Impact of hydrogen solubility on depleted gas field's caprock: an application for underground hydrogen storage

2021 ◽  
Vol 61 (2) ◽  
pp. 366
Author(s):  
Mohammad Bahar ◽  
Reza Rezaee
Keyword(s):  
Hydrogen Storage ◽  
Organic Material ◽  
High Pressures ◽  
Significant Risk ◽  
Gas Production ◽  
Threshold Pressure ◽  
Gas Field ◽  
Wide Range ◽  
Gas Fields ◽  
Underground Hydrogen Storage

Depleted gas fields are considered a low-risk location for underground hydrogen storage purposes to balance seasonal fluctuations in hydrogen supply and demand. The objective of this study was to identify any significant risk of hydrogen leakages stored in depleted gas fields. The capability of the storage area in terms of sealing efficiency varies with parameters such as rate of diffusion, solubility, thickness and capillary threshold pressure of the caprock. The most common caprock are shales, which contain organic material. The solubility of hydrogen into organic material could change the petrophysical properties of the rock, such as porosity and permeability. Any changes in these petrophysical characteristics can reduce the capillary threshold pressure thus reducing the caprock efficiency for the safe storage of hydrogen. There is about 20% of the remaining gas volume in the depleted gas field, which helps to prevent brine from entering the production streamlines and maintain reservoir pressure. The characteristic data of hydrogen at different high pressures and temperatures have been evaluated and imported into the simple finite element model using the Python programming language. Most of the parameters that influence reducing the strength of the caprock are identified. Crucial parameters are the rate of diffusion, the solubility of hydrogen in kerogen, geomechanical deformation, threshold capillary pressure, long period of injection and withdrawing of hydrogen. The model shows that the native gas production with hydrogen is low due to significant density variation and mobility ratio between methane and hydrogen. Finally, a wide range of parameters and reservoir conditions has been considered for minimising the potential risks of possible leakages.

scholarly journals Hydrogeochemical Modeling to Identify Potential Risks of Underground Hydrogen Storage in Depleted Gas Fields

2018 ◽  
Vol 8 (11) ◽  
pp. 2282 ◽  
Author(s):  
Christina Hemme ◽  
Wolfgang van Berk
Keyword(s):  
Hydrogen Storage ◽  
Transport Model ◽  
Reservoir Rock ◽  
Redox Equilibrium ◽  
Hydrogeochemical Modeling ◽  
Wide Range ◽  
Mass Transport Model ◽  
Cap Rock ◽  
Gas Fields ◽  
Underground Hydrogen Storage

Underground hydrogen storage is a potential way to balance seasonal fluctuations in energy production from renewable energies. The risks of hydrogen storage in depleted gas fields include the conversion of hydrogen to CH4(g) and H2S(g) due to microbial activity, gas–water–rock interactions in the reservoir and cap rock, which are connected with porosity changes, and the loss of aqueous hydrogen by diffusion through the cap rock brine. These risks lead to loss of hydrogen and thus to a loss of energy. A hydrogeochemical modeling approach is developed to analyze these risks and to understand the basic hydrogeochemical mechanisms of hydrogen storage over storage times at the reservoir scale. The one-dimensional diffusive mass transport model is based on equilibrium reactions for gas–water–rock interactions and kinetic reactions for sulfate reduction and methanogenesis. The modeling code is PHREEQC (pH-REdox-EQuilibrium written in the C programming language). The parameters that influence the hydrogen loss are identified. Crucial parameters are the amount of available electron acceptors, the storage time, and the kinetic rate constants. Hydrogen storage causes a slight decrease in porosity of the reservoir rock. Loss of aqueous hydrogen by diffusion is minimal. A wide range of conditions for optimized hydrogen storage in depleted gas fields is identified.

scholarly journals Gas transport at dense phase conditions for the development of deepwater fields in the Colombian Caribbean sea

