bluuebunny/crossref_metadata_2025_split huggingface dataset:
Using Crosswell Electromagnetics to Map Water Saturation and Formation Structure at Lost Hills
Authors: Wilt Mike , Zhang Ping , Morea Mike , Julander Dale , Mock Paul 
Published: December 2007

Abstract
In 1992, Chevron USA initiated a large waterflood program in the Belridge Diatomite at Lost Hills Field. Injection and production wells are hydraulically propped-fractured, and water is injected across a vertical interval of approximately 600 ft. The injected water is assumed to follow the hydraulic fractures and spread laterally outward. However, the extent of flooding, the saturation variations between individual layers, and the connection between waterflood patterns are poorly understood.
During this same time period, crosswell electromagnetic technology was developed and tested in other fields in the San Joaquin Valley. This technology can provide an interwell resistivity distribution from wells separated by up to 1000 ft, and thus, may be suitable for mapping water saturation variation and reservoir structure.
In this paper we describe the application of crosswell EM technology to several waterflood patterns at Lost Hills. The first cases involve surveys between closely spaced fiberglass-cased observation wells across and perpendicular to a hydraulic fracture. The interwell resistivity distribution identified the edge of the waterflooded region and mapped saturation variation between the layers that were affected by the flood. In another example, crosswell data that were collected parallel to hydraulic fracture planes show the connection of injection plumes and also significant saturation variation between layers
Ternary Diagram To Visualize Well Intervention Opportunities for Production Improvement - A Case History in Cusiana Field, Colombia.
Authors: Prada A. , Lazaro G. E. , Gonzalez F. A. , Carrillo L. F. , Osorio A. M. 
Published: December 2007

Abstract
Ternary diagrams have been used mainly in chemistry applications, and in geology for characterizing mineral components of rocks. In this study the ternary diagram called the Cusiana Well Performance Triangle is being proposed as a powerful well - reservoir surveillance evaluation tool. The main contribution of this diagram is to provide well surveillance engineers and managers with a tool that facilitates the decision making process.
Decline in productivity is influenced by reservoir related factors such as fluid properties, rock properties, pressure depletion trend, GOR and WOR increase trends and physical skin build up, generated by different methods. Usually organic substances, inorganic scales or very fine materials are transported and/or deposited in thenear wellbore region, hence, high decline rates can be observed.
In this study a well performance analysis and a formation damage evaluation were conducted using nodal analysis. The final delivery was the quantitative contribution of the main factors influencing the well productivity. The results are presented graphically in the ternary diagram referred to as Cusiana well Performance triangle.
The position of a well in the triangle indicates the factors that are influencing well performance. The triangle is used as a first step in understanding well performance with a view to wellwork candidate selection.
Recommendations based upon the observed results can provide the operator with a reliable tool to implement a formation damage management strategy for the Cusiana field.
Development and Application of a Dual-Parameter Instrument for Steam Two Phase Flow
Authors: Dai Peiwen , Wu Guowei , Wang Zuoqing , Zhang Yi 
Published: December 2007

Abstract
Though theoretical and experimental study, This program create a method which makes use of pulsating characteristic of the water and steam two-phase flow to measure both steam flow rate and quality parameters. Using only a restriction device (orifice), online measures simultaneously on steam flow rate and quality are achieved by measuring different pressure and its corresponding pulsating value.
According this method, a two-phase flow instrument has been developed, which is with simple structure and easy to operate. The measuring mean square errors of both flow rate and quality are less than 5% in the pressure range 2-16Mpa, flow rate 1-16t/h and quality 0-100%.
The instrument has been distributed over 430 sets in Shengli, Xinjiang, Henan and Neimeng Erlian Oil Field.
Geothermal Reservoir Modelling
Authors: Coats K.H. 
Published: December 2007

