bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Sensitivity of Micellar Flooding to Reservoir Heterogeneities
Authors: Kossack C.A. , Bilhartz H.L. 
Published: December 2007

American institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the Improved Oil Recovery Symposium of the Society of Petroleum Engineers of AIME, to be held in Tulsa, Okla., March 22–24, 1976. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made. provided agreement to give proper credit is made. Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. 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
This paper provides a comparative evaluation of the effect of reservoir heterogeneity on a miscible-tertiary micellar flood. The sensitivity of slug size, preflush volume, surfactant loss, and miscibility saturation of this complex displacement process was evaluated for a homogeneous, randomly heterogeneous, non-communicating layered and partially communicating layered model partially communicating layered model reservoir. The five-component, finite-difference reservoir simulator used for this study is described in detail.
The results show that reservoir heterogeneity is a dominant factor, adversely affecting the performance of micellar flooding to such an extent that the process may not be feasible in many non-homogeneous reservoirs. In the partially communicating layered model reservoir large volumes of preflush were required; and even after adequate preflushing, 50 to 70 percent of the post waterflood oil in place was unrecoverable. The results indicate place was unrecoverable. The results indicate that for a heterogeneous reservoir the most economical slug size may be a very small surfactant slug that displaces only the easily mobilized oil. This work also shows that a reduction in the surfactant's adsorption properties and a micellar fluid that mobilizes properties and a micellar fluid that mobilizes oil at low surfactant concentrations will, for a micellar flood with a given slug size, both substantially improve recovery.

Introduction
The objective of this work was to study the effect of reservoir heterogeneity on the performance of micellar flooding using a performance of micellar flooding using a numerical simulator. The four reservoir descriptions used in this study were homogeneous, randomly heterogeneous, noncommunicating layered, and partially communicating layered models.
A Practical Solution To Preparing A Sour Water For Injection
Authors: Weeter R.F. 
Published: December 2007

Introduction
Degasification of hydrogen sulfide from sour San Andres source water in West Texas has increased the availability of water for a flood project in Midland County. The plant is treating water for Mobil Oil Co.'s flood project in the Pennsylvanian beds of the Pegasus field.
About three years ago, it became apparent that supplies of water to be used in secondary recovery in the Permian Basin would soon become critically short and that use of available sour waters would be necessary in many floods yet to be started. It became further apparent that this sour water would have to be treated for removal of hydrogen sulfide before it could be used economically.
Several methods of stripping H2S from water which were considered of limited potential success included: aeration with forced draft aerators; stripping the H2S with engine exhaust in a packed column; and stripping the H2S with exhaust gas produced by a submerged burner in a packed column.
Finally, after studying all available methods, the following method was decided upon: Stripping the H2S with exhaust gas generated in an external vessel under carefully controlled conditions to produce an oxygen-free gas, using a bubble cap column of sufficient height to remove hydrogen sulfide to an acceptable residual, arbitrarily chosen as 1.5 ppm. However, this method had several drawbacks:
The method had not been tried, even on a pilot scale. No equipment had been designed for this purpose. Design efficiencies had not been established. Time did not permit pilot plant operation.
The bubble cap column was chosen since it is less subject to fouling than a packed column and, if fouled, is more readily cleaned. Some data were established by the author in a similar column using natural gas to strip oxygen from water. That column has operated successfully for approximately six years under operating conditions which place extreme design restrictions on the column, with resulting low efficiencies.

COLUMN DESIGN
Design of the column is based on Henry's law, which states that "the solubility of a gas in a liquid is directly proportional to the partial pressure [in atmospheres] of that gas in the surrounding atmosphere at a given temperature." Thus, if the partial pressure of H2S in the atmosphere surrounding the water approaches zero and if, at the same time, the H2S is given sufficient opportunity to escape from the water, the dissolved H2S will also approach zero. It is obvious that countercurrent stripping is ideal for obtaining these conditions.
Design of the column trays was made using published data and the following criteria:
Capacity = 13,000 BWPD Riser velocity = 10 ft/sec Tower diameter = 4 ft 1D Weir length = 3 ft Weir height = 4 in. Available gas pressure = 5 psig
Since no samples of water from supply wells were available for the design, the following assumptions were made:
Minimum operating temperature, 68 F Operating pressure, Atmospheric H2S content of water, 170 ppm Tray efficiency, 7 per cent pH of water, 6.0 Sulfides which are H2S, 86 per cent Gas/water ratio, 66. 7 scf/bbl
Using Enzymatic Breakers in Horizontal Wells to Enhance Wellbore Clean-up
Authors: Hembling Drew , Chan Albert , Garner Jay , Beall Brian 
Published: December 2007

