid-insoluble scale.
Unlike typical types of oilfield scales, iron sulfide is present in different species. The chemical structure of these species affects the method that should be used to remove this scale. This study addresses various types of iron sulfide and methods to remove and prevent the formation of this type of scale.
Fully Coupled Geomechanics in a Commercial Reservoir Simulator
Authors: Stone Terry , Bowen Garfield , Papanastasiou Panos , Fuller John 
Published: December 2007

Abstract
Oil recovery operations are seeing increased use of integrated geomechanical and reservoir engineering to help manage fields. This trend is partly a result of newer, more sophisticated measurements that are demonstrating that variations in reservoir deliverability are related to interactions between changing fluid pressures, rock stresses and flow parameters such as permeability. Several recent studies, for example, have used finite-element models of the rock stress to complement the standard reservoir simulation.
We discuss current work on fully coupling the geomechanical elastic/plastic rock stress equations to a commercial reservoir simulator. This finite difference simulator has black-oil, compositional and thermal modes and all of these are available with the geomechanics option. In this paper, the focus is on the implementation of the stress equations into the code. Some work on benchmarking against an industry standard stress code is also shown as well as an example of the coupled stress/fluid flow. Our goal in developing this technology within the simulator is to provide a stable, comprehensive geomechanical option that is practical for large-scale reservoir simulation.
Enhanced Oil Recovery from Oil Fields with Bottom Water
Authors: Zakirov S. , Yulmetjev T. , Zakirov E. 
Published: December 2007

Abstract
A significant number of developed oil fields in the world possess bottom water and almost all reservoirs have edge water. Correspondingly water-oil zones can be of a large dimension. Oil recovery under bottom or edge water presence is characterised by the low efficiency of recovery: first by a high water cut that leads to a low oil recovery factor. This paper presents results of the research designed to improve recovery under these conditions.
Integrating Geomechanics and Geophysics for Reservoir Seismic Monitoring Feasibility Studies
Authors: Vidal S. , Longuemare P. , Huguet F. 
Published: December 2007

Abstract
Seismic measurements acquired at different stages in the life of a reservoir can monitor the fluid distribution over production time. Changes in saturation, pore pressure and stresses, induced by reservoir production may influence the process of wave propagation in rocks. The variations in mean effective stresses, due to changes in mean stress or /and pore pressure, are not always integrated in a proper manner. We present here a methodology to evaluate what is the contribution of a geomechanical approach on the computation of seismic velocities. This methodology has been used for the monitoring of an underground gas storage site of Gaz de France, the French gas Supply Company. Successful results illustrate the importance of integrating geomechanics with geophysics to validate real sonic data from DSI.
Perforating Requirements for Sand Control
Authors: Venkitaraman A. , Behrmann L. A. , Chow C. V. 
Published: December 2007

AbstractThis paper presents an improved approach to selecting perforation parameters (charge type, shot density and phasing) for sand-control applications that takes into account both laboratory and field data. Laboratory experiments have shown that perforation-generated rock debris can induce gravel-pack impairment, thus leading to a decline in gravel-packed perforation productivity. Previously published analytical models for predicting gravel-packed well performance relied on field data analyses and back-calculations of gravel permeability in the casing/cement portion of the perforation tunnel and/or effective shot density. In all cases the damage was attributed to the casing/cement portion of the perforation tunnel with varying extent of effective shot density.Distinction is first made on the perforation tunnel definition (open/collapsed) in the formation depending on the strength (consolidation) of the rock. The selection of perforation parameters (penetration, area open to flow in casing, shot density) for a conventional gravel pack involves a tradeoff between the pressure drop in the formation (resulting from formation damage, damage in the tunnel) and in the casing/cement portion of the tunnel filled with damaged gravel. In the case of fracturing while gravel packing, the perforation phasing and shot density play a dominant role in the inflow performance because these parameters dictate the perforation tunnel area open to flow in communication with the fracture. The benefits of oriented perforating as a technique for such completions is discussed. A comprehensive set of optimum perforating guidelines is provided for both types of completions (gravel packing and fracturing while gravel packing) for different rates (oil and gas flow).Field data are presented from a well in Nigeria where this technique was used to improve gravel-pack completion efficiency in weak sand completions. Sample calculations are also provided.
Restriction of Gas Flow in Gas-Capped Oil Reservoirs: Field Experiences and Lessons to Learn
Authors: Lakatos I. , Lakatos-Szabó J. , Kosztin B. , Palásthy Gy. 
Published: December 2007

