Structural and stratigraphic evolution of the Mid North Sea High region of the UK Continental Shelf

Interpretation of newly acquired seismic and legacy well data has led to a greater understanding of the Upper Paleozoic–Recent geological evolution of the Mid North Sea High (MNSH), an under-explored region of the North Sea. The position of granite-cored blocks controlled the distribution of Devono-Carboniferous highs and basins before Variscan uplift led to peneplanation and the creation of the Base Permian Unconformity. The MNSH became the dominant feature during the Permian when it formed a west–east-striking ridge between the Southern and Northern Permian basins. Following a period of non-deposition, sedimentation was renewed in the Late Permian–Triassic before Middle Jurassic doming caused uplift to the NE. Subsequent Late Jurassic North Sea rifting transected the MNSH to create the Western Platform between the Central Graben and Moray Firth rift arms. Following Cretaceous post-rift deposition, the area experienced a significant easterly tilt in the Cenozoic that led to the demise of the MNSH as a prominent topographical feature. The tectonic and stratigraphic evolution exerts a strong control over reservoir facies distribution, source-rock deposition and maturation. However, the area is not barren of petroleum potential. Despite the lack of Upper Carboniferous source rocks over large areas, hydrocarbon potential is evident through shows in legacy wells, indicating the Lower Carboniferous as a potential source rock. Cenozoic uplift to the west imparted a regional tilt, the effects of which remains key to unlocking the area's prospectivity since it reconfigured structures and formed remigration pathways from Lower Carboniferous and Jurassic source rocks. Thematic collection: This article is part of the Under-explored plays and frontier basins of the UK continental shelf collection available at: https://www.lyellcollection.org/cc/under-explored-plays-and-frontier-basins-of-the-uk-continental-shelf

After almost six decades of exploration, the North Sea is generally considered to be a mature petroleum province. Whilst vast areas of the basin have seen intense exploration activity, other parts remain relatively under-explored. One such area is the region between the east coast of the UK and the North Sea rift system (Fig. 1). Loosely defined as the Mid North Sea High (MNSH), licences were taken and wells drilled in the early years of UK Continental Shelf (UKCS) exploration. However, drilling activity rapidly tailed off as attention focused on the highly prospective Southern Permian Basin, the Viking Graben, East Shetland Basin, Central Graben and Moray Firth. The region was largely neglected in subsequent licensing rounds. In an attempt to rejuvenate interest in the area, the UK Government supported the acquisition of new seismic data over the Mid North Sea High area through the offices of the Oil and Gas Authority (OGA) as part of a larger programme promoting frontier basins of the UK Continental Shelf (UKCS). This paper documents the interpretation of the seismic data that enables new insights to be gained about the tectonostratigraphic evolution and petroleum prospectivity of the area. The results of the work help to resolve long-standing issues regarding the true nature and genesis of the Mid North Sea High, demonstrate the controls it had on the distribution of Upper Permian (Rotliegend Group and Zechstein Group) clastic and carbonate deposystems, and highlight the overprinting role that Cenozoic tilting has had in controlling the geographical extent of petroleum maturation and (re)migration in the region. As such, the seismic acquisition and our subsequent study help to provide a new understanding of the factors governing prospectivity in the area, an awareness of which has seen new block awards in recent offshore licensing rounds.

