Geophysical technology continues to progress in leaps and bounds. We see wireless technology leaping ahead, new approaches to depth imaging, Full Tensor Gravity Gradiometry, more realistic assessment of the role of electro-magnetic surveying, brand new ideas on how to interpret seismic data, much more integration of different technologies…..all leading to much more insightful and useful images of basins, plays and prospects!
And the underpinning digital technology continues to expand at an amazing rate – Moore’s Law does seem to be true!
As a result of these developments, the business of exploration & production is undergoing fundamental changes. For example, reservoir management is being transformed by the availability of 4D seismic (or permanent seismic monitoring), down-hole production monitoring, the ability to transmit large amounts of data to onshore centres, and new interpretation and visualisation techniques. There is the intriguing possibility that we can see a causal connection between reservoir dynamics and (new) geophysics instead of simple correlations such as "since we last did a 4D survey here, the reflectivity has changed".
Our March Forum will take stock of these developments, offering the opportunity to consider where the next ‘breakthroughs’ in geophysical technology are going to occur – the new ideas that once again will transform our business.
David Bamford is a geophysicist by background and an explorer by recent history, and is well known as both around the oil & gas industry. In addition to acting as a director or advisor to several small companies, including his own consultancy, he writes regularly for journals such as OilVoice, ROGTEC etc, and has recently co-founded OilVoice Forums as a vehicle for on-line communication in the oil & gas industry.
He is a non executive Director of Tullow Oil (since 2004, and is a member of the Audit, Nominations and Remuneration Committees).
With a PhD in Geological Sciences from the University of Birmingham, he has had over 23 years exploration experience with BP where he was Chief Geophysicist from 1990 to 1995, General Manager for West Africa from 1995 to 1998, and acted as Vice President, Exploration, directing BP's global exploration programme, from 2001 to 2003.
New Eyes Exploration
New Eyes Exploration, founded by David Bamford, explores new ways to discover Oil and Gas.
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Martyn founded Ikon Science in 2001. He has over 30 years experience in new ventures and technology application in the oil and gas industry, working in International Geoscience and commercial roles for GSI Inc, Candecca Resources plc, Hardy Oil and Gas, Jebco Inc, Acre Oil plc and BG Plc. Prior to IKON Science, he was Managing Director of IKODA Ltd and built the company from a start up to one of the largest independent upstream consulting groups dealing with some of the highest profile upstream deals over the past decade including the North Caspian PSA negotiations and awards to the OKIOC consortium and related deals including a half billion dollar disposal of these assets.
He has a long term interest in the public role of Geoscience and has provided this expertise on the board of a number of Industry R&D "think tanks" such as the Petroleum Science and Technology institute (PSTI) and Centre for Marine and Petroleum Technology (CMPT). He is currently a member of the CeREES Geo-Energy board of Durham University. He has been a founding shareholder or director of a number of oil companies including the Africa focused AIM listed Fusion Oil and Gas plc, Virgo Energy plc a private oil and gas explorer sold to Encore oil plc in 2006 and Ophir Energy Plc.
Martyn earned an Honours degree in Geology from Durham University UK and a post graduate qualification in Geophysics from Queen Mary College University of London. He is an active member of the Society of Exploration Geophysicists, Institute of Petroleum, and the Petroleum Exploration Society of Great Britain.
Ikon Science
Ikon Science is a geoscience technology company committed to bringing innovative geoscience technology to the upstream oil and gas industry. As specialists in subsurface workflows, we are developing and delivering quantitative prediction and reservoir characterisation to customers with a fresh and flexible approach. With our industry-leading software, The RokDoc® System, and our responsive teams, we are dedicated to providing you with excellence, by combining innovation and scientific rigour on every project. Leading a journey to discover and share new technology, products and know how, we deliver results and value on time, every time.
Ikon Science, founded in 2001, employs over 80 people and has offices in London, Durham, Edinburgh, Houston, Boulder, Lagos, Kuala Lumpur and Perth Western Australia.
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Talk Description.
Seismic vessels have essentially operated in the same manner for the past sixty years. The principles of an acoustic source and hydrophone receivers have remained the same. Sensors have been placed on the seabed, in cables or nodes, but the majority of all marine seismic remains by towed streamer. Unfortunately the data quality is affected by the ghost - the result of an almost perfect reflection of the acoustic wavefield from the sea surface. Up-going waves are reflected back as down-going waves with a reversed polarity, and interfere constructively for certain frequencies and destructively for other frequencies. This phenomenon occurs both on the source side and on the receiver side and the affected frequencies depend solely on source and receiver tow depths. In 2007 PGS launched a dual-sensor streamer and broadband seismic became reality. The ability to separate the up-going and down-going wavefields is set to revolutionise the quality of marine seismic. In 2011 PGS took the next step and developed a ghost free source. Removal of both acquisition effects provides a broader bandwidth with improved noise characteristics ideal for accurate imaging and reservoir property analysis.