2020 ◽  
Vol 10 (1) ◽  
pp. 17-32
Author(s):  
Manuel Cabarcas Simancas ◽  
Angélica María Rada Santiago ◽  
Brandon Humberto Vargas Vera
Keyword(s):  
High Pressures ◽  
Gas Transport ◽  
Cost Savings ◽  
Caribbean Sea ◽  
Gas Production ◽  
Dense Phase ◽  
Reservoir Properties ◽  
Hydraulic Simulation ◽  
Target Field ◽  
Gas Fields

The purpose of this article is to set out the benefits of using the dense phase gas transport in future projects in the Caribbean Sea and to verify that when operating pipelines at high pressures, more mass per unit of volume is transported, and liquid formation risks are mitigated in hostile environments and low temperatures.This study contains key data about gas production fields in deep and ultra-deep waters around the world, which serve as a basis for research and provide characteristics for each development to be contrasted with the subsea architecture proposed in this paper. Additionally, analogies are established between the target field (Gorgón-1, Kronos-1 and Purple Angel-1) and other offshore gas fields that have similar reservoir properties. Using geographic information systems, the layout of a gas pipeline and a subsea field architecture that starts in the new gas province is proposed.Finally, using a hydraulic simulation tool, the gas transport performance in dense phase is analyzed and compared with the conventional way of transporting gas by underwater pipelines, achieving up to 20 % in cost savings when dense phase is applied.

Enhanced gas recovery, CO2 storage and implications from the CO2CRC Otway Project

2011 ◽  
Vol 51 (2) ◽  
pp. 684
Author(s):  
Peter Cook ◽  
Yildiray Cinar ◽  
Guy Allinson ◽  
Charles Jenkins ◽  
Sandeep Sharma ◽  
...  
Keyword(s):  
Pore Space ◽  
Co2 Storage ◽  
Co2 Concentration ◽  
Gas Production ◽  
Anthropogenic Sources ◽  
Future Price ◽  
Gas Field ◽  
Enhanced Gas Recovery ◽  
Gas Recovery ◽  
Gas Fields

Successful completion of the first stage of the CO2CRC Otway Project demonstrated safe and effective CO2 storage in the Naylor depleted gas field and confirmed our ability to model and monitor subsurface behaviour of CO2. It also provided information of potential relevance to CO2 enhanced gas recovery (EGR) and to opportunities for CO2 storage in depleted gas fields. Given the high CO2 concentration of many gas fields in the region, it is important to consider opportunities for integrating gas production, CO2 storage in depleted gas fields, and CO2-EGR optimisation within a production schedule. The use of CO2-EGR may provide benefits through the recovery of additional gas resources and a financial offset to the cost of geological storage of CO2 from gas processing or other anthropogenic sources, given a future price on carbon. Globally, proven conventional gas reserves are 185 trillion m3 (BP Statistical Review, 2009). Using these figures and Otway results, a replacement efficiency of 60 % (% of pore space available for CO2 storage following gas production) indicates a global potential storage capacity—in already depleted plus reserves—of approximately 750 Gigatonnes of CO2. While much of this may not be accessible for technical or economic reasons, it is equivalent to more than 60 years of total global stationary emissions. This suggests that not only gas—as a lower carbon fuel—but also depleted gas fields, have a major role to play in decreasing CO2 emissions worldwide.

Feasibility analysis for time-lapse seafloor gravity monitoring of producing gas fields in the Northern Carnarvon Basin, offshore Australia

Geophysics ◽  
2015 ◽  
Vol 80 (2) ◽  
pp. WA149-WA160 ◽  
Author(s):  
Wendy May Young ◽  
David Lumley
Keyword(s):  
Pure Water ◽  
Time Lapse ◽  
Gas Production ◽  
Gas Reservoirs ◽  
Flow Monitoring ◽  
Wide Range ◽  
Small Density ◽  
Northern Carnarvon Basin ◽  
Gas Fields ◽  
Carnarvon Basin