Exploration history
The very first wells to be drilled in UK waters were located on the Mid North Sea High (MNSH) (Brennand et al. 1998). Well 38/29-1 ( Fig. 2) was spudded in December 1964 and aimed to test the stratigraphy of the UKCS down through the Carboniferous. The well unexpectedly identified numerous missing sections through the Jurassic-Upper Triassic and Lower Permian-Carboniferous. No hydrocarbons or potential source rocks were identified. A second well was drilled the following year 40 km to the SW, along the southern margin of the MNSH (Fig. 2). Well 44/02-1 was also dry; however, Carboniferous coals of Namurian age were penetrated. The first gas was discovered in September 1965 at the West Sole Field in the Southern North Sea, followed by a number of nearby Permian Rotliegend accumulations. This, along with the discovery of oil in the Central North Sea at the Norwegian Ekofisk Field in December 1969, resulted in exploration efforts becoming increasingly focused on the Southern North Sea Gas Basin and the Upper Jurassic trilete rift system of the Central and Northern North Sea (Fig. 2). The MNSH region has, therefore, remained largely underexplored in the last decades, and has not replicated the success of its adjacent prolific oil and gas basins.
Despite this downgrading of prospectivity, there have been a number of important discoveries made on the margins of the study area. The discovery of gas in the Gordon Field in 1969 opened up the Triassic Bunter Sandstone play along the southern margin of the MNSH, and ultimately led to the discovery of the nearby Forbes and Esmond fields. It was not until the 1990s that deeper play levels were identified along this southern margin, with a small uneconomic accumulation being identified at Crosgan (Fig. 2). Gas was reservoired within Carboniferous Namurian sands and Permian Zechstein dolomites, importantly opening up the possibility of a Lower Carboniferous play fairway to the north of the existing Carboniferous Westphalian discoveries of the Southern North Sea Gas Basin (Besly 2018). This led to the discovery of Breagh in 1997, reservoired within Lower Carboniferous Namurinan Yoredale and Visean Scremerston sandstones (Booth et al. 2018). The most significant discovery along this southern margin was made in 2012 at Cygnus (Fig. 2). At over 600 bcf recoverable, Cygnus is the largest gas development in the Southern North Sea in over 30 years. This Base Permian inversion structure was first drilled in 1988; however, the reservoir was deemed to be of poor quality and non-commercial. Re-evaluation and advances in technology have allowed for the appraisal and development of Cygnus's Permian Rotliegend and Carboniferous Westphalian reservoirs (Catto et al. 2017).
To the north of the MNSH, fields are charged from the oil-prone Upper Jurassic Kimmeridge Clay Formation of the Central Graben. A number of noteworthy discoveries have been made within the study area, on the SW flank of the graben, the earliest of which is the Auk Field (Fig. 2). Discovered in 1970, the Auk Field consists of stacked reservoirs within the Permian Zechstein and underlying Rotliegend groups within a large tilted fault block (Trewin and Bramwell 1991). This was followed by a number of discoveries to the SE along the margin of the Central Graben within upthrown Upper Jurassic (Fife, Fergus and Fulmar fields), Rotliegend (Innes Field), and Carboniferous Westphalian (Flora Field) reservoirs. The most significant oil discovery in the study area is located in the very north, at the edge of the Outer Moray Firth. Discovered in 2001, the Buzzard Field is estimated to contain over 1500 MMbbl original oil in place (OOIP) within an Upper Jurassic turbidite stratigraphic trap (Ray et al. 2011). Most recently, the Catcher Field was sanctioned in 2010, and developed as a cluster with the nearby Varadero and Burgman fields (Fig. 2). They produce from Late Paleocene to Early Eocene turbidite sands. A number of unsanctioned heavy oil accumulations are identified nearby at the Pilot Cluster. Both the northern and southern margins of the MNSH, therefore, have shown continued high-volume exploration success from the initial stages of North Sea exploration through to the present day, and currently provide approximately 9% of domestic gas and a quarter of domestic oil supply to the UK.
Tectonostratigraphic setting Initial regional gravity-based surveys in the 1950s resulted in the first interpretations of the subsurface structure of the North Sea (Collette 1958). However, it was not until the acquisition of seismic data (Cook 1965) that the MNSH was first identified and mapped  Licence blocks are shaded grey, and drilled wells are indicated. The study area is highlighted by a blue polygon. Gas (red) and oil (green) discoveries are highlighted, in addition to the unsanctioned Crosgan discovery. Highlighted wells 28/29-1 and 44/02-1 are the first and second exploration wells to be drilled offshore the UKCS. (Heybroek et al. 1967). Although early seismic failed to allow interpretation of the pre-Zechstein, the Base Permian was mapped regionally and the MNSH was described as a western extension of the Ringköbing-Fyn High that saw thin Zechstein deposition compared to adjacent salt basins. Glennie (1998) now defines the MNSH as an east-west-orientated high separating the North and South Permian basins, and notes the orientation as being subparallel to the Variscan front, and therefore likely to have formed as a result. Much emphasis has been put on the evolution of the surrounding basins, and the tectonic evolution of the wider North Sea is now well constrained.
Basement mapping by Frogtech Geoscience (2016) identifies six North Sea Basement terranes associated with the collision of palaeocontinents Avalonia, Baltica and Laurentia ( Fig. 1): (1) the Grampian Highland Terrane, derived from Laurentia, was highly deformed during its collision with Avalonia and the resulting Caledonian Orogeny; (2) the Midland Valley Terrane comprises Cambrian-Ordovician Iapetus Ocean ophiolite and forearc complexes (Frogtech Geoscience 2016) that have been deformed by dextral strike-slip movement along the bounding Highland Boundary and Southern Uplands faults (Underhill et al. 2008); (3) the Southern Uplands Terrane is formed from an accretionary wedge of deformed and metamorphosed Ordovician and Silurian deep-water sediments deposited in the Iapetus Ocean that once separated Laurentia and Avalonia (Frogtech Geoscience 2016); (4) the North Sea South Terrane represents the continent of Baltica once separated by the Tornquist Sea; (5) the Devil's Hole Terrane comprises basement of unknown age and origin; this long-standing high is located at the triple junction between the three palaeocontinents ( Fig. 1) and is likely to be formed of fragments of each (Frogtech Geoscience 2016); and (6) the Leinster-Lakesman Terrane represents the palaeocontinent of Avalonia. Closure of the Iapetus Ocean led to volcanic activity within the basement across the south of the study area (Frogtech Geoscience 2016) and the emplacement of numerous granite intrusions. Granites have been rarely penetrated by offshore wells but onshore dating suggests an emplacement date of Late Silurian-Carboniferous (Ziegler 1990;Kimbell et al. 2010).
Following the Caledonian Orogeny, large volumes of sediment were eroded from the mountain range in the north. At this time, much of the North Sea formed a depocentre where Devonian fluvial, lacustrine and aeolian Old Red Sandstone deposits are now identified in the subsurface (Cameron 1993). A change in stress regime during the Carboniferous led to transtensional and extensional basins forming along lineaments created in the Caledonian Iapetus and Tornquist orientations . In the Late Carboniferous (Westphalian), extension ceased, and compressional movements associated with the closure of the Rheic Ocean and the Variscan orogeny initiated . Post-orogenic collapse and volcanism during the Early Permian saw uplift and erosion, followed by thermal subsidence and the deposition of the Rotliegend Group of sands, silts and mudstones (Glennie et al. 2003). The Northern and Southern Permian basins were formed by a series of depressions or half-grabens that were separated by the MNSH (Fig. 1) (Doornenbal and Stevenson 2010). Continued subsidence through the Late Permian led to the deposition of the Zechstein Group (Doornenbal and Stevenson 2010) consisting of a succession of evaporites and carbonates (Tucker 1991). Renewed extension in the Triassic formed the Dowsing and South Hewett fault zones which show evidence of syndepositional movement and the deepening of the Sole Pit Basin (Fig. 1) (Pharaoh et al. 2010).
Triassic subsidence was interrupted in the Middle Jurassic, suggested as being due to mantle-driven thermal doming by Underhill and Partington (1993). During the Late Jurassic-Early Cretaceous, a major episode of rifting occurred in the Central and Northern North Sea to form the Viking Graben, Moray Firth Basin and the Central North Sea Trough ( Fig. 1) (Erratt et al. 1999). Importantly, the initiation of the Central Graben resulted in the separation of the MNSH from its eastern continuation: the Rinkøbing-Fyn High (Fig. 1). By the Early Cretaceous, the focus of rifting had switched to the Proto-Atlantic, and thermal subsidence began in the North Sea (Erratt et al. 1999). Late Cretaceous-Mid Tertiary compressional reactivation of faults is thought to be associated with the Alpine Orogeny to the SE (Cartwright 1989), and resulted in uplift and inversion anticlines across southern England (Underhill and Stoneley 1998), the Southern North Sea (Glennie and Boegner 1981;Van Hoorn 1987) and the Central Graben (Cartwright 1989). Today, continued thermal subsidence leads to differential sediment loading and associated salt movements  but, in general, this is a tectonically quiet time for the Central North Sea.

Seismic data
In an effort to encourage renewed exploration interest in underexplored regions of the UKCS, the UK's Oil and Gas Authority (OGA) launched their Frontier Basins Research Programme in 2015. As part of this initiative, the OGA provided sponsorship for the acquisition and release of long offset 2D seismic data by WesternGeco over the MNSH, Rockall and Western Approaches.
A 2 year postdoctoral project award was made to Heriot Watt University in 2016 to provide an independent academic view on the newly-released MNSH dataset, and aimed to review the petroleum systems and their remaining exploration potential.
The newly acquired 2D long offset seismic comprises over 10 000 km of line data (Fig. 3). In addition, a number of reprocessed and legacy lines were released to complement the WesternGeco survey (Fig. 3). The MNSH_2015 data are zero-phase, normal polarity (Fig. 4). Data quality is moderate to excellent from the seabed down to the Base Zechstein, deteriorating from c. 500 ms two-way time (TWT) in the west to 2500 ms TWT in the east (Fig. 4).
Following quality control of the data, tectonostratigraphically significant horizons were picked across the survey area to identify dominant structural trends and depocentres. Thirteen regionally significant horizons were chosen for interpretation which formed either onlap/truncation surfaces or showed significant acoustic impedance contrast ( Fig. 5; Table 1). Seismic to well (S2W) ties were completed for wells with check-shot data to tie the seismic observations to the lithostratigraphy. Surfaces were generated using the following workflow: (1) initial interpretation tied to wells and seismic response; (2) infill interpretation in areas without S2W tie, including the interpretation of legacy seismic where required; (3) gridding completed using trend surfaces where appropriate; (4) smoothing where required; (5) surfaces combined or eliminated where erosion has removed stratigraphy; (6) isochron maps generated from surfaces; and (7) surface maps and isochrons were combined with well information to make conclusions on facies distributions and main depocentres through time. Where required, a very simple 'back-stripping' was completed by removing overburden thickness from surfaces.
No time-to-depth conversion has been completed as part of this study. After review of the available check-shot data, it was concluded that the data require specialist input from a geophysicist on account of the multiple uplift events and how they affect the velocities across the region. In particular, the fastest velocity functions are seen in the deepest part of the basin and are likely to be controlled by localized uplift, changing thicknesses of Cretaceous chalk and/or Zechstein salts, and changing Zechstein facies. Lateral velocity changes across the study area will be of key importance when time-to-depth conversion is carried out.

