Performance of 15 Years of Hydraulic Fracturing of Oil Wells in South of Oman

2022 ◽  
Author(s):  
Mathieu M. Molenaar ◽  
Ali Al-Ghaithi ◽  
Said Kindi ◽  
Fahad Alawi
Keyword(s):  
Hydraulic Fracturing ◽  
Low Cost ◽  
Oil Wells ◽  
Regression Methods ◽  
Coiled Tubing ◽  
New Concepts ◽  
Business Objective ◽  
Large Growth ◽  
Multivariable Regression ◽  
Production Increase

Abstract The first application of Hydraulic Fracturing in the South Oman started in 2000 to enhance water disposal wells. In 2004 the first oil wells were frac'ed. Although the technology was deployed many times, it never grew into a conventional practice. From 2004 to 2017 on average 5 Oil Wells were hydraulically fractured on yearly basis. In November 2017, a Hydraulic Fracturing Maturation & Expansion Workshop was conducted with the vision of growing the application by applying new frac concepts. A focused effort was initiated to drastically reduce cost, and simultaneously increase the scope by executing larger frac campaigns. The first hydraulic fracturing campaign introducing the frac new concepts, started end 2018 and a rapid growth from 5 wells per year to 45 wells per year was anticipated in the next three years. This large growth of scope relied on a steady supply of frac candidates and needed to be supported by screening and selecting processes that are fit for purpose in finding candidates. Although more than a hundred wells had already been frac'ed wells, selection of the most appropriate wells for stimulation was and remains one of the greatest challenges. A frac performance database was created for over 100 wells that had been hydraulically fracture stimulated to date. Recognizing that the frac performance depends on many variables ranging from subsurface properties to surface execution of the frac job, the size of the dataset proved to be too small to find correlations using sophisticated multivariable regression methods. Instead, the dataset was analyzed through careful investigation and evaluation of each frac job. In this paper the net oil gain will be used as the key success criteria i.e., value driver to demonstrates how effective the frac is achieving its business objective. Some 40% of the producers had been producing from the same zone before the hydraulic fracture stimulation. This provided the opportunity to understand the efficiency of the stimulation in terms of the "stimulation ratio" i.e., measuring the net oil gain. This paper will focus on investigating the suitability of frac'ing the reservoir based on the initial production variables; Gross Rate and BS&W. Also, this paper will discuss benefits and impacts of Hoist versus Coiled-Tubing clean-out on the frac delivery process and compare the frac performance. To date, the project demonstrated that hydraulic fracturing at low cost, can be applied as a viable development concept for producing oil wells, with the potential unlock additional and new reserves. Significant folds in production increase are possible from 2x to 7x.

Novel Coiled Tubing Perforation Approach Enables Efficient Multistage Hydraulic Fracturing Operations in a Horizontal Well in Oman

2016 ◽  
Author(s):  
Ali Al-Ghaithi ◽  
Fahad Alawi ◽  
Ernest Sayapov ◽  
Ehab Ibrahim ◽  
Najet Aouchar ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Horizontal Well ◽  
Multistage Hydraulic Fracturing ◽  
Coiled Tubing

Challenging Catenary Coiled Tubing Thru Tubing Screen Deployment Operation Offshore Borneo

2021 ◽  
Author(s):  
Seng Wei Jong ◽  
Yee Tzen Yong ◽  
Yusri Azizan ◽  
Richard Hampson ◽  
Rudzaifi Adizamri Hj Abd Rani ◽  
...  
Keyword(s):  
Oil Wells ◽  
Well Control ◽  
Coiled Tubing ◽  
Open Hole ◽  
Catenary System ◽  
Offshore Oil ◽  
Gravel Pack ◽  
Emergency Measures

Abstract Production decline caused by sand ingress was observed on 2 offshore oil wells in Brunei waters. Both wells were completed with a sub-horizontal openhole gravel pack and were subsequently shut in as the produced sand would likely cause damage to the surface facilities. In an offshore environment with limited workspace, crane capacity and wells with low reservoir pressures, it was decided to intervene the wells using a catenary coiled tubing (CT) vessel. The intervention required was to clean out the sand build up in the wells and install thru-tubing (TT) sand screens along the entire gravel packed screen section. Nitrified clean out was necessary due to low reservoir pressures while using a specialized jetting nozzle to optimize turbulence and lift along the deviated section. In addition, a knockout pot was utilized to filter and accommodate the large quantity of sand returned. The long sections of screens required could not be accommodated inside the PCE stack resulting in the need for the operation to be conducted as an open hole deployment using nippleless plug and fluid weight as well control barrier. A portable modular crane was also installed to assist the deployment of long screen sections prior to RIH with CT. Further challenges that needed to be addressed were the emergency measures. As the operation was to be conducted using the catenary system, the requirement for an emergency disconnect between the vessel and platform during the long cleanout operations and open hole deployment needed to be considered as a necessary contingency. Additional shear seal BOPs, and emergency deployment bars were also prepared to ensure that the operation could be conducted safely and successfully.

