High Density Fluids Customization and Field Application in Khursaniyah Challenging Wells

Gad-Alla, Ahmed E; Pino, Rafael; Ezi, P. C.; Zayer, Nadeer; Hudaithi, Mohammad Al; Addagalla, Ajay; Kosandar, Balraj; Jadhav, Prakash; Lawal, Ishaq; Imran, Aqeel; Hassan, Omran

doi:10.2118/183997-ms

Cited by 10 publications

(3 citation statements)

References 6 publications

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“…Rheological property control: A drilling fluid with high density is required to develop control over hydrostatic pressure and well control [91]. The rheology properties of high-volume fraction of weight material in drilling fluid must be properly controlled.…”

Section: Hpht Drilling Fluid Challengesmentioning

confidence: 99%

Nanomaterial-Based Drilling Fluids for Exploitation of Unconventional Reservoirs: A Review

et al. 2020

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The world’s energy demand is steadily increasing where it has now become difficult for conventional hydrocarbon reservoir to meet levels of demand. Therefore, oil and gas companies are seeking novel ways to exploit and unlock the potential of unconventional resources. These resources include tight gas reservoirs, tight sandstone oil, oil and gas shales reservoirs, and high pressure high temperature (HPHT) wells. Drilling of HPHT wells and shale reservoirs has become more widespread in the global petroleum and natural gas industry. There is a current need to extend robust techniques beyond costly drilling and completion jobs, with the potential for exponential expansion. Drilling fluids and their additives are being customized in order to cater for HPHT well drilling issues. Certain conventional additives, e.g., filtrate loss additives, viscosifier additives, shale inhibitor, and shale stabilizer additives are not suitable in the HPHT environment, where they are consequently inappropriate for shale drilling. A better understanding of the selection of drilling fluids and additives for hydrocarbon water-sensitive reservoirs within HPHT environments can be achieved by identifying the challenges in conventional drilling fluids technology and their replacement with eco-friendly, cheaper, and multi-functional valuable products. In this regard, several laboratory-scale literatures have reported that nanomaterial has improved the properties of drilling fluids in the HPHT environment. This review critically evaluates nanomaterial utilization for improvement of rheological properties, filtrate loss, viscosity, and clay- and shale-inhibition at increasing temperature and pressures during the exploitation of hydrocarbons. The performance and potential of nanomaterials, which influence the nature of drilling fluid and its multi-benefits, is rarely reviewed in technical literature of water-based drilling fluid systems. Moreover, this review presented case studies of two HPHT fields and one HPHT basin, and compared their drilling fluid program for optimum selection of drilling fluid in HPHT environment.

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Section: Hpht Drilling Fluid Challengesmentioning

confidence: 99%

Nanomaterial-Based Drilling Fluids for Exploitation of Unconventional Reservoirs: A Review

et al. 2020

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“…Accordingly, there were extended attempts to come up with an applicable weighting agent to match the requirements for such growth in the drilling activities for ultradeep drilling. This leads to broadening the use of various substances as weighting agents such as ilmenite, hematite, micromax, manganese tetroxide, micromanganese, dolomite, Tiro (Stibnite), Kaun (Potash), and galena as alternative weighting agents to be used in the drilling fluid instead of the predominant agent (barite) in different areas of the world, − which disseminate the use of the local resources of the weighting agents and cut the cost of the drilling operations. The demand has extended to formulate the drilling fluid with a mixture of weighting agents such as barite–micromax, barite–ilmenite, and hematite–barite, to minimize the associated issues and yield higher stability to increase the drilling efficiency.…”

