scholarly journals O3, CH4, CO2, CO, NO2 and NMHC aircraft measurements in the Uinta Basin oil and gas region under low and high ozone conditions in winter 2012 and 2013

Elem Sci Anth ◽  
2016 ◽  
Vol 4 ◽  
Author(s):  
S. J. Oltmans ◽  
A. Karion ◽  
R. C. Schnell ◽  
G. Pétron ◽  
D. Helmig ◽  
...  
Keyword(s):  
Boundary Layer ◽  
Oil And Gas ◽  
Primary Source ◽  
Combustion Products ◽  
Gas Production ◽  
Cold Pool ◽  
Strong Positive Correlation ◽  
Uinta Basin ◽  
Gas Field ◽  
Oil And Gas Production

Abstract Instrumented aircraft measuring air composition in the Uinta Basin, Utah, during February 2012 and January-February 2013 documented dramatically different atmospheric ozone (O3) mole fractions. In 2012 O3 remained near levels of ∼40 ppb in a well-mixed 500–1000 m deep boundary layer while in 2013, O3 mole fractions >140 ppb were measured in a shallow (∼200 m) boundary layer. In contrast to 2012 when mole fractions of emissions from oil and gas production such as methane (CH4), non-methane hydrocarbons (NMHCs) and combustion products such as carbon dioxide (CO2) were moderately elevated, in winter 2013 very high mole fractions were observed. Snow cover in 2013 helped produce and maintain strong temperature inversions that capped a shallow cold pool layer. In 2012, O3 and CH4 and associated NMHCs mole fractions were not closely related. In 2013, O3 mole fractions were correlated with CH4 and a suite of NMHCs identifying the gas field as the primary source of the O3 precursor NMHC emissions. In 2013 there was a strong positive correlation between CH4 and CO2 suggesting combustion from oil and natural gas processing activities. The presence of O3 precursor NMHCs through the depth of the boundary layer in 2013 led to O3 production throughout the layer. In 2013, O3 mole fractions increased over the course of the week-long episodes indicating O3 photochemical production was larger than dilution and deposition rates, while CH4 mole fractions began to level off after 3 days indicative of some air being mixed out of the boundary layer. The plume of a coal-fired power plant located east of the main gas field was not an important contributor to O3 or O3 precursors in the boundary layer in 2013.

LANDSCAPE MAP OF BYTKIVSKE OIL FIELD AND NEIGHBORING TERRITORIES OF THE CARPATHIAN REGION

2017 ◽  
Vol 31 (2) ◽  
pp. 49-55
Author(s):  
Yaroslav Adamenko ◽  
◽  
Mirela Coman ◽  
Oleh Adamenko ◽  
Keyword(s):  
Oil And Gas ◽  
Gas Production ◽  
Oil Field ◽  
Nature Protection ◽  
Gas Field ◽  
Oil And Gas Production ◽  
Main Research ◽  
Oil And Gas Field ◽  
Age Features ◽  
Landscape Map

Environmentally safe oil and gas production demands permanent control for the development of ecological situation which should be managed on the basis of existing nature protection requirements and corresponding instruction documents. Purpose of the research and formulation of the problem is to select landscape complexes at the hierarchical levels of locations and facies in the Bykiv oil and gas field to make landscape map with morphological genetic and age features of landscape structure as the basis of environmental assessment of oil and gas field impact on the natural geosystems. Presentation of the main research material with full justification of the received scientific results. Landscape analysis of the investigated area allowed to select, ground and make mapping the following landscape complexes: landscape localities, foothill landscape complexes. Characteristic feature of the Bytkiv oil and gas field and neighborhoods is their high-altitude stratification from middle and lowmountainous to foothills and lowlands. The genesis or origin of the area under study is various - from denudation relics of the top peneplenization surface of leveling much younger pedyplenization surface pediments on the transition from mountainous to foothill relief, to deeply portioned erosionally active steep slopes and stairstepping of the river terraces. Age boundaries of the created landscape structures were determined on the availability of adjoint sedimentary formations from the producents of bedrock destruction, resedimented eolivan, deluvial, proluvial and alluvial processes.