Well data
In addition to the open-access release of new and legacy seismic data, the OGA also released a complementary set of legacy wells. Ninety-eight wells were supplied ( Fig. 3) with various quantities  of supporting data: well heads and trajectories with assorted well logs; well tops across a selection of the wells; check shots for 32 wells; core analysis for six wells, including porosity-permeability ( poroperm) and saturation readings; and various supporting documents including completion logs, final well reports, palynology reports, etc. An additional set of 37 wells were downloaded from the Common Data Access web portal (now replaced by the OGA's National Data Repository (NDR)) (Fig. 3). These were added in order to better constrain the structural evolution of the southern margin of the MNSH.
All well data were standardized with respect to well top nomenclature and depth units. This was used to produce a series of well penetration, thickness and facies maps which could be fed into play mapping. In addition, a single-page well summary sheet and well failure analysis was completed for each well in the study (Brackenridge et al. 2018). Digitized composite logs and final well tops were compiled so that a series of well-correlation panels could be generated. Finally, a number of burial history curves were created for wells selected to complement key seismic lines.
Three wells were identified for burial history reconstruction along a north-south transect across the MNSH: 39/02-4, 38/16-1 and 43/ 06-1 (Fig. 3). The inputs for the creation of the burial graphs were the stratigraphic tops and ages from the wells, the main lithologies in each section, estimates of the amount of missing section at unconformities, the duration of these erosion events, and the palaeobathymetric history. These inputs were then supplied to Shell's proprietary basin modelling tool, BPA-CAULDRON. The decompaction behaviour of the sediments in BPA-CAULDRON is dependent on the input lithologies or lithology mixes, the vertical effective stress and the estimated pore pressure.

Additional data and previous studies
The OGA_2015 seismic and well data were released open access via the OGA data centre website as part of a larger data pack containing limited seismic horizon interpretations, gravity and magnetic data. Prior to this data release, a number of bespoke studies on legacy data over the MNSH were commissioned, for which a number of companies completed studies including the Frogtech's 'Depth to Basement' study (Frogtech Geoscience 2016), the British Geological Survey's Paleozoic Plays study (Monaghan et al. 2015) and the Lloyd's Register regional mapping project (Lloyd's Register 2019), amongst others. These studies have helped to inform aspects of the interpretation of the newly released OGA_2015 data where required.

Seismic mapping and well results
The seismic and well data were used to interpret 13 regionally significant horizons (Table 1; Figs 4 and 5). Of these, four horizons are onlap/truncation surfaces, and are classed as unconformities. These are: (1) the Base Permian Unconformity, an angular unconformity separating Carboniferous and Devonian tilted fault blocks from overlying Upper Permian facies; (2) the Mid Cimmerian Unconformity, observed only in the north of the region where Upper Jurassic strata onlaps onto the Lower Triassic; (3) the Base Cretaceous Unconformity, a significant erosional truncation surface with a complex subcrop of Jurassic, Triassic and Permian strata; and (4) the Mid Tertiary Unconformity, a shallow diachronous onlap surface onto which sediments prograde from the NE (Figs 4 and 5).
In addition, a number of significant high-amplitude horizons represent regional facies changes (Fig. 5). These define the remaining seven horizons interpreted: (1) the Top Permian Rotliegend Group, or Base Zechstein Group, represented by a strong soft event that signifies a move from halites and evaporites of the Zechstein to the underlying clastics of the Rotliegend; (2) the Top Permian Zechstein or top salt; (3) the Top Lower Triassic is picked close to the well top where the overlying Upper Triassic Rot Halite forms a regional acoustic impedance (AI) peak; (4) the Top Upper Triassic is observed only in the south of the study area; (5) the Top Lower Cretaceous, or Base Chalk, forms a regionally-interpretable AI soft peak in the seismic as chalks give way to the marly muds of the Lower Cretaceous; (6) the Top Upper Cretaceous Chalk with a strong AI peak in the seismic. To the NE of the study, Lower Paleocene chalks are also recorded in the well data but a chronostratigraphic Upper Cretaceous seismic pick has been maintained; and (7) the Top Balder (or equivalent), dated as Early Eocene, represents the opening of the Atlantic Ocean to the NW. In addition, the seabed was picked, and a near top basement was interpreted. Locally, the top basement is clearly imaged where the highly reflective Devonian Kyle Limestone is present; however, elsewhere the basement was interpreted with the aid of gravity data and the Frogtech 'Depth to Basement' study (Frogtech Geoscience 2016).

Structural evolution and facies distribution
Mapping of unconformity surfaces has allowed the MNSH to be placed within the North Sea tectonostratighaphic framework. Four megasequences are identified (Figs 5 and 6) on the basis of seismic reflection terminations at key unconformities (Base Permian Unconformity, Base Cretaceous Unconformity and Mid Tertiary Unconformity). In addition, the Mid Cimmerian UC is identified locally and forms part of major Tectonostratigraphic Sequence B. Each seismic sequence boundary and the facies within each unit are instrumental in understanding the structural evolution of this region.

