A Novel Approach to Drill Stem Selection for Drilling in Sour Fields

2021 ◽  
Author(s):  
Guillaume Plessis ◽  
Andrei Muradov ◽  
Laurent Bordet ◽  
Richard Griffin ◽  
Lucien Hehn
Keyword(s):  
Drilling Fluid ◽  
Drill Pipe ◽  
High Strength ◽  
Drill String ◽  
Oil Companies ◽  
Technology Leader ◽  
Drill Stem ◽  
Novel Approach ◽  
Sulfide Stress ◽  
Sour Service

Abstract For years the drilling industry has used sour service drill pipe within a narrow set of specifications and industry guidelines. That left room for original equipment manufacturers (OEM) to have customization on an iterative basis, which resulted in a wide product offering to fulfill operator needs. While this method worked, it did not lead to building the product in the most efficient and economical manner. As a result of this product diversity, drilling engineers could specify the best product to deliver their projects when running drilling models, only to have to redesign it around what is effectively available on rigs or for rental. This disconnect puts pressure on the industry players and is the result of a lack of standardization. We wiped the board to provide a simple solution that is more suited to allow alignment between operators, contractors, and rental companies. The new philosophy is based on the National Association of Corrosion Engineers (NACE) MR0175-2015 severity diagram, where environmental severity is defined in regions (1, 2, and 3), which have been used by oil companies’ engineers for their oil country tubular goods (OCTG) product selection. Even though the drill string will not be exposed to the well fluid for the same extended time and is surrounded by a more forgiving medium, the drilling fluid, the diagram allows a segmentation of customer's needs. This framework helped define targeted product properties. A research and development (R&D) and industrialization test campaign could then be started to confirm that sound product configurations could be offered with targeted properties. The study also explored the limitations imposed on connection make-up torque in a sour gas environment relative to the NACE severity diagram. Emphasis was given on methods to increase the make-up torque, which is needed to deliver the most extended reach wells that are now commonplace. The result of this two-year development campaign is a short list of grades with an optimized balance between pipe subcomponents strength and sulfide stress cracking (SSC) resistance. Region 1 (mild severity) products will offer as much tension and torque as possible, matching or exceeding these of API products, including excellent resistance to SSC, thus making drilling operation safer. Region 2 (medium severity) will offer products with medium to high strength and enhanced SSC resistance. Finally, region 3 (high severity) products will be aligned with the industry specifications for maximized SSC resistance and lower strength. This paper discusses a proactive approach that contrasts with a historical, more reactive one. As the drill stem technology leader, we saw an opportunity to drive this initiative that will benefit the drilling industry by offering a more natural way to select drill stem products. For the first time a sour service product range aligns with the needs of drilling engineers and the inventory of their selected service companies.

Pipe stick problems of deep well drilling

2021 ◽  
Vol 66 (05) ◽  
pp. 192-195
Author(s):  
Rövşən Azər oğlu İsmayılov ◽  
Keyword(s):  
Drilling Fluid ◽  
Drill Pipe ◽  
Drill String ◽  
Differential Pressure ◽  
Drilling Mud ◽  
Fluid Circulation ◽  
Well Drilling ◽  
Deep Well ◽  
Pressure Pipe ◽  
Bottomhole Pressure

The aricle is about the pipe stick problems of deep well drilling. Pipe stick problem is one of the drilling problems. There are two types of pipe stick problems exist. One of them is differential pressure pipe sticking. Another one of them is mechanical pipe sticking. There are a lot of reasons for pipe stick problems. Indigators of differential pressure sticking are increase in torque and drug forces, inability to reciprocate drill string and uninterrupted drilling fluid circulation. Key words: pipe stick, mecanical pipe stick,difference of pressure, drill pipe, drilling mud, bottomhole pressure, formation pressure

Fit For Service Qualification for Sour Service High Strength Production Casing For High Temperature