Abstract
The laboratory and field studies were focused on development of a well treatment technology which can be used for restriction of gas coning in the Algyö reservoir. The method is based on simultaneous placement of a polymer/silicate gel at the GOC and a supporting foam pillow into the oil bearing layer. Extensive laboratory studies were carried out to tailor the chemical system to the field conditions. The use of short chain alcohol in the gel-forming system and natural protein or glycerine as additive in the foam-forming solutions were in the focus of improvements. Special attention was paid to implementation of the technology. Two-point injection regime was elaborated to develop a horizontal barrier between the oil and gas bearing zones. Three projects consisting of five treatments, one of the a repeated one, were carried out between 1991 and 1999. The field test resulted usually partial success: the hydrodynamic measurement definitely shown that the barrier was correctly placed, the oil flow in the pay zone was not effected, the GOR temporarily improved and the WOR positively changed. The long-term observations, however, definitively prove that application of foam pillow instead of other supporting media increase significantly the chance to have measurable change in the unwanted gas production. On the other hand, however, the investment and the return rate of expenditure is not balanced even in those cases when the treatment is qualified as successful in technical sense. The Hungarian experts take a stand on extending the observation period for more cycles and to collect abundant arguments to continue or to suspend the R&D activities and the field projects.
The Use Of Photon Logs To Evaluate Gravel Packing
Authors: Neill B.E. , Haire J.N. , Lynch D.A. , Lawrence T.D. 
Published: December 2007

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

Abstract
The application of gravel packing in the soft and unconsolidated sands of California has enjoyed increasing use in recent years. The practice has allowed sand-free production from zones that have been impossible to produce by other means.
The photon log is available to the oil industry to evaluate grovel packs prior to placing the well on production, enabling operators to determine the production, enabling operators to determine the success of grovel packing operations and take immediate action when needed. Failures due to incomplete packs are minimized, as (ire workover programs, damaged equipment, and lost production. programs, damaged equipment, and lost production. A complete pack is especially important in steam operations because of the long time span between completion and actual recovery of hydrocarbons.
The photon logs supply valuable information pertaining to the quality of the grovel pack to the pertaining to the quality of the grovel pack to the engineer in time to isolate and eliminate potential problems and improve the probability of a problems and improve the probability of a productive and trouble free completion. productive and trouble free completion. This paper will discuss the photon log, its presentation, interpretation, applications, and discuss field presentation, interpretation, applications, and discuss field examples.

Introduction
Sand control is a chronic problem for the petroleum industry. The cost of sand production is enormous in terms of damaged equipment, expensive workover programs, and lost production. The problem exists programs, and lost production. The problem exists to some degree in (almost every producing area throughout the world, and considerable effort is devoted to preventing sand production so that oil and gas can be profitably produced.
Sand control methods fall in two broad categories: limiting production rates to reduce the tendency of the sand to move and various means of either artificially consolidating sand or of mechanically propping the formation. propping the formation. Open hole gravel packing is one of the most common examples of the latter category.
Open hole grovel packs are extensively used in the soft and unconsolidated sands of California. A wirewrapped liner or a slotted liner is set across the productive zone, and sand or grovel is pumped into productive zone, and sand or grovel is pumped into the annular space between the liner and the formation. The section is usually underreamed prior to setting the liner, so that a thicker pack is provided between the formation and the liner.
The purpose of the packed annular space is to provide a permeable filter that will allow production provide a permeable filter that will allow production and prevent the formation sand from moving toward the well bore.
Important Considerations In Geothermal Well Log Analysis
Authors: Sanyal S.K. , Meidav H.T. 
Published: December 2007

