This seminar will teach participants how to identify, evaluate, and quantify risk and uncertainty in everyday oil and gas economic situations. It reviews the development of pragmatic tools, methods, and understandings for professionals that are applicable to companies of all sizes. The seminar also briefly reviews statistics, the relationship between risk and return, and hedging and future markets. Strategic thinking and planning are key elements in an organisation’s journey to maximise value to shareholders, customers, and employees. Through this workshop, attendees will go through the different processes involved in strategic planning including the elements of organisational SWOT, business scenario and options development, elaboration of strategic options and communication to stakeholders.
Decisions in E&P ventures are affected by Bias, Blindness, and Illusions (BBI) which permeate our analyses, interpretations and decisions. This one-day course examines the influence of these cognitive pitfalls and presents techniques that can be used to mitigate their impact. Bias refers to errors in thinking whereby interpretations and judgments are drawn in an illogical fashion. Blindness is the condition where we fail to see an unexpected event in plain sight. Illusions refer to misleading beliefs based on a false impression of reality.
This paper attempts to use analogs of coals and Coal bed Methane (CBM) properties in Sedimentary basins to mutual advantage from the knowledge of each other.
An attempt has been made here to showcase as to why two Coal bearing formations, Lower Eocene, Cambay in India and Miocene, South Sumatra, Indonesia can be compared with each other in terms of coal quality and CBM characteristics.
Cambay basin, with an area of 56,000 sq kms is an elongated NNW-SSE rift basin in the western part of India. The basin fill comprises Mesozoic(?) sediments capped by Late Cretaceous Deccan volcanics and a thick tertiary pile of fluvio deltaics. Thick Lignite to sub bituminous coal is found in Middle (two thick seams) and Lower Eocene section (three thick seams of 20-35 m range and one thin seam of 1-10m). Chemically, the Middle Eocene lignite-sub bituminous coal is characteristically low in moisture (4-5%), quite low in ash (1-11%) and high in volatiles (43-55%). The Lower Eocene coals are sub bituminous with 10-20% moisture, low ash(5-10%), low Sulphur(<1%) content. The gas content of the Lower Eocene coals are 6 cubic metre / tonnne, with permeability 1-3 Md with seams slightly over pressured. Depth ranges of both these coal horizons are between1000-1800m approximately.
South Sumatra basin, double in size wrt Cambay basin with an area of 100,000 sq kms, is a NE-SW trending, backarc basin. Series of half grabens punctuated with basement highs, holds Miocene and Eocene Coals in the grabens of a mostly Tertiary sedimentary pile. The Miocene coals (formed in tide dominated coastal plain) are sub bituminous, with VRo 0.4-0.5, low ash(<10%), Moisture(10-18%), high volatile matter of around 40% at depths 300-1000m, with 20-30 seams with gas content of 7 cubic metre / tonne. The Older Eocene Coals are1-10 m thick at depths 1000-2000m formed in peat bogs in fluvial settings.
The Indonesian Coals of Miocene age are very comparable in coal properties and gas content to the Middle and Lower Eocene Coals of Cambay basin and can supplement each other in studies for CBM exploration and exploitation. Of great similarity are the coal quality, ash% and gas content. To take the comparisons further ahead, detailing of thickness, extent, geometry and depositional environments of each of these basins would be advantageous.
Unconventional shale oil/gas has been envisaged as one of the most promising resources of India. India is having enormous untapped shale oil/gas potential of 96 TCF risked technically recoverable shale gas and 3.8 billion barrel risked technically recoverable shale oil. But, its development is still nascent and not very much conducive due to insufficient data availability and limited exploration and exploitation activities. The present study is an attempt to minimize the existing data gap and providing useful information pertaining to shale geochemistry, sweet spots delineation, geomechanics and fracability. Shale has an important feature of acting as both source as well as reservoir for hydrocarbon generation, expulsion and accumulation. Demarcating sweet spots are helpful in identifying these prospective hydrocarbons bearing zones in shales and hence in locating favorable drilling targets. High content of organic matter, kerogen richness, clay content, shale geomechanics are the key parameters that affect sweet spots distribution in shale and so the generation of hydrocarbons. In the present work, a link from the hydrocarbon enriched zones (i.e. Sweet Spots) of Cambay Basin to its seismic attributes has been created and parameters like - thermal maturity, organic richness, kerogen typing, shale geomechanics, fracability and brittleness index of Cambay Shale are experimentally determined using characterization techniques - Rock Eval Pyrolysis, FTIR and Geomechanical Analysis. Sweet spots were identified in the deeper formation of Cambay Basin. The shale is thermally mature, organically rich and have good potential of hydrocarbon generation. However, from the fracability point of view, the selected section is geomechanically weak and may be unfavourable for advance stimulation.