First Multistage Hydraulic Fracturing in Russian Offshore: Integrated Approach to Completion and Stimulation of Apt Deposits of V.Filanovsky Field

2021 ◽  
Author(s):  
Mikhail Yurievich Golenkin ◽  
Denis Vladimirovich Eliseev ◽  
Alexander Anatolyevich Zemchikhin ◽  
Alexey Alexandrovich Borisenko ◽  
Akhmat Sakhadinovich Atabiyev ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Caspian Sea ◽  
Complex Type ◽  
The Caspian Sea ◽  
Multistage Hydraulic Fracturing ◽  
Coiled Tubing ◽  
Sand Control ◽  
Friction Reducing ◽  
First Time ◽  
Stimulation Of

Abstract The paper describes the results of the first multistage hydraulic fracturing operations in Russia on the Caspian Sea shelf in the gas condensate and oil deposits of the Aptian formation of V. Filanovsky field. In addition to the small productive formation depth, long horizontal sections with a complex trajectory and high collapse gradients due to large zenith angles when passing the Albian and Aptian deposits of poorly consolidated sandstones are an additional challenge for choosing a multistage hydraulic fracturing assembly. The above features require the use of modern sand control screens with enhanced frac sleeves. A design was developed which includes frac sleeves and sand control screens that can withstand multiple cycles of hydraulic impact during hydraulic fracturing, as well as many opening/closing cycles. A seawater-based frac fluid system was applied. The frac fleet was located on a pontoon, the coiled tubing – on a platform. For the first time in Russia, a 2-5/8 inch coiled tubing with a complex-type friction reducing system was used to switch coupling/sleeves in conditions of very long horizontal sections, complex trajectories, and high friction coefficients. The minimum distances between the screen's sliding sleeves and frac sleeves did not prevent from performing manipulations in complex environment. For well cleaning, the frac assemblies of reverse rotary-pulse and rotary-directional types were used. At the first stage of the project, the development of an optimal method of well completion was successfully implemented. Due to the close interaction of the operating company, service company, and science & engineering team of the operator, for the first time in Russia the design of downhole equipment with the use of advanced technologies of sand control screens, frac sleeves was presented. This solution has proved its effectiveness – the downhole equipment has retained its operational properties after a long period of well operation and further in the process of hydraulic fracturing. At the second stage of the project, 32 MSHF operations were performed at four wells. To reduce nonproductive time and operational risks, a satellite communication complex was additionally deployed on the pontoon to join the engineering centers of Astrakhan, Moscow, and Houston. After finishing the well development, the design indicators for formation fluid rates were achieved, which proved the effectiveness of the stimulation of the field's target objects – this opens great prospects for further development of low-permeability reservoirs at offshore sites in the Caspian Sea. The successful project implementation and the achievement of the design values of oil flow rates has expanded the possibilities of commercial operation of the low-permeable Aptian formation, complicated by the presence of a gas cap and underlying water. A solution was presented for working in extended horizontal well sections with 2-5/8 inch coiled tubing together with a complex-type mechanical friction reducing system. The economic effect was achieved when solving tasks of manipulating mechanical screen couplings and frac port sleeves without the involvement of downhole tractors. The use of new solutions in the completion assembly made it possible to eliminate additional sand ingress problems.

Microhole Coiled Tubing Drilling: A Low Cost Reservoir Access Technology

2009 ◽  
Vol 131 (1) ◽  
Author(s):  
Kent Perry
Keyword(s):  
Low Cost ◽  
Cost Savings ◽  
Field Testing ◽  
Widespread Application ◽  
Unconventional Gas ◽  
Drilling Rig ◽  
Coiled Tubing ◽  
Drilling Technology ◽  
Drilling Rigs ◽  
The U.S

Although the microhole coiled tubing drilling rigs have been used extensively in Canada, their application in the U.S. has been very limited. In an effort to introduce this technology to the U.S. operators, GTI, with the support of DOE∕NETL, has completed a successful field testing of the coiled tubing microhole drilling technology. In this paper we report results of field testing of the system in 25 wells drilled in the Niobrara unconventional gas play of Kansas and Colorado. The objective of the field test was to measure and document the rig performance under actual drilling conditions. In these tests, a coiled tubing drilling rig (designed and built by T Gipson with Advanced Drilling Technologies Inc.) was utilized. The rig operations have continued to improve to the point where it now drills a 3100ft well in a single day. Well cost savings of approximately 30% over conventional rotary well drilling have been documented. A description of the rig and a summary of its performance in the Niobrara unconventional gas play are included. In addition, an estimate of economic advantages of widespread application of microhole drilling technology in the lower 48 states is presented.

Mechanic simulator fluids for clean-up operations and phases separation in vertical and horizontal wells with coiled tubing technology

2015 ◽  
Vol 13 (32) ◽  
pp. 61-73
Author(s):  
Juan David Tarache Serrano ◽  
Germán Eduardo Martínez Barreto ◽  
Jenny Catalina González Peña ◽  
Magda Alexandra Trujillo Jiménez
Keyword(s):  
Phase Separation ◽  
Horizontal Wells ◽  
Oil Wells ◽  
Previous Knowledge ◽  
Coiled Tubing ◽  
Cleaning Methods ◽  
Physical Features

This Project look for the processes simulation that take place in the oil Wells that operate the coiled tubing technique, so its workers, Company personal and anyone that wants to look these processes, can prove that consist in their cleaning methods and phase separation in these Wells, and at the same time, in what way the substances that in and out of well are controlled, show their physical features and allow that a person, without previous knowledge about the topic, may understand easily what is it injection fluid purpose by means of the C. T. in oil Wells. 