Highly accurate seafloor gravity data can detect small density changes in subsurface hydrocarbon reservoirs by precisely repositioning the gravimeters on the seafloor. In producing gas fields, these small density changes are primarily caused by production-related changes to the pressure and gas/fluid saturations in the reservoir pore space. Knowledge of the pressure and saturation changes is vital to optimize the gas recovery, especially in offshore environments in which wells are expensive and sparse. We assessed the feasibility of time-lapse seafloor gravity monitoring for the giant gas fields in Australia’s premier hydrocarbon province, the Northern Carnarvon Basin. We determined that gravity monitoring is more feasible for reservoirs with a large areal extent and/or shallow burial depths, with high porosities and high net-to-gross sand ratios. Forward modeling of the gravity responses using simple equivalent geometry shapes and full 3D complex heterogeneous models predicted that density changes in several of these producing gas reservoirs will result in readily detectable gravity signals ([Formula: see text]) within just a year or so of gas production. In a pure water-drive production regime, this gravity response equated to a fieldwide change in the gas-water contact height of approximately 2–3 m, or in a pure depletion-drive regime, a pressure decline equated to approximately 3–4 MPa (435–580 psi). We assessed the feasibility of time-lapse seafloor gravity monitoring for producing gas reservoirs that is flexible and practical, and it may be useful for a wide range of subsurface fluid-flow monitoring applications.

scholarly journals Media corrosiveness and materials resistance at presence of aggressive carbon dioxide

2021 ◽  
Vol 64 (11) ◽  
pp. 793-801
Author(s):  
R. R. Kantyukov ◽  
D. N. Zapevalov ◽  
R. K. Vagapov
Keyword(s):  
Carbon Dioxide ◽  
Oil And Gas ◽  
Gas Production ◽  
Carbon Dioxide Corrosion ◽  
Gas Field ◽  
Hydrocarbon Production ◽  
Field Development ◽  
Wide Range ◽  
Corrosive Effect ◽  
Equipment And Pipelines

At the present stage of gas field development, the products of many mining facilities have increased content of corrosive CO2 . The corrosive effect of CO2 on steel equipment and pipelines is determined by the conditions of its use. CO2 has a potentially wide range of usage at oil and gas facilities for solving technological problems (during production, transportation, storage, etc.). Simulation tests and analysis were carried out to assess the corrosion effect of CO2 on typical steels (carbon, low-alloy and alloyed) used at field facilities. Gas production facilities demonstrate several corrosion formation zones: lower part of the pipe (when moisture accumulates) and top of the pipe (in case of moisture condensation). The authors have analyzed the main factors influencing the intensity of carbon dioxide corrosion processes at hydrocarbon production with CO2 , its storage and use for various technological purposes. The main mechanism for development of carbon dioxide corrosion is presence/condensation of moisture, which triggers the corrosion process, including the formation of local defects (pits, etc.). X-ray diffraction was used for the analysis of corrosion products formed on the steel surface, which can have different protective characteristics depending on the phase state (amorphous or crystalline).

Pluto gas field: Successful placement of an infill well based on 4D seismic monitoring

2020 ◽  
Vol 39 (7) ◽  
pp. 464-470
Author(s):  
Benjamin Peterson ◽  
André Gerhardt
Keyword(s):  
Feasibility Studies ◽  
Gas Production ◽  
Seismic Survey ◽  
Gas Field ◽  
Water Contact ◽  
North West ◽  
Water Ingress ◽  
Gas Fields ◽  
4D Seismic ◽  
Gas Expansion

