bluuebunny/crossref_metadata_2025_split huggingface dataset:
Steamflooding Experiences at Petrotrin (Trintopec's Operations): A Historical and Technical Perspective
Authors: Khan J. , Lewis W. , Maharajh D. H. 
Published: December 2007

Abstract
Thermal oil recovery was first initiated in Trintopec's operations in 1966, with a small cyclic pilot project in the Company's Palo Seco field. Since that inception, twenty-seven (27) years of thermal recovery, comprising both cyclic and flood-type operations, have witnessed vigorous growth and dynamic expansion to the extent that, by 1993, the thermal recovery statistics of Trintopec's portion of the now overall Company's (Petrotrin's) operations are as follows : Steamflooding operations exist in all the major land fields, viz.: Palo Seco, Central Los Bajos, Guapo, Fyzabad and Apex-Quarry /Coora/Quarry.Production from thermal recovery averages 7,500 bopd, representing 50% of current land production.A total of approximately 40,000 bspd is being supplied by twenty-three (23) steam generators to more that one hundred and fifty (150) injectors
This paper presents highlights of Trintopec's experiences in the design, implementation and operation of its thermal oil recovery schemes. New concepts, innovations, modelling and monitoring techniques over the past twenty-seven (27) years are outlined.
Heavy Oil Recovery by Subcritical Carbon Dioxide Flooding
Authors: Srivastava R. K. , Huang S. S. , Dyer S. B. , Mounts F. M. 
Published: December 2007

ABSTRACT
The immiscible CO2 displacement process appears to be a very promising enhanced oil recovery technique for thin or marginal heavy-oil reservoirs where thermal recovery methods are generally unsuitable. This paper discusses results of laboratory and simulation studies for determining oil recovery mechanisms and displacement characteristics for this recovery method. Phase behaviour, linear coreflood, and scaled model studies were conducted with a medium heavy oil (14°API gravity) from a thin, sandy reservoir. The effects on oil recovery of reservoir operating pressure, CO2 injection rate, waterflood rate, CO2 slug size, and secondary and tertiary WAG (water-alternating-gas) schemes were examined. Oil recovery behaviour for a CO2 presoak process (which involves secondary or tertiary CO2 preflush followed by extended waterflood) was also investigated.
Study results indicated that oil swelling and viscosity reduction were the predominant recovery mechanisms for the subcritical CO2 displacement process (operating at 2 to 5 MPa, 28°C) with the oil. The CO2 presoak process improved the oil recovery because of higher mass transfer of CO2 into oil. A reduction in either waterflood rate (or CO2 injection rate) resulted in an increase in oil recovery and showed the interplay of viscous, capillary, and diffusive forces. The incremental oil recovery data, in conjunction with the CO2 requirements, showed that a slug size of approximately 0.4 pore volume (PV) was suitable for laboratory CO2 flooding studies. An increase in the operating pressure improved oil recovery for the CO2 water-alternating-gas (WAG) processes in sandpacks saturated with stock tank oil. However, the recovery in reservoir-fluid-saturated sandpacks was relatively insensitive to the operating pressures investigated, indicating mobility effects to be dominant in laboratory coreflood studies. Poorer oil recoveries for the secondary than for the tertiary WAG process were attributed to the high mobility of the injected CO2 gas. The CO2 presoak and WAG processes appear to offer strong potential for enhancing oil recovery from thin heavy oil reservoirs.
Selective Technique for the Resolution of Oil and Gas Transportation Networks
Authors: González J. , Rotolo M. A. , Suárez S. 
Published: December 2007

ABSTRACT
An algorithm for the analysis and simulation of isothermal networks under steady state flow conditions that could be fed by one or more fluids(liquid or gases), was developed. The algorithm allows solving the network once the fluid properties and the node pressure are known.
The system of equations representing the network is generated through a selective method consisting in dividing the network into open/closed subnetworks, and generating the specific equations system for each subnetwork. Identification of network loops and their pipes was obtained by applying Graph Theory1.
Algorithm validation was carried out by comparing the results, for typical networks2 , with those obtained from the simulator P1PEPHASE3, while effectiveness of the selective method was assessed by comparing its execution times with those of standard methods (node and circuit methods).
Selective method proved to be more effective than the other two, by reducing the response times from 30–1800%.
Identification of Acute Toxicity Sources in Produced Water
Authors: Johnsen Stale , Smith A. T. , Brendehaug Johanne 
Published: December 2007

