De-Risking Fluid Compartmentalization of the Barik Reservoir in the Khazzan Field, Oman - An Integrated Approach

2021 ◽  
Author(s):  
Abdullah Al Anboori ◽  
Stephen Dee ◽  
Khalil Al Rashdi ◽  
Herbert Volk
Keyword(s):  
Oil And Gas ◽  
Water Pressure ◽  
Integrated Approach ◽  
Fluid Distribution ◽  
Geological Time ◽  
Gas Reservoirs ◽  
Gas Field ◽  
Development Costs ◽  
Potential Reservoir ◽  
Reservoir Compartmentalization

Abstract The degree of fluid compartmentalization has direct implications on the development costs of oil and gas reservoirs, since it may negatively impact gas water contacts (GWC) and fluid condensate gas ratios (CGR). In this case study on the Barik Formation in the giant Khazzan gas field in Block 61 in Oman we demonstrate how integrating independent approaches for assessing potential reservoir compartmentalization can be used to assess compartmentalization risk. The three disciplines that were integrated are structural geology (fault seal analysis, movement and stress stages of faults and fractures, traps geometry over geological time), petroleum systems (fluid chemistry and pressure, charge history) and sedimentology-stratigraphy including diagenesis (sedimentological and diagenetic controls on vertical and lateral facies and reservoir quality variation). Dynamic data from production tests were also analyzed and integrated with the observations above. Based on this work, Combined Common Risk Segment (CCRS) maps with a most likely and alternative scenarios for reservoir compartmentalization were constructed. While pressure data carry significant uncertainty due to the tight nature of the deeply buried rocks, it is clear pressures in gas-bearing sections fall onto a single pressure gradient across Block 61, while water pressures indicate variable GWCs. Overall, the GWCs appear to shallow across the field towards the NW, while water pressure appears to increase in that direction. The "apparent" gas communication with separate aquifers is difficult to explain conventionally. A range of scenarios for fluid distribution and reservoir connectivity are discussed. Fault seal compartmentalization and different trap spill points were found to be the most likely mechanism explaining fluid distribution and likely reservoir compartmentalization. Perched water may be another factor explaining variable GWCs. Hydrodynamic tilting due to the flow of formation water was deemed an unlikely scenario, and the risk of reservoir compartmentalization due to sedimentological and diagenetic flow barriers was deemed to be low.

Experimental Study on the Saturation Model of Volcanic Rock Based on Fluid Distribution

2021 ◽  
Vol 62 (4) ◽  
pp. 422-433
Author(s):  
Baozhi Pan ◽  
◽  
Weiyi Zhou ◽  
Yuhang Guo ◽  
Zhaowei Si ◽  
...  
Keyword(s):  
Volcanic Rock ◽  
Oil And Gas ◽  
Water Saturation ◽  
Early Stage ◽  
Evaluation Model ◽  
Acoustic Velocity ◽  
Distribution Model ◽  
Fluid Distribution ◽  
Water Drainage ◽  
Gas Reservoirs

A saturation evaluation model suitable for Nanpu volcanic rock formation is established based on the experiment of acoustic velocity changing with saturation during the water drainage process of volcanic rock in the Nanpu area. The experimental data show that in the early stage of water drainage, the fluid distribution in the pores of rock samples satisfies the patchy formula. With the decrease of the sample saturation, the fluid distribution in the pores is more similar to the uniform fluid distribution model. In this paper, combined with the Gassmann-Brie and patchy formula, the calculation equation of Gassmann-Brie-Patchy (G-B-P) saturation is established, and the effect of contact softening is considered. The model can be used to calculate water saturation based on acoustic velocity, which provides a new idea for the quantitative evaluation of volcanic oil and gas reservoirs using seismic and acoustic logging data.

scholarly journals Development of a prmA genes quantification technique and assessment of the technique’s application potential for oil and gas reservoir exploration

2018 ◽  
Vol 36 (5) ◽  
pp. 1172-1188 ◽  
Author(s):  
Zhuo Ning ◽  
Ze He ◽  
Sheng Zhang ◽  
Miying Yin ◽  
Yaci Liu ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Quantitative Polymerase Chain Reaction ◽  
Oil Field ◽  
Gas Reservoirs ◽  
Gas Reservoir ◽  
Gas Field ◽  
Detection Range ◽  
Gene Copies ◽  
Application Potential ◽  
Sensitivity Specificity

