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.

ENVIRONMENTAL DRILLING SOLUTIONS ON THE POLYMERIC BASIS

2020 ◽  
Author(s):  
E.A. Flik ◽  
◽  
Y.E. Kolodyazhnaya
Keyword(s):  
Oil And Gas ◽  
Drilling Fluid ◽  
Oil And Gas Industry ◽  
Environmental Safety ◽  
Drilling Fluids ◽  
Gas Industry ◽  
Fluid Systems ◽  
Water Based

The article assesses the environmental safety of drilling fluids that are currently widely used in the oil and gas industry. It shows active development of water-based drilling fluid systems using xanthan biopolymer.

scholarly journals A REVIEW OF NANOTECHNOLOGY APPLICATIONS IN THE OIL AND GAS INDUSTRIES

2019 ◽  
pp. 1-14
Author(s):  
B.M. Das ◽  
D. Dutta
Keyword(s):  
Oil Recovery ◽  
Oil And Gas ◽  
New Technology ◽  
Minimum Cost ◽  
Gas Production ◽  
Oil Fields ◽  
Drilling Fluids ◽  
Oil And Gas Production ◽  
Exploration And Production ◽  
Exploration Drilling

Nanotechnology encompasses the science and technology of objects with sizes ranging from 1 nm to 100 nm. Today, exploration and production from conventional oil and gas wells have reached a stage of depletion. Newer technologies have been developed to address this problem. Maximum oil production at a minimum cost is currently a huge challenge. This paper reviews nanotechnology applications in the oil and gas production sector, including in the fields of exploration, drilling, production, and waste management in oil fields, as well as their environmental concerns. The paper reviews experimental observations carried out by various researchers in these fields. The effect of various nanoparticles, such as titanium oxide, magnesium oxide, zinc oxide, copper oxide, and carbon nanotubes in drilling fluids and silica nanoparticles in enhanced oil recovery, has been observed and studied. This paper gives a detailed review of the benefits of nanotechnology in oil exploration and production. The fusion of nanotechnology and petroleum technology can result in great benefits. The physics and chemistry of nanoparticles and nanostructures are very new to petroleum technology. Due to the greater risk associated with adapting new technology, nanotechnology has been slow to gain widespread acceptance in the oil and gas industries. However, the current economic conditions have become a driving force for newer technologies.

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.

Anti-Collapse Drilling Fluids for the Cretaceous Scientific Drilling in Songliao Basin, China: A Case Study

2012 ◽  
Vol 170-173 ◽  
pp. 1196-1201
Author(s):  
Ji Hua Cai ◽  
Xiao Ming Wu ◽  
Sui Gu
Keyword(s):  
Drilling Fluid ◽  
Songliao Basin ◽  
Wellbore Stability ◽  
Drilling Fluids ◽  
Shale Formations ◽  
Scientific Drilling ◽  
Fluid Systems ◽  
Managed Pressure Drilling ◽  
Shale Formation

CCSD-SK1 well was the first Cretaceous scientific drilling well in the world, locating in Songliao basin, Northeast China. It included main well (also called north well) and south well. This paper introduced the anti-collapse drilling fluid technology in main well where the desired continuous coring section was from 164.77 m to 1792.00 m. Continuous technical barriers challenged the intelligence of drilling engineers of this project. First, preserving the wellbore stability was the most critical aspect of continuous core drilling. From top to bottom, the unconsolidated sandstone in the Quaternary super stratum, the water sensitive shale in the Sifangtai group and upper stratum of the Nenjiang group, and the brittle shale of under stratum of the Nenjiang group increased the difficulty of anti-collapse drilling fluid technology. Water invasion into the shale formation often weakens the wellbore and causes problems such as wellbore collapse, shale destabilization and stuck pipe. Fluids should be designed to mitigate these shale problems. Secondly, the openhole strategy imposed the difficulty of maintaining wellbore stability in the second open process (from 245.00 m to the bottom). Finally, the total expense of the well was only one fifth of south well, which was drilled by an oilfield drilling contractor. To overcome these technical challenges, not only different drilling fluid systems such as PAM drilling fluid, DFD-LG-CMC drilling fluid and DFD-NH4HPAN-SAKH drilling fluid were adopted separately, but also technology of feasible viscosity and managed pressure drilling were used. A total of 395 trips had been run in this Cretaceous scientific drilling well and no accidents even dangerous cases occurred. The experience of CCSD-SK1 (main well) explored a successful way of employing economic drilling fluid to preceding similar scientific drilling projects in similar shale formations.