Abstract
This paper describes the lab testing procedures and results for testing formation core material and used drill-in fluid samples to optimize wellbore clean-up procedures. In addition, a three well case history reviewing completion damage of horizontal wells in the Kuparuk Field on the North Slope of Alaska will be discussed. The case history will compare three separate horizontal completions all completed in the same fault block, one of which, includes the use of enzymatic type breaker system for enhanced wellbore clean-up. Production data, spinner log surveys, and pressure transient testing results will be reviewed from all three completions. Matching the drilling fluid with the formation properties and understanding the completion effect on well performance can be critical to economic success of most sand control and slotted liner type completions.
Extensive laboratory studies were conducted to determine the extent of damage occurring while drilling the pay zone section, especially in horizontal wells using a starch / xanthan based drill-in fluid. This study also defined and evaluated filter-cake removal methods using actual drill-in fluids from the field and formation core samples. Results of these laboratory studies as well as case histories will be presented to illustrate the benefit of using Polymer Specific Enzymes1 (PSE) to reduce drill-in fluid damage in horizontal wells where slotted liner type completions are used.
A Laboratory Drilling Mud Overbalance Formation Damage Study Utilising Cryogenic SEM Techniques
Authors: Byrne M. T. , Spark I. S. C. , Patey I. T. M. , Twynam A. J. 
Published: December 2007

Abstract
Laboratory reservoir conditions flood tests were used to determine the clean up efficiency of a drilling mud that was applied at two different overbalance pressures. The test was designed to simulate, as closely as possible, the conditions occurring in the reservoir during the drilling operation. Relevant core material was used and the pore/overburden pressures, mud overbalance pressures, temperature and production drawdown pressures/rates applicable to field conditions were applied in the laboratory simulation. Drilling mud filtrate volume loss versus time measurements were made at reservoir conditions using sophisticated pumps. All wetted parts of the rig were constructed of hastelloy C276 alloy to avoid corrosion artifacts interfering with the test. Permeability measurements were made prior to mud application and again at the end of the flood test analysis to determine the level of any formation damage. In order to determine the nature of the formation damage mechanisms, geological techniques which included dry and cryogenic SEM and thin section analyses were undertaken. These techniques were applied to the plug trims prior to testing (untreated samples) to determine the natural state of the rock, paying particular attention to the clay mineral and cement types, morphologies and distributions. The plug samples were examined at the end of testing (treated samples) and any variations noted which would highlight the damage mechanisms. The dry SEM and thin section analyses were used to determine solid damage mechanisms such as clay fines migration, scale precipitation and drilling mud solids invasion. The cryogenic SEM analyses were used to examine any fluid damage mechanisms such as wettablity alteration, microemulsion formation, water/oil blocks or fluid retention.
A new technique of cryogenic SEM using EDX (Energy Dispersive X-Ray) analysis was used for X-ray mapping of the remnant mud bodies to determine solid and fluid distributions.
Controlled Debris Perforating Systems: Prevention of an Unexpected Source of Formation Damage
Authors: Javora P. H. , Ali S. A. , Miller R. 
Published: December 2007

