A Practical Study of the Influence of Drill Solids on the Corrosion of Downhole Tubulars When Using Brine Based Drilling Fluids

2021 ◽  
Author(s):  
Garett Heath ◽  
Temi Okesanya ◽  
Simon Levey
Keyword(s):  
Oxygen Content ◽  
Field Data ◽  
Drill Pipe ◽  
American Petroleum Institute ◽  
Filter Press ◽  
Drilling Fluids ◽  
Chemical Additives ◽  
Active System ◽  
Corrosion Rates ◽  
Fluid Properties

Abstract The proliferation of highly concentrated brine drilling fluids systems due to their enhanced performance benefits has instigated a plethora of technical studies on the mechanisms and control of their induced corrosion on downhole drilling tools and tubulars. The majority of these studies often overlook the effect of drill solids on corrosion rates. Therefore, a pragmatic and experimental study was conducted to investigate the effects of various factors on the corrosion rates of downhole tubulars with a streamlined focus on the obscure role of the understudied drill solids; which have not been fully elucidated. Drill pipe corrosion coupons and drilling fluids/solids obtained from 5 similar wells (located in Grande Prairie, Alberta, Canada) were utilized for experimental analysis. Wells 1 to 4 were on the same pad (surface drilling location) drilling the same formation with the same fluid properties, while the 5th well was on a different pad but drilled the same formation with the same fluid properties to exclude disparity. Industry-standard measurement was carried out on the live used corrosion coupon rings, drilling fluids and solids obtained from these wells to determine selected properties. The total solids content analysis was carried out using an OFITE API (American Petroleum Institute) filter press. Weight loss tests on drill pipe corrosion coupons were used to determine field corrosion rates which were bolstered with the Parr Hastelloy autoclave test in the Laboratory. The oxygen content was monitored using Hach 2100Q dissolved oxygen meter. Field data, images and experimental results showed that a rapid and minuscule increase of drill solids (as little as 1% v/v) in the active system can impact corrosion rates greater than chemical additives and even oxygen content. It was discovered that low concentration of solids can produce significant damage and a high corrosion potential in non-viscosified fluids thereby making live monitoring of drilling fluids’ properties a priority to mitigate corrosion. This study fills an important technical gap in corrosion study that is indispensable for the optimization of corrosion control in drilling operations. By carrying out a controlled and investigative study backed up with drilling field data and images, the effects of the less understood drill solids have been partially demystified.

Effect of Nanofluids of CuO and ZnO in Polyethylene Glycol and Polyvinylpyrrolidone on the Thermal, Electrical, and Filtration-Loss Properties of Water-Based Drilling Fluids

SPE Journal ◽  
2016 ◽  
Vol 21 (02) ◽  
pp. 405-415 ◽  
Author(s):  
Swaminathan Ponmani ◽  
R.. Nagarajan ◽  
Jitendra S. Sangwai
Keyword(s):  
Polyethylene Glycol ◽  
American Petroleum Institute ◽  
Filter Press ◽  
Fluid Loss ◽  
Drilling Fluids ◽  
Drilling Mud ◽  
Lost Circulation ◽  
Filtration Loss ◽  
Water Based ◽  
Oilfield Operations

Summary The challenges in drilling problems such as formation damage, pipe sticking, lost circulation, poor hole cleaning, and fluid loss need better solutions. Nanotechnology, by means of nanofluids, provides potential solutions for the development of improved water-based mud (WBM). This work presents the use of nanofluids of CuO and ZnO prepared in various base fluids, such as xanthan gum, polyethylene glycol, and polyvinylpyrrolidone (PVP), which are commonly used in oilfield operations, for the development of nanofluid-enhanced drilling mud (NWBM). In this paper, formulations of various nanofluids with varying concentrations of nanoparticles, such as 0.1, 0.3, and 0.5 wt%, were investigated for their effect on the thermal, electrical, and fluid-loss properties of NWBM. In addition, these results also were compared with those obtained with microfluids of CuO and ZnO for the microfluid-enhanced drilling mud (MWBM) to understand the effect of particle size. It is observed that the use of nanofluids in WBM helps to improve their thermal properties, with an associated direct impact on their cooling efficiency at downhole and surface conditions compared with those using microfluid. Filtration-loss and filter-cake-thickness studies on WBM, MWBM, and NWBM were also carried out with an American Petroleum Institute (API) filter press. It is observed that the fluid loss decreases with addition of the nanofluids and microfluids in WBM, with nanofluids showing an improved efficacy over microfluids. The studies, in general, bear testimony to the efficacy of nanofluids in the development of next-generation improved water-based drilling fluids suitable for efficient drilling.

