bluuebunny/crossref_metadata_2025_split huggingface dataset:
High-Diffusivity Correction in Gas Interval Using 2D Magnetic Resonance
Authors: Oifoghe Stanley , Sy Rex , Okowi Victor 
Published: October 2018

Abstract
Due to a high noise-to-signal ratio, 10 of the 24 acquired magnetic resonance echo data logs from a field in the Niger Delta were excluded from the processing result. The reduction in the total number of echoes led to a high diffusivity, especially in the gas-bearing reservoir sand. High diffusivity caused some of the movable fluids to appear as irreducible bound water. The low hydrogen index of the gas also caused a low-permeability profile.
The effect of high diffusivity was very prominent in the Apparent Transverse Relaxation Time (T2app) spectrum, but the intrinsic transverse relaxation time (T2intrinsic) spectrum was unaffected. Consequently the, T2intrinsic spectrum was used to determine partial porosities and fractional fluid volumes. However, the total and effective porosities were not seriously impacted.
2D NMR (T2intrinsic – Diffusivity) maps were used to determine the partial porosities and fractional fluid volumes. These maps are produced by plotting diffusivity, D, against the Transverse Relaxation Time, T2. 2D NMR maps aid the discrimination of the magnetic resonance fractional volumes – clay-bound water (CBW), irreducible bound water (BVI) and movable volume (BVM). The maps can further be used for fluid-typing analysis.
The common processing result using T2app showed little or no permeability and little or no BVM in the gas interval, while the 2D NMR result showed an average permeability index of 3mD and an average movable fluid volume of 8pu. There was also very little BVI in this gas interval.
This paper effectively demonstrates the ability to use advanced magnetic resonance techniques to address issues related to high a noise-to-signal ratio, as well as minimal sensor failures. As presented, the paper clearly shows that we can get useable data from as high as 50% echo trains failure rate.
Though efforts are made to prevent signal failures and high noise-to-signal situations, there is a fix to such problems when they arise. Rather than re-log, the data can be savaged and the desired result achieved.
Waste Cooking Oil- A Potential Source of Raw Material for Localization of Green Products Development
Authors: Amanullah Md , Arfaj Mohammed K. 
Published: October 2018

Abstract
The oil and gas industry has a long standing initiative to develop and use the most environmental solutions in the exploration and recovery of oil and gas resources. As part of this continual effort, research is ongoing to create eco- friendly, virtually non-toxic and readily biodegradable base fluids, lubricants, emulsifiers to successfully complete drilling and completion requirements without causing any damage to the environment or other resources.
There is a significant volume of waste vegetable oil generated by the food and catering industry has no aromatic oil content, is virtually nontoxic and readily biodegradable and thus can be a potential source for the development of eco-friendly base fluids, lubricants, emulsifiers and spotting fluids to be in the forefront of best drilling practices This paper describes a set of newly developed green mud additives that have been synthesized using waste cooking oil generated by the food and catering industry. Recycling of the waste cooking oil not only provides a technical solution for the oil and gas industry, but also addresses the disposal problems of the food and catering industry.
Experimental results demonstrating the various applications of the newly developed green products indicate similar or better performance compared to the commercially available equivalent products used by the oil and gas industry. Hence, the newly developed products are viable alternatives for some of the imported non-ecofriendly or less eco-friendly oil-based products used for exploration and exploitation of oil and gas resources. Due to the replacement of equivalent imported products, these locally developed products will reduce the mud additive import cost significantly. On the other hand, due to the eco-friendly nature of the products, they will help explore and exploit oil and gas resources without any negative impact on other marine and terrestrial resources.
Effect of Polypropylene Fibers on Oil-Well Cement Properties at HPHT Condition
Authors: Ahmed Anas , Elkatatny Salaheldin , Gajbhiye Rahul , Rahman Muhammad Kalimur , Sarmah Pranjal , Yadav Prahlad 
Published: October 2018

