Green fields today mostly can be regarded as marginal fields and successfully developed. It covers the complete assessment of the oil and gas recovery potential from reservoir structure and formation evaluation, oil and gas reserve mapping, their uncertainties and risks management, feasible reservoir fluid depletion approaches, and to the construction of integrated production systems for cost effective development of the green fields. Depth conversion of time interpretations is a basic skill set for interpreters. There is no single methodology that is optimal for all cases. Next, appropriate depth methods will be presented. Depth imaging should be considered an integral component of interpretation. If the results derived from depth imaging are intended to mitigate risk, the interpreter must actively guide the process.
Schedule Session Details Expand All Collapse All Filter By Date All Dates Sunday, November 12 Monday, November 13 Tuesday, November 14 Wednesday, November 15 Thursday, November 16 Filter By Session Type All Sessions Social and Networking Events Technical Sessions Panel, Plenary, and Special Sessions Training Course/Seminar Sunday, November 12 08:00 - 17:00 Production Optimisation System Instructor(s) Atef Abdelhady The basic objective of this course is to introduce the overview and concept of production optimisation, using nodal analysis as a tool in production optimisation and enhancement. Learn More 08:00 - 17:00 Practical Depth Conversion and Depth Imaging for the Interpreter Instructor(s) Pavel Vasilyev Depth conversion of time interpretations is a basic skill set for interpreters. There is no single methodology that is optimal for all cases. Depth imaging should be considered an integral component of interpretation. If the results derived from depth imaging are intended to mitigate risk, the interpreter must actively guide the process. Participants will gain an understanding of depth conversion methodologies and QCs for validity of methods used. Learn More 08:00 - 17:00 Marginal Field Development and Optimisations Instructor(s) Abdolrahim Ataei Green fields today mostly can be regarded as marginal fields and successfully developed. It covers the complete assessment of the oil and gas recovery potential from reservoir structure and formation evaluation, oil and gas reserve mapping, their uncertainties and risks management, feasible reservoir fluid depletion approaches, and to the construction of integrated production systems for cost effective development of the green fields. This session will show how chip technology has resulted in a miniaturised Electron Paramagnetic Resonance (EPR) spectrometer for online monitoring of asphaltenes (a chemical that clogs oil wells). The EPR sensor technology developed in the laboratory has been successfully deployed in major oil and gas fields across the world. This technology is used to monitor the concentration of asphaltenes in real-time and to minimise the use of environmentally hazardous chemical inhibitors in energy production. Employee suggestions for improvement cover a wide variety of topics such as economic efficiency, productivity, safety, operability, environmental friendliness, and to a greater or lesser extent, has led to efficient and improved operations.
The ALBION project applies a new and disruptive methodology of reservoir characterisation to the carbonate Urgonian Formation (South-East France) considered as the very best analogue of Mid Cretaceous reservoirs from Middle East. Thanks to numerous field sections and outcrops descriptions, to tens of wells drilled in the reservoir, to kilometres of cores, to monitoring of groundwater dynamics such as decades of hydraulic observations at pretty much the only natural outlet of a major groundwater reservoir (Fontaine-de-Vaucluse spring) and to a unique underground laboratory (LSBB, about four kilometers in the heart of the reservoir), a multi-scale model is being built for reservoir purpose. Different observation sites with wells whose spacing ranges from 2 to 20 meters contribute to the assessment of together the matrix, the fractures and the karst flow behaviours. Through the building of an observatory in the heart of a reservoir, the ALBION project is delivering advanced concepts and methodologies to apply to industrial projects in Middle East carbonate fields.
With new oil sands projects and expansions of existing projects coming onstream, it is anticipated that production of heavy crude and bitumen will reach more than 318,975 m3/d (two million barrels per day) by 2012, and over 794,937 m3/d (five million barrels per day) by 2030 (on a synthetic crude oil basis). It is assumed that most of this anticipated production can be marketed in the United States; however, the U.S. currently only accepts limited volumes of synthetic crude oil (SCO), as it must be blended with other crude to meet refinery specifications. This combination of limited U.S. refinery capacity and current SCO quality means there is risk that much of this new production either cannot be marketed, or that market price will be reduced because of oversupply, unless new markets can be found. An obvious new market for Canadian heavy oil and bitumen is the Asian-Pacific region, due both to increasing demand for petroleum products and proximity. The Alberta Energy Research Institute, in partnership with industry from Asia and Canada, is investigating both short and long-term exports of Alberta crude and value-added products to Asia. This paper provides an update on this study, which will identify the technology gaps that should be addressed to match Alberta products to Asian refineries.