Top basement-Base Permian Unconformity
Tectonostratigraphic Unit A is bounded by the basement and topped by the Base Permian Unconformity (BPU). The isochron thickness map ( Fig. 7) reveals highly variable thickness changes across the region: reaching over 3000 ms TWT within isolated depocentres, and thinning to c. 600 ms over basement highs in the centre of the study area. Here, we propose that the basement exerts a strong control on the distribution of Devonian-Carboniferous sediments. In the north, the Forth Approaches Basin forms a depocentre on the Midland Valley Terrane (Figs 1 and 7). This basin is bounded by the Highland Boundary and the Southern Uplands Fault complexes, which greatly reduce the seismic imaging and therefore the confidence in basement interpretation in this region. The Devono-Carboniferous succession overlying the Southern Uplands Terrane consists of multiple smallscale depocentres separated by localized highs (Fig. 7). This is interpreted as being in response to the underlying accretionary wedge of deformed and metamorphosed Iapetus Ocean deposits (Frogtech Geoscience 2016). The Devil's Hole Terrane is represented by a Devono-Carboniferous thin across the Devil's Hole Horst (Fig. 7). Closure of the Iapetus Ocean led to deformation, volcanic activity and the emplacement of numerous granite intrusions across the Lenister-Lakesman Terrane in the south (Frogtech Geoscience 2016). The presence of granites across the MNSH has long been documented in gravity studies (Donato et al. 1983;Kimbell and Williamson 2016). Well 37/25-1 penetrated the basement on the mapped Dogger granite (Fig. 7). It recorded an increasing volume of quartzite cuttings and a significant decrease in rate of penetration (ROP) as the drill string reached the basement. Cuttings showed 'transparent, white, locally pink, very hard, blocky, massive quartz with randomly orientated euhedral biotite inclusions up to 1 mm' (Esso 2009, p. 16). The completion log describes the basement lithology as 'Metamorphics 2346-2359 m' (Esso 2009). This suggests that the granites have intruded into basement blocks (rather than forming basement themselves) and act as a buoyant core to strengthened crustal blocks.
Although imaging of the top basement is generally very poor, locally blocks are topped with high-amplitude, laterally continuous, seismic reflections (Fig. 8). Two wells have penetrated this highamplitude package: well 37/12-1 and well 38/03-1 (Fig. 9). They show that the marked AI increase is due to the presence of the Devonian Kyle Limestone. The nearby well 37/25-1 targeted this stratigraphic level at the Devonian Corbenic prospect but did not encounter the Kyle reservoir (Fig. 9). This high-amplitude seismic package is absent at the core site (Fig. 8). Detailed seismofacies mapping of the unit shows that its distribution is restricted to the Dogger and Auk highs in the east of the study area (Fig. 9). The high-amplitude Kyle Limestone package is absent from the west of the study area and, although very few wells penetrate this stratigraphic level, three wells in the west confirm that the Kyle is not present here (Fig. 9). These observations suggest that granite placement had occurred as early as the Devonian to form the relative highs for limestone deposition to occur. This is in agreement with radiometric dating of granites onshore (Ziegler 1990).
Erosion of the Caledonian mountain range to the north generated huge volumes of sediment, deposited across the Central North Sea as fluvial, lacustrine and aeolian Old Red Sandstone deposits (Cameron 1993). However, where granites were present, they locally acted to increase the buoyancy of basement blocks and generated long-standing isolated highs, over which more limited Devonian deposition occurred. This is comparable to the traditional block and trough morphology seen at this time along the east coast of the UK. A number of wells in the north of the study area penetrate Devonian sandstones (Fig. 7); however, core and field descriptions in the Midland Valley (wells 26/12-1 and 26/14-1) report that the Devonian is highly altered. This is confirmed in the NE where wells 38/03-1 and 38/10-1 report low porosity (<16%) and net to gross (NTG) (<0.26) values.  (2) the Upper Carboniferous Namurian Yoredale package; and (3) the Upper Carboniferous Westphalian Coal Group. Despite seismic imaging challenges, there is evidence of expanding sections throughout the survey (Fig. 10). Inversion is clearly seen in various locations (Fig. 10), which is likely to be associated with the Variscan Orogeny . To the SE of the study area, the BPU is clearly imaged where erosional truncation of the Carboniferous within tilted fault blocks has occurred (Fig. 10). This uplift and erosion has resulted in a complex subcrop of the Devonian and Carboniferous below the BPU, with a general trend towards older stratigraphy subcropping in the north and over the buoyant granite highs (e.g. the Dogger Granite High) (Fig. 7).
The Carboniferous contains a number of plays of interest, and important source-rock intervals. The uppermost Carboniferous Westphalian play fairway is defined by the overlying Permian Silverpit Mudstone which acts as the principal top seal. Although present at the southernmost MNSH at Cygnus and in the NE at the Flora Field, the Westphalian is not described in detail herein as well penetrations show that it does not extend across the MNSH (Figs 7  and 11). It does feed into play mapping as an important source rock across the southern margin of the study area. The underlying Yoredale Formation is seen in well penetrations across the south and NE of the study area (Figs 7 and 11). It represents a highly cyclic deltaic succession consisting of interbedded muds, sands and limestones (Fig. 11) (Doornenbal and Stevenson 2010). Delta-top fluvial sands form good reservoir targets. Deposition is thought to have occurred over much of the southern MNSH region, with the exception of local granite-cored highs such as the Dogger High. In the Southern North Sea, the Millstone Grit represents a basinal Yoredale equivalent. The Upper Carboniferous Namurian play is proven to work at Breagh, located on the southern margin of the MNSH (Fig. 2). An additional non-commercial accumulation is identified to the NE of the Breagh discovery at Crosgan (Fig. 2). The underlying Visean is formed of three distinct formations (Fig. 11): (1) The basal Cementstone Formation, consisting of interbedded mudstones, thin sands and limestone. Deposited in an arid coastal  plain and lake setting (Cameron 1993), the Cementstone shows little reservoir potential and low seal integrity due to the overlying Fell Sandstone Formation. (2) The Fell Sandstone is a thick succession of coarse-grained fluvial-alluvial deposits. This laterally extensive, high NTG sand unit (Fig. 11) shows good reservoir potential. However, it relies on charge from the overlying Scremertson and Westphalian, or its lateral equivalent the basinal Cleveland Group.
(3) The overlying Scremerston Formation is a succession of interbedded sands, silts, muds and coals (Fig. 11) deposited in a delta-plain environment (Cameron 1993). Fluvial distributary channels provide the reservoir section, and interbedded coals provide source-rock potential. The Visean extends well onto the MNSH platform, and is seen within the Forth Approaches Basin. It is locally absent across the Dogger High and to the NE of the study area (Fig. 7).

