oil and gas development
Recently Published Documents


TOTAL DOCUMENTS

565
(FIVE YEARS 136)

H-INDEX

23
(FIVE YEARS 5)

2022 ◽  
pp. 118073
Author(s):  
Rachel Michaels ◽  
Kevin Eliason ◽  
Teagan Kuzniar ◽  
J. Todd Petty ◽  
Michael P. Strager ◽  
...  

2021 ◽  
Vol 9 ◽  
Author(s):  
Donglei Jiang ◽  
Wenbo Meng ◽  
Yi Huang ◽  
Yi Yu ◽  
Youwei Zhou ◽  
...  

The subsea production system is presently widely adopted in deepwater oil and gas development. The throttling valve is the key piece of equipment of the subsea production system, controlling the safety of oil and gas production. There are many valves with serious throttling effect in the subsea X-tree, so the hydrate formation risk is relatively high. In this work, a 3D cage-sleeve throttling valve model was established by the numerical simulation method. The temperature and pressure field of the subsea throttling valve was accurately characterized under different prefilling pressure, throttling valve opening degree, and fluid production. During the well startup period, the temperature of the subsea pipeline is low. If the pressure difference between the two ends of the pipeline is large, the throttling effect is obvious, and low temperature will lead to hydrate formation and affect the choice of throttling valve material. Based on the analysis of simulation results, this study recommends that the prefilling pressure of the subsea pipe is 7–8 MPa, which can effectively reduce the influence of the throttling effect so that the downstream temperature can be kept above 0°C. At the same time, in regular production, a suitable choke size is opened to match the production, preventing the serious throttling effect from a small choke size. According to the API temperature rating table, the negative impact of local low temperature caused by the throttling effect on the temperature resistance of the pipe was considered, and the appropriate subsea X-tree manifold material was selected to ensure production safety. The hydrate phase equilibrium curve is used to estimate the hydrate formation risk under thermodynamic conditions. Hydrate inhibitors are injected to ensure downstream flow safety.


Author(s):  
Chrystal L. Erickson ◽  
Ileana G. Barron ◽  
Isain Zapata

Background: There is growing concern about the recent increase in oil and gas development using hydraulic fracturing. Studies linking adverse birth outcomes and maternal proximity to hydraulic fracturing wells exist but tend to use individualized maternal and infant data contained in protected health care records. In this study, we extended the findings of these past studies to evaluate if analogous effects detected with individualized data could be detected from non-individualized county-wide aggregated data.Design and Methods: This study used a retrospective cohort of 252,502 birth records from 1999 to 2019 gathered from a subset sample of 5 counties in the state of Colorado where hydraulic fracturing activities were conducted. We used Generalized Linear Models to evaluate the effect of county-wide well density and production data over unidentified birth weight, and prematurity data. Covariates used in the model were county-wide statistics sourced from the US Census.Results: Our modeling approach showed an interesting effect where hydraulic fracturing exposure metrics have a mixed effect directional response. This effect was detected on birth weight when well density, production and their interaction are accounted for. The interaction effect provides an additional interpretation to discrepancies reported previously in the literature. Our approach only detected a positive association to prematurity with increased production.Conclusions: Our findings demonstrate two main points: First, the effect of hydraulic fracturing is detectable by using county-wide unidentified data. Second, the effect of hydraulic fracturing can be complicated by the number of operations and the intensity of the activities in the area.


2021 ◽  
Author(s):  
Alexander Moroz ◽  
Pavel Myakishev ◽  
Nikita Titovsky ◽  
Anton Buyanov ◽  
Oksana Gorbokonenko

Abstract Production surveillance in the producing wells has been an important task for many years in oil and gas development since it provides relevant information useful for the effective management of the HC production. The main objective pursued by operators is to increase the production volume and enhance the oil recovery rate, which often requires some additional well interventions in the existing producing wells. For this purpose, it is necessary to understand how and where to perform stimulations and properly select adequate EOR technologies in order to avoid the risks associated with premature complications of well operation. Usually, production surveillance can be performed using standard logging methods (PLT complex), aimed at the inflow profile monitoring in a well. There are many factors, however, that may complicate the data recording and affect the reliability of the study results. In addition, it is not always possible to shut down the well for production logging purposes. As an alternative approach, it is proposed to consider a technology that involves the placement of special marker-reporters in the bottom-hole zone of the well [3]. The inflow tracers are gradually washed out in the course of production, thus providing the possibility to directly assess the current flow rate, while different codes of productive intervals enable quantification of the production with a phase-wise analysis (hydrocarbon and water) [5]. This paper presents the results of the analysis of reserves recovery in a multi-layer reservoir characterised by relatively low porosity and permeability parameters by means of a tracer-based technology designed for production profiling in directional wells. Surveillance of each productive interval's performance over time was conducted by taking reservoir fluid samples from the mouth of several wells during stable production without well shut-down.


2021 ◽  
Author(s):  
Farasdaq Muchibbus Sajjad ◽  
Alvin Derry Wirawan ◽  
Dharmawan Alfian Rachmadi ◽  
Wingky Suganda ◽  
Dany Susanto ◽  
...  

