Experimental investigation of a new weak-gel-type clay-free and water-based drilling fluid with high-temperature and high-salt resistance for determining its optimized formulation

2020 ◽  
pp. 1-18
Author(s):  
Zhijun Li ◽  
Chaogang Xiang
Keyword(s):  
Experimental Investigation ◽  
High Temperature ◽  
Drilling Fluid ◽  
Salt Resistance ◽  
High Salt ◽  
Water Based ◽  
Weak Gel

scholarly journals Synthesis of a Novel Filtrate Reducer and Its Application in Water-Based Drilling Fluid for Ultra-High-Temperature Reservoirs

Geofluids ◽  
2021 ◽  
Vol 2021 ◽  
pp. 1-11
Author(s):  
Dongyu Qiao ◽  
Zhongbin Ye ◽  
Lei Tang ◽  
Yiping Zheng ◽  
Xindong Wang ◽  
...  
Keyword(s):  
Particle Size ◽  
High Temperature ◽  
Adsorption Capacity ◽  
Fresh Water ◽  
Drilling Fluid ◽  
Salt Resistance ◽  
Fluid Loss ◽  
Drilling Fluids ◽  
Water Based ◽  
Water Base

The high-temperature stability and filtration property controlling of ultra-high-temperature water-based drilling fluids is a worldwide problem. To resolve this problem, a high-temperature-resistant quaternary copolymer (HTRTP) was synthesized based on molecular structure optimization design and monomer optimization. The physical and chemical properties were characterized by infrared spectroscopy, thermal weight, and spectrophotometry, and their temperature and salt resistance was evaluated in different drilling fluids, combined with adsorption, particle size analysis, and stability test. The results show that the thermal stability of HTRTP is very strong, and the initial temperature of thermal decomposition is above 320°C. The salt resistance of HTRTP is more than 162 g/L, and the calcium resistance is more than 5000 mg/L, which is equivalent to the foreign temperature-resistant polymer DCL-a, and is superior to the domestic metal ion viscosity increasing fluid loss agent PMHA-II for drilling fluids. It has excellent high-temperature resistance (245°C) and fluid loss reduction effect in fresh water base mud, fresh water weighted base mud, saturated brine base mud, and composite salt water base mud, which is better than foreign DCL-a (245°C) and domestic PMHA (220°C). The adsorption capacity of HTRTP on clay particles is large and firm, and the adsorption capacity changes little under the change of chemical environment and temperature. Both before and after HTRTP aging (245°C/16 h), the permeability of filter cake can be significantly reduced and its compressibility can be improved. By optimizing the particle size gradation of the drilling fluid and enhancing the colloid stability of the system, HTRTP can improve the filtration building capacity of the drilling fluid and reduce the filtration volume. The development of antithermal polymer provides a key treatment agent for the study of anti-high-temperature-resistant saline-based drilling fluid.

Rheology and fluid loss of a polyacrylamide-based micro-gel particles in a water-based drilling fluid

2020 ◽  
Vol 10 (5) ◽  
pp. 657-662
Author(s):  
Gang Wang ◽  
Honghai Fan ◽  
Guancheng Jiang ◽  
Wanjun Li ◽  
Yu Ye ◽  
...  
Keyword(s):  
Particle Size ◽  
High Temperature ◽  
Particle Size Distribution ◽  
Size Distribution ◽  
Drilling Fluid ◽  
Crosslinking Agent ◽  
Fluid Loss ◽  
Temperature Property ◽  
Water Based ◽  
The Cross

In this paper, the cross-linked micro-gel polymer between acrylamide (AM) and N, N-Methylenebisacrylamide (MBA) was synthesized by dispersion polymerization. The initiator and crosslinking agent concentration were used to control the particle size of micro-gel polymer. The filtration property and mechanism of micro-gel were investigated comprehensively. The characteristics of micro-gel were checked by means of Fourier transform infrared spectroscopy, thermogravimetry, transmission electron microscopy, and particle size distribution, respectively. The results indicated that the cross-linked micro-gel polymer exhibited several outstanding merits, such as thermal stability (up to 200 °C), filtration control and rheological property. Microstructure analysis and particle size distribution examinations showed that the scale of micro-gel polymer was micro, which is in accord with design. Rheological tests demonstrated that the nonlinear structure of micro-gel polymer showed less impact on the apparent viscosity. The anti-high temperature property of micro-gel polymer was better than poly anioniccellulose (PAC) and asphalt widely applied in drilling fluid for anti-high temperature fluid-loss additive. As a result, the cross-linked micro-gel polymer had great potential to be applied in high temperature water-based mud.

scholarly journals Experimental investigation of environmentally friendly drilling fluid additives (mandarin peels powder) to substitute the conventional chemicals used in water-based drilling fluid