Abstract
In deeper wells, high pressure and temperature post cementing operations put extreme stresses on the cement sheath and dramatically affect the cement integrity. So, the design of the cement slurry is very important to ensure the durability and long-term integrity of the cement sheath. The design should lead to a better zonal isolation and strengthen the bonding with the casing. Furthermore, it should help to shield the casing from corroding and unpredictable shock loads in deeper zones and sustain plugs to control the lost circulation in fractured and high permeability zones. Different additives were used to provide these functions such as; polymers, fibers, and bio-medicine in concrete history. Because of their large surface areas and small size, those particles are highly being used in the petroleum industry in the latest decades.
In this study, the usage of polypropylene fibers (PPF) is evaluated for oil well cement at high pressure and high temperature (HPHT) condition. The polypropylene fibers were added to the base cement in a different amount to evaluate its influence on enhancing the performance of cement.
The results obtained showed that adding polypropylene fiber to the base cement has a negligible effect on cement density, rheological properties, and free water. Using polypropylene fiber (0.75% base weight of cement (BWOC)) with the base cement reduced the thickening time by 75%; from 317 minutes to 78 minutes. The addition of Polypropylene fiber (0.5% BWOC) increased the compressive strength of class G cement by 17.8%. Polypropylene fiber can be used as an alternative material for silica floor in shallow wells. Polypropylene fiber has a significant effect on reducing the porosity and the permeability of the base cement.
New Hydrogen Sulfide Scavenger for Drilling Sour Horizontal and Multilateral Reservoirs
Authors: Elkatatny Salaheldin , Basfer Salem , Mahmoud Mohamed , Shawabkeh Reyad , Bahgat Mohamed 
Published: October 2018

Abstract
Hydrogen sulfide is naturally occurring gas that can be found in gas reservoirs, dissolved in hydrocarbon, water, or even liquid Sulphur. H2S can also be produced by microbiological processes, for example the reduction of sulfates by anaerobic bacteria such as sulfate reducing bacteria (SRBs). The existence of hydrogen sulfide even at low concentration yielded in localized corrosion and cause stress cracking. In addition, H2S causes damage to the pipes, valves and surface equipment.
Hydrogen sulfide is naturally occurring gas that can be found in gas reservoirs, dissolved in hydrocarbon, water, or even liquid Sulphur. H2S can also be produced by microbiological processes, for example the reduction of sulfates by anaerobic bacteria such as sulfate reducing bacteria (SRBs). The existence of hydrogen sulfide even at low concentration yielded in localized corrosion and cause stress cracking. In addition, H2S causes damage to the pipes, valves and surface equipment.
The objective of this study is to assess the using of copper nitrate as a catalyst for drilling fluids that can be used in drilling sour horizontal and multilaterals reservoirs. In addition, the effect of copper nitrate in rheological properties and the corrosion rate of the pipe will be evaluated.
The obtained results showed that adding copper nitrate with 1lb/bbl for the drilling fluid enhanced the rheological properties and H2S scavenging. The yield point/plastic viscosity ratio was increased by 20% without affecting the stress-strain behavior of the drilling fluid. The corrosion rate of the drilling fluid with the copper nitrate was very small (0.00060 lb/ft2 after 6 hrs) and (0.00084 lb/ft2 after 24 hrs) at 100°C. The standard corrosion (H2S + CO2, N2) test of the developed formulation showed that the corrosion rate was 0.00077 lb/ft2 after 6 hrs at 100°C. Breakeven experiments for base fluid, fluid with conventional Triazine scavenger, and the developed fluid showed that the drilling fluid with copper nitrate has three times the sorption capacity to H2S as compared to the drilling fluid with Triazine. The sorption capacity of the drilling fluid with copper nitrate is 5143 mg H2S/ml fluid, while that of both Bases and Base with Triazine fluids are 503 mg H2S/ml and 1666 mg H2S/ml, respectively.
The developed technique for H2S scavenging is very cheap and non-corrosive and will help the drilling engineer to drill multilateral and deep horizontal wells with safe and environmentally friendly method.
Designing Invert Emulsion Drilling Fluids for HTHP Conditions
Authors: Wagle Vikrant , Al-Yami Abdullah S. , AlSafran Ali 
Published: October 2018

