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Collaborating Authors
Unconventional and Complex Reservoirs
When Gerald Schotman, Shell's chief technology officer, looks at the unconventional oil and gas business, he sees so many young technologies and "from the perspective a chief technology officer, that is such an opportunity." Shell's list of promising areas for research and development is broad, ranging from creating cheaper, more effective sensors for seismic testing to a new generation of specialized, automated drilling rigs. The goal is always "change that creates value." In natural gas the rewards can be broken down three ways: produce more gas per well now, bring down the costs per well, and reduce the footprint when doing so. The footprint can be defined in many ways: the size of the pads used for drilling multiple wells; the level of emissions; the water used; and the many ways exploration and production can touch the people and the environment, near and far.
- Oceania > Australia > Western Australia > Western Australia > Timor Sea > Browse Basin (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Timor Sea > Browse Basin (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Browse Basin > WA-371-P Permit > Block WA-371-P > Prelude Field > Plover Formation (0.99)
- (4 more...)
- Well Drilling (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- Data Science & Engineering Analytics (1.00)
- (3 more...)
Copyright 2012, Society of Petroleum Engineers This paper was prepared for presentation at the SPE Middle East Health, Safety, Security, and Environment Conference and Exhibition held in Abu Dhabi, UAE, 2-4 April 2012. This paper was selected for presentation by an SPE program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the Society of Petroleum Engineers and are subject to correction by the author(s). The material does not necessarily reflect any position of the Society of Petroleum Engineers, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the Society of Petroleum Engineers is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuous acknowledgment of SPE copyright. Abstract Accurate prediction of individual well potential and estimation of field capacity are the key for managing Coal Seam Gas (CSG) wells and its deliverability to Liquefied Natural Gas (LNG) plant. Because there are no downhole gauges in these wells there is limited reservoir data. The associated uncertainty, the absence of fast predictive wellbore models and challenges in generating accurate well performance predictions add to the deliverability challenge. This paper presents a method used to estimate CSG well performance for Australian CSG assets using neural network (NN) and proxy modeling. Traditional methods for prediction of well potential, such as numerical simulation or statistical techniques, have significant limitations. Numerical prediction is traditionally accurate but very complex in setup and computation; statistical techniques have the advantage of being fast but often lack accuracy. The approach starts with the automatic acquisition, validation, and quality control of static and dynamic production parameters in proxy modeling.
- Oceania > Australia (1.00)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.54)
- North America > United States > Oklahoma (0.46)
- Overview > Innovation (0.50)
- Research Report (0.46)
- North America > United States > Texas > Anadarko Basin (0.99)
- North America > United States > Oklahoma > Red Fork Channel Sand Formation (0.99)
- North America > United States > Oklahoma > Anadarko Basin (0.99)
- (2 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Coal seam gas (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
- (2 more...)
Abstract Petroleum producers are currently engaged in significant expenditure towards exploration and development in unconventional oil and gas plays in Western Canada. Finding & Development costs are different in various plays and strategies. But where the producer should focus their resources to achieve most cost efficient production? The paper describes methodology of analysis of Finding & Development cost. A probabilistic model was developed to quantitatively assess exploration and development expenditure, production, and reserves for various producers for different oil and gas plays. The model employs a number of key performance indicators (KPIs) such as Finding & Development costs with and without acquisitions, reserves life, reinvestment, and others. The methodology was applied to a comprehensive study of Finding & Development expenditure in Western Canada focused mostly on unconventional oil and gas. The study included more than 80 oil and gas companies. Each company may be involved in exploration and development of many plays. The expenditure, production, and reserves were analyzed for the last 12 years. The companies were subdivided into three groups based on their production. Each companyโs Finding & Development costs and other KPIs were calculated for Western Canada as a whole and for a particular strategy or play where the company was operating, as well as for CBM, tight, and shale gas. The study found significant variance in finding and development cost in Western Canada. All companies and all strategies are ranked based on their Finding & Development costs and other KPIs. The results of the study can be applied to the comparative analysis of efficiency of the exploration and development expenditure, which in turn can help improve portfolio management and decision making processes.
- Research Report > New Finding (0.69)
- Research Report > Experimental Study (0.67)
- North America > Canada > Saskatchewan > Western Canada Sedimentary Basin > Alberta Basin > Viking Formation (0.99)
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Horn River Basin > Horn River Shale Formation (0.99)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Alberta Basin > Viking Formation (0.99)
- (3 more...)