Outsourcing and clustering as a development form of coope- ration in the national service industry of oil and gas production

2020 ◽  
pp. 65-68
Author(s):  
O.B. Huseinli ◽  
Keyword(s):  
Oil And Gas ◽  
Service Industry ◽  
Gas Production ◽  
Service Market ◽  
Gas Field ◽  
Oil And Gas Production ◽  
Service Companies ◽  
Business Customers ◽  
Oil Gas ◽  
Oil Company

The paper reviews the formation prospects of two up-to-date forms of economic cooperation in the sphere of oil and gas production – outsourcing and clustering, as well as the schematic presentation of their implementation. The outsourcing means the execution of the functions on the systematic professional support of working efficiency of the business customer by the operation company under the permanent contract. The outsourcing allows the oil-gas producing company increasing its capitalization and profit amount. Therefore, the oil company can fix innovative, scientific and technological resources in its hands providing maximum meeting of business customers’ demands. The development of oil service cluster, in its turn, aims to provide the interaction of all corporate parties. The establishment of cluster unions in oil-gas field with the participation of petroleum service companies under the principles mentioned in the paper will contribute to the development of both oil-gas complex in a whole and petroleum service market.

Development of Dynamic Tube Blocking Test Method to Study Halite Scale Deposition and Inhibition

2021 ◽  
Author(s):  
Samridhdi Paudyal ◽  
Gedeng Ruan ◽  
Ji-young Lee ◽  
Xin Wang ◽  
Alex Lu ◽  
...  
Keyword(s):  
High Temperature ◽  
Oil And Gas ◽  
Gas Production ◽  
Oil Field ◽  
Test Method ◽  
Bulk Precipitation ◽  
Gas Field ◽  
Oil And Gas Production ◽  
High Temperature And Pressure ◽  
Temperature And Pressure

Abstract Halite scaling has been observed in the oil/gas field with high TDS and low water cut. Due to its higher solubility, slight changes in temperature (T) and pressure (P) and evaporative effect could yield a large amount of scale, causing significant operational problems. Accurate prediction and control of halite scaling in the oil and gas production system have been a challenge. Therefore, this study aims to shed light on the prediction of halite scale formation, deposition behavior, and inhibition at close to oil field conditions. We have designed and developed a dynamic scale loop (DSL) test methodology that can be used at various T and P. The test method utilizes a change in temperature (ΔT) as a driving force to create halite supersaturation and follow with the scale precipitation/deposition. The tube blocking experiments suggest that the tube blockage can be caused by bulk precipitation and or deposition of halite precipitate. SEM analysis of the tube cross-sections indicated that tube blockage, presumably by bulk precipitation, could be seen at the beginning of the reaction tube, but deposition was observed towards the exit end of the tube. Similarly, various experimentation to simulate the water dilution at constant pressure and ΔT were conducted. The effect of the addition of water to prevent halite deposition was analyzed computationally by using ScaleSoftPitzer (SSP) software. Brine compatibility of several inhibitors were tested via bottle tests and autoclave tests and qualified inhibitors were tested in the tube blocking experiments to identify the performance of the inhibitor to treat the halite precipitation at high temperature and pressure. Overall, a robust test method was designed and developed for halite scaling under high temperature and pressure that can simulate the oil and gas production in the field.

scholarly journals A New Production Prediction Model Based on Taylor Expansion Formula

2018 ◽  
Vol 2018 ◽  
pp. 1-12 ◽  
Author(s):  
Xianfeng Ding ◽  
Dan Qu ◽  
Haiyan Qiu
Keyword(s):  
Oil And Gas ◽  
Gas Production ◽  
Taylor Formula ◽  
New Production ◽  
Expansion Formula ◽  
Gas Field ◽  
Oil And Gas Production ◽  
New Model ◽  
Application Range ◽  
Cumulative Production

On the basis of the analysis of the cumulative production growth curve model, the model variables are adjusted, and the Taylor formula is expanded on the adjusted model. Then the appropriate expansion order n is selected, and the new model for the prediction of cumulative production is established. Furthermore, the error of the new model is discussed, and the model can theoretically achieve any given precision. The model can forecast oil and gas production, cumulative production, and recoverable reserves. Finally, the example analyses show that the greater the order number (n) is, the smaller the error between the prediction data and the actual data and the greater the correlation coefficient become. Compared with other models, the results show that the model has higher prediction accuracy and wider application range and can be used to forecast the production of oil and gas field.