scholarly journals Wet Drilled Cuttings Bed Rheology

Energies ◽  
2021 ◽  
Vol 14 (6) ◽  
pp. 1644
Author(s):  
Camilo Pedrosa ◽  
Arild Saasen ◽  
Bjørnar Lund ◽  
Jan David Ytrehus
Keyword(s):  
Drilling Fluid ◽  
Drilling Fluids ◽  
Parallel Plates ◽  
Single Particles ◽  
Cuttings Transport ◽  
Transport Studies ◽  
Water Based ◽  
Fluid Properties ◽  
External Forces ◽  
Cuttings Bed

The cuttings transport efficiency of various drilling fluids has been studied in several approaches. This is an important aspect, since hole cleaning is often a bottleneck in well construction. The studies so far have targeted the drilling fluid cuttings’ transport capability through experiments, simulations or field data. Observed differences in the efficiency due to changes in the drilling fluid properties and compositions have been reported but not always fully understood. In this study, the cuttings bed, wetted with a single drilling fluid, was evaluated. The experiments were performed with parallel plates in an Anton Paar Physica 301 rheometer. The results showed systematic differences in the internal friction behaviors between tests of beds with oil-based and beds with water-based fluids. The observations indicated that cutting beds wetted with a polymeric water-based fluid released clusters of particles when external forces overcame the bonding forces and the beds started to break up. Similarly, it was observed that an oil-based fluid wetted bed allowed particles to break free as single particles. These findings may explain the observed differences in previous cutting transport studies.

Full Scale Flow Loop Experiments of Hole Cleaning Performances of Drilling Fluids

2015 ◽  
Author(s):  
Jan David Ytrehus ◽  
Ali Taghipour ◽  
Sneha Sayindla ◽  
Bjørnar Lund ◽  
Benjamin Werner ◽  
...  
Keyword(s):  
Test Section ◽  
Drilling Fluid ◽  
Drilling Fluids ◽  
Flow Loop ◽  
Base Oil ◽  
Hole Cleaning ◽  
Cleaning Performance ◽  
Water Based ◽  
Fluid Properties ◽  
Drilling Cost

One important requirement for a drilling fluid is the ability to transport the cuttings out of the borehole. Improved hole cleaning is a key to solve several challenges in the drilling industry and will allow both longer wells and improved quality of well construction. It has been observed, however, that drilling fluids with similar properties according to the API standard can have significantly different behavior with respect to hole cleaning performance. The reasons for this are not fully understood. This paper presents results from flow loop laboratory tests without and with injected cuttings size particles using a base oil and a commercial oil based drilling fluid. The results demonstrate the importance of the rheological properties of the fluids for the hole cleaning performance. A thorough investigation of the viscoelastic properties of the fluids was performed with a Fann viscometer and a Paar-Physica rheometer, and was used to interpret the results from the flow loop experiments. Improved understanding of the fluid properties relevant to hole cleaning performance will help develop better models of wellbore hydraulics used in planning of well operations. Eventually this may lead to higher ROP with water based drilling fluids as obtained with oil based drilling fluids. This may ease cuttings handling in many operations and thereby significantly reduce the drilling cost using (normally) more environmentally friendly fluids. The experiments have been conducted as part of an industry-sponsored research project where understanding the hole cleaning performance of various oil and water based drilling fluids is the aim. The experiments have been performed under realistic conditions. The flow loop includes a 10 meter long test section with 2″ OD freely rotating drillstring inside a 4″ ID wellbore made of concrete. Sand particles were injected while circulating the drilling fluid through the test section in horizontal position.