- Management > Asset and Portfolio Management > Reserves replacement, booking and auditing (1.00)
- Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (0.69)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (0.67)
- Management > Energy Economics > Unconventional resource economics (0.64)
Abstract Strong LNG demand, both here in Australia and overseas, fuelled by worldwide transition to a low carbon economies is driving unprecedented growth in coal seam gas (CSG) exploration and development of east coast resources, not to mention the other conventional gas resources around Australia. With this accelerated growth in demand for gas, particularly with the onshore CSG production, comes the matter of the associated environmental affects and the need for socially responsible environmental management and mitigation of impacts. Why do I single out the CSG industry in this regard โ after all the oil and gas industry has been the subject of considerable environmental regulation during the many decades of production in this country, and has a very proud record in doing the right thing. This paper relates specifically to one unique attribute associated with the production of CSG, namely the need to extract groundwater from the gas production wells in order that they be depressurised as a precursor to gas release. Pumping groundwater from of the coal seam โaquifersโ targeted for the resource reduces the hydraulic pressure to the point that the adsorption bonds holding the methane to the surfaces of the coal cleats (or microfractures) are reversed and the gas moves into the gaseous phase, and is hence available to flow to the well under the prevailing hydraulic gradients. Typically, a CSG well is pumped for its groundwater, producing its peak flows early in the life of the well, with flows of water tapering off with time, as gas flows increase and peak some years into its life.
- Oceania > Australia > Queensland (1.00)
- North America > United States (1.00)
- Oceania > Australia > New South Wales (0.72)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.46)
- Oceania > Australia > South Australia > Great Artesian Basin (0.99)
- Oceania > Australia > Queensland > Surat-Bowen Basin (0.99)
- Oceania > Australia > Queensland > Great Artesian Basin (0.99)
- (11 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Coal seam gas (1.00)
- Health, Safety, Environment & Sustainability > Environment > Water use, produced water discharge and disposal (1.00)
- Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (1.00)
Abstract Coal Seam gas (CSG) is a rapidly growing industry in Queensland, Australia. Water is produced as a by-product of the CSG production process, with the management of this associated water (called CSG water) widely accepted as one of the industry's main challenges. The Australia Pacific Liquefied Natural Gas (LNG) project is a coal seam gas (CSG) to liquefied natural gas (LNG) joint venture between Origin, ConocoPhillips and Sinopec Group. The Australia Pacific LNG project proposes to supply CSG from the Walloons gas fields in south central Queensland to a LNG plant located on Curtis Island, off the coast of Gladstone, on the central Queensland coast. Origin is the upstream operator of the Australia Pacific LNG project (the Project). In the Walloons coal seams, CSG water keeps natural gas adsorbed as a thin film on the surface of the coal. The pressure of the surrounding body of CSG water allows the gas to be retained within the seam by adsorption to the surface of coal particles. Hence to extract gas the water pressure needs to be reduced by transferring the water to the surface. Water from CSG wells extracted to enable gas production is variable in quantity, difficult to predict and influences gas production rates. Variability in water production can be due to the location of the well, communication with other wells, decline in pressure during well life and permeability of the coal seam. The quality of the CSG water can vary from well to well and more noticeably across the project area, but it consistently contains elevated quantities of salts. Appropriate management of CSG water is required to mitigate environmental risks associated with untreated CSG water. Uses for such large and difficult-to-predict quantities of both treated and untreated water in theWalloons gas fields region are limited. As such, it is acknowledged that the treatment, use and disposal of CSG water present a challenge for the Project and the CSG industry in general. This paper will use the Talinga development area, established in 2008 and located southwest of Chinchilla in Queensland as a case study in water management adopted by Australia Pacific LNG. In particular, this paper focuses on the discharge of treated CSG water to surface watercourses (creeks/rivers) - one of a suite of water management options used by the Project. This paper explores the regulatory framework governing this aspect of water management and Origin's approach to ensuring the environmental values of receiving waters are preserved. At time of writing, the gas production from the Talinga field has been operated under an Environmental Authority (EA) with provision for an initial 18-month continuous discharge to the Condamine River of 20 ML/d as the preliminary water management option underpinning a broader management strategy. The broader strategy includes transitioning to a managed discharge flow regime that mimics the natural flows of the River.