scholarly journals Ways to optimize steppe under of oil and gas production

2021 ◽  
Vol 16 (1) ◽  
pp. 76-86
Author(s):  
К. V. Myachina ◽  
E. V. Krasnov
Keyword(s):  
Oil And Gas ◽  
Gas Production ◽  
Gas Field ◽  
Oil And Gas Production ◽  
Multi Scale ◽  
Public Consciousness ◽  
Oil And Gas Field ◽  
The Impact ◽  
Transformation Processes ◽  
Ecological Optimization

Aim. To substantiate ways of geo‐ecological optimization of an oil and gas field landscape (through the example of the Volga‐Ural steppe region).Materials and Methods. The development of directions for geoecological optimization of landscape is based on the authors’ previously developed ideas about the transformation processes of landscape, the formation and stages of the oil and gas natural‐technogenic geosystem development, and the hierarchy and multi‐scale of technogenic changes of landscape.Results. Optimization solutions were developed for the successive stages of planning of oil and gas extraction, operation of an oil and gas natural‐technogenic geosystem field and the end of development and disposal of oil and gas facilities. The main direction of landscape optimization is highlighted and its tasks and principles formulated.Conclusion. Reducing technogenic impact on steppe landscape, its control and regulation is not only a problem of scientific research, but also one of the state of public consciousness and the setting of priorities by management bodies. Methods of reducing the impact and restoringsteppe landscapes can only be effective as a result of implementing a targeted policy of greening education and a corresponding change in public consciousness. 

ADVANCES IN VISUALISATION TECHNOLOGIES: A CASE STUDY, LAHO GAS FIELD—OFFSHORE PENINSULAR MALAYSIA

2004 ◽  
Vol 44 (1) ◽  
pp. 513
Author(s):  
C.M. Gell ◽  
D.E. Meyer ◽  
R.A. Majid ◽  
D.J. Carr
Keyword(s):  
Oil And Gas ◽  
Peninsular Malaysia ◽  
Gas Production ◽  
Wave Form ◽  
Gas Field ◽  
Oil And Gas Production ◽  
3D Data ◽  
New Information ◽  
Multiple Attribute ◽  
3D Volume

A typical problem facing oil company asset teams today is the integration of new information into existing fields. Recently acquired 3D seismic for example, can add much needed detail for understanding reservoirs from producing wells. The key step of interpreting faults and surfaces, on which many other results depend, can often be time consuming and delay efforts to bring additional oil and gas production on-line. Using a volume-based approach to seismic interpretation with today’s visualisation technology, however, can lead to more accurate results produced up to four times faster than traditional line-by-line methods.Over the last four years, visualisation technologies have advanced to the point where these new techniques provide a faster, more geologically correct interpretation and evaluation of potential reservoirs in a shorter amount of time by comparison with line-by-line methods. These advanced techniques include, but are not limited to: multiple attribute voxel interpretation; interpreting fault planes (rather than fault sticks); real-time volume rendering with the ability to create geobodies; quick reconnaissance work in volume; the ability to combine workflows using non-3D volume tools such as wave-form classification with volume interpretation.This paper provides an example of the Laho gas field, offshore Peninsular Malaysia, where two wells were already producing gas and the operator, Petronas Carigali Sdn. Bhd (PCSB), acquired 3D data to evaluate the possibility of additional drilling locations.

Caspian Oil and Gas Leverages Strengths To Survive in a Low-Carbon World

2021 ◽  
Vol 73 (11) ◽  
pp. 23-27
Author(s):  
Pat Davis Szymczak
Keyword(s):  
Soviet Union ◽  
Joint Venture ◽  
Oil And Gas ◽  
Gas Production ◽  
Oil Field ◽  
Low Carbon ◽  
Gas Field ◽  
Oil And Gas Production ◽  
Oil Export ◽  
Oil Company