Abstract
An unexpected source of potential formation damage can be generated when controlled debris perforating systems are detonated in clear completion brines. This paper presents the results of a systematic laboratory study of this potential damage, previously unreported in the published technical literature.
One source of the damage is related to the powdered metals and metal alloys incorporated into controlled debris perforating systems for the purpose of generating, upon detonation, highly desirable, finely divided residues consisting mostly of particles 200 mesh or smaller. When sprayed into clear completion brine at the high detonation temperatures, high surface area particles become activated and then react with water to form metal oxides, metal hydroxides and hydrogen gas.
However, when the activated particles are sprayed into clear completion brines with certain specific compositions, cemented by-products are also generated at the formation face. These by-products can be extremely formation damaging. Fortunately, the nature and damaging characteristics of the cemented byproducts can be altered and prevented by the addition of a chemical inhibitor into the clear completion brine.
Objectives of this paper are therefore to: 1) Identify clear completion brines which generate cemented byproducts and those which do not; 2) determine brine properties that control the cementing process and inhibit damage from by-products; 3) review operating conditions that accentuate the damage caused by cemented by-products; and 4) provide a chemical inhibitor for clear completion brines which prevents the formation of cemented by-products and damage to the formation.
Guidelines for the selection, modification and field application of clear completion brines used with controlled debris perforating systems based are presented.
Fracture Containment Mechanisms in Soft Rock Frac-Packs
Authors: Buie Ronald P. , Yen H. Dang 
Published: December 2007

Abstract
This study presents a 9-well case history that examines fracture height containment and how variable rock properties affect soft-rock fracture geometry. All frac-packs were designed to remove near wellbore damage while simultaneously installing sand control. Several completions have perforation intervals close to water sands or underlying water contacts. Even with aggressive pump schedules, contrasts in rock properties successfully kept fractures contained. This study examines what reservoirs can be fracpacked without fracturing into water; how contrasts in rock properties will keep a fracture contained; and how variable rock types affect soft-rock frac-packs.
Case histories for depleted, normal pressured, and slightly geopressured reservoirs are included in this study. Bottom hole pressure data during pumping operations, radioactive tracer logs, and production histories were used to evaluate the completions.
Evaluation of this study has minimized the concerns of fracturing into water; led to aggressive treatment schedules when fracturing around water; increased the awareness and importance of alternate path technology; and changed overall perforating strategies.
Application of Inflatable Packers for Production Testing and Conformance Problems in Algeria
Authors: Poitrenaud H. , Souilah B. Y. , Fragachán F. E. 
Published: December 2007

Abstract
Through tubing inflatable packers conveyed with coiled tubing have proved to be ideally suited for multiple zones stimulation, water and/or gas control intervention where accurate fluid placement is essential for the success of the job. The high expansion ratio and sealing capabilities of modern elastomers used today in through tubing Inflatable have allowed operations in more hostile wells than previously possible, increasing job reliability.
Conformance problems related to non desired water and/or gas production is drastically affecting the oil production of certain fields in Algeria. The exclusion of this water and/or gas represents a challenging task by itself. Even more under the hostility of multiple zones intervals open for simultaneous production, making the problem diagnosis a key factor for the success of the intervention.
This paper presents the successful application of a methodology to diagnose and effectively exclude the non desired production with a novel technique using through tubing inflatable packers. A thorough discussion about the inflatable packers, deployment, inflation procedures, zone isolation and selective placement is presented. In addition, four case studies corresponding to the application of this methodology are discussed in detail. Two corresponding to exclusion of water and gas production, respectively, by selective placement of a x-link rigid polymer gel and two corresponding to production testing of isolated intervals.
Finally, results of these interventions are presented. Including stabilized production before and after each treatment.
Floating Production and Offloading Vessels with Dynamic Positioning: An Approach for the Future
Authors: Delgado-Saldivar Gabriel 
Published: December 2007

Abstract
This document describes briefly some aspects on the possibility of using FPSOs for the production of oil in fields that have been developed at deep or ultra-deep water as well as marginal fields or fields where the environmental hazard is high. Both the FPSO components and DP capabilities are briefly described, some issues regarding classification and existing regulations are indicated. The document is presented more in a conceptual manner, although there are several units with this combination working around the world, the concept has not been fully developed, and there is plenty of research and study to be done, and the alternative should be explored as a very feasible possibility.
Effect of Drag-Reducing Agents in Multiphase, Oil/Gas Horizontal Flow
Authors: Kang C. , Jepson W. P. 
Published: December 2007

