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Characterizing Controls on Reservoir Properties in Unconventional Shale and Tight Reservoirs＊

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Characterizing Controls on Reservoir Properties in Unconventional Shale and Tight Reservoirs＊ 35 石油技術協会誌 第 85 巻 第 1 号 （令和 2 年 1 月）35 ～ 43 頁 Journal of the Japanese Association for Petroleum Technology Vol. 85, No. 1（Jan., 2020）pp. 35～43 講 演 Lecture Characterizing controls on reservoir properties in unconventional shale and tight reservoirs＊ Levi J. Knapp ＊ ＊ ，† , Shinnosuke Uchida ＊＊ , Takashi Nanjo＊＊ , Tatsuya Hattori＊＊ Omid Haeri-Ardakani ＊＊＊ and Hamed Sanei ＊＊＊ , ‡ （Received August 30, 2019；accepted November 21, 2019） Abstract： Since 2014 JOGMEC has been collaborating with Natural Resources Canada（ NRCan） along with industry partners in the area of unconventional reservoir characterization and technology development. Based on a June 12 2019 presentation at the JAPT Exploration Technology Symposium in Tokyo, this paper presents research from two major shale and tight unconventional reservoirs, the Upper Devonian Duvernay and Lower Triassic Montney formations in western Canada, and examines the differences between these two fundamentally different types of reservoirs. Solid bitumen strongly inuences reservoir quality in both types of reservoirs but in very different ways. In tight reservoirs（ i.e., Montney Formation） solid bitumen typically occludes pores and pore throats, while in shale reservoirs（ i.e., Duvernay Formation） solid bitumen can be the primary host of porosity. Keywords： Unconventional, tight reservoir, shale, bitumen, Montney Formation, Duvernay Formation, Canada rocks themselves, or only contain thin source rock intervals. 1. Introduction The hydrocarbons within tight reservoirs have typically The geological and petrophysical properties of unconventional migrated from overlying, underlying, or intraformational source shale and tight reservoirs are highly variable（ Jarvie, 2012）. The rock intervals（ Wood et al., 2015）. Duvernay Formation shale reservoir and Montney Formation The distinction of these two types of unconventional reservoirs tight siltstone reservoir of western Canada offer an excellent has massive implications for expected reservoir properties such opportunity to compare these two types of unconventional as porosity and permeability, as well as strategies for exploration reservoirs. Shale reservoirs are dominated by clay-sized and production. Since shale reservoirs tend to be self-sourced, particles（＜ 4 µm）, are organic-rich source rocks, and the contain abundant primary organic matter, and reduced inorganic reservoir intervals are self-sourced. In shale reservoirs the fluid matrix porosity due to compaction, organic porosity tends to hydrocarbons（ gas, oil, and viscous bitumen） are generation be a significant fraction of the total porosity（ Loucks et al., products of the primary depositional kerogen within the same 2009; Jarvie, 2012）. This leads to positive correlations between formation. In contrast, tight reservoirs, also known as “hybrid total organic carbon（ TOC） and porosity. In contrast, tight reservoirs”（ Jarvie, 2012）, are typically coarser-grained, reservoirs generally show a negative correlation between dominated by silt and very fine sand, or carbonates, especially TOC and porosity because the solid organic matter present in in producing intervals. Tight reservoirs often are not source the reservoir is generated from migrated oil and occludes the primary inorganic pores and pore throats（ Sanei et al., 2015; Wood et al., 2015, 2018）. Shale reservoirs are typically most porous in intervals with moderate to high TOC, while tight ＊ 令和元年 6 月 12 日，令和元年度石油技術協会春季講演会 地質・探 鉱部門シンポジウム「天然ガス探鉱・開発の現状と課題－低炭素 reservoirs are most porous in intervals of low TOC. 社会に向けて」にて講演 This paper was presented at the 2019 JAPT Petrophysical properties of unconventional shale and tight Geology and Exploration Symposium entitled “Natural Gas Exploration & Development - Current State & Challenges Toward Low Carbon Society” reservoirs are closely associated with organic matter（ e.g. held in Tokyo, Japan, June 12, 2019. Jarvie, 2012; Mastalerz et al., 2013）, and as such it is important ＊＊ 石油天然ガス・金属鉱物資源機構 Japan Oil, Gas and Metals National Corporation（JOGMEC） to define the various organic components present. In source ＊＊＊ カナダ地質調査所 Geological Survey of Canada rocks, kerogen is the primary depositional organic matter ‡ オーフス大学 now at Aarhus University † Corresponding author：E-Mail：[email protected] from which oil and gas are eventually generated（ Tissot and Copyright © 2020， JAPT 36 Characterizing controls on reservoir properties in unconventional shale and tight reservoirs Welte, 1984; Hunt, 1996; Vandenbroucke and Largeau, 2007）. However, by the time a source rock reaches a thermal maturity necessary to become an unconventional reservoir, much of the primary kerogen has been