Section: Introductionmentioning

confidence: 99%

Effect of Different Weighting Agents on Drilling Fluids and Filter Cake Properties in Sandstone Formations

et al. 2021

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Weighting agents such as barite, micromax, ilmenite, and hematite are commonly added to drilling fluids to produce high-density fluids that could be used to drill deep oil and gas wells. Increasing the drilling fluid density leads to highly conspicuous fluctuation in the drilling fluid characteristics. In this study, the variation in the drilling fluid's rheological and filtration properties induced by adding different weighting agents was evaluated. For this purpose, several water-based drilling fluid samples were prepared and weighted up using the same concentration of various weighting materials including barite, micromax, ilmenite, and hematite. The characteristics of the used weighting agents' (particle size distribution and mineralogy) were measured. Subsequently, the rheological properties of the drilling fluid were obtained using a Fann viscometer at 80 °F. The filtration test was carried out at 200 °F and 300 psi differential pressure to form a filter cake over the sandstone core samples. The properties of the formed filter cake layer such as thickness, porosity, and permeability were determined. Furthermore, the typical properties of core samples including porosity and permeability were assessed before and after the filtration test. The displayed results confirmed that the plastic viscosity (PV), yield point (YP), and filter cake sealing properties were all significantly influenced by the ratio of the large to fine particle size (D 90 /D 10 ) of the weighting agents irrespective of the weighting material type. Among the examined weighting agents, barite showed novel potency to control both rheological and filter cake properties for 14 ppg drilling fluid. The results showed that D 90 /D 10 is a key factor for the PV and YP properties as increasing the D 90 /D 10 ratio caused PV increase and YP decrease, which indicated that the interaction among the loaded weighting materials in the drilling fluid dominated its viscosity.

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“…Many materials were used as weighting agents over the years, and researchers are still looking for new materials and ways to improve the existing ones. Examples of common weighting materials include barite, calcium carbonate, ilmenite, hematite, manganese tetroxide (Micromax), galena, stibnite, and potash. − One potential method to improve the weighting material performance is by reducing its particle size; this introduced more options such as micronized barite, micronized ilmenite, and micronized manganese tetroxide as weighting materials. − Furthermore, other researchers used a mixture of several weighting materials with the aim of mitigating drilling instability issues such as barite sagging and of improving the drilling mud properties. , Also, nanoparticles were investigated as weighting agents by several studies that showed a general improvement in the drilling fluid properties. ,− Accordingly, selecting the right weighting material is not a trivial task and it depends on many factors including the cost, the required properties (i.e., density), and its solubility in conventional filter cake removal treatments since it affects approximately 70–80% of the filter cake structure …”

Section: Introductionmentioning

confidence: 99%

The Role of Drilled Formation in Filter Cake Properties Utilizing Different Weighting Materials

et al. 2021

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The filter cake formed during a filtration process plays a vital role in the success of a drilling operation. There are several factors affecting the filter cake build-up such as drilled formation, drilling fluid properties, and well pressure and temperature. The collective impact of these two factors (i.e., formation and the drilling fluid) on the filter cake build-up needs to be fully investigated. In this study, two types of formations represented as limestone and sandstone were used with different weighting materials to assess and compare their impact on the filter cake properties, filtration behavior, and solid invasion. The used weighting materials are manganese tetroxide, ilmenite, barite, and hematite. The filter cake was formed under a temperature of 200 °F and differential pressure of 300 psi. Nuclear magnetic resonance spectroscopy was employed to explore the pore structure of the used core samples. The results showed that the properties (i.e., shape and dimensions) of the different weighting materials are the dominant factors compared to the formation characteristics in most of the investigated filter cake properties. Nevertheless, the formation properties, namely, the permeability and pore structure, have a somehow higher contribution when it comes to the filter cake porosity and thickness. For solid invasion, there were no clear results about the main factor contributing to this issue.

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High Density Fluids Customization and Field Application in Khursaniyah Challenging Wells

Cited by 10 publications

References 6 publications

Nanomaterial-Based Drilling Fluids for Exploitation of Unconventional Reservoirs: A Review

Nanomaterial-Based Drilling Fluids for Exploitation of Unconventional Reservoirs: A Review

Effect of Different Weighting Agents on Drilling Fluids and Filter Cake Properties in Sandstone Formations

The Role of Drilled Formation in Filter Cake Properties Utilizing Different Weighting Materials

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