Success Story from Drilling Program Evaluation of Development Wells in 2018 & 2019, and How to Promote An Effective Drilling Program for 2020 and Beyond for Indonesia

2020 ◽  
Author(s):  
S. Faisal
Keyword(s):  
Oil And Gas ◽  
Gas Production ◽  
Oil And Gas Production ◽  
Actual Performance ◽  
Oil Companies ◽  
Drilling Performance ◽  
Production Sharing ◽  
Drilling Parameters ◽  
Drilling Parameter ◽  
Drilling Cost

There are 32 oil companies in Indonesia that will perform development drilling in 2020 with total number of development drilling plans are 395 comparison, there were 289 development wells in 2018 and 322 development wells in 2019 respectively were drilled and contributed to national oil and gas production. All development drilling activities are reported to Satuan Kerja Khusus Pelaksana Kegiatan Usaha Hulu Minyak dan Gas Bumi (SKK Migas) by the Production Sharing Contract (PSC) contractors in the form of spreadsheets. SKK Migas will then evaluate the development drilling performance to be used as references and for consideration in the drilling program approvals for the following year in the Work Program & Budget event. The evaluation includes important drilling parameters. During the last 3 years, SKK Migas has managed to collect data and actual report programs from all PSC’s. Based on that data, an evaluate was exercised and will be used as reference for the next development drilling program for the same PSC or other PSCs which has the similar subsurface challenges or operates in the same areas. This will therefore make a good engineering future plan and will achieve the efficiency of the drilling cost, and can be challenged to be more efficient and effective. For the future, these drilling parameter data will become as benchmark such as a cost/ft or cost/day per PSC per well which is already drilled in Indonesia. There will be more data for PSC’s when making a Plan of Development (POD) proposal from some areas which will be developed into a prospective targets for producing oil and gas, and will also enable SKK Migas to get effective calculations for the related economic issues. This paper will illustrate how SKK Migas manages development drilling program activities in Indonesia using spreadsheets. This paper also illustrates how historical data of actual performance is compared, evaluated and analyzed for future reference.

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.

Electric Impulse Drilling: Future-Orientated HT/HP Analysis of Drilling Fluids

2017 ◽  
Author(s):  
Franziska Lehmann ◽  
Katja Beier ◽  
Anne Schulz ◽  
Erik Anders
Keyword(s):  
Oil And Gas ◽  
Drilling Fluid ◽  
Oil And Gas Industry ◽  
Measuring System ◽  
Drilling Fluids ◽  
Atmospheric Conditions ◽  
High Pressure Cell ◽  
Fluid Systems ◽  
Temperature Regimes ◽  
Electric Impulse

Modern rheological analyses provide good possibilities to understand the deformation and flow of fluids under different conditions. These methods used so far in the food industry as well as in the paints and coatings industry should transferred to the oil and gas industry, especially to the drilling fluid sector, to understand the drilling fluid behavior under borehole conditions. Traditionally, the rheology of drilling fluids is based on measurements under atmospheric conditions. The present study describes a new HT/HP measuring system by Anton Paar GmbH consisting of a modern rheometer including a high-pressure cell. This new system allows rheological analyses under a pressure up to 1000 bar and a temperature up to 300 °C. In consequence it is possible to observe conventional challenges within the drilling fluid sector under new points of view. Within the present study different drilling fluid systems were analyzed under common as well as under new rheological aspects. The results of both measuring systems were compared to each other. Furthermore, drilling fluid properties such as density, filtration and settling behavior were determined under different temperature regimes. Regarding to the operating principle of the electric impulse drilling (EID) technique the electric conductivity plays an important role and has to be taken into account. The results of these tests are also presented shortly.

A Case History: Evaluating Well Completions in the Eagle Ford Shale Using a Data-Driven Approach

2015 ◽  
Author(s):  
Amir M. Nejad ◽  
Stanislav Sheludko ◽  
Robert F. Shelley ◽  
Trey Hodgson ◽  
Riley McFall
Keyword(s):  
Neural Network ◽  
Neural Network Model ◽  
Oil And Gas ◽  
Gas Production ◽  
Data Driven ◽  
Eagle Ford Shale ◽  
Eagle Ford ◽  
Oil And Gas Production ◽  
Treatment Designs ◽  
Different Parts

Abstract Unconventional shale resources are key hydrocarbon sources, gaining importance and popularity as hydrocarbon reservoirs both in the United States and internationally. Horizontal wellbores and multiple transverse hydraulic fracturing are instrumental factors for economical production from shale assets. Hydraulic fracturing typically represents a major component of total well completion costs, and many efforts have been made to study and investigate different strategies to improve well production and reduce costs. The focus of this paper is completion effectiveness evaluation in different parts of the Eagle Ford Shale Formation, and our objective is to identify appropriate completion strategies in the field. A data-driven neural network model is trained on the database comprised of multiple operators' well data. In this model, drilling and mud data are used as indicators for geology and reservoir-related parameters such as pressure, fluid saturation and permeability. Additionally, completion- and fracture-related parameters are also used as model inputs. Because wells are pressure managed differently, normalized oil and gas production is used as a model output. Thousands of neural networks are trained using genetic algorithm in order to fully evaluate hidden correlations within the database. This results in selection of a neural network that is able to understand reservoir, completion and frac differences between wells and identify how to improve future completion/stimulation designs. The final neural network model is successfully developed and tested on two separate data sets located in different parts of the Eagle Ford Shale oil window. Further, an additional test data set comprised of eight wells from a third field location is used to validate the predictive usefulness of the data-driven model. Under-producing wells were also identified by the model and new fracture designs were recommended to improve well productivity. This paper will be useful for understanding the effects of completion and fracture treatment designs on well productivity in the Eagle Ford. This information will help operators select more effective treatment designs, which can reduce operational costs associated with completion/fracturing and can improve oil and gas production.

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