scholarly journals The composition of groundwater in Palaeogene and older formations in the Netherlands. A synthesis

2016 ◽  
Vol 95 (3) ◽  
pp. 349-372 ◽  
Author(s):  
Jasper Griffioen ◽  
Hanneke Verweij ◽  
Roelof Stuurman

AbstractThere is increasing interest in the exploitation of the deep subsurface of the Netherlands for purposes other than conventional oil and gas production, such as geothermal energy, shale gas exploitation and the disposal of radioactive waste, so for technical and environmental reasons it is important to understand the composition of the deep groundwater. A synthesis has been made of almost 200 existing groundwater analyses for the Oligocene and older formations in the Netherlands. Three groundwater categories are considered: (1) deep oil and gas reservoirs, (2) deep, buried and confined aquifers and (3) shallower, semi-confined aquifers with or without outcrop areas nearby. No distinct water types are found but a continuous series, with Cl ranging from around 10,000 to 200,000 mg l−1: the highest concentrations are found in the reservoirs and the lowest in the semi-confined aquifers. The most saline brines are found in the northern onshore area and adjacent offshore area, where Permian and Triassic rock salt also occurs regionally in the subsurface. The groundwater is usually pH-neutral, saturated in carbonates and anaerobic. Anhydrite saturation occurs when the Cl concentration exceeds 100,000 mg l−1, and halite saturation occurs at Cl concentrations close to 200,000 mg l−1. Few tracer analyses have been done for δ2H–H2O, δ18O–H2O, δ37Cl, Br, Li and B, which makes a rigorous palaeohydrological interpretation impossible. Lithium and B may be controlled by water–rock interaction which makes them less suitable as tracers. Some of the analyses suggest that dissolution of rock salt plays a role in determining the salinity of groundwater for some deep wells in the southern part of the Netherlands, whereas other analyses suggest that evaporated seawater influences the salinity in the associated wells. Cation-exchange patterns and alkalinity to Ca ratios indicate that groundwater in the deep, buried and shallow, semi-confined aquifers is usually freshening. Six14C analyses of samples from the buried aquifers indicate an apparent age of at least 20,000 years. Six δ37Cl analyses of formation waters from reservoirs in South-Holland suggest diffusion of Cl from a brine towards fresher water, and the associated K and also Li concentrations further suggest that these brines are related to rock salt dissolution and are not the residue of evaporated seawater. The high Ca concentrations are enigmatic for the hypersaline formation waters in the reservoirs. A limited series of samples had been analysed for various trace elements. The median concentrations are similar to the seawater and Dutch background concentration limits for shallow groundwater, but maximum concentrations can be up to three orders of magnitude higher. In conclusion, the data synthesis shows that the composition of groundwater in reservoirs and aquifers of Palaeogene and older age varies strongly in salinity at the national scale. Presence of evaporite deposits and diffusive transport seem to play important roles in controlling the salinity. Many existing analyses have no or only a few tracer analyses, that even vary among the samples. A complete suite of analyses is needed to elucidate the hydrogeological and geochemical processes that control the groundwater composition.

2007 ◽  
Vol 61 (1) ◽  
pp. 43-51 ◽  
Author(s):  
G. Huppes ◽  
M.D. Davidson ◽  
J. Kuyper ◽  
L. van Oers ◽  
H.A. Udo de Haes ◽  
...  

2021 ◽  
Author(s):  
Alexey Yudin ◽  
Abdul Muqtadir Khan ◽  
Rostislav Romanovskii ◽  
Alexey Alekseev ◽  
Dmitry Abdrazakov

