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.

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.

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.

Ghana's petroleum industry: expectations, frustrations and anger in coastal communities

2020 ◽  
Vol 58 (3) ◽  
pp. 397-424
Author(s):  
Jesse Salah Ovadia ◽  
Jasper Abembia Ayelazuno ◽  
James Van Alstine
Keyword(s):  
Oil And Gas ◽  
Local Development ◽  
Petroleum Industry ◽  
Field Research ◽  
Gas Production ◽  
Oil Field ◽  
Oil And Gas Production ◽  
High Expectations ◽  
Petroleum Resources ◽  
Negative Impacts

ABSTRACTWith much fanfare, Ghana's Jubilee Oil Field was discovered in 2007 and began producing oil in 2010. In the six coastal districts nearest the offshore fields, expectations of oil-backed development have been raised. However, there is growing concern over what locals perceive to be negative impacts of oil and gas production. Based on field research conducted in 2010 and 2015 in the same communities in each district, this paper presents a longitudinal study of the impacts (real and perceived) of oil and gas production in Ghana. With few identifiable benefits beyond corporate social responsibility projects often disconnected from local development priorities, communities are growing angrier at their loss of livelihoods, increased social ills and dispossession from land and ocean. Assuming that others must be benefiting from the petroleum resources being extracted near their communities, there is growing frustration. High expectations, real and perceived grievances, and increasing social fragmentation threaten to lead to conflict and underdevelopment.

Solubility Of Common Oil Field Scales Of Injection Water And High–barium Concentration And High–salinity Formation Water

2012 ◽  
Author(s):  
Amer Badr Merdhah ◽  
Abu Azam Mohd Yassin
Keyword(s):  
Oil And Gas ◽  
High Salinity ◽  
Sea Water ◽  
Water Injection ◽  
Gas Production ◽  
Oil Field ◽  
Formation Water ◽  
Oil And Gas Production ◽  
Barium Concentration ◽  
Injection Water

Kerak pemendapan merupakan satu daripada masalah paling penting dan serius dalam sistem suntikan air. Kerak kadangkala mengehadkan atau menghalang penghasilan gas dan minyak melalui penyumbatan matrik atau perpecahan pembentukan minyak dan jeda yang berlubang. Makalah ini mengetengahkan kesimpulan pengukuran makmal bagi kerak terbentuk di dalam keterlarutan medan minyak biasa dalam sintetik air masin (pembentukan air dan air laut) bagi pembentukan air yang mengandungi barium dan kandungan garam yang tinggi pada suhu 40 hingga 90°C pada tekanan atmosfera. Keputusan uji kaji mengesahkan pola kebergantungan keterlarutan bagi kerak medan minyak biasa pada keadaan ini. Pada suhu yang lebih tinggi, kerak bagi CaCO3, CaSO4, dan SrSO4 meningkat manakala kerak BaSO4 menurun disebabkan oleh keterlarutan CaCO3, CaSO4, dan SrSO4 menurun dan keterlarutan BaSO4 meningkat dengan kenaikan suhu. Kata kunci: Masalah pengskalaan; skala keterlarutan; paras kandungan garam tinggi; logam barium tinggi Scale deposition is one of the most important and serious problems which water injection systems are generally engaged in. Scale sometimes limits or blocks oil and gas production by plugging the oil–producing formation matrix or fractures and the perforated intervals. This paper presents a summary of the laboratory measurements of the solubility of common oil field scales in synthetic brines (formation water and sea water) of high–barium and high–salinity formation waters at 40 to 90°C and atmospheric pressure. The experimental results confirm the general trend in solubility dependencies for common oil field scales at these conditions. At higher temperatures the deposition of CaCO3, CaSO4 and SrSO4 scale increases and the deposition of BaSO4 scale decreases since the solubilities of CaCO3, CaSO4 and SrSO4 scales decreases and the solubility of BaSO4 increases with increasing temperature. Key words: Scaling problems; solubility of scale; high salinity; high barium

Ultrahigh-Temperature/Ultrahigh-Pressure Scale Control for Deepwater Oil and Gas Production