Propane-oxidizing bacteria in surface soils are often used to indicate the position of oil and gas reservoirs. As a potential replacement for the laborious traditional culture-dependent counting method, we applied real-time fluorescent quantitative polymerase chain reaction detection as a quick and accurate technology for quantification of propane-oxidizing bacteria. The propane monooxygenase gene was set as the target and the assay is based on SYBR Green I dye. The detection range was from 9.75 × 108 to 9.75 × 101 gene copies/µl, with the lowest detected concentration of 9.75 copies/µl. All coefficient of variation values of the threshold cycle in the reproducibility test were better than 1%. The technique showed good sensitivity, specificity, and reproducibility. We also quantified the propane-oxidizing bacteria in soils from three vertical 250 cm profiles collected from an oil field, a gas field, and a nonoil gas field using the established technique. The results indicated that the presence of propane monooxygenase A genes in soils can indicate an oil or gas reservoir. Therefore, this technique can satisfy the requirements for microbial exploration of oil and gas.

THE DEVELOPMENT OF THE TIRRAWARRA OIL AND GAS FIELD

1984 ◽  
Vol 24 (1) ◽  
pp. 278
Author(s):  
H. T. Pecanek ◽  
I. M. Paton
Keyword(s):  
Carbon Dioxide ◽  
Oil And Gas ◽  
Gas Injection ◽  
Oil Field ◽  
Oil Reservoir ◽  
Gas Reservoirs ◽  
Gas Field ◽  
Associated Gas ◽  
Oil And Gas Field ◽  
Cooper Basin

The Tirrawarra Oil and Gas Field, discovered in 1970 in the South Australian portion of the Cooper Basin, is the largest onshore Permian oil field in Australia. Development began in 1981 as part of the $1400 million Cooper Basin Liquids ProjectThe field is contained within a broad anticline bisected by a north-south sealing normal fault. This fault divides the Tirrawarra oil reservoir into the Western and Main oil fields. Thirty-four wells have been drilled, intersecting ten Patchawarra Formation sandstone gas reservoirs and the Tirrawarra Sandstone oil reservoir. Development drilling discovered three further sandstone gas reservoirs in the Toolachee Formation.The development plan was based on a seven-spot pattern to allow for enhanced oil recovery by miscible gas drive. The target rates were 5400 barrels of oil (860 kilolitres) per day with 13 million ft3 (0.37 million m3) per day of associated gas and 70 million ft3 (2 million m') per day of wet, non-associated gas. Evaluation of early production tests showed rapid decline. The 100 ft (30 m) thick, low-permeability Tirrawarra oil reservoir was interpreted as an ideal reservoir for fracture treatment and as a result all oil wells have been successfully stimulated, with significant improvement in well production rates.The oil is highly volatile but miscibility with carbon dioxide has been proven possible by laboratory tests, even though the reservoir temperature is 285°F (140°C). Pilot gas injection will assess the feasibility of a larger-scale field-wide pressure maintenance scheme using miscible gas. Riot gas injection wells will use Tirrawarra Field Patchawarra Formation separator gas to defer higher infrastructure costs associated with the alternative option of piping carbon dioxide from Moomba, the nearest source.

Long Pile Upending Lifting Study for Fixed Platform on Offshore Oil and Gas Field

2014 ◽  
Author(s):  
Yandong Zhou ◽  
Facheng Wang
Keyword(s):  
Deep Water ◽  
Oil And Gas ◽  
Cost Effective ◽  
Analysis Model ◽  
Gas Reservoirs ◽  
Gas Field ◽  
Water Developments ◽  
Oil And Gas Field ◽  
Offshore Oil And Gas ◽  
Offshore Oil

Fixed platform have been widely employed in the offshore oil and gas reservoirs development. Pile foundation reliability is critical for these platforms where drilling, production and other functions are integrated. The lifting operation for the long pile, being a key step in the jacket installation, has been considered for further developments. With deep water developments, the sizes and weights of long piles are reasonably bigger. The corresponding process and equipment employed are subsequently altered, which brings challenges to developing a cost-effective, easy-operable approach for lifting operation. In this paper, the technology for the offshore long pile upending lifting operation including pile feature, installation methodology, lifting rigging and analysis model, covering water depths ranging from shallow to near deep water zone (60–300 m water depth) has been suggested. In addition, the applicability of the adoptable novel approaches has been discussed considering the practical project experience.