Seismic 4D monitoring technology has not been as widely employed for gas fields as it has for oil. Many gas fields rely on depletion drive, which has a 4D seismic response that can be uncertain and difficult to predict. On the other hand, aquifer-supported gas fields with measurable water ingress have a reasonable chance of success in terms of generating an interpretable 4D amplitude signal. Pluto gas field in the North West Shelf of Australia falls into this category. Following discovery in 2005, Pluto was appraised by five wells, which found a consistent gas gradient and gas-water contact across the entire field and its various reservoirs. Gas production began in 2012. Time-lapse seismic feasibility studies concluded that gas-saturation changes could be observed with a monitor seismic survey acquired three to four years after first gas. The Pluto 4D Monitor 1 survey was acquired at the start of 2016 and revealed both hardening and softening anomalies. Hardening is interpreted as water ingress (expected) and softening as gas expansion (unexpected). The Pluto 4D results provided important insights into reservoir connectivity and discontinuities. Large hardening anomalies at the TR27 (lower) level can be clearly seen in the data, showing avenues for water ingress. More importantly, a large softening anomaly below the original gas-water contact in the TR29 (upper) reservoir is interpreted to be gas expansion into the aquifer created by a U-tubing effect around a possible barrier in the gas leg. This suggests that the entire TR29 reservoir may not be accessed by the producing PLA04 well. Based on this 4D interpretation, the PLA07 well was drilled and completed in 2019 to produce the TR29 gas updip from the gas expansion anomaly and to increase Pluto field recovery.

scholarly journals Tight gas production model considering TPG as a function of pore pressure, permeability and water saturation

2020 ◽  
Vol 17 (5) ◽  
pp. 1356-1369
Author(s):  
Atif Zafar ◽  
Yu-Liang Su ◽  
Lei Li ◽  
Jin-Gang Fu ◽  
Asif Mehmood ◽  
...  
Keyword(s):  
Pressure Gradient ◽  
Pore Pressure ◽  
Water Saturation ◽  
Great Influence ◽  
Gas Production ◽  
Production Model ◽  
Threshold Pressure ◽  
Tight Gas ◽  
Gas Field ◽  
Threshold Pressure Gradient

Abstract Threshold pressure gradient has great importance in efficient tight gas field development as well as for research and laboratory experiments. This experimental study is carried out to investigate the threshold pressure gradient in detail. Experiments are carried out with and without back pressure so that the effect of pore pressure on threshold pressure gradient may be observed. The trend of increasing or decreasing the threshold pressure gradient is totally opposite in the cases of considering and not considering the pore pressure. The results demonstrate that the pore pressure of tight gas reservoirs has great influence on threshold pressure gradient. The effects of other parameters like permeability and water saturation, in the presence of pore pressure, on threshold pressure gradient are also examined which show that the threshold pressure gradient increases with either a decrease in permeability or an increase in water saturation. Two new correlations of threshold pressure gradient on the basis of pore pressure and permeability, and pore pressure and water saturation, are also introduced. Based on these equations, new models for tight gas production are proposed. The gas slip correction factor is also considered during derivation of this proposed tight gas production models. Inflow performance relationship curves based on these proposed models show that production rates and absolute open flow potential are always be overestimated while ignoring the threshold pressure gradients.

GEOLOGICAL CONTROLS ON EXPLOITABLE COAL SEAM GAS DISTRIBUTION IN QUEENSLAND

2006 ◽  
Vol 46 (1) ◽  
pp. 343 ◽  
Author(s):  
J. J. Draper ◽  
C.J. Boreham
Keyword(s):  
Coal Seam ◽  
Vitrinite Reflectance ◽  
Gas Production ◽  
Gas Content ◽  
Burial History ◽  
Coal Seam Gas ◽  
Gas Generation ◽  
Delta Plain ◽  
Wide Range ◽  
Gas Fields

