Solid-Free Flexible Colloidal Completion Fluid with Variable Density for Gas Well Completion in High-Temperatureand High-Pressure Reservoirs: Experimental Study and Pilot Test

SPE Journal ◽  
2021 ◽  
pp. 1-18
Author(s):  
Hu Jia ◽  
Cheng-Cheng Niu ◽  
Chang-Lou Dai
Keyword(s):  
High Pressure ◽  
Dynamic Viscosity ◽  
Colloidal Particles ◽  
Oil And Gas ◽  
Free Water ◽  
Variable Density ◽  
Well Completion ◽  
Pump Rate ◽  
Water Blocking ◽  
Ultrahigh Temperature

Summary Despite the increasing contribution of renewables to global energy, fossil fuels such as oil and gas still play an important role in energy supply. The development of deep and ultradeep oil and gas reservoirs has become more urgent. Typically, the ultrahigh-temperature and high-pressure (HTHP) environment is a big challenge. Solid-free brine is often used as a weighting component of high-density well completion fluid in the process of well operation, but the large amount of free water can easily cause water blocking damage to the reservoir. Therefore, there is an urgent need to develop a high-density completion fluid system that can be used in HTHP reservoir environments with little free water. In this paper, based on the theory of dispersion, degradation, viscosity extraction, and viscosity stabilization of polymer flexible colloidal particles in brines, an ultrahigh-temperature (180°C)-resistant, solid-free flexible colloidal completion fluid (SFCCF) with variable density and low corrosion was prepared. It breaks through the classical Flory’s water absorption theory. The phosphate brine was selected as the weighting base fluid of SFCCF, and the flexible colloidal particles were saturated with the phosphate brine to improve the density of SFCCF, as well as to reduce free water to lower the potential of water blocking damage. The results show that the dynamic viscosity of SFCCF is adjustable and ranges from 27 to 690 mPa·s, and the density is adjustable in the range of 1 to 1.8 g/cm3. SFCCF is a typical pseudoplastic fluid with shear dilution property, which is the result of the network destruction and the shear deformation of the flexible colloidal particles. The pump rate vs. dynamic viscosity curve is drawn. Under the pump rate of 50 to 800 L/min, the dynamic viscosity of SFCCF (1.2 to 1.7 g/cm3) is less than 40 mPa·s. In addition, SFCCF is viscosity stable for at least 4 days at 180°C and has excellent clay swelling resistance and reservoir fluid compatibility. Finally, SFCCF provides good reservoir protection and rock carrying capabilities and has the advantage of low cost. The successful application of SFCCF in a high-pressure gas well in the East China Sea is summarized, and some recommendations are proposed. The developed SFCCF can significantly reduce water blocking damage in HTHP well operations, providing a new avenue for HTHP well completions.

The Feasibility for Potassium-Based Phosphate Brines To Serve as High-Density Solid-Free Well-Completion Fluids in High-Temperature/High-Pressure Formations

SPE Journal ◽  
2018 ◽  
Vol 24 (05) ◽  
pp. 2033-2046 ◽  
Author(s):  
Hu Jia ◽  
Yao–Xi Hu ◽  
Shan–Jie Zhao ◽  
Jin–Zhou Zhao
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Oil And Gas ◽  
Pressure Coefficient ◽  
High Density ◽  
Well Drilling ◽  
Well Completion ◽  
Oil And Gas Resources ◽  
Completion Fluids ◽  
High Temperature High Pressure