Abstract
This paper describes and partially evaluates an implicit, three-dimensional geothermal reservoir simulation model. The evaluation emphasizes stability or time-step tolerance of the implicit finite-difference formulation. In several illustrative multiphase flow problems, the model stably accommodated time steps corresponding to grid block saturation changes of 80–100% and grid block throughput ratios the order of 10(8). This compares to our experience of limits of 3 to 10% saturation change and roughly 20,000 throughput ratio with semi-implicit oil and geothermal reservoir models.
The illustrative applications shed some light on practical aspects of geothermal reservoir behavior. Applications include single- and two-phase single-well behavior, fractured-matrix reservoir performance and well test interpretation, and extraction of energy from fractured hot dry rock. Model stability allows inclusion of formation fractures and wellbores as grid blocks.
An analytical derivation is presented for a well deliverability reduction factor which can be used in simulations using large grid blocks. The factor accounts for reduced deliverability due to hot water flashing and steam expansion accompanying pressure decline near the well.
This paper describes a numerical model for simulating geothermal well or reservoir performance. The model is considerably more performance. The model is considerably more general than any described in the literature to date. It treats transient, three-dimensional, single- or two-phase fluid flow in normal heterogeneous or fractured-matrix formations. Both conductive and convective heat flow are accounted for and fluid states in the reservoir can range from undersaturated liquid to two-phase steam-water mixtures to superheated steam. Aquifer water influx and heat source/sink terms necessary in simulating free convection cells are included in the model formulation.
The primary purpose of the work described here was evaluation of the capability of an implicit model formulation. our experience with semi-implicit simulation of petroleum and geothermal reservoirs has shown time step restrictions related to conditional stability. In multiphase flow problems, the maximum tolerable time step size generally corresponds to a maximum of 3 to 10 percent saturation change in any grid block in one time step. In some steamflood and geothermal simulations, we have found this to result in very small time steps and correspondingly high computing costs. This work was performed with the hope that the implicit model formulation would give unconditional stability with no time step restriction other than that imposed by time truncation error.
Calculated results are presented for a variety of geothermal well and reservoir illustrative problems. Emphasis in connection with these results is placed on the stability or time step tolerance of the model. However, the applications are also intended to shed some light on practical aspects of geothermal reservoir practical aspects of geothermal reservoir behavior.
Policy Implications of Locating Energy Development Facilities in the Rocky Mountain Region
Authors: Smith Michael D. , Ielinek Dwayne 
Published: December 2007

Abstract
This paper addresses characteristics of Rocky Mountain regional energy development and focuses upon the policy positions taken by affected states in handling social and economic impact. The standardizing influence of the National Environmental Protection Act has eliminated many regional differences in the way companies deal with the environmental aspect of their energy development planning. However, within the general environmental impact category, social and economic impacts have not been adequately dealt with in the past. This is true for two reasons: first, past. This is true for two reasons: first, the precedent or body of knowledge associated with impact assessment of social and economic changes has been poorly developed; and second, the required economic theory needed to approach the problems has not been applied. In a sense, with regard to the theory of regional development economics when applied to western energy areas, we are dealing with the same or similar problem that underdeveloped countries face during periods of rapid development. In order to get an economic sense of the problem and to introduce the corrective or mitigating measures taken, this paper will cover the problem background, the development process, problem background, the development process, rapid regional growth process, impact analysis, impact control and, finally, a potential state planning role.
The central thesis is that, without planning, the region will probably reach planning, the region will probably reach economic equilibrium with severe local economic dislocations. However, with appropriate planning, even to the point of managing the state's economy, national energy expectations from the Rocky Mountains can be achieved and the region can prosper.

Introduction
" The whole is the synergistic sum of its parts" is an appropriate focus for parts" is an appropriate focus for understanding the dynamics of a national economy. However, thinking regional has not received the level of attention commensurate with regional roles in the determination of national income and companion social welfare. The question of thinking regional, with regard to energy and mineral development in the Unites States or in any Country, is one of recognizing national economic implications while focusing upon the economic impacts of regional development.
The Mixed and Vexed Subject of Oil Industry Profits
Authors: Johnson William A. 
Published: December 2007

Abstract
The U.S. oil industry has come under widespread criticism for having earned excessive profits. Partly for this reason, the industry has also been subjected to increasing regulation by the federal government. It is widely thought that the industry's profits reflect the monopoly power of U.S. oil companies and that freeing U.S. producers from price controls would only producers from price controls would only allow them to share in additional extraordinary profits now being earned by OPEC. In fact, federal controls have denied to U.S. producers part of their "producers' surplus," the rewards they have earned for having pioneered new ways of doing business, taken extraordinary risks successfully, minimized their costs of production, and, perhaps most important, chosen, in the past, perhaps most important, chosen, in the past, to focus their investment in exploration and production in the United States and not production in the United States and not abroad. As a result, these controls are, in various ways, discouraging output of oil by U.S. companies and encouraging unnecessary demand by U.S. consumers. This is, in turn, increasing U.S. dependence on imported oil primarily from OPEC. primarily from OPEC