Abstract
Good and optimal rheology is a primary requisite for a drilling fluid to achieve better hole-cleaning and barite sag resistance. Conventional thickeners like organophilic clay that provide rheology to invert emulsion fluids degrade with time and thereby fail to maintain sufficient rheology of the drilling fluid. Generally, excess amount of organophilic clay or low gravity solids (LGS) is added to the drilling fluid to enhance rheology. However, addition of excess amount of organoclay or low gravity solids not only increases the cost of drilling but also may severely affect other drilling fluid properties, which will require further treatment. In addition, addition of organoclay or low gravity solids increases the plastic viscosity, decreases the rate of penetration thereby ultimately increasing the cost of drilling. Thus, there was a need to develop a drilling fluid with optimal rheology sufficient to give good hole cleaning and barite sag resistance.
This paper describes the formulation of 70pcf, 90pcf and 120pcf organoclay-free invert emulsion drilling fluids formulated with the novel rheology modifier combination of RM1 and RM2. The invert emulsion drilling fluids were hot rolled at 250°F, 250°F and 350°F respectively. The paper also describes the static aging and contamination studies of 90pcf and 120pcf fluids at 250°F and 350°F respectively. Rheology of the 90pcf invert emulsion fluid was measured across high temperatures and pressures to observe their effects on the rheological properties of the fluid.
70pcf, 90pcf and 120pcf organoclay-free invert emulsion drilling fluids formulated with the novel rheology modifier combination of RM1 and RM2 showed optimal rheology and low HTHP fluid loss. Static aging studies of 90pcf IEFs at 250°F respectively showed that the fluids are sag-resistant with low top-oil separation. Contamination studies of 90pcf fluid showed that the contaminants have minimal effect on the rheology and filtration properties of the invert emulsion fluid. HTHP rheology of the 90pcf invert emulsion fluid shows consistent rheology across high temperatures and pressures. The paper thus demonstrates the superior performance of the rheology modifier combination to achieve good rheological and filtration properties.
Prediction of Cutting Concentration in Horizontal and Deviated Wells Using Support Vector Machine
Authors: Al-Azani Khaled , Elkatatny Salaheldin , Abdulraheem Abdulaziz , Mahmoud Mohamed , Ali Abdulwahab 
Published: October 2018

Abstract
Hole cleaning, or drilled-cutting transportation, is one of the main concern in the petroleum industry. This is due to the high impact of improper downhole cleaning during drilling operations. To illustrate, many drilling problems can happen because of inefficient cleaning of the wellbore. These problems may include premature bit wear, slow drilling rate (i.e. low ROP) and, in most severe cases, a stuck pipe which in some cases can lead to complete loss of the well. Moreover, measuring the cleaning efficiency using field or experimental measurements is highly costly and time-consuming which makes it a very complicated problem. Therefore, a lot of studies have been conducted to understand cutting transport efficiency in drilling operations. However, most of these studies are experimental and try to come up with the best measures including experimental models or empirical correlations. In this study, artificial intelligence techniques were used to estimate the cutting concentration in the wellbore.
The purpose of this study is to use Support Vector Machine (SVM) technique to indirectly measure the hole cleaning efficiency by predicting the cutting concentration in the wellbore from other operational parameters. Based on 116 experimental data points collected from the literature, the cutting concentration in the borehole was predicted from the properties of the mud itself such as the mud rheological properties (e.g. yield point and plastic viscosity) and mud density (mud weight) and other operational parameters during drilling including the drill pipe rotary speed (RPM), pipe eccentricity (i.e. the axial location of the drill pipe), hole inclination angle, the rate of penetration (ROP), flow rate (GPM), temperature and annular size.
The results obtained from SVM show the ability of this method to accurately predict the cutting concentration in the wellbore with an average absolute error (AAE) of less than 5% and a correlation coefficient (R) of more than 0.9. For this specific group of data, comparing the results obtained from this technique with a correlation presented in the literature shows that the SVM method provides a better prediction of cutting concentration and higher accuracy than that in the literature. Finally, the method developed in this study to predict the cutting concentration is based on continuously measured parameters during any drilling operation. Therefore, integration of the developed model into the drilling system will allow for real-time prediction of the concentration of the cuttings (i.e. the amount of cuttings present in the wellbore) and, hence, the cleaning efficiency during the drilling operation.
Prevention of Barite Sagging While Drilling High-Pressure High-Temperature (HPHT) Wells
Authors: Basfar Salem , Elkatatny Salaheldin , Mahmoud Mohamed , Kamal Muhammad Shahzad , Murtaza Mobeen , Stanitzek Theo 
Published: October 2018

