The Influence of Faulting on Hydrocarbon Migration in the Kupe Area, South Taranaki Basin, New Zealand

<p>Faults play an important role in petroleum systems as both barriers and conduits to the flow of hydrocarbons. An understanding of the relationship between fluid and gas migration and accumulation, and faulting is often required during hydrocarbon exploration and production, and CO2 storage. While methods for predicting across-fault flow are well advanced (e.g. Yielding et al., 1997; Manzocchi et al., 1999), current geomechanical and geometrical methods for predicting the locations of up-fault (up-dip) hydrocarbon migration (and leakage) are relatively untested. This thesis investigates the relationships between up-sequence gas migration in the form of gas chimneys and Pliocene to Recent normal faults in the Kupe Area, South Taranaki Basin. It undertakes studies of the Kupe Area’s structural development, examines spatial relationships between faults and gas chimneys, tests current geomechanical and geometrical models to predict up-dip gas flow in faults, and investigates the outcrop expression of fault structure below seismic reflection data resolution and gas flux rates at an onshore site of fault-related gas leakage. Data for this study are provided by highquality 2D and 3D seismic reflection lines (tied to stratigraphy in fifteen wells), and outcrop of Miocene and Oligocene strata in coastal cliff sections, together with methane concentration and flux measurements. Structural development in the Kupe Area was complex and provides a near complete record of deformation since the Late Cretaceous (~85 Ma). Basin strata up to 9 km thick record four main periods of deformation that reflect changing plate boundary configurations. Fault reactivation was common in the Kupe Area, with the locations and orientations of pre-existing faults strongly influencing the locations and geometries of younger faults and folds. Pliocene to Recent normal faults are highly segmented with low strain, consistent with an immature fault system in which fault lengths were established rapidly and subsequent fault growth was mainly achieved by accumulation of displacement. Plio-Pleistocene to Recent reactivation of Cretaceous rift faults provides conduits for gas migration from below the regional top seal in the Kupe Area into shallow strata and results in up-dip gas migration within the Plio-Pleistocene to Recent fault zones. These late-stage normal faults (younger than 4 Ma) are shown to have a strong spatial relationship with gas chimneys suggesting that fault zones are capable of producing channelised pathways for up-dip hydrocarbon migration. Fifteen of seventeen gas iii chimneys within the study area are rooted within fault zones. All of these fifteen faultrelated gas chimneys occur at geometrical complexities in fault structure (i.e. relay zones, lateral fault tips or fault intersections). Geometrical complexities are associated with locally high throw gradients which are inferred to be accompanied by off-fault strain in the form of fractures and/or bedding rotation. Three geomechanical modelling techniques (Slip Tendency, Dilation Tendency and Fracture Stability) for predicting the locations of up-fault hydrocarbon flow (leakage) are tested using the spatial distribution of gas chimneys and Pliocene to Recent normal faults in the Kupe Area. Slip Tendency, Dilation Tendency and Fracture Stability data for all of the faults analysed predict comparable likelihoods of gas migration on chimney and non-chimney sections of the fault surfaces and therefore do not provide a robust basis for predicting where on fault surfaces channelised up-dip gas flow will occur. Field-based observations of faults show that fractures observed in outcrop and below seismic reflection data resolution are localised around bends, steps and intersections of faults and show evidence of fluid flow post fault activity. In north Taranaki these fault complexities are present in a lateral equivalent to the Otaraoa top seal and, if present in the Kupe Area, are also likely to induce up-sequence gas migration through fracture networks. Methane concentrations measured at one site (Bristol Road Quarry) along the Inglewood Fault suggest that gas flux rates up faults may not be uniform over time. Based on the measured gas flux rates gas chimneys in the Kupe Area may form in association with gas migration in a series of discrete events lasting from days to years, with possible gas flows at the seabed of ~930 ft3 per chimney per day or 0.34 million ft3 per year.</p>

The Influence of Faulting on Hydrocarbon Migration in the Kupe Area, South Taranaki Basin, New Zealand