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Coal seam gas (1.00)
- Production and Well Operations (1.00)
- Health, Safety, Environment & Sustainability > Environment (1.00)
- Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (1.00)
Robust forecasts for natural gas growth from conventional and unconventional sources continue to see a smooth shift to a world in which gas is the dominant fuel of choice by industry and consumers. But market forces may have a say on how quickly the world gets there. A new report examining the top 10 growth markets in energy, air, and water puts shale gas development at the head of the list. The McIlvaine consultancy sees a continuing increase in investment in US shale gas projects, as well as in other promising areas such as China, Argentina, and Europe. Shale is followed on the list of growth industries by vessel air and water treatment, water reuse, NOxย control, aquaculture, power plant efficiency improvements, soil and groundwater remediation, fine particulate reduction technology, solid waste management, and renewable energy. But questions are being raised about the rapid rise of gas in Europe, where gas prices are tied closely tied to oil prices. With the price of Brent comfortably above USD 100/bbl, at least for now, and a good USD 20/bbl higher than the US West Texas intermediate oil price benchmark, power generators and industries are becoming increasingly cautious about the finances of increased gas usage. The US International Energy Agency speaks of a โgolden age of gas,โ in which European electricity generation alone will increase 40% by 2015. And many market forecasts have predicted huge capital outlays in gas infrastructure across Europe in the near future. The Netherlands, for instance, has plans for a network of pipelines and liquefied natural gas (LNG) terminals that would allow it to become of the regionโs gas hubs. But recent demand has been softer than expected because gas, at current price levels, is less economic than coal. That, in turn, has raised questions about the need for huge outlays for infrastructure if there is uncertainty about the long-term attractiveness of gas, including new pipelines or terminals to import LNG from producers in Qatar and Nigeria. European government initiatives to promote energy efficiency also could have an effect. In the US, it is low gas prices that are taking a toll. Producers with strong ties to US gas production are โlosing their shirts,โ ExxonMobil Chief Executive Officer Rex Tillerson said in releasing his companyโs second-quarter earnings. ExxonMobil has yet to see the benefit of buying US gas producer XTO 2 years ago. Chesapeake, Noble, Encana, Anadarko, and others all have suffered because of sustained low gas prices in the US caused, in part, by the success of shale plays. Shale gas has quickly become a place not to sink additional capital, and many producers have shifted their attention toward liquids production instead. What would help is a sooner-rather-than-later ramping up of new LNG export facilities in the US, which would allow producers to take advantage of more attractive markets such as Asia and which would eventually firm prices in the US. Until that hap-pens, US gas prices at Henry Hub will remain under pressure because US gas is not tradable on the open market. Whether the public and politicians can agree to exporting US energy resources after seeing the country finally lessening its dependence on foreign sources is another question.
- Europe (1.00)
- North America > United States > Texas (0.57)
- North America > United States > Louisiana > Vermilion Parish > Erath (0.25)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Management > Energy Economics (1.00)
- Health, Safety, Environment & Sustainability > Environment (1.00)
- Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (1.00)
Summary As populations and economies continue to grow globally, energy demand will grow proportionally. Extensive work by Tertzakian (2007, 2009) has shown crude-oil supplies may not keep pace with this increased demand. The shortfall must be met by other energy sources. Only two current energy sources have the global capacity to, by themselves, address increased energy demand in a timely manner. These are natural gas and coal. Traditionally, the major use of crude oil has been for processing into transportation fuels, with lesser amounts being used for petrochemicals and home heating. Natural gas and coal have been used primarily for electrical generation and heating. A pivotal transition will likely occur in which natural gas and coal begin to see increased use as transportation fuels. A battle for market share between primary fuels will likely ensue. The objective of this paper is to present data comparing the environmental impact of using methane vs. coal. A compelling case for the use of natural gas as the future "green fuel" emerges.
- North America > United States (1.00)
- North America > Canada > British Columbia (1.00)
- North America > Canada > Alberta (1.00)
- (2 more...)
- Geology > Rock Type > Sedimentary Rock > Organic-Rich Rock > Coal (0.46)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play (0.46)
- Energy > Oil & Gas > Upstream (1.00)
- Energy > Oil & Gas > Midstream (1.00)
- Energy > Oil & Gas > Downstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.93)
- South America > Atlantic Basin (0.99)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- (28 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Production and Well Operations (1.00)
- (5 more...)
Abstract The paradigm shift toward natural gas as a preferred fuel for marine offshoresupport vessels (OSV) and platform support vessels (PSV) represents a newmarine era. This paper examines five key trends driving this change; how thetwo shale gas phenomena of availability plus affordability combine with threeEnvironmental Protection Agency (EPA) mandates that together make a compellingcase for adoption of natural gas as a fuel. Introduction Earlier this decade the widely held belief was that expansion of natural gaswould arise by increasing imports of LNG into the US thus causing furtherdependence on foreign energy sources. Then came the vast shale gas discoveriesdomestically within the US and Canada as illustrated in figure 1. Within thispast few years a true transformation of the energy equation was aided by threestep advances; profound advances in computer capability aiding detectionefforts, efficiency advances from new horizontal drilling techniques, andhydraulic fracturing " fracing" technology for improved recovery. These elementsand an industry keen to develop such domestic resources have vaulted shale gasfrom 1% of US natural gas supply nearly 30% by the end of 2011, it continuesclimbing, and is projected now to provide nearly a century of supply. Adefinitive long term fundamental transformation has occurred that providesstrong stabilization to the North America market for many future generations. Current estimates position recoverable natural gas as exceeding 2,214 trillioncubic feet (TCF), a value which includes recent modest downward revisions bythe U.S. Energy Information Administration. Shale gas growth offsets other U.S.supply declines while meeting consumpation growth and nearly eliminates needsfor importation of LNG.