transformed into bitumen and oil（ Rippen et al., 2013; Kondla et al., 2015; Emmanuel et al., 2016; Hackley and Cardott, 2016）. This is particularly true beyond peak oil generation. Viscous fluid bitumen is generated directly from kerogen at early stages of transformation（“ pre-oil ” bitumen; Curiale, 1986）. Upon further thermal maturation fluid bitumen will undergo transformation into a solid product（ solid bitumen） and lighter hydrocarbons（ oil and gas）. Solid bitumen can also be generated from secondary cracking of oil（“ post- oil” bitumen; Curiale, 1986）. Pre-oil bitumen generally has low mobility owing to its high viscosity, and therefore pre-oil Fig. 1 Map of western Canada showing outlines of the solid bitumen typically represents an in-situ transformation of Montney Formation and Duvernay Formation kerogen. In contrast, post-oil solid bitumen is generated from oil as well as study areas. which had high mobility and pore-filling tendencies. As a result, post-oil solid bitumen is often observed to have filled primary pore spaces between detrital grains and within fossil chambers, and commonly envelops early diagenetic mineral cements Starting in 2018, JOGMEC and NRCan extended their （e.g., Loucks and Reed, 2014）. The Duvernay Formation shale collaboration to the Duvernay Formation which is a true source reservoir contains both pre- and post-oil solid bitumen, while rock and self-sourced shale reservoir in Alberta（ Fig. 1）. The the Montney Formation tight reservoir is dominated by post-oil, Duvernay work so far has identified mineral - organic matter pore-filling solid bitumen. relationships that strongly influence the pore system. 2. Background 3. Tight Reservoirs: Montney Project JOGMEC’s motivation for conducting research on The Lower Triassic Montney Formation is primarily unconventional reservoirs is to support Japanese companies by composed of fine dolomitic sandstone and siltstone with improving exploration and production efficiency and reducing minor amounts of shale（ Davies, 1997; Zonneveld et al., 2010; investment risk. Over the last 10 years Japanese companies Chalmers and Bustin, 2012）. The up-dip（ depositionally have been active in many unconventional reservoirs around the and structurally） section of the Montney Formation hosts world, with the most activity centered in the United States and conventional oil and gas fields with exploration and production Canada. In many of these projects JOGMEC has collaborated dating back to the 1950s. The down-dip section of the Montney with Japanese companies and their North American partners by has been targeted as an unconventional tight gas reservoir providing technical analysis. In Canada, JOGMEC’s long term since 2005（ NEB, 2013）. The unconventional section of the collaboration partner in unconventional resources research is Montney Formation contains 449 TCF of marketable natural Natural Resources Canada（ NRCan）. This partnership has been gas, 14.5 billion barrels of marketable natural gas liquids, and very fruitful, as NRCan’s expertise in organic geochemistry 1.1 billion barrels of marketable crude oil（ NEB, 2013）. compliments JOGMEC’s expertise in laboratory petrophysical JOGMEC’s initial research into the Montney strived to analyses. NRCan and their subsidiary, the Geological Survey define the controls on reservoir quality, particularly porosity of Canada（ GSC）, also contribute a wealth of knowledge and and permeability. Wood et al.（ 2015）, Sanei et al.（ 2015）, and experience in the Western Canada Sedimentary Basin. Akihisa et al.（ 2018） demonstrated that solid bitumen in the This paper focuses on the collaborative efforts of JOGMEC Montney reservoir was strongly detrimental to permeability. and NRCan since 2014. From 2014 to 2017 JOGMEC and Sanei et al.（ 2015） and Wood et al.（ 2015, 2018） illustrated NRCan collaborated with Encana and Mitsubishi in the through the use of organic petrology and SEM imagery that Montney tight gas reservoir which occurs in the Canadian solid bitumen exhibited pore-filling textures and suggested that provinces of Alberta and British Columbia（ Fig. 1）. This solid bitumen formed as a secondary cracking product of oil collaborative research helped to define relationships between that had migrated into the reservoir at an earlier time. Akihisa organic matter and reservoir quality, and the processes et al.（ 2018） showed that these relationships could also be responsible for the Montney reservoir’s complex variations identified using cuttings rather than core. This work helped to in hydrocarbon composition（ condensate-gas ratio; CGR）. demonstrate the overlooked value of cuttings, which represent 石油技術協会誌 85 巻 1 号（2020） Levi J. Knapp, Shinnosuke Uchida, Takashi Nanjo, Tatsuya Hattori, Omid Haeri-Ardakani, Hamed Sanei 37 Fig. 2 （a） Regional Montney map from Wood and Sanei（ 2016） showing methane migration pathways based on calculation of excess
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