Introduction
In 1895, the American economist, Frank Taussig, declared profits to be "that mixed and vexed income" after surveying what had been written on the subject by the learned men of his profession. This description is equally appropriate today, especially when describing the current controversy over oil industry profits. The industry's profits have been condemned by one senator as "unconscionable" and by another as "obscene". Partly because of their alleged profiteering, Partly because of their alleged profiteering, the major oil companies have been called such names as "robber barons" and "unfeeling monopolists' in the press.
What is at issue are abnormal profits in excess of the basic minimum level of payment to management or return to capital payment to management or return to capital necessary to keep a company in business. Economists have identified many reasons for abnormal profits—some bad, some good— and it is this that has made profits a "mixed and vexed" subject in both Taussig's and our times. Abnormal profits may reflect the presence of monopoly or an "unearned presence of monopoly or an "unearned increment" accruing to a landlord. Or abnormal profits may reward a businessman for profits may reward a businessman for extraordinary performance and successful innovation and risk-taking.
Use of a Fullbore-Access Level 3 Multilateral Junction in the Orinoco Heavy Oil Belt, Venezuela
Authors: Smith K. M. , Rohleder S. A. , Redrup J. P. 
Published: December 2007

Abstract
Petrozuata C.A. has initiated an aggressive campaign of constructing multilateral wells in their shallow extra-heavy-oil field in the Faja of the Orinoco River, Venezuela. The RapidTieBack* multilateral drilling and completion system has been used on many of the multilaterals.1 The system uses a casing section, with a factory-milled window, that is run in the 9 5/8-in. production casing string. Lateral 8 1/2-in. boreholes are drilled from the 9 5/8-in. casing and fitted with 7-in. slotted liners. The system employs a liner tieback on the top of the 7-in. liner. The liner tieback is mechanically pressed into the window. The tieback creates a fullbore TAML Level 3 (lateral cased, uncemented) junction. The fullbore access within the 9 5/8-in. production casing allows placement of a progressive cavity pump (PCP) below the junction(s) and thus closer to the lowest lateral. The system utilizes a production whipstock to allow selective reentry into any lateral.
The benefits of utilizing this system and a general description of the running procedures are presented in this paper. Some of the problems are described as well as the changes to the procedures that helped prevent reoccurrence of the problems.
Formation Damage Control Utilizing Composite-Bridge-Plug Technology for Monobore, Multizone Stimulation Operations
Authors: Garfield Garry 
Published: December 2007

Abstract
Composite bridge plugs (CBPs) save operator time and money by enabling quick and easy installation and removal. CBPs can be installed under pressure in multi-zone, commingled gas wells without using expensive formation kill weight fluids. Kill weight fluids can reduce production from the well, and in some cases have damaged newly fractured zones to the extent that production has been cut in half.
After remedial operations, CBPs can be removed using coiled- tubing-conveyed milling equipment in one fourth of the time required to mill traditional cast iron bridge plugs. Formation damage can be substantially reduced using low viscosity milling fluids that easily remove composite cuttings from the wellbore. This is especially important because of the low annular velocities characteristic of coiled tubing operations. The wellbore is left cleaner than those using cast iron bridge plugs in similar operations.
CBPs can withstand high pressures for up to 10 days without compromising their pressure integrity and without the need for a cement barrier on top of the CBP. Initial field runs have demonstrated that the CBPs can be milled as quickly as 30 minutes compared to 2 hours for milling conventional cast iron bridge plugs. Multi-zone, commingled gas wells using as many as 7 CBPs have been brought back on production after taking only 12 hours to remove all CBPs, including rig-up and rig- down of the coiled tubing unit. Field runs also indicate CBPs can be milled quickly when set at depths exceeding 19,000 feet.
Estimating Bulk Volume Oil in Thin-Bedded Turbidites
Authors: Weiss W. W. , Stubbs B. A. , Balch R. S. 
Published: December 2007

Abstract
Determining the water saturations in thin-bedded turbidites using wire-line logs is difficult; errors in Sw calculation frequently result in uneconomical completions. Consequently, current Brushy Canyon completion decisions include expensive core information to provide an acceptable indicator of oil saturation in order to compensate for the Sw calculation problem. Completion decisions can be improved and less core data is needed using a new method that correlates wire-line logs with core measured bulk volume oil (ΦSo).
A neural network was trained and tested using density and neutron porosity plus shallow and deep resistivity logs as input variables. The neural network was trained to predict the ΦSo product from whole core analysis.
The trained and tested neural network was then used to estimate ΦSo in 25 additional Brushy Canyon wells that were not used in the training, but had the same four wire-line logs. A ΦSo cutoff of 22 units was determined and values greater than the cutoff were summed through the perforated interval in each well. The summed bulk volume oil of the 25 wells was plotted versus the first year’s total production. The plot suggests that ΣΦSo greater than 20,000 units will usually result in an economical new well or reentry completion.
During the course of optimizing the neural network architecture, valuable insights into network architecture design were gained. For this type of study, less complex architectures produced robust testing results, indicating that the solution, though non-linear, is still reasonably simple.
The method should be useful when evaluating behindpipe completion opportunities in the Brushy Canyon interval of the Delaware Sands in the Permian Basin. Re-completion costs are lower than new well costs; thus thin zones with high values of ΦSo are potential targets.
A Full Field Simulation Model of the Minagish Oolite Reservoir in Kuwait
Authors: AL-Mutairi Saad , AL-Medhadi Fahad , AL-Ajmi Hamad , Meadows David , Oosthuizen Ulrich R. 
Published: December 2007