Methane is present in all coals, but a number of geological factors influence the potential economic concentration of gas. The key factors are (1) depositional environment, (2) tectonic and structural setting, (3) rank and gas generation, (4) gas content, (5) permeability, and (6) hydrogeology. Commercial coal seam gas production in Queensland has been entirely from the Permian coals of the Bowen Basin, but the Jurassic coals of the Surat and Clarence-Moreton basins are poised to deliver commercial gas volumes.Depositional environments range from fluvial to delta plain to paralic and marginal marine—coals in the Bowen Basin are laterally more continuous than those in the Surat and Clarence-Moreton basins. The tectonic and structural settings are important as they control the coal characteristics both in terms of deposition and burial history. The important coal seam gas seams were deposited in a foreland setting in the Bowen Basin and an intracratonic setting in the Surat and Clarence-Moreton basins. Both of these settings resulted in widespread coal deposition. The complex burial history of the Bowen Basin has resulted in a wide range of coal ranks and properties. Rank in the Bowen Basin coal seam gas fields varies from vitrinite reflectance of 0.55% to >1.1% Rv and from Rv 0.35-0.6% in the Surat and Clarence-Moreton basins in Queensland. High vitrinite coals provide optimal gas generation and cleat formation. The commercial gas fields and the prospective ones contain coals with >60% vitrinite.Gas generation in the Queensland basins is complex with isotopic studies indicating that biogenic gas, thermogenic gas and mixed gases are present. Biogenic processes occur at depths of up to a kilometre. Gas content is important, but lower gas contents can be economic if deliverability is good. Free gas is also present. Drilling and production techniques play an important role in making lower gas content coals viable. Since the Bowen and Surat basins are in a compressive regime, permeability becomes a defining parameter. Areas where the compression is offset by tensional forces provide the best chances for commercial coal seam gas production. Tensional setting such as anticline or structural hinges are important plays. Hydrodynamics control the production rate though water quality varies between the fields.

Application of Due Diligence Audit for Value Creation: Case Study from Gas PSC of Malaysia

2021 ◽  
Author(s):  
Ankaj Kumar Sinha ◽  
Hue Teng Lim
Keyword(s):  
Value Creation ◽  
Operating Cost ◽  
Gas Production ◽  
Early Years ◽  
Due Diligence ◽  
Gas Field ◽  
Technical Assessment ◽  
Gas Fields ◽  
Gas Supply

Abstract As resource owner of all hydrocarbon assets of Malaysia, Petroliam Nasional Berhad (PETRONAS) through Malaysia Petroleum Management (MPM) is responsible for providing asset integrity assurance, maintaining producing assets in safe and operable conditions and ensuring compliance to data management by Petroleum Agreement Contractors (PACs). For mature fields nearing expiry of production sharing contracts (PSCs), it is even more critical to safeguard the integrity of petroleum facilities and to conduct an inventory check of acquired data during transition from existing to new PACs. A Due Diligence Audit (DDA) provides an important milestone to benchmark the health of existing assets (subsurface and surface) and outlining roadmap for future development opportunities for the PSC fields. This paper presents key technical results and value creation areas from the DDA conducted for one of the largest gas field PSC in Malaysia. This gas PSC consisted of multiple gas fields and production hubs catering to a majority of gas production in the region. Although the fields had been in production for more than 20 years, maintaining production plateau rate and optimizing operating cost were identified as key concerns for long term sustainability. New development opportunities were also needed to mitigate the same. For existing fields, incremental recovery projects focused on lowering the abandonment pressure are planned. To maximize the utilization of gas processing capacity in production hubs, nearby gas fields have also been identified for cluster development and evacuation. Assurance on long-term gas supply is targeted through fast pace exploration in the early years of new PSCs to discover new gas development areas and to further increase the operating life of these hubs. As ageing assets, each of the fields also faced unique challenges such as liquid handling, subsidence issues and increasing inventory of idle wells. Through successful application of the DDA framework, a detailed technical assessment of deliverables was conducted along with liability management to address these asset integrity risks. With the successful completion of DDA for these fields, the technical assessment deliverables have created significant PSC value by securing identified opportunities under minimum work commitments. In addition, it facilitated a roadmap for idle wells management plan and new technology in "Implement Replicate" phasing. This has helped PETRONAS to further monetize opportunities in ageing assets, and safeguard producing hubs for long-term gas supply. This paper presents an efficient Due Diligence Audit workflow for long term value creation in mature fields and assets.

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