Abstract
Identification of acute toxicity sources in produced water has been considered an important task for the past few years. The present study outlines a new approach to the problem, where artificial produced water is made based on detailed knowledge of the composition and toxicity of produced water from two major North Sea oil fields. Acute toxicity testing by Microtox (Photobacterium phosphoreum) of produced water qualities made according to a statistical experimental design model, has in combination with multivariate statistical analysis identified the aromatic and phenolic fractions as the main contributors to the toxicity of these produced waters. Process chemicals did not contribute significantly.
A study of changes in acute toxicity and chemical composition during biodégradation of produced water verified that biodégradation of the aromatic and phenolic fractions played a dominant role in the decrease in acute toxicity.
Migrating Legacy Applications to Object-Oriented Frameworks
Authors: Barrett T. , Kennelly M. 
Published: December 2007

ABSTRACT
During the 80's the message ’Wire up the enterprise’ led to a boom in networking computers together. Through the 90's this message will become ’Service up the enterprise’. Businesses will require their computing infrastructure to deliver 'services’ in a reliable, uniform and transparent manner, enabling them to operate effectively.
However it is not feasible or practical to replace many existing (legacy) applications with applications adhering to modern architecture specifications at once. Nor is it possible to have the bulk of the software developers retrained to object based programming overnight. This can only be achieved over the course of time. This document presents the issues encountered when we look to protect the investment made in legacy applications, together with a practical, incremental migration strategy.
Experiences in Incorporating a 3D Geological Model into a Reservoir Simulator
Authors: Rae S. F. , Neve Patrick 
Published: December 2007

Abstract
Advances in computing technology have allowed the development of sophisticated 3D cellular modelling and visualisation software which has found a variety of applications in the oil industry. This includes spatial attribute modelling and the visualisation of hydrocarbon reservoirs to improve the understanding of the geological structure including internal features, the distribution of formation properties and the movement of fluids once field production begins.
This paper discusses experiences gained in building a geological 3D model of the West Flank of the Alwyn North reservoir and the subsequent manipulation and transfer of this data into a 3D reservoir simulator for initialisation. The techniques used differ considerably from the traditional method using 2D surface mapping packages. The advantages of both geoscientist and reservoir engineer being able to see and review the 3D image of the reservoir at an early stage in the project is discussed. The paper covers the modelling of the reservoir's complex heterogeneities, the handling of both vertical and sloping fault surfaces, deviated wells and the contrasts in the number of cells of the geological model compared with the number of blocks in the reservoir simulation model. Procedures for up-scaling from geological to reservoir model are discussed along with the errors introduced in the transfer of data and subsequent re-sampling by different software packages.
The paper concludes with suggestions for future developments of software to further enhance this effective method of modelling.
The Cost-Effective Implementation of Production Operation Systems for a New North Sea Development
Authors: Shipton E. C. 
Published: December 2007

Abstract
The development of Kerr-McGee Oil (U.K.) PLC. 's first North Sea operation has provided an opportunity to install modem cost-effective systems in accordance with recent North Sea development philosophy. A greenfield site in Aberdeen provided the chance to install the operation from the cabling upwards and to select a local area network configuration to suit our particular needs. This paper describes how all of the required voice and data systems were installed successfully in a narrow time frame.
Partnering the Development of a New Client-Server-Based Drilling Information Technology System Results in Real Benefits
Authors: Sentance Andrew , Gillett Keith 
Published: December 2007

Abstract
This paper describes how the Drilling Engineering Applications Platform (DEAP) has been designed, built and implemented by a partnership of BPX and Baker Hughes INTEQ based on the open systems principles and a client - server architecture. Through the implementation of this system, real benefits have been realized in delivering information technology (IT) solutions to the partners’ business. By developing DEAP as a commercial rather than a proprietary product these benefits are available to other operators and contractors. In partnering the development of a commercial system, the development costs and risks were shared and the long term maintenance costs can be spread over a broad user base.
Computer Control of Oilfield Production in China
Authors: Song F. Y. , Teng X. S. , Yu G. P. , Islam M. R. 
Published: December 2007

ABSTRACT
Daqing Oilfield is the largest oilfield in China. It provides 50% of China's yearly total oil production of 120 million tons. The no. 6 production plant of Daqing Oilfield is the pioneer in computer application for petroleum production in China. In 1981, the No. 6 production plant bought its first computer. In 1985, based on the comprehensive applications of computers, a network was built to connect all the information sources and decision making agents including production teams, technical service teams, geology teams, testing teams, production management and control offices. Later on, the operation system was put into the network. According to the specific situations in the oilfield, over 300 softwares were developed and their application was very fruitful. With the application of computers, oil production increased by over 1%, production cost decreased by 15%. Energy consumption and equipment damage are decreased. After the computerization in the oilfield, the no. 6 production plant gets economic benefits over 30 million Yuan (5 million U.S. dollars).
Reserve Optimization Utilizing Graphical Analysis Techniques
Authors: Chen Shing-Ming , Chen Li-Wei , George I. R. 
Published: December 2007