SPE Journal ◽  
2012 ◽  
Vol 17 (01) ◽  
pp. 177-186 ◽  
Author(s):  
C.. Fan ◽  
W.. Shi ◽  
P.. Zhang ◽  
H.. Lu ◽  
N.. Zhang ◽  
...  
Keyword(s):  
Thermal Stability ◽  
High Temperature ◽  
Oil And Gas ◽  
Gas Production ◽  
Ultrahigh Pressure ◽  
Flow Loop ◽  
Oil And Gas Production ◽  
Loop Method ◽  
Ultrahigh Temperature ◽  
Scale Control

Summary Scale control in deepwater oil and gas production is often challenging not only because of the geological and mechanical limitations associated with deepwater wells, but also because of the high-temperature (>150°C) and high-pressure (>10,000 psi) (HT/HP) environment, which may be associated with brine containing high total dissolved solids (TDSs) (>300,000 mg/L). These extreme conditions make scale prediction, control, and testing difficult because of the requirements for special alloys, pumps, and control equipment that are not readily available. Therefore, few reliable ultrahigh-temperature/ultrahigh-pressure (ultra-HT/HP) data are available. To overcome such challenges, an efficient flow-loop method has been established to study both the equilibrium and the kinetics of scale formation and inhibition at ultra-HT/HP conditions. This paper will discuss (1) an efficient flow-loop method to study the solubility of scale minerals at ultra-HT/HP conditions, (2) solubility of barite at temperature up to 200°C and pressure up to 20,000 psi, and (3) scale control and inhibitor selection for deepwater oil and gas production at ultra-HT/HP conditions. Specifically, the performance and thermal stability of some common scale inhibitors at the high-temperature conditions were studied in terms of barite-scale inhibition. The results to date indicated that (1) the solubility of barite at up to 200°C and 24,000 psi can be measured precisely by this newly developed flow-loop apparatus, (2) the rate of mineral scale formation at HT/HP may be considerably faster than previously projected from low-temperature studies and, hence, difficult to inhibit, (3) different scale inhibitors have shown considerably different thermal stability. The results and findings from these studies validate a new HT/HP apparatus for scale and inhibitor testing and information for better scale control at HT/HP conditions.

Design of Sand Washing and Plug Removal Device with High Pressure Foam Fluid Jet

2012 ◽  
Vol 155-156 ◽  
pp. 722-725
Author(s):  
Wen Bin Cai ◽  
Guo Wei Qin ◽  
Yan He
Keyword(s):  
High Pressure ◽  
Oil And Gas ◽  
Horizontal Wells ◽  
Gas Production ◽  
Oil Field ◽  
Good Effect ◽  
Well Bore ◽  
Sand Production ◽  
Oil And Gas Production ◽  
And Performance

In the oil and gas production process, serious sand production causes reservoir and pipe blocked, which makes productivity declined, even stopped. It's the efficient means of sand washing and plug removal by using high-pressure foam fluid jet. The structure and performance of sand washing device determines the efficiency of sand washing and plug removal. The device's nozzle consists of anti-blocking valves, three kinds of nozzles with self-drive, rotation characteristics during the operation. The nozzles include sand washing nozzle, couple nozzle and power nozzle. This device can be used in horizontal wells with complex well bore situation to carry out sand and plug removal. The device has a good effect on sand washing and plug removal in the oil field.

Research and Application of the Deep Horizontal Drilling and Completion Technology for Liaohe Oilfield Buried Hill Reservoir

2012 ◽  
Vol 241-244 ◽  
pp. 1396-1399
Author(s):  
Gui Min Nie ◽  
Dan Guo ◽  
Yan Wang ◽  
Xiao Wei Cheng
Keyword(s):  
Oil And Gas ◽  
Drilling Fluid ◽  
Horizontal Wells ◽  
Gas Production ◽  
Oil Field ◽  
Oil And Gas Production ◽  
Horizontal Drilling ◽  
Liaohe Oilfield ◽  
Buried Hill ◽  
Composite Drilling