Base Permian Unconformity-Base Cretaceous Unconformity
Tectonostratigraphic Unit B, between the BPU and the Base Cretaceous Unconformity (BCU), shows continued thinning across the central part of the study area and thickening into the South Permian, North Permian and Forth Approaches basins to almost 2000 ms TWT (Fig. 6).
The Rotliegend Group sits directly above the BPU. Well penetrations confirm that its distribution is limited to the North and South Permian basins and the Forth Approaches Basin (Fig. 12). The isochron shows a thickening to over 400 ms TWT in the North and South Permian basins (Fig. 12a). There is an additional accumulation in the Forth Approaches Basin, although there is no evidence from well or seismic data that this is in communication with the North Permian Basin. Over the central part of the study area, the Rotliegend Group is absent and the Permian Zechstein Group sits directly above the Carboniferous, indicating that this area remained a regional high throughout the Lower-early Upper Permian. Well data show that at the time of deposition, the region was exposed to semi-arid tropical desert conditions and consists of playa-lake and aeolian deposits. A number of distinct facies are seen across the region (Fig. 12b). The youngest Permian deposits are seen in the very NE of the study area, where Lower Permian basalts and tuffs are identified (Fig. 12b). These are the Inge Volcanics, which extend eastwards into Denmark, Germany and Poland. They are thought to represent post-Carboniferous transtensional faulting in the region . Above and adjacent to the Inge Volcanics in the north of the region, the Auk Formation is dominantly dune-bedded sandstones (Cameron 1993), resulting in an attractive thick aeolian sandstone reservoir target (Fig. 12b). Locally the Auk Formation is interbedded or replaced by the Fraserburgh Formation (Fig. 12b) (Doornenbal and Stevenson 2010). Although no wells in this study penetrated this formation, studies show that this muddy siltstone represents a dune-bordered sabkha deposit with limited reservoir potential (Cameron 1993). To the south of the MNSH, the Silverpit Mudstone represents a large playa lake (Johnston et al. 1993) (Fig. 12b). The southern margin of this lake has previously defined the play fairway for the Leman Sandstone play of the Southern North Seawhich is formed of lake-margin and aeolian sandstones. The recent discovery at the Cygnus gas field is the first to target the thin northern margin of the Silverpit Lake, and shows red silt-rich sandstones of fine-medium grain size pinching out onto the MNSH (Fig. 11). These are interpreted to have been deposited on a playa shoreline environment that shows evidence for repeated flooding and drying events (Catto et al. 2017). The Permian Rotliegend Group is a proven play within the study area, both on the northeastern margin at the Auk Field and on the southernmost margin at Cygnus (Fig. 2).
Directly overlying the Rotliegend Group, the Zechstein Group consists of repeated sequences of carbonates and evaporites with minor mudstones deposited during the Late Permian (Johnston et al. 1993;Taylor 1998). Mapping the Top Zechstein is challenging for a number of reasons: (1) the lithostratigraphic top identified in well penetrations is not always represented by a significant AI contrast; (2) there are numerous lateral changes in depositional facies that lead to changing acoustic characteristics; and (3) salt halokinesis and overburden faulting has resulted in complex salt pillows, diapirs and wings being formed within depocentres. Despite these challenges, a Near Top Zechstein surface has been mapped regionally and shows a broad deepening to the east down to c. 3200 ms TWT. An isochron of the Zechstein Group (Fig. 13a) shows its presence over much of the study area, with the exception of the very west where Tertiary erosion has occurred. The isochron clearly highlights zones of halokinesis in the North and South Permian basins and the Forth Approaches Basin. Salt diapirs reach a maximum thickness of 800 ms TWT. Figure 14 demonstrates the changing Zechstein seismofacies across the study. Internal reflections within the Zechstein relate broadly to the Z1-Z5 cycles which were formed due to multiple desiccation events. High-amplitude hard reflections represent anhydrite layers directly below carbonate build-ups (Taylor 1998). Two distinct seismofacies are identified. First, carbonate-dominated facies are characterized by highamplitude laterally continuous reflections with common ramp or platform morphologies (Fig. 14). They correlate to regions where the isochron thins to less than 120 ms (Fig. 13a). Wells penetrating these thins generally show dolomite layers of up to 16% porosity, and are named the Mid North Sea, Dogger and Auk-Flora Carbonate platforms (Fig. 13). Although lacking in well control, seismic observations suggest that the Devil's Hole platform also comprises carbonate platform facies (Fig. 13). Salt-dominated facies form the thickest accumulations of the Zechstein Group, and are found in the North and South Permian, and Forth Approaches basins (Fig. 13). Facies mapping suggests a salt 'seaway' protruding through Quad 37 that separates two carbonate margins (Fig. 13) (Jenyon et al. 1984). Where the salt basin reaches thicknesses of over 500 ms TWT, salt pillows and diapirs dominate. Mapping of the salt structures is biased due to spacing and orientation of 2D seismic lines; however, it is clear that salt structures are orientated NW-SE to NNE-SSW, which is likely to be due to gravitational compression of the salt away from basin margins. These facies have been compared to well results and mapped across the area of interest to produce a facies map (Fig. 13b). The Permian Zechstein dolomites are a proven play on the northern edge of the study area at the Auk Field (Fig. 2). These dolomites were developed on the long-standing Auk High, and the reservoir shows excellent vuggy porosity, charged with Jurassic oils sourced from the Central Graben (Trewin and Bramwell 1991). Elsewhere, the Zechstein dolomites record a number of shows across the region, and one uncommercial discovery is identified at Crosgan, located on the southern margin of the MNSH (Fig. 2). Despite these positive indications of a widespread working play, the Zechstein dolomites of the MNSH have yet to replicate the success of its counterpart onshore Poland in the easternmost South Permian Basin. The Bronsko and Koscian discoveries (Doornenbal and Stevenson 2010) make good analogues for the dolomite play of the MNSH.
Tectonostratigraphic Unit B is topped by Triassic and Jurassic strata. Over the MNSH, much of the upper Mesozoic section is absent due to erosion. The resulting Mid Cimmerian Unconformity (MCU) and BCU show a complex interaction over the region. Remaining Lower Triassic accumulations are largely limited to the salt minibasins generated by salt halokinesis in the underlying Zechstein (Fig. 15a). Over much of the NE of the region, however, the Triassic has been removed by Jurassic uplift and erosion that created the 'Mid Cimmerian Unconformity'. Underhill and Partington (1993) attribute the formation of the unconformity to Early-Mid Jurassic mantle-driven thermal doming under the triple rift junction of the Central North Sea. The observations over the MNSH corroborate this hypothesis.
As a result of the Middle Jurassic uplift, localized erosion down to Lower Triassic levels has occurred in the NE of the region. Importantly, the lack of Upper Triassic or Lower-Mid Jurassic sediments does not imply that they were never deposited, but rather that they have been deposited at a reduced rate, and/or removed through post-depositional uplift, something that has been factored in to burial curves. The Upper Jurassic is seen clearly to onlap the MCU and indicates renewed subsidence prior to the onset of rifting in the Central Graben (Figs 4 and 15b). It should be noted that in the south of the region, within the Solepit Basin, there is no evidence of a break in sedimentation, with a full Triassic and Jurassic sequence being identified. The interaction of these major unconformities can be illustrated with the MCU and BCU subcrop maps ( Fig. 15c and  d). The maps show that these two unconformities become conformable to the south. This area shows a complex structural evolution, with the Dowsing and North Dogger fault zones clearly mappable in the isochron (Fig. 15). These fault zones are made up of large, listric, extensional faults that detach in the Triassic and Permian evaporate sequences. Well data confirm that the most widespread Lower Triassic facies is the Smith Bank Formation, which was deposited across a hot, arid continental plain that consisted of playa mud flats. Locally, ephemeral desert lakes formed within the basin depocentres where salt-withdrawal strongly controlled deposition. Clastic input was limited, or certainly sourced distally, and deposited in a low-energy environment. Any sand beds encountered are thin (<1 m) and, as a result, the Smith Bank Formation shows little to no reservoir potential. To the south,   Figure 13. the Bacton Group represents a succession of distal floodplain and playa lake muds topped by the Bunter Sandstone fluvial and alluvial sands. Sand deposition appears to be restricted to depocentres adjacent to structural highs that can provide clastic input. Within the study area, the Bunter sands are interpreted as being deposited by braided rivers on a series of alluvial fans (Bifani 1986), eroded proximally from the footwall of the Dowsing and North Dogger fault zones (Fig. 15). Due to Jurassic erosion of the MNSH, there are a number of regions where the Triassic is completely absent, including the east of the study area, the Mid North Sea Platform and the Devil's Hole High (Fig. 15). Later Tertiary uplift has removed the Triassic in the west of the region (Fig. 15). The Lower Triassic Bunter Sandstone is a proven play over the southern margin of the MNSH at the Esmond Cluster (Fig. 2). To the west, the Furasta discovery remains non-commercial and unsanctioned. All these fields show underfilled gas accumulations within salt-cored anticlines at the Triassic Bunter Sandstone level. The fields are sealed by the Upper Triassic Rot Halite and a thick succession of upper Triassic mudstones. Underhill (2009) suggested that their charge relies upon migration pathways created by igneous dykes that also induced halokinetic movement that created the traps and led to touch down of the supra-salt section on the Permian and older units.
Mapping of facies distributions and isochron thins therefore suggests that the Mid North Sea High Platform and Dogger Granite High remained elevated throughout the deposition of Tectonostratigraphic Unit B, with additional Jurassic uplift of the NE of the study area, related to the Central North Sea rift system, forming the Western Platform on the flank of the graben. The South Permian and Sole Pit Basin in the south, and the Forth Approaches and North Permian basins in the north, are the main depocentres for sediment at this time.