Nearly 30 years ago as the Soviet Union lay in tatters, Azerbaijan and Kazakhstan signed off on the Caspian’s first oil and gas megaprojects, hoping to guarantee their independence by transforming the region’s energy landscape and their role in it. Nursultan Nazarbayev, then president of Kazakhstan, took the first step in April 1993 by creating Tengizchevroil (TCO), a joint venture between Chevron and Kazakh state oil company KazMunaiGaz, to develop the super-giant Tengiz oil field and nearby Korolev field. Today, Chevron still holds 50% of the venture, ExxonMobil controls 25%, KazMunaiGaz, 20%, and LukArco, a subsidiary of Russia’s Lukoil, 5%. A year and a half later, in September 1994, Azerbaijan’s president, the late Heydar Aliyev, signed a production-sharing agreement (PSA) to develop the deepwater reserves of the Azeri, Chirag, and Gunashli (ACG) fields, attracting the participation of a “who’s who” of the world’s oil and gas elite—13 global companies representing eight countries. These and other signings had a knock-on effect as more upstream megaprojects popped up across the region in the late 1990s and throughout the early 2000s, attracting more international participation and the need to develop midstream infrastructure such as Azerbaijan’s Baku-Tbilisi-Ceyhan pipeline (BTC) export line to Turkey and Kazakhstan’s Caspian Pipeline Consortium (CPC) to Russia’s oil export terminal at Novorossiysk, as landlocked Central Asia devised ways to get its crude oil to market. For a generation, the Caspian’s top-heavy “bigger is better” way of doing things, led by global majors, did a good job of attracting upstream investment. But what about the next generation as those same supermajors rebrand and shift their portfolios to produce more energy with less carbon? Ashley Sherman, research director at Wood Mackenzie for upstream oil and gas, predicted in June that Caspian oil and gas production will continue to grow in this decade as already-committed oil and gas investments percolate through the system (Fig. 1). These investments, however, target expansion and optimization of existing operations. Thus, by 2030, upstream capital expenditures are likely to be at only half of their 2019 levels, Sherman wrote. BP and Socar’s (the state oil company of the Azerbaijan Republic) deepwater Shafag Asiman discovery in Azerbaijan may be an exception, but while a first exploration well drilled and completed in March detected gas condensate, the well was suspended pending further evaluation and possible drilling of a sidetrack appraisal well, BP said in a news release. The block lies 125 km (78 miles) southeast of Baku in an unexplored area in 650-to-800 m water depths. It is likely that tomorrow’s Caspian upstream will look a lot like today’s Caspian upstream, which is dominated by five projects: the onshore Tengizchevroil and Karachaganak projects in Kazakhstan; shallow-water offshore Kashagan, also in Kazakhstan; and Azerbaijan’s offshore deepwater ACG and the Shah Deniz gas field. While each of these projects elicits a definite “wow” factor in terms of sheer size, it is worth noting that the PSAs on which most of the projects are based will expire in the 2030s, though some remain in effect into the 2040s.

scholarly journals Aerial and ground-based optical gas imaging survey of Uinta Basin oil and gas wells

Elem Sci Anth ◽  
2019 ◽  
Vol 7 ◽  
Author(s):  
Seth N. Lyman ◽  
Trang Tran ◽  
Marc L. Mansfield ◽  
Arvind P. Ravikumar
Keyword(s):  
Oil And Gas ◽  
Aerial Survey ◽  
Gas Production ◽  
Oil Well ◽  
Storage Tanks ◽  
Uinta Basin ◽  
Oil And Gas Production ◽  
Liquid Storage ◽  
Ground Survey ◽  
Control Devices

We deployed a helicopter with an infrared optical gas imaging camera to detect hydrocarbon emissions from 3,428 oil and gas facilities (including 3,225 producing oil and gas well pads) in Utah’s Uinta Basin during winter and spring 2018. We also surveyed 419 of the same well pads from the ground. Winter conditions led to poor contrast between emission plumes and the ground, leading to a detection limit for the aerial survey that was between two and six times worse than a previous summertime survey. Because the ground survey was able to use the camera’s high-sensitivity mode, the rate of detected emission plumes was much higher in the ground survey (31% of all surveyed well pads) relative to the aerial survey (0.5%), but colder air temperatures appeared to impair plume detection in the ground survey as well. The aerial survey cost less per facility visited, but the ground survey cost less per emission plume detected. Well pads with detected emissions during the ground and aerial surveys had higher oil and gas production, were younger, were more likely to be oil well pads, and had more liquid storage tanks per pad relative to the entire surveyed population. The majority of observed emission plumes were from liquid storage tanks (75.9% of all observed plumes), including emissions from pressure relief valves and thief hatches on the tank or from piping that connects to the tank. Well pads with control devices to reduce emissions from tanks (combustors or vapor recovery units) were more likely to have detected emissions. This finding does not imply that the control devices themselves were not functioning properly. Instead, gas was escaping into the atmosphere before it reached control devices. Pads with control devices tended to be newer and have higher oil and gas production, which probably explains their higher rate of detected emissions.