Summary Many oil and gas resources in deep–sea environments worldwide are often located in high–temperature/high–pressure (HT/HP) and low–permeability reservoirs. The reservoir–pressure coefficient usually exceeds 1.6, with formation temperature greater than 180°C. Challenges are faced for well drilling and completion in these HT/HP reservoirs. A solid–free well–completion fluid with safety density greater than 1.8 g/cm3 and excellent thermal endurance is strongly needed in the industry. Because of high cost and/or corrosion and toxicity problems, the application of available solid–free well–completion fluids such as cesium formate brines, bromine brines, and zinc brines is limited in some cases. In this paper, novel potassium–based phosphate well–completion fluids were developed. Results show that the fluid can reach the maximum density of 1.815 g/cm3 at room temperature, which makes a breakthrough on the density limit of normal potassium–based phosphate brine. The corrosion rate of N80 steel after the interaction with the target phosphate brine at a high temperature of 180°C is approximately 0.1853 mm/a, and the regained–permeability recovery of the treated sand core can reach up to 86.51%. Scanning–electron–microscope (SEM) pictures also support the corrosion–evaluation results. The phosphate brine shows favorable compatibility with the formation water. The biological toxicity–determination result reveals that it is only slightly toxic and is environmentally acceptable. In addition, phosphate brine is highly effective in inhibiting the performance of clay minerals. The cost of phosphate brine is approximately 44 to 66% less than that of conventional cesium formate, bromine brine, and zinc brine. This study suggests that the phosphate brine can serve as an alternative high–density solid–free well–completion fluid during well drilling and completion in HT/HP reservoirs.

Laboratory-Scale Investigation of the Utilisation of Multiple Flat-Fan Nozzles in Descaling Petroleum Production Tubing

2021 ◽  
Author(s):  
Kabir Hasan Yar'Adua ◽  
Idoko Job John ◽  
Abubakar Jibril Abbas ◽  
Salihu M. Suleiman ◽  
Abdullahi A. Ahmadu ◽  
...  
Keyword(s):  
High Pressure ◽  
Oil And Gas ◽  
Gas Production ◽  
Oil And Gas Production ◽  
Scale Removal ◽  
Petroleum Production ◽  
Well Completion ◽  
Water Jets ◽  
Well Integrity ◽  
Injection Pressures

Abstract Despite the recent wide embrace of mechanical descaling approaches for cleaning scales in petroleum production tubings and similar conduits with the use of high-pressure (HP) water jets, the process is still associated with downhole backpressure and well integrity challenges. While the introduction of sterling beads to replace sand particles in the water recorded high successes in maintaining well completion integrity after scale removal in some recent applications of this technique, it is, unfortunately, still not without questions of environmental degradation. Furthermore, the single nozzle, solids-free, aerated jetting descaling technique – recently published widely – is categorized with low scale surface area of contact, low descaling efficiency and subsequent high descaling rig time. The modifications to mechanical descaling techniques proposed in this work involve the use of three high-pressure flat fan nozzles of varying nozzles arrangements, standoff distances and injection pressures to remove soft scale deposits in oil and gas production tubings and similar circular conduits. This experiment provides further insights into the removal of paraffin scales of various shapes at different descaling conditions of injection pressures, stand-off distances and nozzle arrangements with the use of freshwater. The results obtained from this study also show consistency with findings from earlier works on the same subject.

Novel Well Flow-Control Valve for Flexible Well Completion and Application in Commingled Production of Oil and Gas in West Africa

2016 ◽  
Author(s):  
Joseph Bagal ◽  
Maximilien Hallaire ◽  
Paul Hazel
Keyword(s):  
High Pressure ◽  
Flow Control ◽  
Field Trial ◽  
Oil And Gas ◽  
Control Valve ◽  
Gas Production ◽  
Flow Control Valve ◽  
Well Completion ◽  
Gas Lift ◽  
Flow Valve

