Sustainable Natural Gas Reservoir and Production Engineering

2022 ◽  
Keyword(s):  
Natural Gas ◽  
Production Engineering ◽  
Gas Reservoir

scholarly journals Quantitative study on natural gas production risk of Carboniferous gas reservoir in eastern Sichuan

2021 ◽  
Author(s):  
Guo Yu ◽  
Haitao Li ◽  
Yanru Chen ◽  
Linqing Liu ◽  
Chenyu Wang ◽  
...  
Keyword(s):  
Risk Factors ◽  
Risk Factor ◽  
Natural Gas ◽  
Gas Production ◽  
Probability Method ◽  
Gas Reservoir ◽  
Production Risk ◽  
Probability Interval ◽  
Natural Gas Production ◽  
Stable Production

AbstractQuantifying natural gas production risk can help guide natural gas exploration and development in Carboniferous gas reservoirs. In this study, the Monte Carlo probability method is used to obtain the probability distribution and growth curve of each production risk factor and production in a Carboniferous gas reservoir in eastern Sichuan. In addition, the fuzzy comprehensive evaluation method is used to conduct the sensitivity analysis of the risk factors, and the natural gas production and realization probability under different risk factors are obtained. The research results show that: (1) the risk factor–production growth curve and probability distribution are calculated by the Monte Carlo probability method. The average annual production under the stable production stage under different realization probabilities is obtained. The maximum probability range of annual production is $$\left( {43.43 - 126.35} \right) \times 10^{8} {\text{m}}^{3} /{\text{year}}$$ 43.43 - 126.35 × 10 8 m 3 / year , and the probability range is 14.59–92.88%. (2) The risk factor sensitivity analysis is significantly affected by the probability interval. In the entire probability interval, the more sensitive risk factors are the average production of the kilometer-deep well (D) and the production rate in the stable production stage (A). During the exploration and development of natural gas, these two risk factors can be adjusted to increase production.

scholarly journals Split Sales of Gas

1971 ◽  
Vol 9 (3) ◽  
pp. 496
Author(s):  
Robert C. Muir
Keyword(s):  
Natural Gas ◽  
Gas Reservoir ◽  
Gas Industry ◽  
Natural Gas Industry ◽  
Gas Market

The Natural Gas Industry is highly competitive and once a gas reservoir is discovered the various producers are anxious to enter into Gas Purchase Contracts. The contracts are with different purchasers and on different terms giving rise to split stream deliveries - there would never be any split stream problems if all producers made simultaneous deliveries to one or more purchasers in exactly the same volumes at exactly the same price. This article examines the position of the producers in the gas reservoir in the absence of an agreement and then discusses different contractual methods which the producers may use to resolve the conflict between the Doctrine of Correlative Rights and the Rule of Capture, such as gas market sharing contracts, cash adjustments, gas balancing schemes and deferred production agreements. To further complicate the problems of 'the producer in dealing with split sales of gas, the lessee-producer must keep in mind the interests of the lessor-royalty owner. The article concludes with a consideration of the interest of the royalty owner in the prepayment received by the producer and in the price for which the producer is selling the gas.

Economic Comparison of Alternatives for a Stranded Offshore Gas Reservoir

2021 ◽  
Vol 73 (08) ◽  
pp. 63-64
Author(s):  
Chris Carpenter
Keyword(s):  
Natural Gas ◽  
Economic Feasibility ◽  
Sensitivity Analyses ◽  
Pricing Models ◽  
Gas Reservoirs ◽  
Gas Reservoir ◽  
Pipe Length ◽  
Offshore Technology ◽  
University Of Oklahoma ◽  
Natural Gas Industry