Abstract The oilfield industry is rapidly changing towards reduced CO2 emissions and sustainability. Although hydrocarbons are expected to remain the leading source for global energy, costs to produce them may become prohibitive unless new breakthrough in technology is established. Fortunately, the digital revolution in the IT industry continues at an accelerating pace. A digital stimulation approach for tight formations is presented, using the achievements of one industry to solve the challenges of another. The fracture hydrodynamics and in-situ kinetics model is incorporated in the advanced simulator together with the detailed multiphysics models based on acid systems digitization, including rheology and fluid- carbonate interactions data obtained from the laboratory experiments. Digitization of fluid-rock interaction and fluid leakoff was performed using a coreflooding setup that allowed pumping concentrated acids in core samples at high-pressure/high-temperature (HP/HT) conditions. Varying the testing parameters across a broad range allowed refining the model coefficients in the simulator to obtain high accuracy in the predicted results. The digital slot concept was used to validate physical models in an iterative experimental approach. The software proved efficient at providing validation of multiphysics models used together with advanced slurry transport in the simulator. The fine computational grid allowed accurate predictions of the fracture geometry, etched width, and channel conductivity, resulting in realistic well productivity anticipations. Since multiple fluid systems of the acid stimulation portfolio were digitized and incorporated into the simulator, it was possible to optimize complex acid fracturing designs in the real field operations that included retarded single-phase and multiphase acid systems, self-diverting viscoelastic acids, and fiber- based diverting systems. Several case studies from multiple areas and reservoirs from Caspian and Middle East areas have demonstrated extremely positive oil and gas production results with reduced acid volumes with the digital stimulation workflow compared to conventionally stimulated offset wells. The digital stimulation workflow brings a new approach to acid fracturing optimization based on an integrated cycle in which high-resolution data from several sources are processed by powerful computing capacities. Starting from digitizing acid reactions with the core samples, through digitized rheology and particle transport in multiphysics models, an advanced numerical simulator tailors an optimum design from a number of acid system options, pumping rates, additive concentrations, and stage volumes to achieve best geometry of etched channels inside a fracture.


Author(s):  
Николай Панасенко ◽  
Nikolay Panasenko ◽  
Алексей Синельщиков ◽  
Aleksey Sinel'schikov ◽  
Павел Яковлев ◽  
...  

The article touches upon the problem of technogenic risks arising in the course of building and operating oil and gas complexes in the Caspian Sea taking into account the adoption of the Con-vention on the legal status of the Caspian Sea and regulation of the territorial division of the Caspian Sea. Technological risks are presented from the position of safety of industrial facilities in the offshore area and in the coastal zone, the impact of these facilities on the ecology of the Caspian is considered. The risk analysis was carried out taking into account world experience, as well as incidents that occurred at the offshore oil and gas production facilities in the Caspian Sea. There has been presented the layout of oil and gas fields at the bottom of the Caspian Sea and the division of the bottom based on adopting the Convention. A general description of the Caspian Sea has been given; unique features of the Caspian and the most unexplored seismic effects have been stated. It has been recommended to conduct a comprehensive assessment of the state of the seabed according to seismological, mud, volcanic and engineering-geological conditions; to develop measures for preventing and reducing the damage from hazardous natural processes and exploitation of oil and gas fields; to forecast the fluctuations of the Caspian Sea level, taking into account today’s economic activity; to study the natural and technogenic factors determining the environmental safety of the Caspian Sea; to monitor seismic phenomena, crustal movement in zones of tectonic faults at the sea bottom, etc. The speed and direction of wind currents in the Caspian Sea have been analyzed. The maps of mud volcanoes location in the Caspian basin (located on land, hidden and identified by seismic, geological, geophysical and geochemical methods, etc.) are illustrated. Conclusions are made about the high risks for developing hydrocarbon deposits in the Caspian Sea basin. There is the need to take into account environmental requirements and standards, to use modern technologies, to prevent incidents at offshore oil and gas production facilities.