Base Cretaceous Unconformity-Mid Tertiary Unconformity
Directly overlying the BCU are the Lower Cretaceous Cromer Knoll and Upper Cretaceous Chalk succession. These units signify a move to more stable tectonic conditions. This package is locally modified by Zechstein salt movement which forms NW-SE-striking minibasins (Fig. 6). In the central study area, where salt is thin or absent, Tectonostratigraphic Unit C is fairly consistent in thickness at around 750-1000 ms TWT. Of note is the thinning in the NE along the flank of the Central Graben (Fig. 6). It is in this region that additional thinning occurred during Mid Cimmerian uplift and erosion. In the west of the study area, there is a dramatic thinning to zero thickness where the unit is subcropping the seabed due to Tertiary tilting and erosion (Figs 4 and 6).
Tectonostratigraphic Unit C can be subdivided into two units: (1) the Cretaceous, predominantly Upper Cretaceous chalk succession, with the Lower Cretaceous section being very thin across the MNSH (<200 ms); and (2) the Lower Paleogene clastics, which is topped by the Mid Tertiary Unconformity (MTU). By the early Cretaceous, the focus of rifting had switched to the Proto-Atlantic, and thermal subsidence began in the North Sea (Erratt et al. 1999). This was a relatively quiet time in the tectonic evolution of the area, with ongoing thermal and compaction-related subsidence with minor fault reactivation. The Lower Paleogene (Paleocene, Eocene and earliest Oligocene) section shows significant thinning over the Cygnus Field in the SE of the study area. No related faulting is observed in the post-salt but the inversion is represented by a broad anticline. This suggests that inversion of the Base Zechstein Cygnus structure, and therefore trap formation, occurred at this time. Given this timing of the inversion and the orientation of compression, it is tentatively assigned to far-field stresses related to the Pyrenean Orogeny (Parrish et al. 2018) and/or Alpine Orogeny (Ziegler 1983).

Mid Tertiary Unconformity-seabed
The MTU is gently dipping to the NE with only some minor modification by halokinesis. Overlying Tectonostratigraphic Unit D is absent over the west of the study area, thickening in the NE to c. 2000 ms TWT and forming a thickening wedge of prograding sediment sourced from the east (Figs 4 and 6). The MTU represents the regional tilting of the UK in response to the opening of the Atlantic Ocean (Guariguata-Rojas and Underhill 2017). Only a handful of wells in the region date formation tops in the Tertiary, and name the unconformity as 'Top Hordaland' or Early Eoceneearliest Oligocene. Therefore, the MTU is dated at c. 30 Ma at this location. Further east in the Dutch sector, the downlap surface is dated to the Miocene Unconformity (Verweij et al. 2018). It is therefore likely that this surface is highly diachronous.

Defining the Mid North Sea High
The newly acquired OGA_2015 regional seismic data allow for a revised evaluation of the structural evolution and facies distribution over the greater Mid North Sea High region of the Central North Sea (Fig. 16). This study identifies four tectonostratigraphic megasequences that each represent a significant tectonic reorganization of the Central North Sea. Tectonostratigraphic Unit A comprises the Devonian and Carboniferous. This study clearly demonstrates that the basement terrane exerts a strong control over the Devonian and Carboniferous depocentres. Detailed seismofacies mapping of the Devonian Kyle Limestone (Fig. 9) demonstrates that early emplacement of granite bodies in the east of the study area has created isolated buoyant basement blocks at the Dogger and Auk highs, much like the block and trough morphology observed onshore at the time. Therefore, during the Devonian and Carboniferous, the MNSH was a region of isolated highs separating a number of heavily faulted depocentres (Figs 7 and 16).
The Variscan Orogeny marked a time of uplift and erosion over the Central North Sea. The BPU shows erosional truncation of the underlying Tectonostratigraphic Unit A (Fig. 10), and a complex subcrop of Carboniferous and Devonian strata over isolated highs such as the Dogger High and the Mid North Sea Platform (Arsenikos et al. 2015). The limited distribution of the Permian Rotliegend Group over the BPU (Fig. 12) shows that following the Variscan Orogeny, the MNSH was a much more regionallyextensive feature. Facies mapping of the overlying Zechstein Group has shown carbonate-dominated deposition across the Mid North Sea High, and Dogger, Auk, Flora and Devil's Hole platforms, and indicates that these areas were relative highs compared to the adjacent salt basins of the North and South Permian basins and the Forth Approaches Basin (Figs 13 and 16).
The Triassic saw renewed extension and the development of the Dogger and North Dowsing fault zones in the south (Fig. 15). In the north, there is a complex interplay of Mesozoic unconformities developed in association with the Jurassic rifting of the Central North Sea. The MCU is tied to the thermal doming of the Central North Sea prior to the development of the trilete rift system (Underhill and Partington 1993). Continued rift development led to rift flank uplift in the NE along the edge of the Central Graben, which is identified as a NW-SE-orientated region where Jurassic strata is absent (Fig. 15b). Moving southwards, the MCU becomes conformable with the BCU. Therefore, there is a significant reconfiguration of the MNSH during the Mesozoic, with uplift focused in the NE, along the western flank of the Central Graben. We propose that the region should be named the Western Platform. Erosion has led to a complex subcrop of Triassic and Jurassic strata across the region (Fig. 15); however, burial curves suggest reduced rates of sediment accumulation throughout the Triassic and Jurassic (Fig. 16), and therefore the region remained a high throughout the development of Tectonostratigraphic Unit B.
Lower Cretaceous deposits are extremely thin over the study area. Upper Cretaceous Chalk deposition blankets the region, with the exception of the Western Platform of the Central Graben which shows a depositional thin (Figs 4 and 6). This indicates a switch to widespread post-rift thermal subsidence and basin fill. The Paleocene documents the beginning of a regional tilting of the UK with progradation from the west (Fig. 4). In the NW of the region, the highly reflective Balder package signifies the opening of the Atlantic Ocean, and the beginning of the demise of the MNSH. In the south, far-field stresses generate localized tectonic activity, and it is during this time that inversion is seen across the Cygnus structure to the south of the Dogger High.
Tectonostratigraphic Unit D is formed of a thickening wedge of prograding sediment sourced from the east. It is separated from Tectonostratigraphic Unit C by the MTU, a complex diachronous surface which was formed during the tilting of the study area down to the east. Uplift in the west has caused extensive erosion at the seabed, and a progressive subcropping of Mesozoic strata westwards (Fig. 4). This tilting led to a significant tectonic overprinting, and the disappearance of the MNSH and Western Platform as prominent features. Jones et al. (2002) proposed that the uplift is a result of magmatic underplating of the crust related to the interaction of Atlantic seafloor spreading and the Iceland Plume.
Others have suggested asthenosphere diapirism, which generated domal uplift related to the eastward advance of the plume towards Europe (Rohrman and van der Beek 1996). Finally, other authors attributed the uplift to crustal compression associated with plate boundary forces (Hillis et al. 2008). We note that the uplift is coincident with seafloor spreading switching off in the Labrador Sea and the onset of Pyrenean orogenic compression (Doré et al. 1999;Parrish et al. 2018).

