scholarly journals The effect of capillary pressure and buoyancy on the production performance of the Mobara type dissolved-in-water natural gas field

2006 ◽  
Vol 71 (6) ◽  
pp. 582-590
Author(s):  
Tsutomu Nakagawa ◽  
Takeru Ogatsu ◽  
Yoshiyuki Tazaki
Keyword(s):  
Natural Gas ◽  
Capillary Pressure ◽  
Production Performance ◽  
Gas Field

Integrated Unit Technology for Gas Field Surface Gathering and Transmission

2012 ◽  
Vol 271-272 ◽  
pp. 1328-1345
Author(s):  
Jin Li ◽  
Jian Yang Zhao
Keyword(s):  
Natural Gas ◽  
Power Consumption ◽  
New Technologies ◽  
Ball Valve ◽  
Gas Field ◽  
Pneumatic Control ◽  
Initial Application ◽  
Design Idea

In combination with the author's experiences in design for integrated unit for natural gas field gathering and transmission, this paper describes conventional practices and technical characteristics of integrated unit in the processes of standardization design and modularization establishment and analyzes the initial application of pneumatic control ball valve, wedge-shaped flowmeter and other new technologies for surface facilities in the gas field. As a result, a new design idea is proposed in this paper, i.e., to improve the integration level of surface facilities, to minimize power consumption and maintenance works and to realize unattended work mode.

scholarly journals Light hydrocarbon geochemical characteristics and their application in Upper Paleozoic, Shenmu gas field, Ordos Basin

2016 ◽  
Vol 35 (1) ◽  
pp. 103-121 ◽  
Author(s):  
Wenxue Han ◽  
Shizhen Tao ◽  
Guoyi Hu ◽  
Weijiao Ma ◽  
Dan Liu ◽  
...  
Keyword(s):  
Natural Gas ◽  
Ordos Basin ◽  
Light Hydrocarbon ◽  
Source Rocks ◽  
Higher Plant ◽  
Gas Field ◽  
Gas Source ◽  
Upper Paleozoic ◽  
Methyl Cyclohexane ◽  
Normal Stage

Light hydrocarbon has abundant geochemical information, but there are few studies on it in Shenmu gas field. Taking Upper Paleozoic in Shenmu gas field as an example, authors use gas chromatography technology to study light hydrocarbon systematically. The results show that (1) The Shenmu gas field is mainly coal-derived gas, which is mixed by partial oil-derived gas due to the experiment data. (2) Based on K1, K2 parameter and Halpern star chart, the Upper Paleozoic gas in Shenmu gas field belongs to the same petroleum system and the depositional environment of natural gas source rocks should be homologous. (3) The source rocks are mainly from terrestrial higher plant origins and belong to swamp facies humic due to methyl cyclohexane index and Mango parameter intersection chart, which excluded the possibility of the Upper Paleozoic limestone as source rocks. (4) The isoheptane ranges from 1.45 to 2.69 with an average of 2.32, and n-heptane ranges from 9.48 to 17.68% with an average of 11.71%, which is below 20%. The maturity of Upper Paleozoic gas in Shenmu gas field is low-normal stage, which is consistent with Ro data. (5) The Upper Paleozoic natural gas in the Shenmu gas field did not experience prolonged migration or secondary changes, thus can be analyzed by light hydrocarbon index precisely.

scholarly journals Vapor Recovery from Condensate Storage Tanks Using Gas Ejector Technology

2013 ◽  
Vol 27 ◽  
pp. 37-41
Author(s):  
Palash K Saha ◽  
Mahbubur Rahman
Keyword(s):  
Natural Gas ◽  
Chemical Engineering ◽  
Economic Loss ◽  
Low Pressure ◽  
Heat Energy ◽  
Environmental Concerns ◽  
Storage Tanks ◽  
Gas Field ◽  
Recovery Unit ◽  
Yearly Saving

This paper demonstrates a method of recovering the low pressure vapor from the condensate tanks in the Bibiyana gas field. This method uses a gas ejector as a device to compress the low pressure natural gas from the condensate tanks to an intermediate pressure, which would then be fed into the intermediated stage of the existing vapor recovery unit. Thus the natural gas will be saved which would have been otherwise flared. The amount of tank vapor is estimated by different methods, which shows a significant amount of gas is now being flared. Flaring of gas is a problem which entails both economic loss and environmental concerns. It is estimated that, on the average 190 MSCFD tank vapor can be recovered using the proposed method involving a gas ejector. Thus yearly saving would be about 68 MMSCF of natural gas. The equivalent heat energy saving is about 74.55X109 BTU. In terms of greenhouse gas emissions, this project will reduce about 1,112 tons of CO2 emissions per year in the gas plant locality. DOI: http://dx.doi.org/10.3329/jce.v27i1.15856 Journal of Chemical Engineering, IEB Vol. ChE. 27, No. 1, June 2012: 37-41

scholarly journals Pilot test of study on brine injection into shallow formation for mitigating land subsidence in the Southern Kanto Gas Field in Japan

2020 ◽  
Vol 382 ◽  
pp. 787-790
Author(s):  
Noriyuki Muraoka ◽  
Yuji Hayashi ◽  
Katsuhiro Nakamura ◽  
Toshiaki Yamaguchi ◽  
Kazunori Ono ◽  
...  
Keyword(s):  
Natural Gas ◽  
Land Subsidence ◽  
Ground Level ◽  
Pilot Test ◽  
Formation Water ◽  
Gas Field ◽  
Bottom Hole ◽  
Test Study ◽  
Water Formation ◽  
Brine Injection