Abstract
Barite sagging is one of the common issues while drilling high pressure-high temperature wells. This will cause variation in the mud weight in both vertical and deviated wells. Barite sagging can cause many problems such as; density variations, well-control problems, stuck pipe, downhole mud losses, and induced wellbore instability.
The objective of this study is to assess the effect of adding a new copolymer to the invert emulsion drilling fluid to prevent the sagging issue. Sag test was conducted under static conditions over a wide range of temperature (200°F to 350°F). Sag test was performed using vertical and decline (45° degree) aging cell. In addition, the effect of adding the new copolymer on the rheological properties and the electrical stability of the invert emulsion drilling fluid was evaluated.
The results obtained showed that adding 1 lbm/bbl of the new copolymer had no effect on drilling fluid density (14.5 ppg). The new copolymer slightly enhanced the electrical stability of the invert emulsion drilling mud. The new copolymer had a minor effect on the plastic viscosity, yield point, and gel strength. Adding 1 lbm/bbl of the copolymer prevent barite sagging at 350°F, where the sag factor was 0.55 before adding copolymer, and 0.503 after adding it. The storage modulus (G′) was increased by 40% after adding 1 lbm/bbl of the new copolymer confirming the sag test results. There was no effect of adding the new copolymer in the filtration loss and filter cake thickness.
The novelty of this work is the development of a new drilling fluid formulation that can be used in drilling HPHT wells without any sag issue. This development will help the drilling engineers to safely drill deep wells and maintain the drilling fluid integrity during the drilling operation. In general, this will reduce the overall cost of the drilling operation by reducing the non-productive time in solving many issues such as well control, loss of circulation, or pipe sticking.
Real Time Prediction of the Rheological Properties of Oil-Based Drilling Fluids Using Artificial Neural Networks
Authors: Al-Azani Khaled , Elkatatny Salaheldin , Abdulraheem Abdulaziz , Mahmoud Mohamed , Al-Shehri Dhafer 
Published: October 2018

Abstract
Continuous monitoring of the rheological properties of the drilling mud is essential so that any drilling operation can be completed more effectively and efficiently with the least problems. Mud rheological properties play a vital role in the in the efficiency of the drilling fluid to lift the cuttings from the wellbore. The mud rheological properties include the plastic viscosity, apparent viscosity, and the yield point. However, these properties are not measured continuously during the drilling process and they are only measured once or twice a day while other mud properties, such as the mud weight, the Marsh funnel viscosity, and solid content, are measured regularly and continuously. Therefore, it is valuable to come up with a relation that relates the mud rheological properties to these parameters. Many researchers tried to introduce models that allow for the prediction of the apparent viscosity from the Marsh funnel viscosity. However, these models have the deficiency that the prediction is with high errors. For the first time, the solid percent was used to predict the rheological properties of the oil-based drilling fluid based on the artificial neural network using actual field measurements.
The purpose of this study is to use the Artificial Neural Networks (ANN) Technique to develop a model that allows the prediction of the mud rheological properties such as the plastic viscosity, apparent viscosity, the rheometer readings at 600 and 300 rpm and the flow behavior index for oil-based mud from the mud weight, the Marsh funnel viscosity and solid content. The study is based on 400 data points collected from the field measurements of actual drilling fluid samples. The obtained results showed that the five developed models using ANN technique can be used to predict the rheological properties of oil- based drilling fluid with a high accuracy; the average absolute error was less than 5% and the correlation coefficient was higher than 90%. The developed technique is inexpensive with no additional required equipment. It will help the drilling engineers to calculate the equivalent circulation density, surge and swab pressures, and hole cleaning which are strong functions of the rheological parameters in a real time.
The method and approach used in this paper to predict and determine the unknown drilling fluid properties and trend out of accurately defined parameters is futuristic and progressive. The method is one step forward toward automating the drilling fluid system which is another step forward toward fully automating the drilling process overall.
Using Artificial Intelligence to Predict IPR for Vertical Oil Well in Solution Gas Derive Reservoirs: A New Approach
Authors: Basfar Salem , Baarimah Salem O. , Elkatany Salaheldin , AL-Ameri Wahbi , Zidan Khaled , AL-dogail Ala 
Published: October 2018