Implications for petroleum prospectivity
The tectonic evolution of the MNSH and Western Platform region has important consequences for the hydrocarbon prospectivity of the region. Despite some promising indications of remaining hydrocarbon potential along the margins of the region (Fig. 2), the prospectivity has historically been downgraded compared to the adjacent Central Graben and Southern North Sea Gas Basin. Here, we discuss how the structural evolution of the region controls aspects of the petroleum play.
The Devonian Kyle Limestone is the stratigraphically oldest potential reservoir in the region. Mapping of seismofacies tied to well data shows that the Kyle Limestone is restricted to the east of the study area over the Dogger and Auk granite-cored highs (Fig. 9). This suggests that the emplacement of buoyant granite bodies exerted a strong control over reservoir distribution as early as the Devonian. Overlying the Kyle Limestone, the Devonian Old Red Sandstone shows poor reservoir potential due to diagenesis that has occurred during numerous phases of deformation.
The Carboniferous is absent from most wells in the north of the study area (Fig. 7). At this time, the gross depositional environment is interpreted to be a large southward-prograding delta system, fed by sediment eroded from the Caledonian mountains in the north (Doornenbal and Stevenson 2010;Monaghan et al. 2017). Within the Namurian to Visean Yoredale, fluvio-deltaic sandstones form an attractive and proven target (Booth et al. 2020). Within the underlying Visean section, the Scremerston fluvial sands are proven at Breagh, and the fluvial Fell Sandstone has also been considered as a high NTG clastic reservoir target (Cameron 1993). Mapping the extent of these reservoirs is extremely challenging given the faulted nature of the Carboniferous section, the poor pre-Zechstein seismic imaging and the highly cyclic nature of the Carboniferous deltas. Locally, distribution of the Carboniferous is altered where isolated granite-cored structural blocks form topographical highs (Fig. 7). These regions form attractive traps; however, sands deposited are likely to be poorer quality where they are locally sourced from isolated highs (due to lower sediment maturation and sorting) when compared to open delta-plain fluvial or shoreface deposits.
Throughout the Permian, the MNSH exerts a strong control on reservoir distribution. The MNSH becomes an east-west-trending regional feature separating the North and South Permian basins. Variscan uplift caused erosion and non-deposition over the MNSH, and deposition of the Rotliegend Group was restricted to the North and South Permian basins and the Forth Approaches Basin, where aeolian and lacustrine shoreface sands have accumulated (Fig. 12). Regional subsidence led to marine flooding across the entire region and the deposition of the Zechstein Group. Carbonates define the relative highs at the time, which can be accurately mapped using well penetrations and seismofacies (Fig. 13). The reservoir is proven at the Auk Field in the NE, and at Crosgan in the SW, with much reservoir potential remaining across the region, particularly across the west of the MNSH, where a large carbonate platform can be mapped (Patruno et al. 2017), and in the north, where the Devil's Hole carbonate platform remains untested.
The Triassic overlies the Permian Zechstein Group. There is limited reservoir potential, with the exception of the southern margin where the Dogger and North Dowsing fault zones provide local sediment input for the Bunter sandstones (Fig. 15). The modern distribution of the Lower Triassic is further controlled by Jurassic erosion of the MNSH, resulting in the MCU and the BCU, and leading to a number of regions where the Triassic is completely absent over the Western Platform in the east of the study area, the Mid North Sea Platform and the Devil's Hole High (Fig. 15). Later Tertiary uplift has removed the Triassic in the west of the region (Fig. 15).
No significant additional potential reservoir sections are identified over the MNSH, with the exception of the Tertiary. Early Tertiary deep-water sands form the reservoir at the Catcher Cluster in the north on the margin of the Central Graben (Fig. 2). However, these deep-water sands are not likely to extend outside the graben system and onto the Western Platform, and so have been excluded from the discussion. Additional potential reservoirs have been noted in the east of the region in the upper Tertiary prograding wedge of Tectonostratigraphic Unit D. These glacial and fluvial delta-top sands show excellent reservoir potential; however, shallow burial depths make them a challenging play to exploit. There have been a number of small discoveries at this stratigraphic level made in the Dutch North Sea which have been producing since 2007 (Verweij et al. 2018).

Trap and seal
The nature of trapping mechanisms across the MNSH varies per play, and is strongly controlled by it's structural evolution and facies distributions. Carbonate reservoirs (Devonian Kyle Limestone, Permian Zechstein Group) rely on some stratigraphic component to trapping. Clastic plays are more variable, with pre-Zechstein plays (Carboniferous Namurian and Visean) generally exhibiting threeway structural traps within faulted blocks. The plays rely on Base Zechstein cap rocks; however, past drilling activity is skewed to identifying these closures, and intraformational seals remain poorly understood (Besly 2018). Post-Zechstein plays have variable trapping mechanisms. Triassic Bunter fields are generally simple four-way salt-cored anticlinal structures. Although not discussed in detail herein, Upper Jurassic and Tertiary fields along the north of the study area are stratigraphically trapped within deep-water turbidite deposits.
The regional tilting of the area has important implications for hydrocarbon remigration and trap formation. Simple back-stripping of the late Tertiary to reconstruct the margin pre-tilt has been completed (by removing Tectonostratigraphic Unit D overburden) (Fig. 17). Using a key regional seal, the Base Zechstein surface, the effects of the tilt are clearly demonstrated. With the removal of the thickening sediment wedge in the east of the study area, the Base Zechstein surface shows a distinct high in the NE. This tectonic tilting has important implications for the maturation of source rocks in the region. It is also likely to have promoted remigration of hydrocarbons from deep traps in the east of the study area updip towards the west. Uplift and erosion in the west has resulted in strata subcropping the seabed (Fig. 4), and is likely to have meant the loss of hydrocarbons in this region. Further work is required to accurately conduct a regional back-stripping that incorporates compaction trends.