Laureshen, C.J. (Alberta Energy Research Institute) | Plessis, D. Du. (Alberta Energy Research Institute / Alberta Economic Development) | Xu, C.M. (State Key Laboratory of Heavy Oil Processing) | Chung, K.H. (State Key Laboratory of Heavy Oil Processing)
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The following Cumulative Index is organized similar to the specific subject section of the KWIC Index. Additional titles and sub headings have been used. The papers are indexed both according to subject and to author. When applicable, the papers are listed under two subject references. Papers represented by only an abstract in the symposia transactions are labeled as such. There is a Subject Index followed by an Author Index. Following are explanations of the Publication Reference Codes and the Paper Subject Classification.
CORIBAND is a computer program designed to evaluate porosity and water saturation using deep resistivity, micro resistivity, Neutron, Density and Sonic logs, and the accompanying Gamma Ray, S.P. and caliper logs, in reservoir rocks of variable complex lithology with varying clay content. The program has been applied in its standard four mineral form (quartz-calcite-dolomite-anhydrite and clay) with excellent results in most of the reservoirs of the North Sea area. The Jurassic Sandstone reservoirs of the Northern North Sea Basin contain potassium micas in varying amounts. Micas are chemically similar to clay minerals. In addition both clays and mica contain radioactive elements. The Jurassic is usually drilled using muds made with sea water, so that the salinity of the mud filtrate is around 30,000, to 40,000 ppm NaC1, similar to the salinity of the formation water: Spontaneous Potential is, therefore, generally near zero. Thus the indicators normally used in CORIBAND to evaluate clay content are affected in a similar manner by the presence of mica. The result is that when mica is present in the formation, clay content is generally overestimated using the standard CORIBAND option, with the corresponding underestimation of porosity and overestimation of water saturation. A new clay indicator has been devised which incorporates Sonic, Neutron and Gamma Ray measurements. A byproduct of the evaluation of V clay with this new clay indicator is the detection of the presence of mica. This new clay indicator is used in addition to the usual clay indicators incorporated in CORIBAND; clay content can therefore be effectively evaluated whether or not mica is present in the formation. CORIBAND incorporates an option to select two minerals of ,known logging tool response to be considered in varying amounts along with varying clay content, for computation of @ and S,. A lithology model for the micaceous Jurassic sandstones has been developed which is readily adapted to this two-mineral option. Using the mica detection feature of the new clay indicator, either the standard four mineral option or the mica-quartz-clay model can be selected automatically by the computer. Results from CORIBAND computations incorporating the new clay indicator and the new quartz-mica-clay model show excellent correlation with core derived data.
In this reservoir study of the Clinton sand, East Canton oil field, Ohio, results indicate that a properly engineered waterflood may be feasible for secondary oil recovery. Waterflood forecasts that account for a wide range of reservoir conditions are included and can be used for preliminary waterflood performance estimates.
The Morgantown Energy Research Center of the U.S. Bureau of Mines has, for several years, engaged in studies of eastern U.S. oil reservoirs. The goal has been more efficient recovery and more nearly complete recovery of oil through the application of the various secondary-recovery mechanisms. The East Canton oil field in northeastern Ohio was selected for this study because of the impact of its potentially large reserves on the supply of Pennsylvania potentially large reserves on the supply of Pennsylvania Grade crude oil. Because of the unusual reservoir characteristics, secondary-recovery operations in the Clinton sand will be especially challenging for operators and engineers. Previously published reports dealt with reservoir geology and primary recovery in the East Canton field. It was recently reported that waterflooding might be feasible under certain conditions. Here we shall describe, in more detail, the reservoir factors that pertain to waterflooding, and provide the operators with a method for estimating possible oil production by waterflooding from their properties in production by waterflooding from their properties in the East Canton field.
Location, History, and Development
The East Canton oil field is composed of an or parts of 11 townships in Stark, Carroll, and Tuscarawas Counties in northeastern Ohio (Fig. 1). Active drilling started in 1965 in western Rose Township, Carroll County. Rapid development of the East Canton oil field, however, did not start until Oct., 1966, when the discovery well of the East Canton pool was completed. To date, the western and northern limits of the field have been defined, but the eastern and southern edges of be extended by future drilling. At present, the proved to semiproved productive area is approximately 22 miles long and 5 to 7 miles wide. By July, 1970, over 1,000 wells had been drilled, and several operators were drilling additional wells. Although ultimate primary recovery will vary depending on reservoir characteristics, volumetric calculations indicate recoveries between 28,000 and 63,000 bbl/well, based on 40-acre spacing. More recent decline curve analysis for a 15-well study area shows an approximate primary recovery of 43,000 bbl/well, using an economic limit of 90 bbl/well/ month. Initial production rates of individual wells in the field, as reported by completion records, ranged from a few barrels to over 300 BOPD after fracturing. Most wells produce from a few thousand cubic feet to several hundred thousand cubic feet of gas per day. Initial bottom-hole pressures of approximately 1,500 psi have been observed. Very few wells were plugged psi have been observed. Very few wells were plugged as dry. Peak production of the fieldapproximately 13,000 B/D was reached in Aug., 1968. Cumulative production passed the 10-million-bbl mark by July, production passed the 10-million-bbl mark by July, 1970.