2010 ◽  
Vol 89 (2) ◽  
pp. 91-107 ◽  
Author(s):  
R. Herber ◽  
J. de Jager

AbstractThe impact of oil and, in particular, gas fields discovered in the Dutch subsurface has been very significant. However, 50 years after the discovery of the giant Groningen gas field the Netherlands has become very mature for exploration of oil and gas, and the gas volume left to be discovered in conventional traps is insignificant compared to what has been found already. The total portfolio of conventional prospects held by the industry contains several 100s of billions of cubic metres (bcm), as reported by the Ministry of Economic Affairs, but many of these prospects are unattractive to drill because of their small size or other geologically unfavourable aspects. Hence, for planning purposes of future national gas production the risk should be taken into account that the size of the conventional portfolio is overestimated. The major E&P companies have reduced their exploration efforts and the number of wells drilled as well as the size and total volume of discovered gas reserves has seen a steady decline over the last 10 years. Some surprises may still be in store and can occasionally add a welcome addition of gas. But the follow-up potential of new play and trapping concepts has been disappointing for many years now, and it is concluded that this is unlikely to be different in the future. Remaining conventional discoveries will mainly be in small near-field targets that as a result of technological advances made in the last few decades can be drilled with high confidence, despite their small volumes.This leaves the so-called unconventional gas (UG) resources for a real and significant increase in the exploration potential of the Netherlands. UG resources occur outside conventional structural or stratigraphic traps in tight (low permeability) rocks and are of regional or sub-regional extent, without well-defined hydrocarbon-water contacts. The potential for Basin Centred Gas, Shale Gas and Coal Bed Methane is reviewed. As, according to present-day technology, development of UG requires very dense drilling at low costs with well spacing of a few 100s of metres, only the onshore potential can be commercial, even in the longer term.Recent geological uplift is a characteristic for all North American commercial UG developments. Uplift helps bringing the resources close to the surface and facilitates development of fractures, which are essential for achieving commercial flow rates. This significantly reduces the area where commercial UG resources may occur in the Netherlands. In addition, sweet spots, where commercial flow rates and ultimate recovery per well can be achieved, represent only a fraction of the total ‘play area’. The UG plays in the Dutch subsurface remain to be proven, and there is still a significant technical risk associated with these plays, on top of the commercial risk. Therefore, despite potentially enormous in-place gas volumes in these unconventional plays, recoverable volumes are much less. If UG resources can be proven and are commercially developable, their cumulative volume potential is estimated by us in the order of a few tens to one or two hundreds bcm of recoverable gas at best. Finally, as UG resources produce at very low rates and require large numbers of wells to develop, the environmental impact in a densely populated country like the Netherlands is enormous, and needs to be seriously considered, already in the exploration phase.In a mature area like the Netherlands, industry focus should be on technology development to reduce risk, increase recovery, reduce cost and minimize surface impact. Cooperation between Operators to build multi-well campaigns is therefore strongly recommended to reduce mobilisation cost. In addition, government incentives should be targeted at the development phase, in order to increase economic attractiveness for difficult reservoirs, both conventional and unconventional. In this way State and industry will both be able to maximize their returns on the remaining potential for gas and oil in the next two to three decades.


Author(s):  
Mikhail Nikolaevich Pokusaev ◽  
Nikolay Nikitovich Panasenko ◽  
Alexey Vladimirovich Sinelshchikov ◽  
Pavel Victorovich Yakovlev