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

Abstract
The objectives of well logging, logging operation and log analysis in the geothermal industry are considerably different from those in the petroleum industry. This paper discusses these differences. Usually the commercial logging companies provide well logging services using essentially the same equipments and procedure used in the petroleum industry. This creates some problems in quality assessment, normalization and calibration of logs. This paper discusses those problems with examples from geothermal wells in the Imperial Valley, California; Raft River, Idaho; and Jemez Mountains, New Mexico. Interpretation techniques of well logs used in the geothermal industry are borrowed in toto from the petroleum industry. Because of the inherent differences in the nature of petroleum and geothermal reservoirs, log interpretation techniques now used for geothermal wells often provide inaccurate or erroneous answers. This paper points out many such problems in interpretation and suggests improved procedure, where possible.

Introduction
Well logging operation and log analysis in geothermal wells are considerably different from those in the petroleum industry. These differences can be grouped under three main areas: logging objective, logging operation and log interpretation. In this paper we discuss these differences.
Although the development of hardware and interpretation techniques for geothermal wells have begun in earnest, it will be many years before the new hardware and techniques become practical and standardized. At present, practically all the hardware and techniques in the geothermal well logging industry are borrowed in toto from the petroleum industry. This leads to many problems in logging operation, assessment of log quality and log interpretation in the geothermal industry. The purpose of this paper is to point out these problems and suggest remedies, where possible.
A Study on BEM Series of Pour Point Depressants and their Application in China
Authors: Zhang Fusheng , Xie Huizhuan , Dong Lijian 
Published: December 2007

Abstract
On the basis of analyzing composition of the crude oil in China, and according to mechanism of PPD reducing pour point, BEM series of PPDs which have a good pour point-reducing/viscosity-reducing effect for Chinese crude oils, have been developed and already used in Luning, Zhongluo, Pulin, Weijing, Donghuang and Donglin etc. long distance pipelines in China. After the crude oils transported by above-mentioned pipelines were treated by 50mg/kg of BEM series of PPDs, their pour points were reduced by 19□, 19.5□, 18□, 13.5□, 13□ and 20□ respectively, and their viscosities were reduced by 84.6%, 94.9%, 97.5%, 93.0%, 15.7% and 23.0%, in the same time, safety and flexibility of above-mentioned pipelines operation were all enhanced, and a tremendous economic benefit was obtained. The experimental result shows the following. Above waxing out temperature, violent pump shear and weak pipe shear can't affect the rheological behavior of the crude oil; during waxing out peak temperature, violent pump shear can deteriorate the rheological behavior of the crude oil but weak pipe shear can improve the rheological behavior of the crude oil. The main reason for above-mentioned phenomenon is the following. Above waxing out temperature, there are a very small number of wax crystals in crude oil, shear couldn't alter the structure of wax crystals; during waxing out peak temperature, there are a great number of wax crystals in crude oil, the structure of wax crystals was destroyed by violent pump shear and became the smaller wax crystals with the new active centres, then the smaller wax crystals interlocked by the new active centres and formed network structure with the larger strength, but weak pipe shear improved probably interaction between PPD molecules and wax crystals.
HEC No Longer the Preferred Polymer
Authors: Vollmer Daniel P. , Alleman David J. 
Published: December 2007

Abstract
Because of the problems associated with hydroxyethyl cellulose (HEC), several water soluble polymers were evaluated to replace HEC used to viscosify completion and workover fluids. The rheological properties and formation damage tendencies of these polymers were initially tested in dry form in various brines at elevated temperatures. Then the same polymers were prehydrated and re-evaluated in high dense brines (above 11.6 ppg). The results showed that HEC is no longer the preferred polymer.
The preferred polymer at equal polymer concentrations outperformed HEC in nearly all cases based on rheological and formation damage tests. The preferred polymer does not have a tendency to precipitate at elevated temperatures like HEC does in sodium and potassium chloride solutions and unlike HEC can viscosify brines containing a particular concentration range of zinc at any density. This polymer can be used to thicken formate brines where HEC is not recommended. As a result, the polymer was implemented into the field and successful case histories are presented.