Experimental Study of Pipe Pulling Through Settled Barite

2019 ◽  
Author(s):  
Ali Taghipour ◽  
Torbjørn Vrålstad ◽  
Ragnhild Skorpa ◽  
Mohammad Hossain Bhuiyan ◽  
Jan David Ytrehus ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Drilling Fluid ◽  
Gas Production ◽  
Solid Particles ◽  
Cement Slurry ◽  
Oil And Gas Production ◽  
Field Development ◽  
Steel Pipes ◽  
Well Completion ◽  
Side Track

Abstract Wells are essential in oil and gas production and construction of them is one of the main cost drivers for field development. It is normally needed to drill and construct new wells from existing fields during most of the production time. In order to reduce costs one can re-use parts of existing wells when they are no longer efficient. This is done in offshore fields also when there is limitation for new wells due to capacity of the subsea template. Through tubing drilling is a method to drill a side track through the wellbore tubulars. However, this will normally result in a smaller and less effective well completion. Removing parts of the casing section and drill a larger size sidetrack is an option to provide a new full-size wellbore. Removing the 9 5/8” casing through the settled particle in the annulus can be challenging. The wellbore annulus is normally filled with old drilling fluid, displacing fluid and/or cement slurry. The solid particles of these annular fluids are settled during years of shut-in and make it difficult to move the casing sections. There are several techniques for pulling the casing section, but there is a lack of knowledge of some of the key mechanism causing the resistance in these operations. In order to study and address the dominating effects in these operations, down-scaled laboratory tests are performed. The experiments reported here are performed by pulling steel pipes through the settled barite in the annulus. The pipes used in the tests are down-scaled from typical casing sizes with and without collars. The barite slurry compacted inside the annulus have different hydrostatic and pore pressures. When the pipe is pulled the required mechanical force is measured. Results show that the single most significant factor causing resistance when pulling the tubulars is the collars outside the pipe. Furthermore, it is identified that the pore pressure improves the mobility of the settled particle around the collar. In total these results provide improved understanding on the dominating factors during pulling pipes from a packed annulus.

The Effect of Opal-Containing Rocks on the Properties of Lightweight Oil-Well Cement

2021 ◽  
Vol 325 ◽  
pp. 47-52
Author(s):  
Fedor L. Kapustin ◽  
N.N. Bashkatov ◽  
Rudolf Hela
Keyword(s):  
Flexural Strength ◽  
Oil And Gas ◽  
Gas Production ◽  
Cement Stone ◽  
Oil Well ◽  
Cement Slurry ◽  
Water Separation ◽  
Oil And Gas Production ◽  
Geological Conditions ◽  
Cement Grinding

When constructing deep wells for oil and gas production in difficult geological conditions, special lightweight oil-well cements are used. To reduce the density and water separation of the cement slurry as well as to increase the strength, corrosion resistance of cement stone and the quality of well cementing, opal-containing rocks, fly ash, microsphere and other lightening additives are introduced into the cement composition. The influence of sedimentary rocks, such as opoka, tripoli, and diatomite containing from 43 to 81% amorphous silica on the grindability, rheological and physical-mechanical properties of lightweight oil-well Portland cement has been studied. The twelve cement compositions with different content of additives (from 30 to 45%) that meet the requirements of the standard for density, spreadability, water separation, thickening time and flexural strength were selected. The introduction of 45% diatomite or tripoli significantly reduces the duration of cement grinding, provides the cement slurry with water-cement ratio of 0.9 with better density and flexural strength, respectively, 1480 kg/m3 and 1.1–1.5 MPa.

scholarly journals ANTHROPOGENIC INFLUENCE OF THE KOMSOMOLSK OIL AND GAS CONDENSATE FIELD ON MODERN DEFORMATION PROCESSES

2018 ◽  
pp. 11-20 ◽  
Author(s):  
Yu. V. Vasilev ◽  
D. A. Misyurev ◽  
A. V. Filatov
Keyword(s):  
Oil And Gas ◽  
Gas Production ◽  
Gas Condensate ◽  
Industrial Safety ◽  
Subsidence Trough ◽  
Oil And Gas Production ◽  
Field Development ◽  
Repeated Observations ◽  
Deformation Processes ◽  
The Relationship