<p>Faults play an important role in petroleum systems as both barriers and conduits to the flow of hydrocarbons. An understanding of the relationship between fluid and gas migration and accumulation, and faulting is often required during hydrocarbon exploration and production, and CO2 storage. While methods for predicting across-fault flow are well advanced (e.g. Yielding et al., 1997; Manzocchi et al., 1999), current geomechanical and geometrical methods for predicting the locations of up-fault (up-dip) hydrocarbon migration (and leakage) are relatively untested. This thesis investigates the relationships between up-sequence gas migration in the form of gas chimneys and Pliocene to Recent normal faults in the Kupe Area, South Taranaki Basin. It undertakes studies of the Kupe Area’s structural development, examines spatial relationships between faults and gas chimneys, tests current geomechanical and geometrical models to predict up-dip gas flow in faults, and investigates the outcrop expression of fault structure below seismic reflection data resolution and gas flux rates at an onshore site of fault-related gas leakage. Data for this study are provided by highquality 2D and 3D seismic reflection lines (tied to stratigraphy in fifteen wells), and outcrop of Miocene and Oligocene strata in coastal cliff sections, together with methane concentration and flux measurements. Structural development in the Kupe Area was complex and provides a near complete record of deformation since the Late Cretaceous (~85 Ma). Basin strata up to 9 km thick record four main periods of deformation that reflect changing plate boundary configurations. Fault reactivation was common in the Kupe Area, with the locations and orientations of pre-existing faults strongly influencing the locations and geometries of younger faults and folds. Pliocene to Recent normal faults are highly segmented with low strain, consistent with an immature fault system in which fault lengths were established rapidly and subsequent fault growth was mainly achieved by accumulation of displacement. Plio-Pleistocene to Recent reactivation of Cretaceous rift faults provides conduits for gas migration from below the regional top seal in the Kupe Area into shallow strata and results in up-dip gas migration within the Plio-Pleistocene to Recent fault zones. These late-stage normal faults (younger than 4 Ma) are shown to have a strong spatial relationship with gas chimneys suggesting that fault zones are capable of producing channelised pathways for up-dip hydrocarbon migration. Fifteen of seventeen gas iii chimneys within the study area are rooted within fault zones. All of these fifteen faultrelated gas chimneys occur at geometrical complexities in fault structure (i.e. relay zones, lateral fault tips or fault intersections). Geometrical complexities are associated with locally high throw gradients which are inferred to be accompanied by off-fault strain in the form of fractures and/or bedding rotation. Three geomechanical modelling techniques (Slip Tendency, Dilation Tendency and Fracture Stability) for predicting the locations of up-fault hydrocarbon flow (leakage) are tested using the spatial distribution of gas chimneys and Pliocene to Recent normal faults in the Kupe Area. Slip Tendency, Dilation Tendency and Fracture Stability data for all of the faults analysed predict comparable likelihoods of gas migration on chimney and non-chimney sections of the fault surfaces and therefore do not provide a robust basis for predicting where on fault surfaces channelised up-dip gas flow will occur. Field-based observations of faults show that fractures observed in outcrop and below seismic reflection data resolution are localised around bends, steps and intersections of faults and show evidence of fluid flow post fault activity. In north Taranaki these fault complexities are present in a lateral equivalent to the Otaraoa top seal and, if present in the Kupe Area, are also likely to induce up-sequence gas migration through fracture networks. Methane concentrations measured at one site (Bristol Road Quarry) along the Inglewood Fault suggest that gas flux rates up faults may not be uniform over time. Based on the measured gas flux rates gas chimneys in the Kupe Area may form in association with gas migration in a series of discrete events lasting from days to years, with possible gas flows at the seabed of ~930 ft3 per chimney per day or 0.34 million ft3 per year.</p>

Coupled Basin and Hydro-Mechanical Modeling of Gas Chimney Formation: The SW Barents Sea

Gas chimneys are one of the most intriguing manifestations of the focused fluid flows in sedimentary basins. To predict natural and human-induced fluid leakage, it is essential to understand the mechanism of how fluid flow localizes into conductive chimneys and the chimney dynamics. This work predicts conditions and parameters for chimney formation in two fields in the SW Barents Sea, the Tornerose field and the Snøhvit field in the Hammerfest Basin. The work is based on two types of models, basin modeling and hydro-mechanical modeling of chimney formation. Multi-layer basin models were used to produce the initial conditions for the hydro-mechanical modeling of the relatively fast chimneys propagation process. Using hydro-mechanical models, we determined the thermal, structural, and petrophysical features of the gas chimney formation for the Tornerose field and the Snøhvit field. Our hydro-mechanical model treats the propagation of chimneys through lithological boundaries with strong contrasts. The model reproduces chimneys identified by seismic imaging without pre-defining their locations or geometry. The chimney locations were determined by the steepness of the interface between the reservoir and the caprock, the reservoir thickness, and the compaction length of the strata. We demonstrate that chimneys are highly-permeable leakage pathways. The width and propagation speed of a single chimney strongly depends on the viscosity and permeability of the rock. For the chimneys of the Snøhvit field, the predicted time of formation is about 13 to 40 years for an about 2 km high chimney.