scholarly journals TO THE ISSUE OF WASTE WATERS PURIFICATION IN WEST SIBERIA OIL AND GAS FIELD FACILITIES

2015 ◽  
pp. 104-108
Author(s):  
L. A. Parshukova
Keyword(s):  
Oil And Gas ◽  
Open Water ◽  
West Siberia ◽  
Gas Production ◽  
Water Bodies ◽  
Waste Waters ◽  
Gas Field ◽  
Oil And Gas Production ◽  
Oil And Gas Fields ◽  
Oil And Gas Field

The article considers the problems of anthropogenic environmental pollution in the oil and gas fields in West Siberia. Taking into account the experience of wells drilling and statistical reports data there was drawn a map of average many-years pollution of open water bodies in Khanty-Mansi Autonomous Okrug. It is shown that the major pollution is related with drilling wastes in the process of increasing the volumes of drilling and oil and gas production. To reduce the pollution it is offered to use modular plants for treatment of waste waters of BT and BTF type. These plants use will permit to discharge the treated waste waters into the water bodies of fishery purpose.

scholarly journals A high ozone episode in winter 2013 in the Uinta Basin oil and gas region characterized by aircraft measurements

2014 ◽  
Vol 14 (14) ◽  
pp. 20117-20157 ◽  
Author(s):  
S. J. Oltmans ◽  
A. Karion ◽  
R. C. Schnell ◽  
G. Pétron ◽  
C. Sweeney ◽  
...  
Keyword(s):  
Boundary Layer ◽  
Power Plant ◽  
Surface Ozone ◽  
Inversion Layer ◽  
Temperature Inversion ◽  
Gas Production ◽  
Point Sources ◽  
Uinta Basin ◽  
Gas Field ◽  
Near Surface

Abstract. During the winter of 2012–2013 atmospheric surface ozone mole fractions exceeded the US 8 h standard of 75 ppb on 39 days in the Uinta Basin of Utah. As part of the Uinta Basin Winter Ozone Study (UBWOS) aircraft flights were conducted throughout the basin with continuous measurements of ozone (O3), methane (CH4), carbon dioxide (CO2), carbon monoxide (CO), nitrogen dioxide (NO2), and discrete whole air flask samples for determination of ∼50 trace gases including a number of non-methane hydrocarbons (NMHCs). During the course of seven flights conducted between 31 January and 7 February 2013, coinciding with strong, multi-day temperature inversions, O3 levels gradually built up in the shallow boundary layer from ∼45 ppb to ∼140 ppb. Near-surface CH4 mole fractions increased during the episode from near background levels of ∼2 ppm to over 10 ppm. Based on elevated levels of CH4 across the basin and high correlations of CH4 with NMHCs from the discrete air samples, O3 precursor NMHCs were also inferred to be elevated throughout the basin. Discrete plumes of high NO2 were observed in the gas production region of the basin suggesting that gas processing plants and compressor facilities were important point sources of reactive nitrogen oxides (NOx). Vertical profiles obtained during the flights showed that the high O3 mole fractions (as well as other elevated constituents) were confined to a shallow layer from near the ground to 300–400 m above ground level (m a.g.l.) capped by a strong temperature inversion. The highest mole fractions of the measured constituents during the study period were in an isothermal cold layer that varied from ∼300 m depth on 4 February to ∼150 m on 5 February. A gradient layer with declining mole fractions with altitude extended above the isothermal layer to ∼1900 m a.s.l. (300–400 m a.g.l.) indicative of some mixing of air out of the boundary layer. O3 mole fractions continued to increase within the basin as the high O3 episode developed over the course of a week. CH4 mole fractions, on the other hand, leveled off after several days. On several flights, the aircraft sampled the plume of a coal-fired power plant (located east of the main gas field) flowing above the inversion layer. These measurements ruled out the effluents of the power plant as a significant source of NOx for O3 production beneath the temperature inversion in the basin. The presence of elevated O3 precursors within the basin and the rapid daytime production of O3 in the atmosphere beneath the temperature inversion both indicated that O3 was being produced from precursors emitted within the basin beneath the temperature inversion. Although observations show that horizontal winds in the surface layer were relatively light during the high ozone event, they were sufficient to disperse precursors up to 80 km from primary sources in the main gas field in the southeast quadrant to the balance of the Uinta Basin.

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