The authors created a geodynamical polygon on the Komsomolsk oil and gas condensate field to ensure the industrial safety of oil and gas production facilities. The aim of its creation is mul-tiple repeated observations of recent deformation processes. Analysis and interpretation of the results of geodynamical monitoring which includes class II leveling, satellite observations, radar interferometry, exploitation parameters of field development provided an opportunity to identify that the conditions for the formation of recent deformations of the earth’s surface is an anthropogenic factor. The authors identified the relationship between the formation of subsidence trough of the earth’s surface in the eastern part of the field with the dynamics of accumulated gas sampling and the fall of reservoir pressures along the main reservoir PK1 (Cenomanian stage).

Laboratory-Scale Investigation of the Utilisation of Multiple Flat-Fan Nozzles in Descaling Petroleum Production Tubing

2021 ◽  
Author(s):  
Kabir Hasan Yar'Adua ◽  
Idoko Job John ◽  
Abubakar Jibril Abbas ◽  
Salihu M. Suleiman ◽  
Abdullahi A. Ahmadu ◽  
...  
Keyword(s):  
High Pressure ◽  
Oil And Gas ◽  
Gas Production ◽  
Oil And Gas Production ◽  
Scale Removal ◽  
Petroleum Production ◽  
Well Completion ◽  
Water Jets ◽  
Well Integrity ◽  
Injection Pressures

Abstract Despite the recent wide embrace of mechanical descaling approaches for cleaning scales in petroleum production tubings and similar conduits with the use of high-pressure (HP) water jets, the process is still associated with downhole backpressure and well integrity challenges. While the introduction of sterling beads to replace sand particles in the water recorded high successes in maintaining well completion integrity after scale removal in some recent applications of this technique, it is, unfortunately, still not without questions of environmental degradation. Furthermore, the single nozzle, solids-free, aerated jetting descaling technique – recently published widely – is categorized with low scale surface area of contact, low descaling efficiency and subsequent high descaling rig time. The modifications to mechanical descaling techniques proposed in this work involve the use of three high-pressure flat fan nozzles of varying nozzles arrangements, standoff distances and injection pressures to remove soft scale deposits in oil and gas production tubings and similar circular conduits. This experiment provides further insights into the removal of paraffin scales of various shapes at different descaling conditions of injection pressures, stand-off distances and nozzle arrangements with the use of freshwater. The results obtained from this study also show consistency with findings from earlier works on the same subject.

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.

scholarly journals Experimental Investigation of Inhibitive Drilling Fluids Performance: Case Studies from United States Shale Basins

Energies ◽  
2020 ◽  
Vol 13 (19) ◽  
pp. 5142
Author(s):  
Nabe Konate ◽  
Saeed Salehi
Keyword(s):  
Oil And Gas ◽  
Drilling Fluid ◽  
Gas Production ◽  
Drilling Fluids ◽  
Eagle Ford Shale ◽  
Oil And Gas Production ◽  
Shale Formations ◽  
Drilling Performance ◽  
Marine Shale ◽  
Fluid Systems

Shale formations are attractive prospects due to their potential in oil and gas production. Some of the largest shale formations in the mainland US, such as the Tuscaloosa Marine Shale (TMS), have reserves estimated to be around 7 billion barrels. Despite their huge potential, shale formations present major concerns for drilling operators. These prospects have unique challenges because of all their alteration and incompatibility issues with drilling and completion fluids. Most shale formations undergo numerous chemical and physical alterations, making their interaction with the drilling and completion fluid systems very complex to understand. In this study, a high-pressure, high-temperature (HPHT) drilling simulator was used to mimic real time drilling operations to investigate the performance of inhibitive drilling fluid systems in two major shale formations (Eagle Ford Shale and Tuscaloosa Marine Shale). A series of drilling experiments using the drilling simulator and clay swelling tests were conducted to evaluate the drilling performance of the KCl drilling fluid and cesium formate brine systems and their effectiveness in minimizing drilling concerns. Cylindrical cores were used to mimic vertical wellbores. It was found that the inhibitive muds systems (KCl and cesium formate) provided improved drilling performance compared to conventional fluid systems. Among the inhibitive systems, the cesium formate brine showed the best drilling performances due to its low swelling rate and improved drilling performance.

