Formation Damage Due to Static and Dynamic Filtration of Water-Based Muds

1992 ◽  
Author(s):  
Di Jiao ◽  
M.M. Sharma
Keyword(s):  
Formation Damage ◽  
Dynamic Filtration ◽  
Water Based

scholarly journals Prediction of Formation Damage, Fluid Loss and Rheological Properties of Water Based Mud with Corn Cob

2020 ◽  
Vol 5 (10) ◽  
pp. 1269-1273
Author(s):  
Godwin Chukwuma Jacob Nmegbu ◽  
Bright Bariakpoa Kinate ◽  
Bari-Agara Bekee
Keyword(s):  
Rheological Properties ◽  
High Pressures ◽  
Chemical Properties ◽  
Analytical Models ◽  
Formation Damage ◽  
Fluid Loss ◽  
Drilling Mud ◽  
Corn Cob ◽  
Core Samples ◽  
Water Based

The extent of damage to formation caused by water based drilling mud containing corn cob treated with sodium hydroxide to partially replace polyanionic cellulose (PAC) as a fluid loss control additive has been studied. Core samples were obtained from a well in Niger Delta for this study with a permeameter used to force the drilling mud into core samples at high pressures. Physio-chemical properties (moisture content, cellulose and lignin) of the samples were measured and the result after treatment showed reduction. The corn cob was combined with the PAC in the ratio of 25-75%, 50-50% and 75-25% in the mud. Analyzed drilling mud rheological properties such as plastic viscosity, apparent viscosity, yield point and gel strength all decreased as percentage of corn cob increased in the combination and steadily decreased as temperature increased to 200oF. Measured fluid loss and pH of the mud showed an increase in fluid loss and pH in mud sample with 100% corn cob. The extent of formation damage was determined by the differences in the initial and final permeability of the core samples. Experimental data were used to develop analytical models that can serve as effective tool to predict fluid loss, rheological properties of the drilling mud at temperature up to 200oF and percentage formation damage at 100 psi.

scholarly journals Experimental study on thermal, rheological and filtration control characteristics of drilling fluids: effect of nanoadditives

2020 ◽  
Vol 75 ◽  
pp. 36
Author(s):  
Erfan Veisi ◽  
Mastaneh Hajipour ◽  
Ebrahim Biniaz Delijani
Keyword(s):  
Thermal Conductivity ◽  
Heat Capacity ◽  
Drilling Fluid ◽  
Formation Damage ◽  
Fluid Loss ◽  
Drilling Fluids ◽  
Drill Bit ◽  
Rheological Characteristics ◽  
Cu Nanoparticles ◽  
Water Based

Cooling the drill bit is one of the major functions of drilling fluids, especially in high temperature deep drilling operations. Designing stable drilling fluids with proper thermal properties is a great challenge. Identifying appropriate additives for the drilling fluid can mitigate drill-bit erosion or deformation caused by induced thermal stress. The unique advantages of nanoparticles may enhance thermal characteristics of drilling fluids. The impacts of nanoparticles on the specific heat capacity, thermal conductivity, rheological, and filtration control characteristics of water‐based drilling fluids were experimentally investigated and compared in this study. Al2O3, CuO, and Cu nanoparticles were used to prepare the water-based drilling nanofluid samples with various concentrations, using the two-step method. Transmission Electron Microscopy (TEM) and X-Ray Diffraction (XRD) were utilized to study the nanoparticle samples. The nanofluids stability and particle size distribution were, furthermore, examined using Dynamic Light Scattering (DLS). The experimental results indicated that thermal and rheological characteristics are enhanced in the presence of nanoparticles. The best enhancement in drilling fluid heat capacity and thermal conductivity was obtained as 15.6% and 12%, respectively by adding 0.9 wt% Cu nanoparticles. Furthermore, significant improvement was observed in the rheological characteristics such as the apparent and plastic viscosities, yield point, and gel strength of the drilling nanofluids compared to the base drilling fluid. Addition of nanoparticles resulted in reduced fluid loss and formation damage. The permeability of filter cakes decreased with increasing the nanoparticles concentration, but no significant effect in filter cake thickness was observed. The results reveal that the application of nanoparticles may reduce drill-bit replacement costs by improving the thermal and drilling fluid rheological characteristics and decrease the formation damage due to mud filtrate invasion.