ABSTRACT This paper presents the development, qualification and field trial of a novel well flow valve that delivers unlimited zonal selectivity in single skin lower completion without the use of control lines. Control lines have limitations and risks due to complexity during deployment, restrictions on the number of zones, complications with liner hanger feed thru and associated wet connects. It is desirable to remove the control lines whilst maintaining the functionality of multi zone, variable choke flow control. The well flow valve is a full-bore, reliable and robust mechanically operated sleeve, qualified in accordance with ISO14998 including multiple open/close cycles, at a sustained unloading pressure of 1,500 psi, with highly customizable flow ports. The need for such a solution was identified by an operator in West Africa. The well objective was elevated from a gas producer to a well that required the flexibility to produce gas or oil with gas lift capability. The well flow valve was selected and required on site variable choke capability for both oil and gas production, with choke position verification, ability to handle dirty gas production without risk of plugging, compliant with a high rate and high pressure proppant frac along with ease of operation and long term reliability. The field trial included a high pressure proppant frac in the oil zone. In the shallower gas zone, three well flow valves were used to deliver variable choking capability from maximum gas flow rate with minimal delta P adjusting down to a choke size suitable for gas lift. The well flow valves were operated using a high expansion shifting key conveyed on eline through the 3 ½" production tubing. The shifting key expanded in the 4 ½" lower completion to open/close individually all the well flow valves in a single trip. Incorporating this new product overcame the challenges presented and met the objective of commingled production of oil and gas. The well flow control valve demonstrated flexibility through design, supply chain, manufacturing, and operations. This paper will also outline the future road map covering further developments of the well flow valve and its incorporation into an enhanced flexible lower liner solution aimed at lowering well completion costs and risks.

Successful Implementation of the PMCD Technology for Drilling and Completing the Well in Incompatible Conditions at Severo – Danilovskoe Oil & Gas Field

2021 ◽  
Author(s):  
Dmitry Krivolapov ◽  
Ivan Masalida ◽  
Artem Polyarush ◽  
Vyacheslav Visloguzov ◽  
Alexey Averkin ◽  
...  
Keyword(s):  
High Pressure ◽  
Oil And Gas ◽  
Back Pressure ◽  
Successful Implementation ◽  
Drilling Mud ◽  
Gas Field ◽  
Lost Circulation ◽  
Well Completion ◽  
Drilling Technology ◽  
Operating Window

Abstract This paper discusses the successful implementation of PMCD (Pressurized Mud Cap Drilling) technology at Severo – Danilovskoe oil and gas field (SDO) located in the Irkutsk region. The abnormally high-pressure reservoir B1 and the abnormally low-pressure reservoir B5 are the target layers in this field. Wells drilling at SDO is accompanied with simultaneous mud losses and inflows conditions, especially if the strata B1 is being penetrated. Pumping lost circulation materials (LCM) and cement plugs do not solve lost circulation complications which subsequently lead to oil and gas inflows. As a result, most of such wells are getting abandoned. It was assumed that complications in this formation occurs due to the narrow safe pressures’ operating window (ECD window), therefore, the managed pressure drilling technology (MPD) was initially used as a solution to this problem. However, after the penetration of the abnormally high formation pressure B1 horizon with a pore pressure gradient of 1.86 g/cm3 it was found that there is no operating window. In this regard, there were simultaneous mud losses and oil and gas inflows during the circulation. The well was gradually replaced by oil and gas, regardless of the applied surface back pressure value in the MPD system. The mixing of the mud and reservoir fluid was accompanied by catastrophic contamination. As a result, the drilling mud became non - flowing plugging both the mud cleaning system and the gas separator. On the other hand, the plugging of the B1 formation with LCM did not bring any positive results. Bullheading the well followed by drilling with applied surface back pressure and partial mud losses gave only a temporary result and required a large amount of resources. An implementation of PMCD technology instead of MPD has been proposed as an alternative solution to the problem. This technology made it possible to drill the well to the designed depth (2904 - 3010 m interval). For tripping operations, as well as the subsequent running of the production liner it was necessary to develop an integrated plan for well killing and completion in extreme instability conditions. As a result of various killing techniques application, it became possible to achieve the stability of the well for 1 hour. Oil and gas inflows inevitably occurred when the 1 hour lasted. Based on these conditions, the tripping and well completion process was adapted, which in the end made it possible to successfully complete the well, run the liner and activate the hanger in the abnormally high-pressure reservoir.