Automated Fault Detection and Extraction under Gas Chimneys Using Hybrid Discontinuity Attributes

3D-seismic data have increasingly shifted seismic interpretation work from a horizons-based to a volume-based focus over the past decade. The size of the identification and mapping work has therefore become difficult and requires faster and better tools. Faults, for instance, are one of the most significant features of subsurface geology interpreted from seismic data. Detailed fault interpretation is very important in reservoir characterization and modeling. The conventional manual fault picking is a time-consuming and inefficient process. It becomes more challenging and error-prone when dealing with poor quality seismic data under gas chimneys. Several seismic attributes are available for faults and discontinuity detection and are applied with varying degrees of success. We present a hybrid workflow that combines a semblance-based fault likelihood attribute with a conventional ant-tracking attribute. This innovative workflow generates optimized discontinuity volumes for fault detection and automatic extraction. The data optimization and conditioning processes are applied to suppress random and coherent noise first, and then a combination of seismic attributes is generated and co-rendered to enhance the discontinuities. The result is the volume with razor sharp discontinuities which are tracked and extracted automatically. Contrary to several available fault tracking techniques that use local seismic continuity like coherency attributes, our hybrid method is based on directed semblance, which incorporates aspects of Dave Hale’s superior fault-oriented semblance algorithm. The methodology is applied on a complex faulted reservoir interval under gas chimneys in a Malaysian basin, yet the results were promising. Despite the poor data quality, the methodology led to detailed discontinuity information with several major and minor faults extracted automatically. This hybrid approach not only improved the fault tracking accuracy but also significantly reduced the fault interpretation time and associated uncertainty. It is equally helpful in detecting any seismic objects like fracture, chimneys, and stratigraphic features.

Focused Fluid Flow, Shallow Gas Hydrate, and Cold Seep in the Qiongdongnan Basin, Northwestern South China Sea

The 3D seismic data acquired in the central Qiongdongnan Basin, northwestern South China Sea, reveal the presence of shallow gas hydrate, free gas, and focused fluid flow in the study area, which are indicated by multiple seismic anomalies, including bottom simulating reflectors, polarity reverses, pulldowns, minor faults, and gas chimneys intensively emplaced within the shallow strata. A new cold seep is also discovered at approximately 1520 m water depths with an ~40 m wide crater in the west part of the study area. Water column imaging, seafloor observation, and sampling using the remotely operated vehicle “Haima” demonstrate ongoing gas seepages and shallow gas hydrates at this site. Thermogenic gas in the study area migrates from the deep reservoir through the gas hydrate stability zone along deep faults and gas chimneys, forms shallow gas hydrate and free gas, and sustains localized gas seepage within this cold seep. The results provide insight into the relationship between shallow gas hydrate accumulation and deep hydrocarbon generation and migration and simultaneously have important implications for hydrocarbon explorations in the Qiongdongnan Basin, northwestern South China Sea.

The South Chukchi-Hope Tectono-Sedimentary Element

The South Chukchi-Hope Tectono-Sedimentary Element rests on the Neocomian folded basement formed as a result of the South Anyui palaeo-ocean closure. The interpretation of 2D seismic data as well as results of onshore structural field studies and dating of post-kinematic granite plutons suggest post-collisional extensional/transtensional regimes, potentially driving development of the South Chukchi-Hope Basin. The orogenic collapse occurred during the Aptian-Albian and followed by continued poly-phase extensional/transtensional regime during the Late Cretaceous and Cenozoic. Depositional environments in the basin were most likely non-marine in the Cretaceous and Early Tertiary and marine from the Late Oligocene (?) - Miocene onwards. Three onshore wells in the adjacent depocentres penetrated Tertiary sediments and have had gas shows from two sites. Geochemical surveys registered anomalies of thermogenic and biogenic methane and in some instances higher molecular ethane to penthane gases in sea-bottom sediments above gas chimneys observed on seismic lines. The tectono-sedimentary element is characterized by a very high present-day thermal gradient of up to 48 deg. C/km recorded in the Alaskan wells and was previously considered to be gas-prone.