Assessment of Dynamic Filtration Formation Damage for Alaskan North Slope Drilling Fluids

2008 ◽  
Author(s):  
Prasad B. Kerkar ◽  
Shirish Liladhar Patil ◽  
Godwin Amajuoyi Chukwu ◽  
Abhijit Yeshwant Dandekar ◽  
Santanu Khataniar
Keyword(s):  
North Slope ◽  
Formation Damage ◽  
Drilling Fluids ◽  
Dynamic Filtration ◽  
Alaskan North Slope

A New Approach To Estimate Invasion Radius of Water-Based-Drilling-Fluid Filtrate To Evaluate Formation Damage Caused by Overbalanced Drilling

2015 ◽  
Vol 30 (01) ◽  
pp. 27-37 ◽  
Author(s):  
Kegang Ling ◽  
He Zhang ◽  
Zheng Shen ◽  
Ali Ghalambor ◽  
Guoqing Han ◽  
...  
Keyword(s):  
Drilling Fluid ◽  
Formation Damage ◽  
New Approach ◽  
Water Based

Low-Damage Drilling Fluid Technology Used in Jabung Oilfield, Indonesia

2011 ◽  
Vol 347-353 ◽  
pp. 1627-1632
Author(s):  
Jiao Jiao Geng ◽  
Jie Nian Yan ◽  
Wen Yi Chen ◽  
Chun Yao Peng ◽  
Jing Jie Zuo ◽  
...  
Keyword(s):  
High Pressure ◽  
Filtration Rate ◽  
Drilling Fluid ◽  
Formation Damage ◽  
Rock Surface ◽  
Drilling Fluids ◽  
High Permeability ◽  
Dynamic Filtration ◽  
Film Forming ◽  
Sealing Layer

Formation damage is prone to occur during drilling into the formations with medium/high permeability in Jabung Oilfield, Indonesia. To prevent formation damage and enhance productivity of oil wells, a novel low-damage drilling fluid was developed on the basis of the modification of currently used KCl polymer drilling fluid using a special technology. By virtue of the synergistic effect of ideal packing agents and film-forming agents, a sealing layer with high pressure bearing capability can be formed on the rock surface of borehole, so as to prevent drilling fluids from invading into formations effectively. It is shown from the results of numerous experiments that this drilling fluid has excellent rheological properties, very low filtration rates (API filtration rate<4mL and HTHP filtration rate≤12.5mL), good lubricity, and strongly inhibitive character to shale. Also, it exhibits remarkable effectiveness of formation protection indicated by the returned permeability as high as 88.11% and extremely low dynamic filtration rate lower than 4mL.

Design and Implementation of a Water-Based Micronized Weighting Agent Fluid System for Deepwater Drill Stem Testing Operation in Environmentally Restricted Location

2021 ◽  
Author(s):  
Marcelo Dourado Motta ◽  
Sebastião de Loureiro
Keyword(s):  
Case Reports ◽  
Integrated Approach ◽  
Formation Damage ◽  
Skin Damage ◽  
Fluid System ◽  
Pressure Losses ◽  
Drill Stem ◽  
Technical Requirements ◽  
Water Based ◽  
Multiple Challenges

Abstract The use of micronized weighting agents, in multiple operations, have become more commonplace over the years, with current applications now going far beyond their targeted original purpose of reducing pressure losses in extended reach wells. This specific case reports the development of a fit for purpose system engineered to tackle multiple challenges such as: limitation in using heavy density brines composed of bromides in an offshore environment; hydrate suppression under Drill Stem Test (DST) conditions; weighting agent sagging control; plugging of downhole tools due to heavy solids loading; proper pressure transmission for downhole tools activation; and formation damage prevention. The operation involved the following steps: 1 - development of a Water-based Micronized Weighting Agent Fluid System (WBMWAFS), laboratory testing, simulation evaluation and testing validation for all target properties; 2 - development of an appropriate DST approach with the usage of a designed set of explosives to minimize formation damage and the interaction of the DST fluid with such cargos; and 3 - the evaluation of the overall system performance in order to validate the integrated approach used to design such solution. The DST results indicated that the WBMWAFS is capable of delivering all the technical requirements for a trouble-free operation, with no significant register of weighting agent sag, hydrates or with any variation in fluid properties, whilst enabling a DST operation that demonstrated a negative skin damage during the clean-up period and no damage associated with the WBMWAFS. The WBMWAFS performance opens the possibility of the application of this type of fluid as a replacement for high-density clear brines in many challenging environments.

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