Abstract As oil and gas development in Indonesia is shifting towards offshore environment, automation is essential for reducing operating cost. PHE ONWJ as the biggest oil and gas operator in Indonesia develops an automated field operation for gas lift optimization, called PiNTAR. PHE ONWJ has been operating gas lift wells for almost 40 years. The biggest challenge is how to efficiently conduct the business operations in offshore environment. The current regular operations (for instance production monitoring) are conducted manually in monthly basis. It is time-consuming and requires long time for trouble shooting. PiNTAR is designed by PHE ONWJ by integrating smart signal system that can be operated remotely without having to be physically presence at the site. The system is integrated with SCADA sensors, satellite system and fully electronic transmitter that sends production data and related parameters to PHE ONWJ head office to be analyzed 24/7 and mitigated if necessary. PiNTAR has been implemented on more than 50 wells in PHE ONWJ working areas. PHE ONWJ also provides interactive Graphical User Interface based software for monitoring and production adjustment purposes. Standardization is also performed therefore PiNTAR can be implemented in a wider area, with different gas lift situations. PiNTAR enables operators to quickly diagnose flow irregularities ranging from adjusting injected Gas Liquid Ratio (GLR) to minimize annular flow, modify choke openings, dynamic reallocation of injected gas from multiple well systems, and also allows the team to comprehend a significant amount of flow characteristics in gas lifted wells as measurements are taken in a very small-time frame, ranging from minutes to seconds. PiNTAR also enables automated production test that enables the construction of real time Gas Lift Performance Curve, which reduces operator workload and enables dynamic gas lift optimization. Implementation of PiNTAR also reduces HSSE risks for rope jumping operations in offshore and increases efficiency of fuel and personnel timing in platform. The publication presents a success story of gas lift automated optimization using in-house development from PHE ONWJ called PiNTAR. Significant monetary efficiency as well as production increase has been observed during the implementation, encouraging the company to pursue further field automation efforts.


2021 ◽  
Vol 4 (1) ◽  
pp. 9-17
Author(s):  
S M Nazmuz Sakib

This writing will focus on the impact on the impact of oil and gas development on the landscape, surface water and groundwater of the Niger Delta – while also assessing the various means of remediation in use. Geologically, the Niger Delta petroleum systems consist of Lower Cretaceous , Upper Cretaceous–lower Paleocene and Tertiary. When Nigeria became an independent nation on 1 October 1960, Shell–BP began to relinquish its acreage and its exploration licenses were converted into prospecting licenses that allowed development and production. The Federal Government of Nigeria started its Department of Petroleum Resources Inspectorate in 1970 and Nigeria joined the Organization of the Petroleum Exporting Countries in 1971. – and in order to take control of the country’s petroleum industry, Nigeria nationalized BP’s holding completely in 1979, and Shell–BP became Shell Petroleum Development Company of Nigeria. Oil spillages routinely occur in the Niger Delta. The official figures of SPDC show that between 1976 and 2001, 6,187 incidents in which 3 million barrels were spilled. The Niger Delta Environmental Survey An impact assessment of the 1983 Oshika oil spill. Spills of crude oil in Niger Delta farmlands have been reported since 1971. In general, toxicity depends on nature and type of crude oil , level of oil contamination, type of environment and degree of selective of individual organisms. Controlled burning effectively reduce the amount of oil in water, if done properly but it must be done in low wind and can cause air pollution. A principal target for emissions reduction is flaring and venting which causes most of the air pollution. Saltwater tanks can be often susceptible to lightning strikes due to build up in static electricity, with the spilled oil spreading to surrounding lands, waterways. This requires a secondary containment of the tanks that makes it easier to clean up the inevitable spill. In cases of expected major storms or flooding events, crude oil can be removed from tank batteries while refilling the tanks with saltwater to prevent them tipping over during the flooding event.


2021 ◽  
Author(s):  
S M Nazmuz Sakib

In Nigeria, the self-proclaimed ‘Giant of Africa’, the same scenario has been playing for the past fifty years to devastating effects especially in the Niger Delta, where oil is extracted in Nigeria. The entry of oil companies into the Niger Delta has no doubt brought great financial wealth. Despite these concerns, multinational oil companies operating in the Niger Delta region have failed to adopt best practice strategies for risks mitigation and comply with environmental regulations. This essay will focus on the impact on the impact of oil and gas development on the landscape, surface water and groundwater of the Niger Delta – while also assessing the various means of remediation in use.A total of about 1,182 exploration wells have been drilled to date in the delta basin, and about 400 oil and gas fields of varying sizes have been documented. Geologically, the Niger Delta petroleum systems consist of Lower Cretaceous, Upper Cretaceous–lower Paleocene and Tertiary. According to , a large portion of the world’s oil and gas reserves are in tertiary terrigenous passive continental margins – accounting for the significant hydrocarbon deposits Nigeria’s Niger Delta. The ecological zones can be broadly grouped into tropical rainforest in the northern part of the Delta and mangrove forest in the warm coastlines of the south.


Sign in / Sign up

Export Citation Format

Share Document