2021 ◽  
Author(s):  
Luciana I. L Lima ◽  
Christelle Gomes ◽  
Carine Landier ◽  
Marilia Lima ◽  
Kevin Schleiss ◽  
...  
Keyword(s):  
Carbon Steel ◽  
Yield Strength ◽  
High Strength ◽  
Materials Selection ◽  
Well Production ◽  
Stress Cracking ◽  
Sulfide Stress ◽  
Sulfide Stress Cracking ◽  
Sour Service ◽  
Minimum Yield

Abstract In recent years the application of high strength carbon steel with 125ksi specified minimum yield strength as a production casing in deepwater and high-pressure reservoirs has increased. Sulfide stress cracking (SSC) can develop when high strength carbon steel is exposed to a sour environment. The H2S partial pressure in these sour reservoirs is above the 0.03 bar limit for this material at room temperature. Materials SSC performance evaluation requires an accurate simulation of field conditions in the laboratory. To evaluate the production casing SSC behavior, some fit for service (FFS) tests were carried out considering the well geothermic temperature profile for the materials selection. This paper presents a fit for service qualification carried out on Casing 125 ksi SMYS (Specified Minimum Yield Strength) materials. Two products with 125ksi SMYS were considered: one that has existed for several years and one developed more recently with a better SSC resistance – above the pH2S limit considered for the standard 125ksi SMYS material. The results obtained in this test program allowed casing 125 ksi SMYS materials selection for temperature above 65°C and environment more severe in terms of pH2S than the domain previously established for this grade. This allowed a new well production design, which saves one casing phase and avoids the necessity to use intermediate liners to prevent collapse.

New Approaches for Drilling Highly Depleted Reservoir in Deep Water Wells

2021 ◽  
Author(s):  
Ola Mohamed Balbaa ◽  
Hesham Mohamed ◽  
Sherif Mohamed Elkholy ◽  
Mohamed ElRashidy ◽  
Robert Munger ◽  
...  
Keyword(s):  
Deep Water ◽  
Drilling Fluid ◽  
Drill Pipe ◽  
Cost Effective ◽  
Drill String ◽  
Drilling Fluids ◽  
Prevention Measures ◽  
Enabling Factors ◽  
Design Changes ◽  
The Mediterranean

Abstract While drilling highly depleted gas reservoirs with a very narrow drilling window, Common drilling methods like utilizing loss of circulation pills, wellbore strengthening materials and managed pressure drilling (MPD) are being used in several reservoirs, yet it cannot be successful or cost effective if applied in a traditional manner. Innovative approaches to enable drilling wells in highly depleted reservoir in the Mediterranean deep water were adopted. The approaches incorporated design changes to the well and Bottom hole assembly (BHA), optimized drilling practices, and unconventional use of MPD while drilling and cementing production liner. Well design change in comparison to offset wells to allow drilling the reservoir in one hole section. Several design changes were considered in the BHA and drilling fluids to prevent as well as mitigate losses and differential sticking risks. From the BHA viewpoint, one of the key successful prevention measures was maximizing the standoff to reduce the contact area with the formation, this was achieved through utilizing spiral heavy wall drill pipe (HWDP) instead of drill collars in addition to a modeled placement of stabilizers and roller reamers. While on the drilling fluid side, Calcium carbonate material was added to strengthen wellbore, prevent losses and avoid formation damage. Particle size up to 1000 micron and concentration up to 40ppb was used to strengthen the depleted sands dynamically while drilling. Furthermore, as mitigation to stuck pipe, Jar and accelerator placement was simulated to achieve optimum impulse and impact force while maintaining the Jar above potential sticking zone. Whereas to address the consequence of a stuck pipe event, disconnect subs were placed in BHA to allow for recovering the drill string efficiently. MPD was first introduced in the Mediterranean in 2007 and continued to develop this well-known technique to mitigate various drilling challenges. For this well, MPD was one of the key enabling factors to safely drill, run and cement the production liner. Surface back pressure MPD allowed using the lowest possible mud weight in the hole and maintaining downhole pressure constant in order to manage the narrow drilling window between the formation pressure and fracture pressure (less than 0.4 ppg). MPD was also applied for the first time for running and cementing the production liner to prevent losses and achieve good cement quality which is a key to successful well production.