With the depletion of shallow-layer oil and gas pools inLiaohe oilfield, buried hill stratigraphic reservoirs in Liaohe oil field are becoming main objectives for exploration in recent years, especially in high-risk areas of Xinglongtai deep the Hing ancient buried hill resources are particularly rich. Since 2007, Liaohe oilfield increased investment for Buried Hill reservoirs with deep horizontal drilling developt the buried hill reservoir. Liaohe has completed 36 deep horizontal, with a total footage of 183920m, the average depth of 5109m. Improving drilling speed of "buried hill deep horizontal and branch horizontal wells”, and reducing drilling costs are of great urgency. “Hing buried hill deep horizontal, horizontal wells,” with composite drilling technology, supporting the optimization of PDC bits, the high-pressure jet drilling, the MWD borehole trajectory control and optimization of drilling parameters, the new drilling fluid technology and so on. With a large number of horizontal wells put into Buried Hill stratigraphic reservoirs, oil and gas production of average deep horizontal well increase of 2-5 times. Besides, the previous recovery and production of oil and gas reservoirs significantly improved to create an objective economic and social benefits.

Alaska’s North Slope May Yet See Its Renaissance in Arctic Exploration

2021 ◽  
Vol 73 (10) ◽  
pp. 17-22
Author(s):  
Pat Davis Szymczak
Keyword(s):  
Oil And Gas ◽  
Barents Sea ◽  
Oil And Gas Industry ◽  
Gas Production ◽  
Oil Field ◽  
The Arctic ◽  
Energy Information Administration ◽  
Gas Field ◽  
The Us ◽  
Arctic Exploration

It wasn’t too long ago that Arctic oil and gas exploration enjoyed celebrity status as the industry’s last frontier, chock full of gigantic unexplored hydrocarbon deposits just waiting to be developed. Fast forward and less than a decade later, the same climate change that made Arctic oil and gas more accessible has caused an about-face as governments and the world’s supranational energy companies rebrand and target control of greenhouse gases (GHG) to achieve carbon neutrality by 2050. Among countries with Arctic coastlines, Canada has focused its hydrocarbon production on its oil sands which sit well below the Arctic Circle; Greenland has decided to not issue any new offshore exploration licenses (https://jpt.spe.org/greenland-says-no-to-oil-but-yes-to-mining-metals-for-evs), and while Norway is offering licenses in its “High North,” the country can’t find many takers. The Norwegian Petroleum Directorate (NPD) reported that while 26 companies applied for licenses in 2013, this year’s bid round attracted only seven participants. Norway is Europe’s largest oil producer after Russia with half of its recoverable resources still undeveloped and most of that found in the Barents Sea where the NPD says only one oil field and one gas field are producing. That leaves Russia and the US—geopolitical rivals which are each blessed with large Arctic reserves and the infrastructure to develop those riches—but whose oil and gas industries play different roles in each nation’s economy and domestic political intrigues. Russia sees its Arctic reserves, particularly gas reserves, as vital to its national security, considering that oil and gas accounts for 60% of Russian exports and from 15 to 20% of the country’s gross domestic product (GDP), according to Russia’s Skolkovo Energy Centre. With navigation now possible year­round along the Northern Sea Route, Russia’s LNG champion and its largest independent gas producer, Novatek, is moving forward with exploration to expand its resource base and build infrastructure to ship product east to Asia and west to Europe. https://jpt.spe.org/russian­lng­aims­high­leveraging­big­reserves­and­logistical­advantages As a result, Russia’s state­owned majors—Rosneft, Gazprom, and Gazprom Neft—are lining up behind their IOC colleague as new investment in Arctic exploration and development is encouraged and rewarded by the Kremlin. In contrast, the American Petroleum Institute reports that the US oil and gas industry contributes 8% to US GDP, a statistic that enables the US to have a more diverse discussion than Russia about the role that oil and gas may play in any future energy mix. That is unless you happen to be from the state of Alaska where US Arctic oil and gas is synonymous with Alaskan oil and gas, and where the US Geological Survey estimates 27% of global unex­plored oil reserves may lie. Though Alaska is responsible for only 4% of US oil and gas production, those revenues covered two-thirds of Alaska’s state budget in 2020 despite the state’s decline in crude production in 28 of the past 32 years since it peaked at 2 million B/D in 1988, according to the US Energy Information Administration (EIA).

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.

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