- Government > Regional Government > North America Government > United States Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Management > Energy Economics (1.00)
- Health, Safety, Environment & Sustainability (1.00)
- (2 more...)
Technology Focus In 2010, natural-gas reserves were approximately equivalent to 75% of the oil reserves (including oil sands). Unconventional gas sources continue to make up an increasingly important part of the natural-gas supply, particularly shale gas and coal-bed methane (CBM), which contribute approximately 40% to US natural-gas reserves. Generally, very remote offshore gas reserves cannot be exploited economically by use of fixed subsea pipelines that tend to link the field with a specific geographical market. Operators can maximize market reach through natural-gas liquefaction and improved marine liquefied-natural-gas (LNG) tankers. For ultimate flexibility, four floating LNG-production facilities are predicted to come on stream within thisย decade. Commercial exploitation of the known massive hydrate reserves probably is some time off; however, the chemistry research involved in hydrate management for current natural-gas production may accelerate progress in that area. Hydraulic-water reuse is key to the future of the CBM and shale-gas industries. There are many opportunities to learn about and share natural-gas technologies. An SPE workshop, โReducing Environmental Impact of Unconventional Resources Development,โ will take place in San Antonio, Texas, 23โ25 April 2012. A joint SPE/SEG workshop, โInjection Induced Seismicity,โ will be held in Broomfield, Colorado, 12โ14 September 2012. There will be an SPE โTight Gasโ workshop in Adelaide, Australia, 10โ13 June 2012, and the SPE Unconventional Reservoir Technical Interest Group (TIG) provides a useful information exchange, as does the Gas Technology TIG. The 2013 SPE Unconventional Gas Conference and Exhibition will be held in Muscat, Oman, 28โ30 January. The 2013 SPE International Symposium on Oilfield Chemistry to be held in The Woodlands, Texas, 9โ13 April, includes topics on gas-processing chemical applications. Acid-gas (CO2 and H2S) removal from natural gas and sequestration/recovery/disposal technologies are very important in exploitation of poorer-quality gas finds. Much work continues in this area, and very large acid-gas-removal units are in operation or are planned for the Arabian Gulf region. Recommended additional reading at OnePetro: www.onepetro.org. IPTC 15208 Worldโs First Demonstration Project of Natural Gas Hydrate Land Transportation by Tomonori Nogami, Mitsui Engineering and Shipbuilding, et al. IPTC 14206 International LNG Prospects: 2011 and Beyond by Chau Tran, University of Houston, et al. SPE 143019 Underground Natural-Gas Storage in the UK: Business Feasibility Case Study by Esther Escobar, University of Aberdeen, et al.
- North America > United States > Texas > Montgomery County > The Woodlands (0.26)
- North America > United States > Texas > Bexar County > San Antonio (0.26)
- Asia > Middle East > Oman > Muscat Governorate > Muscat (0.26)
- Oceania > Australia > South Australia > Adelaide (0.24)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > Natural gas storage (1.00)
- Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (1.00)
There is plenty to be optimistic about in the upstream oil and gas oil sector. In this article, the Energy Industries Council (EIC) focuses on offshore opportunities globally, and identifies the hot spots of activity. It will also examine some of the key issues facing the sector and the energy supply chain today, such as the need to maximize oil and gas recovery from challenging environments and new offshore fields, and the need to reduce costs and innovate.
- Asia (1.00)
- Europe > United Kingdom (0.96)
- North America (0.73)
- Oceania > Australia > Western Australia > North West Shelf (0.70)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Carnarvon Basin > Dampier Basin > Rankin Platform > Greater Gorgon Development Area > Block WA-268-P > Greater Gorgon Field (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Carnarvon Basin > Dampier Basin > Rankin Platform > Greater Gorgon Development Area > Block WA-267-P > Greater Gorgon Field (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Carnarvon Basin > Dampier Basin > Rankin Platform > Greater Gorgon Development Area > Block WA-25-P > Greater Gorgon Field (0.99)
- (27 more...)