2019 ◽  
Vol 10 (2) ◽  
pp. 407-417 ◽  
Author(s):  
Abo Taleb T. Al-Hameedi ◽  
Husam H. Alkinani ◽  
Shari Dunn-Norman ◽  
Mustafa A. Al-Alwani ◽  
Abdullah F. Alshammari ◽  
...  
Keyword(s):  
Experimental Investigation ◽  
Drilling Fluid ◽  
Environmentally Friendly ◽  
Water Based

Hydrophobic‐associated polymer‐based laponite nanolayered silicate composite as filtrate reducer for water‐based drilling fluid at high temperature

2019 ◽  
Vol 137 (18) ◽  
pp. 48608 ◽  
Author(s):  
Haokun Shen ◽  
Kaihe Lv ◽  
Xianbin Huang ◽  
Jingping Liu ◽  
Yingrui Bai ◽  
...  
Keyword(s):  
High Temperature ◽  
Drilling Fluid ◽  
Water Based

scholarly journals Effect of Cycloaliphatic Amine on the Shale Inhibitive Properties of Water-Based Drilling Fluid

2015 ◽  
Vol 8 (1) ◽  
pp. 19-27 ◽  
Author(s):  
Hanyi Zhong ◽  
Dong Sun ◽  
Weian Huang ◽  
Yunfeng Liu ◽  
Zhengsong Qiu
Keyword(s):  
High Temperature ◽  
Drilling Fluid ◽  
Hardness Test ◽  
Drilling Fluids ◽  
The Novel ◽  
Potential Measurement ◽  
Clay Particles ◽  
Water Based ◽  
Bulk Hardness ◽  
Dispersion Test

In order to improve the inhibitive properties and high temperature resistance of shale inhibitor, cycloaliphatic amines were introduced as shale hydration inhibitors in water-based drilling fluids. Bulk hardness test, shale cuttings dispersion test, bentonite inhibition test and water adsorption test were carried out to characterize the inhibitive properties of the novel amines. Surface tension measurement, zeta potential measurement, XRD, contact angle test, SEM and TGA were performed to investigate the interaction between the cycloaliphatic amines and clay particles. The results indicated that cycloaliphatic amines exhibited superior inhibitive properties to the state of the art inhibitors. Moreover, the amines were high temperature resistant. The hydrophobic amine could intercalate into the clay gallery with monolayer orientation. The protonated ammonium ions neutralized the negatively charged surface. After adsorption, the hydrophobic segment covered the clay surface and provided a shell preventing the ingress of water.

A Novel Water-Based Drilling Fluid Tailored for Challenging Slanted HTHP Wells

2021 ◽  
Author(s):  
Vaughn Reza Traboulay ◽  
Tint Htoo Aung ◽  
Cedric Manzoleloua ◽  
Balakrishnan Panamarathupalayam ◽  
Carmelo Arena ◽  
...  
Keyword(s):  
High Temperature ◽  
Drilling Fluid ◽  
Synthetic Polymer ◽  
Term Stability ◽  
Long Term Stability ◽  
High Temperature Water ◽  
Water Based ◽  
Static Conditions ◽  
Temperature Water

Abstract High-temperature water-based drilling fluid systems hold several advantages over synthetic based systems from financial and environmental viewpoints. However, most conventional water-based systems start to become unstable at temperatures above 300 degF. This paper details the design and implementation of A Novel Water-Based Drilling Fluid that meet these temperature stability requirements. The newly developed high-temperature water-based system discussed in this paper utilizes a custom-made branched synthetic polymer that exhibits superior rheological properties and fluid loss control as well as long term stability above 400 degF. The branched synthetic polymer is compatible with most oilfield brines and maintains excellent low-end rheology necessary for hole cleaning and solids suspension under high-temperatures and pressures. Under static conditions, the high-temperature fluid shows no gelation resulting in lower swab surge pressures while the stability of the highly branched synthetic polymer and enhanced rheological profile minimize sag. To drill a challenging exploration well, a Middle East client required a cost-effective drilling fluid system which remains stable under static temperatures expected to exceed 375 degF. The long-term stability of the system was critical for successful wireline logging operations. In addition, the system was required to provide shale inhibition, hydrogen sulfide suppression and sufficient density (above 16.5 lbm/galUS) to maintain well integrity while drilling through anticipated high-pressure zones. The challenging intermediate (12.25-in and 8.375-in) and reservoir (6-in) sections were successfully drilled and evaluated using this new branched synthetic polymer-based system. Fluid property trends and system treatments will be detailed alongside thermal stability data for extended periods required for wireline logging (up to 9 days static). This paper will discuss how proper laboratory design of the high-temperature water-based system was translated to excellent field performance and will indicate how this technology can be utilized for future campaigns in the region and worldwide.

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