Critical Liquid Velocities for Low Concentration Sand Transport

2011 ◽  
Author(s):  
Alan L. Hill ◽  
Balbino Arevalo ◽  
Faisal M. Almutahar ◽  
Brenton S. McLaury
Keyword(s):  
Critical Velocity ◽  
Oil And Gas ◽  
Liquid Velocity ◽  
Gas Production ◽  
Solid Particles ◽  
Sand Transport ◽  
Particle Volume ◽  
Horizontal Pipe ◽  
Oil And Gas Production ◽  
Definition Of

The transport of solid particles is a concern for several industries and has been the source of extensive research for many years. One topic that has been studied is the critical velocity required to transport particles, but the transport behavior used to determine the critical velocity can be different. For example, one commonly defined critical velocity is the minimum velocity necessary to keep the particles fully suspended. However, this study examined the sand behavior with two different definitions for critical velocity. The first definition simply requires the sand to move enough to prevent a permanent bed from forming. The sand behavior when this velocity requirement is met can be described as intermittent scouring and stopping. All particles do not need to move continuously. The second definition of critical liquid velocity requires the sand particles to continuously move along the bottom of the pipe. The sand behavior when this velocity requirement is met is described as continuous scouring and not fully suspended. Numerous past experiments have amassed a significant amount of slurry data, but the majority of the data is for particle volume concentrations greater than 1%. However for many cases such as in oil and gas production, particle concentrations much below 1% are present. So to examine transport for lower concentrations, experiments were conducted for volume concentrations of 0.01%, 0.1%, and 1%. Three different sand diameters and two different liquid viscosities were also used to observe their effects on the critical liquid velocities. All tests were conducted in transparent, horizontal pipe to observe particle behavior. Results have shown that as particle size, concentration, and liquid viscosity increase, the required critical liquid velocity also increases. Experimental results are compared to existing data and models to examine the effect of concentration, focusing on volume concentrations below 1%.

scholarly journals Analysis of the results of geodynamic monitoring at the Kogalym oil field of LUKOIL-AIK LLC

2020 ◽  
pp. 31-41
Author(s):  
Yu. V. Vasilev ◽  
D. A. Misyurev ◽  
D. P. Inozemtsev ◽  
P. I. Bezhan
Keyword(s):  
Oil And Gas ◽  
Gas Production ◽  
Oil Field ◽  
Industrial Safety ◽  
Anthropogenic Factor ◽  
Oil And Gas Production ◽  
Field Development ◽  
Repeated Observations ◽  
Geodynamic Monitoring ◽  
Deformation Processes

The article gives valuable information on geodynamic monitoring. We created a geodynamical polygon to ensure the industrial safety of oil and gas production facilities. It was created on the Kogalym oil field for multiple repeated observations of recent deformation processes. Analysis and interpretation of the results of geodynamical monitoring: satellite observations, exploitation parameters of field development provided an opportunity to identify that an anthropogenic factor is one of the conditions for the formation of recent deformations of the Earth's surface.

Fraccing forum

2016 ◽  
Vol 56 (1) ◽  
pp. 51
Author(s):  
Maxwell Williamson
Keyword(s):  
Hydraulic Fracture ◽  
Oil And Gas ◽  
South Australia ◽  
Gas Production ◽  
Scientific Practices ◽  
The European Union ◽  
Oil And Gas Production ◽  
Well Completion ◽  
The Us ◽  
Hydraulic Fracture Stimulation

