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TitlePetroleum system analysis using unconventional gas geochemistry: examples from the Montney play of western Canada
AuthorEuzen, T; Watson, N; Chatellier, J -Y; Mort, A; Mangenot, X
SourceProceedings of the SPE/AAPG/SEG Unconventional Resources Technology Conference 2019; 2019 p. 1276-1290,
Alt SeriesNatural Resources Canada, Contribution Series 20190560
PublisherUnconventional Resources Technology Conference (URTEC)
MeetingSPE/AAPG/SEG Unconventional Resources Technology Conference 2019, URTC 2019; Denver, CO; US; July 22-24, 2019
Mediapaper; on-line; digital
File formatpdf
ProvinceAlberta; British Columbia
Subjectsfossil fuels; geochemistry; Science and Technology; Nature and Environment; Economics and Industry; energy resources; petroleum resources; hydrocarbon potential; hydrocarbons; gas; exploration wells; reservoir rocks; hydrocarbon geochemistry; thermal maturation; isotopic studies; carbon isotopes; temperature; pressure; hydrocarbon migration; structural controls; hydrocarbon recovery; production; Montney Play; Montney Formation; Western Canada Sedimentary Basin; Phanerozoic; Mesozoic; Triassic
Released2019 10 16
AbstractWith the development of unconventional resources, the large number and high density of well data in the deep/distal part of sedimentary basins offer new avenues for petroleum system analysis. Gas geochemistry is a widespread and inexpensive data that can provide invaluable information to better understand unconventional plays. This paper illustrates the use of early production gas composition as a proxy for in-situ hydrocarbon phase distribution in the Montney play of westernmost Alberta and northeastern British Colombia. We demonstrate that a careful stratigraphic allocation of the landing zone of horizontal wells is a key step to a meaningful interpretation and mapping of gas geochemical data. The regional mapping of the dryness of early production gas from the Montney formation clearly delineate thermal maturity windows that are consistent with available carbon isotopic data from produced and mud gas. Integrating this mapping with pressure and temperature data also highlights gas migration fairways that are likely influenced by major structural elements and compartmentalization of the basin. In the wet gas window, reported condensate-gas ratios show that the liquid recovery from multi-stage fractured horizontal wells is highly variable and strongly influenced by variations in reservoir quality and stimulation design. Understanding in-situ fluid distribution can help narrow down the number of variables and identifying key controls on liquid recovery. Several examples combining produced and mud gas data illustrate the use of geochemistry to better constrain geological and operational controls on productivity and liquids recovery in the Montney play.

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