General models for topology layout of oil and gas star-tree pipeline network

2021 ◽  
pp. 1-22
Author(s):  
Jun Zhou ◽  
Daixin Zhang ◽  
Liuling Zhou ◽  
Guangchuan Liang ◽  
Xuan Zhou ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Transportation System ◽  
Oil Field ◽  
Mixed Integer ◽  
Hierarchical Optimization ◽  
Pipe Network ◽  
Gas Field ◽  
Pipeline Network ◽  
Development Costs ◽  
Star Tree

Oil&gas gathering pipeline network structure is a significant part of oil&gas field construction, and the rational construction of pipeline network is directly related to the efficiency and benefits of oil&gas field production. Therefore, optimizing the gathering and transportation system of oil and gas fields is the key to reducing development costs. The star-tree type pipe network is widely used in the gathering and transportation system. In order to optimize the star-tree pipe networks (STPNs) that has restrictions on the processing capacity and gathering radius of the station as a whole, this paper establishes four models of pipe network layout with specific constraints. They are Mixed-Integer Linear Programming Models with a large number of discrete variables. We take two virtual fields as examples, use CPLEX solver to solve the above four models as a whole, to obtain the optimal scheme, and also figure out the investment of the pipeline network. We further optimize the hierarchical optimization of the pipeline network with special constraints, then compare and analyze results obtained by the overall optimization. Finally, models are applied to an actual oil field and an actual gas field as examples to optimize the layout, which verifies the validity and feasibility of the models.

scholarly journals The hydrodynamic conditions of the Volyn-Podillya oil and gas-bearing region

2018 ◽  
Keyword(s):  
Oil And Gas ◽  
Water Pressure ◽  
The State ◽  
Upper Devonian ◽  
State Enterprise ◽  
Hydrodynamic Characteristics ◽  
Gas Field ◽  
Hydrodynamic Field ◽  
The Impact ◽  
Gas Bearing

The purpose of the paper was to study hydrodynamic peculiarities of the aquifers of Volyn-Podillya oil and gas-bearing region and their impact on the formation and conservation of gas deposits. The research area is located in the western Ukraine and covers the structures of the Eastern European and the Western European platforms. At present, Lokachi and Velyki Mosty gas fields are discovered here in the deposits of the Middle and Upper Devonian. Non-commercial volumes of gas and oil were received in some exploration wells. Research methodology was based on the evaluation of water initial formation pressures and static levels that were obtained from the funds of the State Enterprise "Lvivgazvydobuvannia" and State Enterprise "Zakhidukrgeologia”. The formation pressures were transformed to one plane of comparison. Also the hydrodynamic characteristics were studied in this work on the basis of the hydrostatic coefficient (P f/P e) in order to evaluate the impact of the factors that determine the nature and form the state of the hydrodynamic field. The maps of the formation pressures and hydrostatic coefficients were constructed and interpreted. Results of researches. It was found out that the parameters of hydrodynamic fields of the Upper Proterozoic, Cambrian, and Lower-Devonian aquifers complexes of the Volyn-Podillya ORG have the features of an exfiltration system. The hydrodynamic tension extends from the most abyssal parts of the sedimentary basin to its peripheral parts. Formation pressures are caused by an increase in the volume of waters due to their squeezing out of clay sediments that have the ability to significant compression into weakly compression sandy rocks. The hydrodynamic energy of the Middle-Upper Devonian aquifer complex is directed from the periphery to its central (the most submerged) part. The peripheral parts have the characteristics of the infiltration water-pressure system. It was established that the hydrodynamic field of the Volyn-Podillya ORG compared with the Bilche-Volytsya ORG is marked by a much lower power due to weak effect of exfiltration in the aquifers and the absence of sustained lithological and tectonic screens. The lateral hydrodynamic field, investigated on the basis of the hydrostatic coefficient, increases from the south to the north. A certain spatial relationship of the isolines of hydrostatic coefficient with diagonal disjunctive breaks is observed. This can determine them as a way of the water-hydrocarbon mixtures migration. Gas deposits of Lokachy and Velyki Mosty fields are located in areas with higher values of the hydrostatic coefficient. Distribution of the hydrostatic coefficient in the section of Lokachi gas field indicates the connection of its overhydrostatic values with the existing gas deposits. Hydrodynamic isolation of the structures promoted conservation of hydrocarbon deposits from mechanical and biochemical destruction.

scholarly journals GROUNDWATER OF THE MESOZOIC HYDROGEOLOGICAL BASIN IN THE TERRITORY OF THE ETY-PUROVSKY OIL AND GAS FIELD

2018 ◽  
pp. 6-11
Author(s):  
V. A. Beshentsev ◽  
R. N. Abdrashitova ◽  
N. K. Lazutin ◽  
I. G. Sabanina ◽  
A. A. Gudkova
Keyword(s):  
Oil And Gas ◽  
Water Pressure ◽  
Gas Field ◽  
Pressure System ◽  
Hydrogeological Conditions ◽  
Oil And Gas Field ◽  
Vertical Zoning

The article considers hydrogeological conditions of the Ety-Purovsky oil and gas field. The authors describe hydrogeological stratification of the field and its hydrogeochemical conditions. These conditions reveal the existence of classical vertical zoning. The research pays attention to the important role of an elution water pressure system in the formation of the hydrogeochemical and hydrogeodynamic fields structure.