There have been 13 major inquiries completed during the past few years that have addressed the issue of hydraulic fracture stimulation (fraccing) in Australia. There are two inquiries due to report before mid-2016; namely in SA (Natural Resources Committee, Parliament of South Australia, 2015), and the Senate Inquiry (Parliament of Australia, 2015). These inquiries are in addition to many others conducted in overseas jurisdictions including various states of the US, Canada, and in countries in the European Union, including the UK. Concerns are usually concluded around ensuring there is a proper regulatory environment to confirm that the use of fraccing is conducted using international best practices, and the risk to the environment is minimised. In each and every responsible inquiry the conclusion has been that there is no scientific or public policy reason that would justifiably prevent the use of fraccing as a pre-well completion stimulation technique. This paper attempts to synthesise basic data about fraccing—why the ability to fracture stimulate wells is no longer a luxury but a necessity in deep oil and gas production—to convey factual information and summarise the results of inquiries in Australia to date. Comparisons between hydraulic fracture stimulation operations and results in the US and Australia are intended to provide comfort that some of the potentially more intense (massive) hydraulic fracture stimulation operations routinely conducted in the US (and Canada) on an individual well basis are not contemplated in the immediate future in Australia. The scale of North American fraccing activities may bear little resemblance to what may be proposed or occur in Australia owing to fundamental differences in geology, basin stress regimes, infrastructure, and cost and logistics, among other factors. The author’s conclusion is that fraccing in Australia can and will be carried out in a sphere of safety and regulation that many other countries are likely to aspire to copy. It would, however, be foolish to suggest hydraulic fracturing operations are not without some risk, as with many industrial and other daily activities, but the risks can be managed or mitigated with sound engineering and scientific practices. This is irrespective of the messages by opponents of hydraulic fracture stimulation in oil and gas wells. The modern practice of fraccing has been used now for more than 65 years, albeit with increasing scale commensurate with technological advances, which has caught the public’s imagination. Indeed, the results of inquiries have given no credence to demonising the technology.

scholarly journals Intelligent Technologies in the Oil and Gas Industry

2019 ◽  
Vol 105 ◽  
pp. 01003
Author(s):  
Sergey Milyushenko
Keyword(s):  
Oil And Gas ◽  
New Technologies ◽  
Oil And Gas Industry ◽  
Gas Production ◽  
Production Costs ◽  
Gas Industry ◽  
Oil And Gas Production ◽  
Field Development ◽  
Oil And Gas Resources ◽  
Smart Technologies

The article is devoted to the discussion of improving the quality of oil and gas production, through the introduction of new technologies for the extraction and processing of natural resources. As well as to the procedure, which aims to ensure the increase in the volume of mineral resource (liquid hydrocarbons) and to optimization of production costs in modern enterprises of oil and gas industry. The development of “smart” technologies in the oil and gas industry is mainly associated with a reduction in proven oil and gas resources in the Russian Federation. However, there are oil and gas reserves in places with an unfavorable climate, which significantly increases the cost of developing such deposits. For solving this problem, the “smart” technology “Smart Field” development is proposed.

scholarly journals A Genetic Algorithm Integrated with Monte Carlo Simulation for the Field Layout Design Problem

2018 ◽  
Vol 73 ◽  
pp. 24 ◽  
Author(s):  
Leonardo de Pádua Agripa Sales ◽  
Anselmo Ramalho Pitombeira-Neto ◽  
Bruno de Athayde Prata
Keyword(s):  
Genetic Algorithm ◽  
Monte Carlo Simulation ◽  
Monte Carlo ◽  
Design Problem ◽  
Oil And Gas ◽  
Probabilistic Approach ◽  
Layout Design ◽  
Gas Production ◽  
Oil And Gas Production ◽  
Field Development

Oil and gas production is moving deeper and further offshore as energy companies seek new sources, making the field layout design problem even more important. Although many optimization models are presented in the revised literature, they do not properly consider the uncertainties in well deliverability. This paper aims at presenting a Monte Carlo simulation integrated with a genetic algorithm that addresses this stochastic nature of the problem. Based on the results obtained, we conclude that the probabilistic approach brings new important perspectives to the field development engineering.

Sign in / Sign up

Export Citation Format

Share Document