3-D Architecture and the Upper Miocene-Pliocene Depositional Pattern of the Gulf of İzmir by Reflection Tomography

&lt;p&gt;The ongoing tectonism in the Western Anatolia creates N-S extension and counter-clockwise rotational motion along the right-lateral North Anatolian fault (NAF) and left-lateral East Anatolian Fault (EAF). This continental extension creates predominantly E-W extending onshore grabens rarely NE to SW and NW to SE trending onshore/offshore grabens characterised by the intense seismic activity, high heat flow associated with volcanism, crustal thinning and geothermal systems. Our study area, the gulf of &amp;#304;zmir, has an &amp;#8220;L&amp;#8221; shape composing of an E-W oriented inner bay from &amp;#304;zmir to Urla and incompatibly NNW-SSE oriented outer bay between offshore Fo&amp;#231;a and Karaburun. It is located at the intersection of the E-W oriented onshore Gediz Graben and NE-SW oriented onshore Bak&amp;#305;r&amp;#231;ay graben. Geophysical evidence for fluid discharge and subsurface gas-associated structures such as gas chimneys, pockmarks, mud diapirs and acoustic turbidity zones&amp;#160;have been detected in the inner and outer parts of the Gulf of &amp;#304;zmir by the previous studies. For this reason, the Gulf of &amp;#304;zmir and the adjacent onshore grabens are areas of great interest for further study of the region.&lt;/p&gt;&lt;p&gt;In this study, the 3-D stratigraphic architecture (up to 1.5 km) and the Upper Miocene-Pliocene depositional settings of the Gulf of &amp;#304;zmir reconstructed by reflection tomography for the first time. Three seismic stratigraphic units, labelled SSU1, SSU2 and SSU3 from bottom to top, were identified by their bounding unconformity surfaces (H1-H5). We have subdivided unit SSU1 into three subunits named SSU1c-SSU1a. The acoustic basement associated with SSU3 is likely tied to the Lower-Middle Miocene Yuntda&amp;#287; Volcanics consisting of tuffs, sandstones, limestones and volcanics. The upper surface of SSU3 (horizon H5) is marked as a major regional unconformity representing a basin-ridge morphology. The first rocks deposited on top of acoustic basement (SSU2) correspond to the sandstones, limestones, volcanics and shales of the Bozk&amp;#246;y Formation and the limestones of the Ularca Formation, dating from the Late Miocene to the Pliocene. The top of SSU2 (horizon H4) is interpreted as another unconformity and is correlated with the Pliocene unconformity. Above that, part of the Bayrami&amp;#231; Formation (SSU1c) is dated as Quaternary, consisting of conglomerates at the base overlain by sandstones and shales above. On top of the SSU1c are two further sub-units of the Bayrami&amp;#231; Formation separated by horizons H3 and H2. SSU1b consists of a similar sequence of conglomerates, sandstones and shales; SSU1a consists of Quaternary sandstones. Following the tomographic analysis, the isopach map of the Plio-Quaternary sediment fills was derived from the depth of interpreted horizons calculated using tomographic interval velocities. According to the isopach map of the sedimentary fills, thickness abruptly decreasing from NW to SE. The maximum thickness of total sedimentary succession is ~1400 m in the NW, whereas the thickness decreases through the west, east (up to ~450 m) and the southeastern flank of the basin, reaching ~150 m forming a ridge. A few local lateral velocity variations were identified within the Plio-Quaternary sedimentary succession associated with faults, fluid escape and shallow gas occurrences or a combination of these.&amp;#160;&lt;/p&gt;

Shallow Imaging of Gas and Hydrate Using the Deep-towed ACS Data in Joetsu Basin, Niigata, Japan

&lt;p&gt;The deep-towed Autonomous Continuous Seismic (ACS) is a deep-towed marine seismic acquisition method. The ACS utilizes high frequency seismic source (ranging from 700 Hz to 2300 Hz) and multi-channel receivers that both source and receivers can be located close the seafloor. Moreover, the ACS is suitable to obtain high-resolution image of shallow geological structures. Since ACS data acquisition can be operated near the seafloor, the ocean (strong) current makes the position of both receivers and sources irregular (unstable) and it is hard to measure the absolute depth of both receivers and sources. During data processing, the unstable depth of both sources and receivers not only make the recorded seismic reflection curve (hyperbolic curve) rugged, but also makes the velocity analysis process more difficult because the velocity semblance is not clear. In this study, we propose a processing scheme to solve the unstable source&amp;#8211;receiver position problem and thus to construct an accurate final stack profile (Hutapea et al., 2020 doi:10.1016/j.jngse.2020.103573). We used deep-towed ACS data acquired in the Joetsu Basin in Niigata, Japan, where hydrocarbon features in the form of gas chimneys, gas hydrate, and free gas have been observed. Furthermore, sidelobes in the ACS source signature defocus the source wavelet and decrease the bandwidth frequency content. We designed a filter to focus the source signature. Our proposed approach considerably improved the quality of bandwidth frequency of the source signature and the final stacked profile. Even though depth information was not available for all receivers, the velocity semblance was well focused. Our seismic attribute analyses for the final stack section shows that free gas accumulations are characterized by low reflection amplitude and an unstable frequency component, and that hydrate close to the seafloor can be identified by its high reflection amplitude.&lt;/p&gt;