Abstract
An experimental study has been carried out in a 36-m long, 10-cm diameter in horizontal multiphase system. Oil with a viscosity of 2.5 cP was used as the liquid phase and carbon dioxide was the gas phase. The effect of drag reducing agents (DRA) on average pressure drop, maximum pressure drop and slug characteristics for superficial liquid and gas velocities of 0.5 to 1.5 m/s and 2 to 12 m/s, respectively, was studied at DRA concentrations of 0, 20 and 50 ppm. Temperature was kept at 25 °C and pressure was maintained at 0.13 MPa.
The DRA was effective in reducing the average pressure drop significantly for all superficial liquid and gas velocities in both slug and annular flow. The average pressure drop reduction of up to 82% for slug flow and 47% for annular flow was achieved. For slug flow, the effectiveness generally decreased with increase in superficial liquid velocity. The maximum pressure drop across the slug also reduced with addition of DRA. The effectiveness for maximum pressure drop was over 28% at a superficial liquid velocity of 1.5 m/s for all gas velocities.
At superficial liquid and gas velocities of 0.5 and 2 m/s, the flow pattern changed from slug flow to stratified flow by decreasing the slug frequency to 0 slug/min. when 50 ppm DRA was added. At higher liquid and gas velocities, the slug frequency also decreased significantly. The effective height of the liquid film decreased with addition of DRA.
Disposal Problems at Drilling Locations
Authors: McDaniel Kent W. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the Improved Oil Recovery Symposium of the Society of Petroleum Engineers of AIME, to be held in Tulsa, Okla., March 22–24, 1976. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made.
Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. 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
In view of the rapidly developing field of environmental law and practices, this presentation is an effort to point out some of the numerous guidelines as they pertain to the rules and regulations of a land drilling operation. The problems of proper rights-of-way and site selection, disposal, restoration and protecting the environment without a complete trade-off in economics are becoming increasingly more challenging each day.
Some of the more obvious and important aspects of a drilling operation from the time the project is conceived to its completion pertaining to the aforementioned are covered. Certainly all facets necessary for consideration and action in this area cannot be explored in depth in a paper of this type due to time allotment. Actual problem situations of a drilling operation and how they can be approached and handled display some of the time and effort required for this task.

Discussion
The complexity and number of regulations now governing current drilling operations require that every effort be made to illustrate as simply as possible some of the guidelines necessary to a project. Reference to specific regulations have been necessarily avoided to minimize inaccuracies from an individual interpretation of any one given set of laws.
On any planned drilling project, a few basic rules of thumb would be applicable and well to keep in mind throughout the planning and doing-stage. These might be summarized as follows:In all cases of unintended conflict, conformance with all applicable laws, rules and regulations is of course mandatory.Some current environmental laws and pertinent regulations contain language to the effect that proposed operations should utilize the best available technology to reduce adverse environmental effects.
Use of 3D Seismic Data for Hazards and Site Assessments, Pipeline Route Planning, and Preliminary Engineering Design
Authors: Baerenwald Paul D. , Ruckman P. J. 
Published: December 2007

Abstract
The advantages of 3D seismic data over conventional 2D geophysical data include: high-density data coverage, improved spatial delimitation of geologic and stratigraphic features, and the ability to visualize geologic, stratigraphic, and structural features in ways not possible with 2D seismic profiles. The widespread availability of 3D exploration seismic data has ushered in a new approach to deepwater hazards and site assessments as well as regional development studies. With the advent of high-powered desktop computers, new software packages, and advanced analysis techniques, these data are now being used for more than the exploration of hydrocarbons, particularly in water depths greater than about 200 m.
Exploration 3D data are routinely used to identify and avoid unfavorable drillsites and pipeline routes, thus reducing overall costs. Whereas exploration 3D seismic data generally have sufficient resolution to identify significant drilling hazards and for preliminary pipeline route planning, these data are not adequate for final structure, site or pipeline route selection or for detailed stratigraphic characterization needed for design. In these cases, high-resolution site- and route-specific surveys are still required.
The advantages of 3D data are now also available in high-resolution geophysical surveys. These data reduce the need for repeated surveying of the same area and provide details unseen on conventional exploration data. A single high-resolution 3D data set can be used for multiple applications throughout the exploration, production, and development process. These data are used for shallow and intermediate exploration, analyses of seabed topography, geohazards assessments, understanding of complex structural and stratigraphic conditions, well planning, and field development. When integrated with geotechnical soil boring data, high-resolution 3D data provide a detailed understanding of stratigraphic variability necessary for final structure siting and design.