RESERVOIR SIMULATION OF THE GIPPSLAND BASIN

1984 ◽  
Vol 24 (1) ◽  
pp. 170
Author(s):  
S. T. Henzcll A. A Young A K. Khurana
Keyword(s):  
Reservoir Simulation ◽  
Single Phase ◽  
Oil And Gas ◽  
Initial Pressure ◽  
Fluid Distribution ◽  
External Boundary ◽  
Gas Reservoirs ◽  
Oil And Gas Reservoirs ◽  
Gippsland Basin ◽  
Exploration And Development

A three-dimensional, single-phase reservoir simulation model of the entire Gippsland Basin aquifer system, together with its oil and gas reservoirs, was first developed in 1973. It was replaced by an improved version in 1975. Now, after fifteen years of production, pressure predictions from the model still compare very well with data obtained from current exploration and development wells.The model, consisting of 4186 grid blocks, incorporates the geological description, and pressure and fluid distribution of the basin. The geological description includes porosity, net-to-gross ratio and permeability with fluid properties representing the aquifer. A well-established initial pressure/depth relationship for the Gippsland Basin is included in the model. Although it is a single-phase model, oil and gas reservoirs are represented by pseudo rock and fluid properties.The model is regularly updated with historical and forecast production rates in order to predict pressure behaviour and therefore aquifer strength in various areal and stratigraphic locations in the basin. Such information is essential for defining external boundary conditions in individual reservoir simulation models and assists in gas deliverability forecasts. In exploration wells, measured pressures are compared with model predictions to help understand the degree of pressure communication with the basin aquifer and hence the level of pressure support. Detailed predictions of the pressure gradients expected in both exploration and development wells are often of assistance in identifying fluid contacts, overpressure and reservoirs with limited communication with the aquifer.

Geological and Field Feasibility Study of Field Development Management Using Marker-Based Production Profiling Surveillance in Horizontal Wells: The Case Study of the Yuzhno-Vyintoiskoye Field

2021 ◽  
Author(s):  
Marat Rafailevich Dulkarnaev ◽  
Yuri Alexeyevich Kotenev ◽  
Shamil Khanifovich Sultanov ◽  
Alexander Viacheslavovich Chibisov ◽  
Daria Yurievna Chudinova ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Oil And Gas ◽  
Water Saturation ◽  
Clay Content ◽  
Horizontal Wells ◽  
Integrated Approach ◽  
Geological Structure ◽  
Gas Field ◽  
Field Development ◽  
Reservoir Rocks

In pursuit of efficient oil and gas field development, including hard-to-recover reserves, the key objective is to develop and provide the rationale for oil recovery improvement recommendations. This paper presents the results of the use of the workflow process for optimized field development at two field clusters of the Yuzhno-Vyintoiskoye field using geological and reservoir modelling and dynamic marker-based flow production surveillance in producing horizontal wells. The target reservoir of the Yuzhno-Vyntoiskoye deposit is represented by a series of wedge-shaped Neocomian sandstones. Sand bodies typically have a complex geological structure, lateral continuity and a complex distribution of reservoir rocks. Reservoir beds are characterised by low thickness and permeability. The pay zone of the section is a highly heterogeneous formation, which is manifested through vertical variability of the lithological type of reservoir rocks, lithological substitutions, and the high clay content of reservoirs. The target reservoir of the Yuzhno-Vyintoiskoye field is marked by an extensive water-oil zone with highly variable water saturation. According to paleogeographic data, the reservoir was formed in shallow marine settings. Sand deposits are represented by regressive cyclites that are typical for the progressing coastal shallow water (Dulkarnaev et al., 2020). Currently, the reservoir is in production increase cycle. That is why an integrated approach is used in this work to provide a further rationale and creation of the starting points of the reservoir pressure maintenance system impact at new drilling fields to improve oil recovery and secure sustainable oil production and the reserve development rate under high uncertainty.

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