Abstract
Well Inflow Performance Relationship (IPR) has a wide range of applications in both applied and theoretical sciences, especially in the petroleum production engineering. An accurate prediction of well IPR is very important to determine the optimum production scheme, design production equipment, and artificial lift systems. For these reasons, there is a need for a quick and reliable method for predicting oil well IPR in solution gas drive reservoirs.
In this paper, back propagation network (BPN) and fuzzy logic (FL) techniques are used to predict oil well IPR in solution gas drive reservoirs. The models were developed using 207 data points collected from unpublished sources. Statistical analysis was performed to define the more reliable and accurate techniques to predict the IPR.
According to the results, the new fuzzy logic well IPR model outperformed the artificial neural networks (ANN) model and the most common empirical correlations. The average absolute error, least standard deviation and highest correlation coefficient were used to evaluate the models results. The proposed fuzzy logic well inflow performance relationship model achieved an average absolute error of 1.8 %, standard deviation of 2.9% and the correlation coefficient of 0.997.
The developed technique will help the production and reservoir engineers to better manage the production operation without the need for any additional equipment. It will also reduce the overall operating cost and increase the revenue.
Production Revival Using Hydraulic Lift Method for a Low Pressure Well: A Case Study
Authors: Rehman Abid Ur , Abdelbary Marwan , Abbasi Haris Shakeel 
Published: October 2018

Abstract
While the oil and gas sector is facing one of its most significant slumps, producers have moved their focus in optimizing production of their existing wells rather than drilling new wells. Artificial Lift Systems (ALS) have played a significant part in optimizing and enhancing the production of existing assets. The primary scope of ALS is to maximize productivity; however, there are many such systems applicable, the selection of the most suitable lift system plays a vital role in cost optimization of the well.
A primary type of ALS is hydraulic lift, which has been recently applied successfully in north Iraq. A special form of hydraulic lift is the jet pump. This technology has proved to be one of the best lift types for the operator in the region, with the unique concept of no moving parts inside the downhole pump, which has dramatically reduced downtime and the need to move a workover rig to the well site. A jet pump can be installed in a well using a variety of techniques, depending upon the well completion and can be customized easily depending upon downhole conditions. However, if one does not monitor the operation and working parameters continuously, the performance of a jet pump will be reduced as well conditions change.
A jet pump was optimized as a test project for a well which was not producing naturally. This study was based on a variety of operational conditions of the well, such as injection parameters, flow restrictions and paths, surface pumping unit power, nozzle throat combinations, vessel operating pressures, and the productivity of nearby wells to calculate the reservoir potential. The evaluation, analysis, and design of a jet pump for this well were carried out on Jet Pump Evaluation and Modeling Software (JEMS). The most suitable nozzle throat combination for this well was 10D, which was used successfully to lift production to approximately 2,000 bpd.
This study describes the process and gives the results for successfully reviving production in a well with hydraulic lift. It also depicts the improvements of the optimized input power for each well depending upon the design selected. In the end, a methodology towards the selection of the best design and operating parameters of the jet pump for the mentioned well is discussed. The installation, types, and operation of the jet pump system are discussed in detail for a proper understanding of the lift method.