Abstract. In the Southern Kanto Gas Field, natural gas dissolved in water has been produced for over 80 years. In order to produce the natural gas dissolved in water, formation water must be pumped from a reservoir in the gas field. The production of formation water is considered to be one of the causes of land subsidence. Because brine injection into shallow formations is expected to be effective to mitigate land subsidence, our association is planning to conduct the pilot test study. In this test, the production and injection of brine are going to be performed, and we will observe a deformation of the shallow formation and a change of ground level and the bottom hole pressure. As a result of these tests, if the land subsidence mitigation effect by injection into shallow formation is confirmed, it is expected that it will be connected to increased production and to reservoir management in consideration of land subsidence mitigation in the future.

scholarly journals The Development of a Low-Cost Method for Monitoring Methane Leakage from the Subsurface of Natural Gas Fields

Methane ◽  
2021 ◽  
Vol 1 (1) ◽  
pp. 24-37
Author(s):  
Muhammad Alfiza Farhan ◽  
Yuichi Sugai ◽  
Nuhindro Priagung Widodo ◽  
Syafrizal Syafrizal
Keyword(s):  
Activated Carbon ◽  
Natural Gas ◽  
Methane Concentration ◽  
Low Cost ◽  
Gas Field ◽  
Methane Leakage ◽  
Wide Scale ◽  
Adsorbed Methane ◽  
In The Beginning ◽  
Gas Fields

The leakage of methane from the subsurface on the coalfield or natural gas field invariably becomes an important issue nowadays. In notable addition, materials such as activated carbon, zeolites, and Porapak have been successfully identified as adsorbents. Those adsorbents could adsorb methane at atmospheric pressure and room temperature. Therefore, in this scholarly study, a new method using adsorbents to detect points of methane leakage that can cover a wide-scale area was developed. In the beginning, the most capable adsorbent should be determined by quantifying adsorbed methane amount. Furthermore, checking the possibility of adsorption in the column diffusion and desorption method of adsorbents is equally necessary. The most capable adsorbent was activated carbon (AC), which can adsorb 1.187 × 10−3 mg-CH4/g-AC. Hereinafter, activated carbon successfully can adsorb methane through column diffusion, which simulates the situation of on-site measurement. The specific amount of adsorbed methane when the initial concentrations of CH4 in a bag were 200 ppm, 100 ppm, and 50 ppm was found to be 0.818 × 10−3 mg-CH4/g-AC, 0.397 × 10−3 mg-CH4/g-AC, 0.161 × 10−3 mg-CH4/g-AC, respectively. Desorption of activated carbon analysis shows that methane concentration increases during an hour in the temperature bath under 80 °C. In conclusion, soil methane leakage points can be detected using activated carbon by identifying the observed methane concentration increase.

scholarly journals Methane emissions in the Netherlands: The Groningen field

Elem Sci Anth ◽  
2018 ◽  
Vol 6 ◽  
Author(s):  
Tara I. Yacovitch ◽  
Bruno Neininger ◽  
Scott C. Herndon ◽  
Hugo Denier van der Gon ◽  
Sander Jonkers ◽  
...  
Keyword(s):  
Natural Gas ◽  
The Netherlands ◽  
Oil And Gas ◽  
Methane Emissions ◽  
Production Volume ◽  
Offshore Platforms ◽  
Source Characterization ◽  
Gas Field ◽  
Study Region ◽  
Individual Site

The Groningen natural gas field in the Netherlands – one of Europe’s major gas fields – deploys a “production cluster” infrastructure with extraction, some processing and storage in a single facility. This region is also the site of intensive agriculture and cattle operations. We present results from a multi-scale measurement campaign of methane emissions, including ground and airborne-based estimates. Results are compared with inventory at both the facility and regional level. Investigation of production cluster emissions in the Groningen gas field shows that production volume alone is not a good indicator of whether, and how much, a site is emitting methane. Sites that are nominally shut down may still be emitting, and vice-versa. As a result, the inventory emission factors applied to these sites (i.e. weighted by production) do a poor job of reproducing individual site emissions. Additional facility-level case studies are presented, including a plume at 150 ± 50 kg CH4 hr–1 with an unidentified off-shore emission source, a natural gas storage facility and landfills. Methane emissions in a study region covering 6000 km2 and including the majority of the Groningen field are dominated by biogenic sources (e.g. agriculture, wetlands, cattle). Total methane emissions (8 ± 2 Mg hr–1) are lower than inventory predictions (14 Mg hr–1) but the proportion of fossil fuel sources is higher than indicated by the inventory. Apportionment of methane emissions between thermogenic and biogenic source types used ethane/methane ratios in aircraft flasks and ground-based source characterization. We find that emissions from the oil and gas sector account for 20% of regional methane, with 95% confidence limits of (0%, 51%). The experimental uncertainties bound the inventory apportionment of 1.9%, though the central estimate of 20% exceeds this result by nearly 10 times. This study’s uncertainties demonstrate the need for additional research focusing on emissions apportionment, inventory refinement and offshore platforms.

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