A New Biopolymer-Free, Low-Solids, High-Density Reservoir Drilling Fluid: Laboratory Development and Field Implementation

Horton, Robert; Tresco, Kim; Dobson, James W.; Bye, Gry Kristvik; Knox, Dave A.; Svoboda, Charles F.; Foxenberg, William; Green, Taylor C.

doi:10.2118/87664-pa

Cited by 15 publications

(7 citation statements)

References 29 publications

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“…17 The amount of CaCO 3 is kept relatively low, 13-35 lb/bbl, so that thin filter cake is formed. 18 Hematite and Mn 3 O 4 (8 wt% solids) were combined to form water-based high density drilling fluid at density of 146 pcf with improved rheology properties. 19 Oil-based drill-in fluids utilizing Mn 3 O 4 was used through tubing rotary drilling (TTRD) to drill Shell's North Cormorant Field.…”

Section: Introductionmentioning

confidence: 99%

Formation Damage Induced by Various Water-Based Fluids Used to Drill HP/HT Wells

Al-Yami

Nasr‐El‐Din

Bataweel

et al. 2008

SPE International Symposium and Exhibition on Formation Damage Control

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Drilling Unayzah-B reservoir (shale and sandstone) in Saudi Arabia requires high mud density (± 95 pcf) to mechanically stabilize the shale and balance the reservoir pressure. Two fluids are used to drill this reservoir: KCl/ BaSO 4 / CaCO 3 whereas the second is potassium formate/CaCO 3 . Barite is added with CaCO 3 to reduce the amount of solids needed to formulate the drill-in fluid. However, BaSO 4 is insoluble in acids and requires chelating agents to remove it from the formation. Formate drill-in fluids with low solid content can then be used, but they are expensive and corrosive at pH values less than 7-8. To overcome some of the problems associated with these two systems Saudi Aramco developed water-based drill-in fluids using Mn 3 O 4 . No similar formulations were developed before to the best of the authors' knowledge.The objective of this study is to determine formation damage induced by KCl/Mn 3 O 4 mud at 95 pcf. A mini-flow loop was used to assess formation damage induced by the three the drill-in fluids. The experiments were conducted using reservoir cores at bottom hole conditions. Another set of experiments were conducted using a dynamic HPHT cell to determine the thickness and composition of the filter cake filter cake, spurt loss and chemical analysis of filtrate. Compatibility tests between mud filtrate and produced water were performed at 300 ºF and 500 psi using see through cells.The KCl/Mn 3 O 4 showed the least formation damage compared to the other two fluids. The return permeability was significantly higher than those obtained with potassium formate/CaCO 3 or BaSO 4 /CaCO 3 mud systems. Potassium formate filtrate was not compatible with Unayzah-b formation brine, which resulted in its low return permeability (42%) in spite of its low solids content. Unlike formate based fluids, mud filtrate of KCl/Mn 3 O 4 was compatible with the formation brine. BaSO 4 /CaCO 3 drill-in fluid resulted in 40% because the barite solids were trapped inside the core. KCl/Mn 3 O 4 drill-in fluid resulted in 70% return permeability. The main reason for this high result is the spherical shape and small size of Mn 3 O 4 particles, which allowed them to be removed by flow of hydrocarbons.

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Section: Introductionmentioning

confidence: 99%

Formation Damage Induced by Various Water-Based Fluids Used to Drill HP/HT Wells

Al-Yami

Nasr‐El‐Din

Bataweel

et al. 2008

SPE International Symposium and Exhibition on Formation Damage Control

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“…All the filter cake residues obtained from NBDF disappeared after a 3.0 h treatment with 5.0% HCl. The complete cleanup was accredited to the removal of biopolymers and the low concentration of bridging CaCO 3 particles …”

Section: Oilfield Applications Of High-density Brinementioning

confidence: 99%

Application of High-Density Brines in Drilling and Completion Fluids: Current Insights and Future Perspectives

Rana,

Murtaza,

Raza

et al. 2024

Energy Fuels

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Fluids for drilling and completion operations are essential components in the oil and gas industry. With the advancement of drilling technology, effective drilling fluid for harsh drilling operations is still challenging to exploit hydrocarbons. One of the prominent developments in this area is the application of high-density brines. The high-density brines have shown the capacity to tackle complicated harsh geological conditions. This review paper gives a detailed review of the properties, formulation, application, and importance of high-density brines in drilling and completion processes. The factors affecting the salient features of high-density brines, such as chemical composition, temperature, pH, and pressure, are discussed. Furthermore, the paper investigates the application of high-density brines in the oil and gas industry as drilling fluids, where they play a crucial role in wellbore stability, formation fluid control, and cuttings transport. In addition, this review highlights emerging trends and research to improve the performance of high-density brines. Finally, the review discusses current challenges and outlook, environmental concerns, economic feasibility, and compatibility with wellbore materials. The current ample review serves as beneficial literature for research scientists, engineers, and industry experts looking for a massive knowledge of high-density brines and their diverse applications.

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“…Boul synthesized a highperformance salt water tackifier which was based on the multi-molecular structure unit. Horton et al [11] and Boul [12] prepared a high-density salt water system with temperature resistance of 162℃ and density of 2.3g/cm 3 . Al-Ansari used potassium formate/ manganousmanganic oxide to increase the density of drilling fluid to 2.1g/cm 3 , with temperature resistance of 155℃, which it was first used in Saudi Arabia [13].…”

Section: Introductionmentioning

confidence: 99%

Study on Rheological Property Control Method of “Three High” Water Based Drilling Fluid

Lijuan

Lei

et al. 2020

IJE

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The rheological regulation of the "three high" (high temperature, high density and high salinity) waterbased drilling fluid is a worldwide problem due to the combined influence of temperature, solid content and salinity. This paper investigates the factors and regulation methods about rheological property of "three high" water based drilling fluid, and the effects of clay, salinity and weighting materials on the drilling fluid rheology. The experimental results show that base mud compound bentonite with attapulgite had good salt resistance and temperature resistance. The clay content should be kept close to 2% in high density mud (ρ=2.0g/cm 3), to control drilling fluid rheology. The sequence of rheological parameters of the "three high" water-based drilling fluid with same density was: manganese oxide> micronized barite> barite> ilmenite powder. When barite compounded with ilmenite powder or micronized barite in the ratio of 1:1 to weight drilling fluid respectively, the rheology and filtration of the "three high" water-based drilling fluid performed well. Based on the optimization of a series of mud additives including fluid loss additive, thinner, anti-collapse filtration reducing agent, lubricant with salt and calcium resistance, a formula of the "three high"water-based drilling fluid system was prepared which had excellent rheology, filtration and sedimentation stability property with the density of 2.2g/cm 3 (180℃). The expansion rate of the drilling fluid was 1.84%, shale recovery rate was 85.73%, lubrication coefficient was 0.122, and resistanced to pollution of 1% CaCl2 and 10% poor clay. It also had excellent reservoir protection and plugging performance.

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A New Biopolymer-Free, Low-Solids, High-Density Reservoir Drilling Fluid: Laboratory Development and Field Implementation

Cited by 15 publications

References 29 publications

Formation Damage Induced by Various Water-Based Fluids Used to Drill HP/HT Wells

Formation Damage Induced by Various Water-Based Fluids Used to Drill HP/HT Wells

Application of High-Density Brines in Drilling and Completion Fluids: Current Insights and Future Perspectives

Study on Rheological Property Control Method of “Three High” Water Based Drilling Fluid

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