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper OTC 30732, “Economic Feasibility Study of Several Usage Alternatives for a Stranded Offshore Gas Reservoir,” by Khoi Viet Trinh, SPE, and Rouzbeh G. Moghanloo, SPE, University of Oklahoma, prepared for the 2020 Offshore Technology Conference, originally scheduled to be held in Houston, 4–7 May. The paper has not been peer reviewed. Copyright 2020 Offshore Technology Conference. Reproduced by permission. This paper compares economics of a floating liquefied natural gas (FLNG) project with those of an onshore LNG plant and gas-to-wire (GTW) processes. Sensitivity analyses and tornado charts are used to evaluate the importance of various uncertain parameters associated with FLNG construction and operation. This study will be helpful for future considerations in using FLNG to convert offshore gas reservoirs previously considered stranded into economically viable resources. The results from this economic model can play a key role in the future of the natural gas industry and energy market in West Africa. Assumptions Before presenting different economic scenarios, the following assumptions must be established: * The pipeline will have the correct diameter, pressure rating, and metallurgy to transport produced gas. Only the pipe length will be considered a variable. * Operating expenses (OPEX) of both onshore LNG and FLNG will be the same. Realistically, however, OPEX of FLNG will be different from that of onshore LNG. * A subsidy from the Nigerian government has been obtained for the onshore LNG plant. * The electricity price is assumed to be $0.25/kWh. * An assumed upstream cost of $2/Mscf to cover onshore LNG gas pretreatment is assumed. * The onshore LNG plant and FLNG will have the same lifespan. However, in reality, availability of FLNG can be lower than that of onshore LNG. Pricing Models FNLG. Because of the relative recency of FNLG, few pricing models have been readily available. For the complete paper, Shell’s Prelude project is the basis for pricing of FLNG. Prelude costs averaged out to approximately $14 billion, which will be used as the cost of the facility for the FLNG scenario in the economic analysis.

scholarly journals Utilization of CO2 as Cushion Gas for Depleted Gas Reservoir Transformed Gas Storage Reservoir

Energies ◽  
2020 ◽  
Vol 13 (3) ◽  
pp. 576 ◽  
Author(s):  
Cheng Cao ◽  
Jianxing Liao ◽  
Zhengmeng Hou ◽  
Hongcheng Xu ◽  
Faisal Mehmood ◽  
...  
Keyword(s):  
Natural Gas ◽  
Production Rate ◽  
Water Saturation ◽  
Gas Storage ◽  
Periodic Change ◽  
Residual Water ◽  
Reservoir Pressure ◽  
Gas Reservoir ◽  
Reservoir Permeability ◽  
Depleted Gas Reservoir

Underground gas storage reservoirs (UGSRs) are used to keep the natural gas supply smooth. Native natural gas is commonly used as cushion gas to maintain the reservoir pressure and cannot be extracted in the depleted gas reservoir transformed UGSR, which leads to wasting huge amounts of this natural energy resource. CO2 is an alternative gas to avoid this particular issue. However, the mixing of CO2 and CH4 in the UGSR challenges the application of CO2 as cushion gas. In this work, the Donghae gas reservoir is used to investigate the suitability of using CO2 as cushion gas in depleted gas reservoir transformed UGSR. The impact of the geological and engineering parameters, including the CO2 fraction for cushion gas, reservoir temperature, reservoir permeability, residual water and production rate, on the reservoir pressure, gas mixing behavior, and CO2 production are analyzed detailly based on the 15 years cyclic gas injection and production. The results showed that the maximum accepted CO2 concentration for cushion gas is 9% under the condition of production and injection for 120 d and 180 d in a production cycle at a rate of 4.05 kg/s and 2.7 kg/s, respectively. The typical curve of the mixing zone thickness can be divided into four stages, which include the increasing stage, the smooth stage, the suddenly increasing stage, and the periodic change stage. In the periodic change stage, the mixed zone increases with the increasing of CO2 fraction, temperature, production rate, and the decreasing of permeability and water saturation. The CO2 fraction in cushion gas, reservoir permeability, and production rate have a significant effect on the breakthrough of CO2 in the production well, while the effect of water saturation and temperature is limited.

Feasibility Analysis of Gas Storage in JB Area Caprock Evaluation

2011 ◽  
Vol 110-116 ◽  
pp. 3117-3124
Author(s):  
Lei Shi ◽  
Shu Sheng Gao
Keyword(s):  
Natural Gas ◽  
Carbonate Platform ◽  
Gas Storage ◽  
High Demand ◽  
Gas Reservoir ◽  
Sealing Capacity ◽  
Important Index ◽  
Long Run ◽  
Cap Rock ◽  
Selection Of

Underground gas storages （UGS） are widely used to store the excess of produced natural gas during periods of low demand, and relieve the pressure during periods of high demand. Depleted natural gas reservoir is generally the best choice against others. Proper selection of a depleted gas reservoir is essential to the succession, steady and reliability of UGS in the long run. Sealing capacity of caprock is an important index for measuring the performance of gas storage reservoir. In order to analysis feasibility of UGS in JB area, the development characteristics of caprock were studied, the sealing gas effectiveness of caprock was evaluated. it was concluded that the main caprock was the formation of evaporative carbonate platform, and the breakthrough pressure of cap rock was high. The cap rocks with good sealing capacity were distributed in the area between S224 well and S39 well. The sealing ability was comprehensively evaluated by use of the development features and sealing capacity of caprock.

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