Near-Tip-Screenout Hydraulic Fracturing Of Oil Wells In The Bach Ho Field, Offshore Vietnam

1995 ◽  
Author(s):  
L.V. Hung ◽  
N.T. San ◽  
A.G. Shelomentsev ◽  
J.A. Tronov ◽  
D.D. Lam ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Oil Wells

scholarly journals C-Reactive protein and SOFA score as early predictors of critical care requirement in patients with COVID-19 pneumonia in Spain

2020 ◽  
Author(s):  
Luis Mario Vaquero-Roncero ◽  
Elisa Sánchez-Barrado ◽  
Daniel Escobar-Macias ◽  
Pilar Arribas-Pérez ◽  
Jose Ramón Gonzalez-Porras ◽  
...  
Keyword(s):  
Critical Care ◽  
Sofa Score ◽  
Care Group ◽  
C Reactive Protein ◽  
Regression Methods ◽  
Reactive Protein ◽  
Early Predictors ◽  
Multivariable Regression ◽  
Care Assistance ◽  
Care Requirement

AbstractBackgroundSome patients infected by SARS-CoV-2 in the recent pandemic have required critical care, becoming one of the main limitations of the health systems. Our objective has been to identify potential markers at admission predicting the need for critical care in patients with COVID-19 pneumonia.MethodsWe retrospectively collected and analyzed data from electronic medical records of patients with laboratory-confirmed SARS-CoV-19 infection by real-time RT-PCR. A comparison was made between patients staying in the hospitalization ward with those who required critical care. Univariable and multivariable logistic regression methods were used to identify risk factors predicting critical care need.FindingsBetween March 15 and April 15, 2020, 150 patients under the age of 75 were selected (all with laboratory confirmed SARS-CoV-19 infection), 75 patients requiring intensive care assistance and 75 remaining the regular hospitalization ward. Most patients requiring critical care were males, 76% compared with 60% in the non-critical care group (p<0.05). Multivariable regression showed increasing odds of in-hospital critical care associated with increased C-reactive protein (CRP) (odds ratio 1.052 (1.009-1.101); p=0.0043) and higher Sequential Organ Failure Assessment (SOFA) score (1.968 (1.389-2.590) p<0.0001) both at the time of hospital admission. The AUC-ROC for the combined model was 0.83 (0.76-0.90) (vs AUC-ROC SOFA p<0.05).InterpretationPatients COVID-19 positive presenting at admission with high SOFA score ≥2 combined with CRP ≥ 9,1 mg/mL could help clinicians to identify them as a group that will more likely require critical care so further actions might be implemented to improve their prognosis.

scholarly journals Clinical Risk Factors for Long-term Hospital Stay in Common Patients with coronavirus disease 2019(COVID-19)

2020 ◽  
Author(s):  
Wei Lu ◽  
Junjie Fang ◽  
Bin Chen ◽  
Dan Wu ◽  
Chunyao Yu ◽  
...  
Keyword(s):  
Risk Factors ◽  
Hospital Stay ◽  
Potential Risk ◽  
Clinical Laboratory ◽  
Short Term ◽  
Factors Associated ◽  
Regression Methods ◽  
Potential Risk Factors ◽  
Multivariable Regression

Abstract Background This study aimed to investigate the potential risk factors associated with hospital stay in mild patients with COVID-19. Methods A total of 109 laboratory-confirmed COVID patients with initial common subtype diseased by real-time RT-PCR that meet discharge standards were retrospectively included from January 16 to March 15 of 2020. Baseline demographic, clinical, laboratory examination was extracted from electronic medical records at the first day of admission and compared between short-term hospital stay and long-term hospital stay. Univariable and multivariable logistic regression methods were used to explore the risk factors associated with hospital stay. Results Of 109 COVID-19 patients, 61 patients were short-term stay (≤ 10 days) and 48 patients were long-term stay (> 10 days). The average age of patients in short-term stay were younger than those long-term stay(P = 0.01). Hypertension was the most common comorbidity (34%, 21/61), followed by diabetes (15%,9/61) and Cardiopathy (8%, 5/61). Fever and cough were the typical clinical manifestation in two group. Decreased WBC, Hemoglobin and increased Monocyte, MLR (Monocyte Lymphocyte ratio) and Hypersensitive CRP showed a long-term stay (all P < 0.05). The treatment of Resochin and Human immunoglobulin had a shorter hospital stay. Multivariable regression showed that MLR and CRP on admission were risk factors for predicting the hospital stay, with the HR (hazard ratio 2.03, 1.02–5.39; P = 0.022) and (1.32,1.05–3.24, P = 0.045) respectively. Conclusions The potential risk factors of MLR and CRP may help clinicians to predict the hospital stay of COVID-19 patients.

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