ABSTRACT
The advent of small, powerful personal computers has led to the development of many inexpensive and comprehensive data analysis packages which allow the engineer to manipulate and display various types of test and field data. Without proper organization and a systematic approach, however, the benefit of such programs in obtaining an understanding of field production trends and mechanisms is often lost.
The objective of this paper is to present a method of displaying performance information in a simple and complete form to assist the engineer in visualizing (i) individual well behaviour, (ii) regional trends, and (iii) overall field performance.
Once the relevant data has been organized and displayed effectively, its use in the determination of
individual well production capability regional performance and inter-well communication reservoir pressure support and effectiveness of water injection oil recovery and possible reservoir extension
will be discussed. It will also be shown how this information can be used to identify wells requiring stimulations to improve productivities, as well as the need for infill drilling to maximize field recovery. Any gaps in the data, or the need for additional information required to assist in development planning, will also be apparent once the data is analysed.
Finally, for increased clarify, use of the techniques will be illustrated with field examples.
Portable, Computer-Based Rig Crew Training
Authors: Jardine P. F. , Waller M. D. , Kehase Berhane 
Published: December 2007

ABSTRACT
Developing and maintaining high levels of crew expertise and awareness is vital to the productivity and safety of rig and platform operations. The effectiveness and longevity of onshore training can be enhanced through the use of training and simulation packages which staff and crews can use on demand at or near their work place. The widespread availability of, and familiarity with, personnel computers gives an ideal platform on which to build and operate such packages. In addition to the provision of basic training they also include performance enhancement so that both the user and supervisor can assess the levels of competence achieved. In addition to basic training the same platforms may be used as engineering aids, the simulators being used to assess the effect of changing parameters or methods of operation.
Implementing New Permeability Selective Water Shutoff Polymer Technology in Offshore, Gravel-Packed Wells
Authors: Gruenenfelder M. A. , Zaitoun Alain , Kohler Norbert , Ali S. A. , Linser T. M. 
Published: December 2007

Abstract
A new polymer, previously evaluated in the laboratory, has been successfully tested to shut off water production in two offshore high temperature gravel packed wells in the Gulf Coast. The polymer is shear resistant, thus easy to handle, and, since it maintains good permeability to oil in the zones into which it is injected, it does not require zone isolation during injection into the well. After treatment, a strong reduction in WOR was observed in both wells. The effect lasted over 2 years in one well and for several months in the second well. These treatments show that the polymer is stable in field applications at 190 and 200 °F (88 and 93 °C).
Evaluation of Tall Oil Fatty Acid Salt as a Steam/Foam Surfactant
Authors: Osterloh W. T. , Jante M. J. 
Published: December 2007

Abstract
We report the results of laboratory experiments designed to evaluate the performance of the sodium salt of tall oil acid, TOA, as a steam-foam surfactant. The objective of the experiments was to determine if this inexpensive material could be used to reduce the chemical costs of the steam foam process. Tall oil acid is a commercially available blend of oleic and linoleic carboxylic acids obtained by distillation of the wastes from pine pulping mills. The sodium salt soap, TOA−Na+, is easily produced by one-step neutralization of TOA with sodium hydroxide.
The performance of TOA−Na+was measured in terms of the rate and magnitude at which the foam pressure gradient, Vp, increased when TOA−Na+and nitrogen were injected into a two-foot sandpack. Performance was also measured as a function of temperature, TOA−Na+ concentration, foam liquid volume fraction, foam velocity, salinity, pH, and oil saturation.
Experimental results show that TOA−Na+ is an effective foaming agent that can produce pressure gradients of hundreds of psi per foot in a sandpack. The dominant parameters found to control TOA−Na+ performance were salinity, temperature, and pH. To generate a large Vp at high temperature and in the presence of oil, the salinity of the TOA−Na* solution had to be increased by adding between 1.0 and 1.5 wt% sodium chloride. The TOA−Na+ was effective up to 400°F, but a large Vp could not be produced at 500°F. The pH of the TOA−Na+ solution had to be greater than about nine to achieve a large Vp. Sodium sesquicarbonate was used to buffer the solution at a pH of ten. Other notable results include that TOA−Na+ foam performance was not adversely affected by oil and that stable foams were produced at high and low foam velocities and at low liquid volume fractions.
Improved Oil Recovery in the United States: The Race Between Technology Advancement and Resource Abandonment
Authors: Brashear J. P. , Biglarbigi Khosrow , Ray R. M. 
Published: December 2007