Abstract
The Minagish Oolite is a thick undersaturated carbonate oil reservoir in the Minagish field in West Kuwait (Fig. 1) containing several billion STB. It is a mature but relatively undeveloped reservoir. Since discovery in 1959, it has produced 10% of its OOIP under a combination of natural depletion, gas re-injection and aquifer drive. Initial reservoir pressure had declined by about 450 psi prior to the Gulf war in 1990. The well blowouts following the war caused a significant pressure drop of another 700 psi. Following the blowout, plans were made to redevelop the West Kuwait fields and increase the production rate starting in 2001 and to sustain the plateau for at least 5 years. This strategy called for three-fold increase in the production rate of Minagish Oolite reservoir. Since the existing well inventory and the loss of the gas re-injection facility could not sustain the desired plateau rate, additional field development was required.
To achieve the production target, a multidisciplinary team was formed to evaluate options. The recommended plan required the drilling of additional producers and installing a field-wide peripheral waterflood. The reservoir, however, presented a number of significant challenges to waterflooding, such as the presence of a substantial and not well defined tarmat near the oil/water contact, and uncertainties of lateral and vertical heterogeneities. In 1997 a full-field simulation model was developed, but this model didn’t capture the water movement properly because of insufficient reservoir data at that time. As new core was obtained, a refined reservoir description was developed. Building on lessons learned from the previous full-field model and sector models, a new full-field model was developed which significantly improved well-by-well history matches. Although containing twice as many grid cells, the new model ran up to four times faster than the previous model by making use of the Analytical Aquifer option within the model, improved relative permeability curves and other model refinements.
This paper traces the history of the field and the systematic evolution of the development plan. The reservoir simulation efforts including modeling strategy, history matching events, prediction runs, future direction and challenges are also addressed.
A Mlcroscoplc Study Of The Effect Of Variable Wettability Conditions On Immiscible Fluid Displacement
Authors: Morris Earl E. , Wieland Denton R. 
Published: December 2007

Publication Rights Reserved
This paper is to be presented at the 38th Annual Fall Meeting of the Society of Petroleum Engineers of AIME in New Orleans, La., on October 6–9, 1963, and is considered the property of the Society of Petroleum Engineers. Permission to publish is hereby restricted to an abstract of not more than 300 words, with no illustrations, unless the paper is specifically released to the press by the Editor of the JOURNAL OF PETROLEUM TECHNOLOGY or the Executive Secretary. Such 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 SOCIETY OF PETROLEUM ENGINEERS JOURNAL is granted on request, providing proper credit is given that publication and the original presentation of the paper.
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 considered for publication in one of the two SPE magazines with the paper.

Abstract
This paper presents the results of a microscopic investigation of immiscible fluid behavior under variable wettability conditions. Seventeen waterfloods were conducted in a monolayer glass-bead flow cell under water-wet neutral-wettability, oil-wet, and wettability-reversal conditions.
Quantitative production data were obtained for each flood. Also, a 16 mm film recording utilizing an arriflex camera was made during each flood test. Photographs taken from 16 mm film recordings are herein presented as being representative of the microscopic and macroscopic behavior for the fluid systems studied.
Residual oil structures were visually defined as being noncontinuous under water-wet conditions. Oil-wet conditions yielded both continuous and noncontinuous type structures. The idea of residual oil continuity under oil-wet conditions is proposed as being responsible for increased oil production when going from an oil-wet to a water-wet condition. In all cases during these experiments where additional oil was recovered during a reversal flood, there was essentially continuity of the residual oil saturation following the conventional waterflood under oil-wet conditions.
It has been shown that, where residual oil continuity existed, oil mobility may be established from a transient change in contact angle. An attempt has been made to define the mechanism responsible for this phenomena.

Introduction
The recovery of additional oil from a reservoir following primary depletion can be achieved only by the application of energy from external sources such as the introduction of heat and/or kinetic energy of other fluids. A process which supplies this additional energy is called a secondary recovery process. Unfortunately, present secondary recovery methods, which are economical, still leave up to 40 per cent of the reservoir's original oil content trapped by capillary and hydrodynamic forces.