Study on the Characteristics of Well Completion Technology in Deepwater Oil and Gas Field Development

2021 ◽  
Vol 3 (8) ◽  
pp. 70-72
Author(s):  
Jianbo Hu ◽  
◽  
Yifeng Di ◽  
Qisheng Tang ◽  
Ren Wen ◽  
...  
Keyword(s):  
Deep Water ◽  
Deep Sea ◽  
Oil And Gas ◽  
Gas Field ◽  
Marine Research ◽  
Field Development ◽  
Research Technology ◽  
Well Completion ◽  
Development Capacity ◽  
Exploration And Development

In recent years, China has made certain achievements in shallow sea petroleum geological exploration and development, but the exploration of deep water areas is still in the initial stage, and the water depth in the South China Sea is generally 500 to 2000 meters, which is a deep water operation area. Although China has made some progress in the field of deep-water development of petroleum technology research, but compared with the international advanced countries in marine science and technology, there is a large gap, in the international competition is at a disadvantage, marine research technology and equipment is relatively backward, deep-sea resources exploration and development capacity is insufficient, high-end technology to foreign dependence. In order to better develop China's deep-sea oil and gas resources, it is necessary to strengthen the development of drilling and completion technology in the oil industry drilling engineering. This paper briefly describes the research overview, technical difficulties, design principles and main contents of the completion technology in deepwater drilling and completion engineering. It is expected to have some significance for the development of deepwater oil and gas fields in China.

Theorical Analysis of Leakage in High Pressure Pipe Using Acoustic Emission Method

2012 ◽  
Vol 445 ◽  
pp. 917-922 ◽  
Author(s):  
Saman Davoodi ◽  
Amir Mostafapour
Keyword(s):  
High Pressure ◽  
Acoustic Emission ◽  
Degrees Of Freedom ◽  
Oil And Gas ◽  
Pipe Wall ◽  
Leak Detection ◽  
Stress Waves ◽  
Motion Equation ◽  
Non Linear ◽  
Acoustic Emission Test

Leak detection is one of the most important problems in the oil and gas pipelines. Where it can lead to financial losses, severe human and environmental impacts. Acoustic emission test is a new technique for leak detection. Leakage in high pressure pipes creates stress waves resulting from localized loss of energy. Stress waves are transmitted through the pipe wall which will be recorded by using acoustic sensor or accelerometer installed on the pipe wall. Knowledge of how the pipe wall vibrates by acoustic emission resulting from leakage is a key parameter for leak detection and location. In this paper, modeling of pipe vibration caused by acoustic emission generated by escaping of fluid has been done. Donnells non linear theory for cylindrical shell is used to deriving of motion equation and simply supported boundary condition is considered. By using Galerkin method, the motion equation has been solved and a system of non linear equations with 6 degrees of freedom is obtained. To solve these equations, ODE tool of MATLAB software and Rung-Kuta numerical method is used and pipe wall radial displacement is obtained. For verification of this theory, acoustic emission test with continues leak source has been done. Vibration of wall pipe was recorded by using acoustic emission sensors. For better analysis, Fast Fourier Transform (FFT) was taken from theoretical and experimental results. By comparing the results, it is found that the range of frequencies which carried the most amount of energy is same which expresses the affectivity of the model.

Development and Evaluation of a Mobile Plant to Prepare Natural Gas for Use in Foam Fracturing Treatments

2017 ◽  
Author(s):  
Griffin Beck ◽  
Melissa Poerner ◽  
Kevin Hoopes ◽  
Sandeep Verma ◽  
Garud Sridhar ◽  
...  
Keyword(s):  
High Pressure ◽  
Natural Gas ◽  
Oil And Gas ◽  
Department Of Energy ◽  
Gas Processing ◽  
Current State ◽  
Fracturing Process ◽  
Mobile Plant ◽  
Processing Plants ◽  
Production Techniques

Hydraulic fracturing treatments are used to produce oil and gas reserves that would otherwise not be accessible using traditional production techniques. Fracturing treatments require a significant amount of water, which has an associated environmental impact. In recent work funded by the Department of Energy (DOE), an alternative fracturing process has been investigated that uses natural gas as the primary fracturing fluid. In the investigated method, a high-pressure foam of natural gas and water is used for fracturing, a method than could reduce water usage by as much as 80% (by volume). A significant portion of the work focused on identifying and optimizing a mobile processing facility that can be used to pressurize natural gas sourced from adjacent wells or nearby gas processing plants. This paper discusses some of the evaluated processes capable of producing a high-pressure (10,000 psia) flow of natural gas from a low-pressure source (500 psia). The processes include five refrigeration cycles producing liquefied natural gas as well as a cycle that directly compresses the gas. The identified processes are compared based on their specific energy as calculated from a thermodynamic analysis. Additionally, the processes are compared based on the estimated equipment footprint and the process safety. Details of the thermodynamic analyses used to compare the cycles are provided. This paper also discusses the current state of the art of foam fracturing methods and reviews the advantages of these techniques.