The article presents a detailed analysis of the technogenic risks in building and operating oil and gas complexes in the offshore area of the Caspian Sea and actualizes the problem of the Caspian environmental crisis, the possible measures for preventing and minimizing the negative consequences from the extensive offshore oil and gas production for the ecosystem being considered. The geothermal regime of the ground of the Caspian Sea has been analyzed in respect of the deep-earth processes. The bottom of the Caspian Sea is rather varied, hence, the risks for constructing facilities in the area under development are possible. The surface, underwater and island mud volcanoes formed by the large longitudinal and transverse tectonic disturbances pose a threat to oil production and transportation facilities. The tectonic processes of the bottom of the Caspian Sea are studied in detail. It has been stated that the global geodynamic processes are taking place in the earth's crust of the region affecting the natural environment of the Caspian Sea, which will inevitably affect the industrial objects on the shelf. The Caspian Sea ground is divided into two parts in terms of seismic activity: the seismically inactive northern part (the Scythian-Turanian platform and the East European platform) and the southern part (alpine orogenic-folded belt) that is currently seismically active. The diagrams of possible earthquakes and seismic activity in the bottom area of the Caspian Sea are presented. Since the mechanism of the developing seismic activity caused by volcanoes is not fully examined, there has been substantiated the need to prognose precisely the location of hazardous zones and joints in connection with the development of the oil and gas industry. The tectonic and geological frame of the Caspian region has been illustrated; the regional fractures that influence the formation of biosphere zones and the largest tectonic joints that affect natural and man-made processes are noted. Particular attention is paid to the risks of the hydrogen sulfide pollution of the Caspian Sea. Conclusions are drawn about the prospects for the development of the Caspian, which is rich in oil and gas reserves; on the need to ensure safety and reduce losses in the ecological system of the Caspian Sea.


Geofluids ◽  
2021 ◽  
Vol 2021 ◽  
pp. 1-12
Author(s):  
Hany Gamal ◽  
Saad Al-Afnan ◽  
Salaheldin Elkatatny ◽  
Mohamed Bahgat

Precipitation of the scale in the oil and gas reservoirs, surface and subsurface equipment, and processing and production facilities is a big problem as it affects petroleum production. The scale precipitations decrease the oil and gas production and cause economical loss. Solving this issue requires an engineering investigation to provide a safe, efficient, and economic solution. Consequently, this study proposed a developed dissolver for barium sulfate scales, where two field-scale samples were collected from different locations. The compositional analysis for scale samples showed that sample 1 is 100% barium sulfate where sample 2 has 97.75% barium sulfate and 2.25% of quartz. The composition of the developed dissolver has diethylenetriamine pentaacetic acid (DTPA) as a chelating agent, oxalic acid, and tannic acids as an activator, nonionic surfactant, and water as the base fluid. The new dissolver was investigated with extensive lab tests to determine the dissolution efficiency, precipitation tendency for the dissolved scale solids, corrosion rate, and fluid-rock interaction. The obtained successful results indicated that the developed dissolver had a dissolution efficiency for two real barium scale samples as the results showed 76.9 and 71.2% at 35°C and 91.3 and 78.4% at 90°C for samples 1 and 2, respectively. The new solution has a great performance compared with common scale dissolvers in the oil field as hydrochloric acid, ethylenediaminetetraacetic acid, and diethylenetriamine pentaacetic acid. The developed dissolver showed a very low precipitation tendency for the scale dissolved solids (1.9 and 3.2% for samples 1 and 2, respectively) under 35°C for 24 hours. Without any additives of corrosion inhibitors, the corrosion rate was 0.001835 g/cm2 at 6.9 MPa and 100°C for 6 hours. Injecting the developed dissolver for damaged sandstone core sample with barite mud by flooding test showed a return permeability of 115%.


Author(s):  
Uche Callistus Anyanwu ◽  
Gbenga F Oluyemi

Scale inhibitors are deployed as preventive and rejuvenation operation in oil and gas industry when production operations are under threat or menace of scale blockage. The application of scale inhibitors is carried out through a method known as squeezing. In general, the squeeze process is governed by inhibitor-rock interaction which is described by adsorption/desorption isotherm. Most reservoirs produce loose sand grains or fine sand which float and flow within the pore spaces along with the squeezed scale inhibitors. Hypothetical reports have shown that not all scale inhibitors pumped into the formation adsorb onto the formation rock. A number of factors (irreversible adsorption, pH changes, competing ions, concentration and temperature) have been considered to affect the adsorption and return profile of these scale inhibitors. This review work examines the performances of most common scale inhibitors used in the oil and gas production activities, theoretical application in reservoirs and how loose fine sand grains affect the adsorption and desorption characteristics of squeezed scale inhibitors. Additionally, presented were overviews of previous reports on fine sand production and migration of fine sands through formation pores in reservoirs.


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