In this presentation we will review the enabling technologies, but mainly concentrate on the value of the resulting data for exploration and production. Improved imaging results from better penetration. Reservoir delineation and geobodies detection are improved due to increased signal to noise ratios and broader bandwidth. The broadening of the low frequencies represents a key improvement for lithology and fluid prediction and seismic reservoir property estimation. The need for a-priori information is considerably reduced by relying more on the data and less on a low frequency background model. As we will demonstrate, increased reliability on the data also delivers increased confidence in the resulting estimated properties and leads to reduced risk.
In concluding, we will also look ahead to future developments – use of the separated wavefields and also a towed streamer for electromagnetics.
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Petroleum Geo-Services (PGS) offers a broad range of products including; seismic and electromagnetic services, data acquisition, processing, reservoir analysis/interpretation and multi-client library data. They help oil companies to find oil and gas reserves worldwide, offshore and onshore.
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Talk Description.
Observing reservoir dynamics
1. When a reservoir, any reservoir, is put under production, fluid compositions change, for example oil may be partially replaced by water or gas, gas may be expelled from oil, and so on. However, what is also well-documented and of significance is the fact that fluid pressures drop, changing the ‘internal stresses’ on the reservoir rock. Tempting as it may be, however, it is not possible to understand the (time-varying) geophysics of reservoir rocks by theorising an isotropic pore space responding to fluid changes and changing ‘internal stress’…………
2. Several studies have shown that the hydraulic conductivities of faults and fractures in reservoirs can be influenced by geomechanical perturbations due to production operations and it is reasonable to anticipate that such dynamic permeabilities will be manifest as changes in flow-rates at production and injection wells. Heffer & co-workers (Edinburgh University) have shown that statistical correlations in flow-rate fluctuations between wells from fields in the North Sea appear to bear out this expectation; they are characterised by high correlations over very large separation distances between wells, and appear to be stress-related and fault related. Heffer has proposed that the most likely geomechanical mechanism to explain such orientational characteristics of correlations relative to stress state is dilatation or compaction of aligned compliant fractures in en echelon patterns and at critical densities, also previously proposed by others as active in the nucleation of shear failure. This mechanism is also consistent with an independent empirical feature of production data: the observed frequencies of directionalities in flooding schemes.
3. These reservoir engineering observations lead to the conclusion that time-lapse geophysics - any observations of any reservoirs over time - must be based on the understanding of the physics of fluid-filled, parallel, compliant, fractures/micro-cracks – dilating or compacting as the reservoir is produced. This physics, this New Geophysics, has been documented over many years by Crampin, based on understanding and observing the effects of closely-spaced stress-aligned fluid-saturated microcracks on seismic shear-wave splitting (SWS) in the crust and upper mantle. Critically, seismic observations of P-wave propagation and P-waves are relatively insensitive to fluid-saturated microcracks, whereas SWS is wholly determined by parallel microcracks and can be measured with first-order accuracy. Thus SWS is a second-order quantity (small changes in shear-wave velocities) that can be read with first-order accuracy- thus there is tremendous resolution.
4. Consequently, there are significant implications for geophysical, especially seismic, monitoring of reservoir dynamics:
• First of all, we can say that conventional 4D seismics – towed streamer surveys for example – only discern changes in P-wave reflectivity and thus offer at best an incomplete view of reservoir dynamics, one that is unquantifiable, allowing only empirical comparisons,
• Secondly, a complete, quantifiable, view of reservoir dynamics requires 3C seismic acquisition (and strengthens the case for permanent installations).
• Thirdly, changes in stress can be monitored by changes in SWS so that stress-accumulation before fractures in reservoirs (and earthquakes and volcanic eruptions) can stress-forecast the time, magnitude, and estimate location of impending fractures (and earthquakes and eruptions).
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New Eyes Exploration, founded by David Bamford, explores new ways to discover Oil and Gas.
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Stingray Geophysical, a TGS Company, provides advanced Permanent Reservoir Monitoring (PRM) solutions to the global oil and gas industry, enabling increased production and recoverable reserves at lower through-life cost and risk through improved reservoir management strategies. By 'listening with light' using Stingray's reliable, permanently installed Fosar® fibre-optic sensing arrays, oil companies benefit from high quality, cost-effective and repeatable seismic on demand in all field scenarios. Together with its global network of trusted partners, and as a part of TGS, Stingray delivers complete, integrated seismic PRM from planning, through active and passive seismic acquisition, to processing and reservoir solutions.
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Jonathan Henderson is a physicist with over 20 years of extensive experience in imaging and image analysis. His initial interests were in medical imaging, where he had worked on developing new methods for extracting and quantifying the information contained in x-rays and ultrasound scans. Since joining ffA in 2001, he has used his knowledge of medical image analysis to help the Company develop unique seismic image analysis technologies. Jonathan has been Managing Director of ffA for 5 years during which time the Company, its global customer base and its software portfolio have all expanded substantially.
Foster Findlay Associates (ffA)
fA provide world leading 3D Seismic Analysis Software and Services to the oil and gas industry.
ffA software extracts geological features from 3D seismic data objectively and more rapidly than with conventional techniques, to help geoscientists and engineers to make better decisions with higher confidence, in less time.
The result - significant gains in productivity and risk reduction at all stages of the E&P cycle including seismic interpretation, prospect generation, target definition and well planning.
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