Testing antifreeze protein from the longhorn beetle Rhagium mordax as a kinetic gas hydrate inhibitor using a high-pressure micro differential scanning calorimeter

2015 ◽  
Vol 93 (9) ◽  
pp. 1025-1030 ◽  
Author(s):  
Nagu Daraboina ◽  
Christine Malmos Perfeldt ◽  
Nicolas von Solms
Keyword(s):  
High Pressure ◽  
Differential Scanning Calorimeter ◽  
Oil And Gas ◽  
Hydrate Formation ◽  
Antifreeze Protein ◽  
Melting Behavior ◽  
Relative Strength ◽  
Operating Pressure ◽  
Longhorn Beetle ◽  
Low Dosage

Low dosage kinetic hydrate inhibitors are employed as alternatives to expensive thermodynamic inhibitors to manage the risk of hydrate formation inside oil and gas pipelines. These chemicals need to be tested at appropriate conditions in the laboratory before deployment in the field. A high pressure micro differential scanning calorimeter HP-μDSC VII (Setaram Inc.) containing two 50 cc high pressure cells (maximum operating pressure 40 MPa; temperature range –40 to 120 °C) was employed to observe methane hydrate formation and decomposition in the presence of hyperactive antifreeze protein from Rhagium mordax (RmAFP) and biodegradable synthetic kinetic inhibitor Luvicap Bio. A systematic capillary dispersion method was used, and this method enhanced the ability to detect the effect of various inhibitors on hydrate formation with small quantities. The presence of RmAFP and Luvicap Bio influence (inhibit) the hydrate formation phenomena significantly. Luvicap Bio (relative strength compared to buffer: 13.3 °C) is stronger than RmAFP (9.8 °C) as a nucleation inhibitor. However, the presence RmAFP not only delays hydrate nucleation but also reduces the amount of hydrate formed (20%–30%) after nucleation significantly. Unlike RmAFP, Luvicap Bio promoted the amount of hydrate formed after nucleation. The superior hydrate growth inhibition capability and predictable hydrate melting behavior compared to complex, heterogeneous hydrate melting with Luvicap Bio shows that RmAFP can be a potential natural green kinetic inhibitor for hydrate formation in pipelines.

scholarly journals EVOLUTION OF THE QUALITY OF HIGH-PRESSURE VALVES DURING THE PERIOD OF THEIR INTENSIVE DEVELOPMENT

2021 ◽  
Vol 05 (01) ◽  
pp. 04-10
Author(s):  
Sabir Babaev ◽  
Ibrahim Habibov ◽  
Zohra Abiyeva
Keyword(s):  
High Pressure ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Machine Building ◽  
High Rate ◽  
Performance Criteria ◽  
Gas Industry ◽  
Evolution Of Technology ◽  
Intensive Development

Prospects for the further development of the oil and gas industry are mainly associated with the development and commissioning of high-rate fields. In this regard, the production of more economical and durable equipment by machine-building enterprises, an increase in the level of its reliability and competitiveness, as well as further improvement of technological production processes, is of paramount importance. The evolution of technology in a broad sense is a representation of changes in designs, manufacturing technology, their direction and patterns. In this case, a certain state of any class of TC is considered as a result of long-term changes in its previous state; transition from existing and applied in practice vehicles to new models that differ from previous designs. These transitions, as a rule, are associated with the improvement of any performance criteria or quality indicators of the vehicle and are progressive in nature. The work is devoted to the study of the evolution of the quality of high-pressure valves during the period of their intensive development. Keywords: technical system, evolution of technology, high-pressure valves, shut-off devices, gate.

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