Source rocks and charge
Source distribution, generation and migration are key risks when exploring the MNSH. There are two proven petroleum systems that charge fields along the margins of the MNSH. First, in the north and NE, fields are oil charged by Kimmeridge-sourced marine mudstones. Deposition was focused within the axis of the Central Graben where maximum Kimmeridge Clay thicknesses reach c. 1000 ft (Fraser et al. 2003). In the footwall to the main bounding faults of the rift, the Upper Jurassic rapidly decreases in thickness. A number of wells in this study record Upper Jurassic sediments (including Kimmeridge Clay source rock) but thicknesses rarely exceed 350 ft for the entire Upper Jurassic section, thus restricting its source potential over the MNSH. In addition, the construction of burial curves has been used to examine the magnitude of uplift events using predicted sedimentation rates (Fig. 16). The burial curve for well 38/16-1 illustrates that the MNSH remained a region of limited subsidence throughout the Mesozoic and Cenozoic compared to adjacent basins (wells 43/06-1 and 39/02-4). The Kimmeridge Clay source rock reaches depths of over 5000 m within the axis of the Central Graben (Day et al. 1981). Therefore, source rocks on the MNSH will not have reached the oil-maturation window historically. Charge from the Kimmeridge Clay, therefore, requires long-distance migration from the source kitchen within the Central Graben where this prolific source rock has been actively generating since reaching sufficient burial depths in the Tertiary (Cornford 1998). Bounding faults do allow for the uplift of older strata above the source rock, and establish a potential migration route. In reality, however, the complex nature of these boundingfault complexes leads to arduous migration routes and possible migration shadows. This is further complicated by the remigration of oil during the Mid Tertiary tilting event (Fig. 17), which provides opportunity for Jurassic oils to move westwards. This remigration into highs across the Western Platform (e.g. at Devil's Hole) is quite possible but is extremely challenging to de-risk. Further work is therefore required to assess the charge story along the Western Platform.
The second MNSH petroleum system of interest is the Carboniferous-sourced gas system of the Southern North Sea Gas Basin. Historically, the Upper Carboniferous Westphalian coal measures have been deemed the main source rock to the plays of the Southern North Sea. Over the MNSH, however, the Westphalian is largely absent (Fig. 7). Recent publications have demonstrated the potential for a second source rock within the Carboniferous at the Scremerston coal level along the southern margin of the study area (Besly 2018). The Breagh Field (and Crosgan unsanctioned discovery) are outliers to the main Carboniferous play fairway. Basin modelling over the Breagh discovery shows that the Scremerston coal measures could be a viable source for the accumulation, and therefore opens up a much wider zone of prospectivity over the southern margin of the MNSH (Monaghan et al. 2017;Grant et al. 2020).
An additional source rock, and important indicator for burial, is the Permian Zechstein Kupferschiefer. Shows are noted in the Zechstein dolomites in the west, in the Forth Approaches Basin, in Quad 41 and in Quad 42. The Permian Zechstein Group, therefore, contains all the components of a petroleum play: source, reservoir (dolomites) and seal (halites and anhydrites) (Patruno et al. 2017). However, the Kupferschiefer rarely exceeds 2 m in thickness, therefore limiting the source-rock's potential to generate economic volumes. Finally, the potential for biogenic shallow gas accumulations in the region should be noted. A Tertiary biogenic gas play is proven to the east of this study, in the Dutch North Sea, where a number of fields are under development with gas in place (GIIP) estimates for the play ranging from 1.2 to 4.1 tcf (Verweij et al. 2018). Well 39/16-1 encountered one such biogenic gas accumulation on the eastern flank of the Dogger High. The well targeted north-south-orientated shoreface sands in front of the westwardprograding delta. Although the end of well report records that Pliocene sands were thinner than expected, bright spots observed in the seismic were confirmed to be gas-bearing intervals. Elsewhere, there are additional bright spots and evidence for shallow gas; however, these are not likely to show the volumes seen in accumulations across the Dutch play fairway given their distal location from the sediment source in the east.

Conclusions
This study examines the newly acquired regional 2D seismic dataset over the Mid North Sea High (MNSH) funded by the UK's Oil and Gas Authority as part of their Frontier Basins Research Programme. It is the first study to examine the MNSH stratigraphy from the Devonian up to the present day.
Seismic mapping identifies four key tectonostratigraphic units that correlate to plate-scale tectonics. Each plate cycle exerts a strong control over the MNSH region, which shows an evolving nature and spatial extent. We demonstrate that during Tectonostratigraphic Unit Athe Devonian and Carboniferousthe study area was largely a depocentre for sediments being shed from the Caledonian mountains in the north. Seismic facies mapping shows that granite-cored blocks formed localized highs across the region. Following the Variscan Orogeny, the MNSH was a regionally-extensive feature, orientated west-east and separating the North and South Permian basins. A connecting seaway is mapped during the Zechstein that separates the MNSH platform from the Dogger-Auk Platform. The region remained a relative high throughout the early Mesozoic; however, the focus of uplift moved to the flank of the Central North Sea trilete rift in the NE, forming the Western Platform. The Mid Tertiary saw a complete tectonic reorganization of the region and the demise of the MNSH. Regional tilting of the UK related to the opening of the Atlantic Ocean led to uplift in the west of the study area and the progradation of sediments from the east. This evolution of the region has important implications for hydrocarbon prospectivity. For example, during the Permian, the clastic-dominated Rotliegend system saw erosion and non-deposition over much of the MNSH, and the play is restricted to the adjacent North and South Permian basins. This is in contrast to the Upper Permian Zechstein play which sees carbonate reservoir facies deposited across the MNSH, with non-reservoir facies within the adjacent basins. It can therefore be concluded that the evolution of the MNSH exerts a strong control on the distribution of play elements. Carbonate reservoir distribution is restricted to the MNSH, although it is susceptible to erosion. Clastic reservoir deposition is strongly controlled by uplift and erosion of the MNSH, providing sediment influx to adjacent depocentres. Multiple uplift events have controlled the distribution of source rocks and their maturation history. Finally, the major tectonic reorganization in the Mid Tertiary has led to the remigration of hydrocarbons to the west, into newly-formed traps or to the seabed. Basin modelling is required to fully understand the consequences of this uplift event for the petroleum systems.