Abstract
Currently available enhanced oil recovery (EOR) and advanced secondary recovery (ASR) technologies could produce a significant amount of the remaining oil resource in the major oil reservoirs of the United States. The potential recovery can be even greater with a well designed, properly focused research, development, and demonstration (RD&D) program and technology transfer effort. However, if low oil prices persist and technology advancement is delayed, a significant portion of the remaining resource could be abandoned before the recovery potential can be realized.
This paper presents the results of a study by the Interstate Oil and Gas Compact Commission (IOGCC) to evaluate the impact of RD&D and technology transfer on future oil recovery in the United States. Major findings of the study include: (1) at the conclusion of conventional recovery operations, over 350 billion barrels will remain in known domestic oil reservoirs; (2) a significant portion (35% to 45%) of the remaining oil resource has already be abandoned, and an even greater portion is at risk of abandonment by the turn of the century; (3) wider application of currently available improved oil recovery technologies could stimulate as much as 7 to 9 billion barrels of incremental reserves in the $16/B to $20/B oil price range; (4) technology advances resulting from a focused RD&D program could stimulate an additional 5 to 8 billion barrels of incremental reserves for a total potential of 12 to 17 billion barrels at these oil prices; and (5) an aggressive and focused RD&D and technology transfer effort on improved recovery technologies needs to be undertaken in order to capitalize on the massive remaining oil resources in the U.S.
Applications and Results of Acrylamide-Polymer/Chromium (III) Carboxylate Gels
Authors: Southwell G. P. , Posey S. M. 
Published: December 2007

Abstract
Since the development of acrylamide-polymer/chromium(III)-carboxylate gels, a wide variety of field applications has demonstrated the utility and versatility of this system. Large volume injection well treatments for areal conformance, treatments for water/oil ratio reduction in producing wells, near wellbore treatments for effective squeeze treatments and the sealing of openhole wellbores as a completion tool will be reported.
The initial treatments were pumped in the Big Horn Basin of Wyoming and in the Permian Basin of western Texas. These large volume treatments pumped into injection wells have added approximately 5 MMBO in reserves at a cost of less than $1.0 per STBO, to naturally fractured waterflood reservoirs. With this success, a program was initiated using the same polymer gel system in high water/oil ratio producing wells with a strong water drive. Water/oil ratios have been reduced from 300:1 to as low as 30:1 in several Big Lake Field wells of western Texas. Another form of the polymer gel system is used for near wellbore total shut-off as a substitute process for conventional squeeze cementing. This technology has been applied to shut off gas or water when pumped into an isolated interval. The same technology is routinely applied to seal the openhole curved section of re-entries for horizontal wellbore completions in the Yates Field Unit of western Texas.
In-Depth Colloidal Dispersion Gels Improve Oil Recovery Efficiency
Authors: Mack J. C. , Smith J. E. 
Published: December 2007

Abstract
In the Rocky Mountain Region, a unique in-depth permeability modification process was applied to 29 field projects over the last 9 years. The process involves continuous, long term injection of environmentally sound colloidal dispersion gels. These gels provide a solution to in-depth channeling and crossflow problems inherent with waterflooding, which cannot be solved by near-wellbore gels. Use of colloidal dispersion gels in the field has never before been reported, yet the process has proven to have a phenomenal impact on efficiency of enhanced oil recovery projects. 22 of the projects were considered successful, resulting in improved oil recovery and reduced water production. Seven of the field projects were considered unsuccessful for a variety of reasons. Both successful and unsuccessful treatments are discussed, as both provide valuable insight into treatment design and application.
Ultimate oil recoveries in successful treatments are in excess of 40% OOIP, in highly heterogeneous matrix reservoirs with Dykstra-Parsons permeability variations on the order of 0.80. Chemical costs of $1.00 to $2.00/BBL incremental oil recovered are typical, and this cost has decreased below $1.00 in more recent floods due to improved technology. The colloidal dispersion gel process was applied successfully at bottom hole temperatures up to 202 °F. Oil viscosities are often high, from 10 cps to more than 20 cps at the reservoir bottom hole temperature. This paper provides a complete picture of project development from start to finish, including initial laboratory design, project selection criteria, field design, field implementation and project performance. The in-depth colloidal dispersion gel process is a versatile process that has proven an effective tool in long term enhanced oil recovery programs.
Pore-Scale Network Modelling of Waterflood Residual Oil Recovery by Immiscible Gas Flooding
Authors: Øren P-E. , Billiotte Joel , Pinczewski W. V. 
Published: December 2007

Abstract
The paper presents a precise description of the pore-scale displacement mechanisms responsible for the mobilization and subsequent recovery of waterflood residual oil by immiscible, gas flooding. The displacement mechanisms are incorporated into a numerical three-phase invasion percolation type network model which is used to compute oil recoveries by tertiary gas flooding for oil-water-gas systems displaying positive and negative spreading behaviour under strongly water wet conditions. Computed oil recoveries are shown to be in good agreement with those observed in micromodel displacement experiments. The network model confirms the. important role of oil spreading films in increasing recovery of water-flood residual oil for positive spreading systems.