Basin-wide rock-physics analysis in Campeche Basin, Gulf of Mexico — Phase II: Reservoir rock and fluid properties

2021 ◽  
Vol 40 (10) ◽  
pp. 716-722
Author(s):  
Yangjun (Kevin) Liu ◽  
Michelle Ellis ◽  
Mohamed El-Toukhy ◽  
Jonathan Hernandez
Keyword(s):  
Oil And Gas ◽  
Rock Physics ◽  
Clay Content ◽  
American Petroleum Institute ◽  
P Wave ◽  
Reservoir Rock ◽  
Gas Oil ◽  
Amplitude Variation With Offset ◽  
Fluid Properties ◽  
The Impact

We present a basin-wide rock-physics analysis of reservoir rocks and fluid properties in Campeche Basin. Reservoir data from discovery wells are analyzed in terms of their relationship between P-wave velocity, density, porosity, clay content, Poisson's ratio (PR), and P-impedance (IP). The fluid properties are computed by using in-situ pressure, temperature, American Petroleum Institute gravity, gas-oil ratio, and volume of gas, oil, and water. Oil- and gas-saturated reservoir sands show strong PR anomalies compared to modeled water sand at equivalent depth. This suggests that PR anomalies can be used as a direct hydrocarbon indicator in the Tertiary sands in Campeche Basin. However, false PR anomalies due to residual gas or oil exist and compose about 30% of the total anomalies. The impact of fluid properties on IP and PR is calibrated using more than 30 discovery wells. These calibrated relationships between fluid properties and PR can be used to guide or constrain amplitude variation with offset inversion for better pore fluid discrimination.

Utilizing Food Waste Product (Date Tree Seeds) to Enhance the Filtration Characteristics in Water-Based Drilling Fluid System: A Comparative Study

2020 ◽  
Vol 142 (12) ◽  
Author(s):  
Abo Taleb T. Al-Hameedi ◽  
Husam H. Alkinani ◽  
Mohammed M. Alkhamis ◽  
Shari Dunn-Norman
Keyword(s):  
Oil And Gas ◽  
Drilling Fluid ◽  
Waste Product ◽  
Oil And Gas Industry ◽  
American Petroleum Institute ◽  
Filter Press ◽  
Fluid Loss ◽  
Low Viscosity ◽  
Tree Seeds ◽  
Materials Used

Abstract Practically, to regulate filtration characteristics of drilling fluid, non-biodegradable materials used commonly have a high cost with side effects on personnel safety and the environment. Hence, eco-friendly additives are needed as an alternative to replace or at least support the commonly used filtration control agents. This experimental investigation examines the possibility of using date tree seeds’ powder (DTSP), as a new eco-friendly fluid loss agent. Under surface and sub-surface conditions (fresh and aged conditions), experiments were executed utilizing low-temperature and low-pressure (LTLP) and high-temperature and high-pressure (HTHP) American Petroleum Institute (API) filter press to comprehend the influence of DTSP on the seepage loss characteristics. The findings were compared with a commonly utilized chemical additive to regulate filtration characteristics of drilling fluid (low viscosity sodium carboxymethyl cellulose (CMC-LV)). Two concentrations of DTSP and CMC-LV were added separately to a reference fluid (RF) to understand the effect of concentration variations on filtration properties. The findings revealed that both DTSP and CMC-LV significantly improved the filtrate and the filter cake when comparing them with the RF under fresh and aged conditions. The findings for fresh conditions also showed that LTLP filtration measurements for CMC-LV additives had almost similar performance as DTSP additives, while HTHP filtration measurements exhibited that the two concentrations of DTSP additives were marginally better than those of CMC-LV additives. For aged conditions, CMC-LV additives were relatively more efficient than DTSP additives for LTLP filtration control experiments. However, DTSP additives were more efficient in improving the filtration characteristics as compared to CMC-LV additives for HTHP filtration control experiments. These results are in aid of shifting the oil and gas industry from using conventional harmful additives to using unconventional eco-friendly additives. This also helps in transforming unwanted food wastes into valuable commercial products, which can revolutionize the domestic and international industries and create new job opportunities, hence minimizing the total cost of drilling fluid and the wastes disposed to the environment.

Correlating Corrosion Field Data With Experimental Findings for the Development of Pipeline Mitigation Strategies

2014 ◽  
Author(s):  
Karina Chevil ◽  
Weixing Chen ◽  
Greg Van Boven ◽  
Richard Kania ◽  
Jenny Been
Keyword(s):  
Field Data ◽  
Pipeline Steel ◽  
Experimental Studies ◽  
Mitigation Strategies ◽  
General Corrosion ◽  
Common Phenomenon ◽  
Corrosion Rates ◽  
Report Data ◽  
Anaerobic Corrosion ◽  
Experimental Findings

Coating disbondment on pipelines is a common phenomenon that leads to exposure of the pipeline metal to ground water solutions, promoting a corrosive environment which is associated with stress corrosion cracking (SCC). This investigation aims to understand the corrosion behavior and rate of pipeline steel under coating disbondments of varying sizes based on field data and experimental studies. In the analysis of the field data, dig reports provided by a Canadian gas transportation company were analyzed for cases of anaerobic corrosion under tape coatings. The analyzed field data provided a correlation between the tape coating disbondment size and corrosion rate found under the coating. The experimental studies aimed to understand the field findings. The analyses were performed on X-65 pipeline steel coupons placed in a vertical coupon holder with a PMMA shielding. To imitate the variation in the disbondment size, the gap size between the metal coupons and the shielding was varied (2 mm, 5 mm, and 10 mm, and infinite). The general corrosion rates were obtained through weight loss calculations. The experimental results were compared and correlated with dig-report data from the field for a development of cathodic protection and pipeline mitigation strategies.

Comparison of corrosion rates obtained from laboratory and field data

2016 ◽  
Vol 67 (6) ◽  
pp. 660-666 ◽  
Author(s):  
J. Ruppert ◽  
F. Frimmel ◽  
R. Baier ◽  
G. Binder
Keyword(s):  
Field Data ◽  
Corrosion Rates

An Alternate Method to API RP 14E for Predicting Solids Erosion in Multiphase Flow

2000 ◽  
Vol 122 (3) ◽  
pp. 115-122 ◽  
Author(s):  
Brenton S. McLaury ◽  
Siamack A. Shirazi
Keyword(s):  
Multiphase Flow ◽  
Production Rate ◽  
Oil And Gas ◽  
Gas Production ◽  
American Petroleum Institute ◽  
Sand Production ◽  
Threshold Velocity ◽  
Oil And Gas Production ◽  
Sand Erosion ◽  
Fluid Properties

One commonly used method for determining oil and gas production velocities is to limit production rates based on the American Petroleum Institute Recommended Practice 14E (API RP 14E). This guideline contains an equation to calculate an “erosional” or a threshold velocity, presumably a flow velocity that is safe to operate. The equation only considers one factor, the density of the medium, and does not consider many other factors that can contribute to erosion in multiphase flow pipelines. Thus, factors such as fluid properties, flow geometry, type of metal, sand production rate and size distribution, and flow composition are not accounted for. In the present paper, a method is presented that has been developed with the goal of improving the procedure by accounting for many of the physical variables including fluid properties, sand production rate and size, and flowstream composition that affect sand erosion. The results from the model are compared with several experimental results provided in the literature. Additionally, the method is applied to calculate threshold flowstream velocities for sand erosion and the results are compared with API RP 14E. The results indicate that the form of the equation that is provided by the API RP 14E is not suitable for predicting a production flowstream velocity when sand is present. [S0195-0738(00)00203-X]

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