Failure Analysis of Fractured S135 Grade Drill Pipe

2013 ◽  
Vol 431 ◽  
pp. 69-74 ◽  
Author(s):  
Cai Hong Lu ◽  
Yong Gang Liu ◽  
Xin Hu Wang ◽  
Fang Po Li ◽  
Ting Ting Qu
Keyword(s):  
Stress Corrosion ◽  
Drill Pipe ◽  
Testing Machine ◽  
High Hardness ◽  
High Strength ◽  
Optical Microscope ◽  
Composition Analysis ◽  
Pipe Material ◽  
Destructive Testing ◽  
Sulfide Stress

The fractured drill pipe was investigated by means of non-destructive testing, chemical composition analysis, optical microscope, material property testing machine and SEM with EDS. The results showed that fracture of drill pipe body was hydrogen sulfide stress corrosion cracking. High strength, high hardness, and stress corrosion sensitivity of the drill pipe material were important reasons leading to failure.

Cuttings Bed Removal in Deviated Wells

2018 ◽  
Author(s):  
Jan David Ytrehus ◽  
Bjørnar Lund ◽  
Ali Taghipour ◽  
Birgitte Ruud Kosberg ◽  
Luca Carazza ◽  
...  
Keyword(s):  
Test Section ◽  
Critical Angle ◽  
Drilling Fluid ◽  
Drill Pipe ◽  
Drill String ◽  
Flow Loop ◽  
Cleaning Efficiency ◽  
Hole Cleaning ◽  
Low Viscosity ◽  
Deviated Wells

A drilling fluid for drilling deviated wellbores must provide adequate hole cleaning efficiency for all well angles relevant to the operation. For angles near vertical, experience show that hole cleaning is straight forward. In wellbore angles larger than, say, 45 degrees hole cleaning is more difficult. Cuttings beds are formed and at some well angles these beds may avalanche during circulation stops etc. This paper presents results from laboratory tests with injected cuttings using a low viscosity oil based drilling fluid with micronized grained barite as weight material. The fluid is designed for highly deviated wells with low ECD requirements and the cuttings transport performance through relevant wellbore inclinations was investigated. The experiments have been performed under realistic conditions. The flow loop includes a 10 meters long test section with 2” OD freely rotating steel drill string inside a 4” ID wellbore made of steel, representing a cased wellbore. Sand particles were injected while circulating the drilling fluid through the test section. Experiments were performed in three wellbore inclinations: 48, 60 and 90 degrees from vertical. Results show that hole cleaning in absence of drill pipe rotation is significantly improved if the well angle is less than a critical angle. This critical angle appears to be less than 60 degrees from vertical. Further result show that this critical inclination angle is dependent to the drill string rotation rate and the annular flow velocity.

Full Ring Evaluation of X70 Grade UOE Line Pipes for Sour Service

2012 ◽  
Author(s):  
Kenji Kobayashi ◽  
Tomohiko Omura ◽  
Masahiko Hamada ◽  
Hiroyuki Nagayama ◽  
Izuru Minato ◽  
...  
Keyword(s):  
Large Diameter ◽  
High Strength ◽  
Casting Process ◽  
Ring Test ◽  
Past Performance ◽  
Stress Cracking ◽  
Hydrogen Induced Cracking ◽  
Sulfide Stress ◽  
Sulfide Stress Cracking ◽  
Sour Service

High-strength large-diameter UOE line pipes over X70 grade are difficult to apply to actual fields, including H2S, because of a deterioration of sour resistance and a lack of past performance. However, API X70 grade large-diameter UOE line pipes for sour service have been manufactured stably by optimizing the continuous casting process, controlling the shape of inclusions and decreasing coarse precipitates. A full-ring test can simulate fairly well the actual applied conditions of line pipes and evaluate hydrogen induced cracking (HIC), sulfide stress cracking (SSC) and stress oriented hydrogen induced cracking (SOHIC) of line pipes for sour service simultaneously. It was confirmed that the X70 grade UOE line pipes have a good sour resistance from standard HIC tests, four-point bent beam SSC tests and the full-ring test including a seam weld under severe sour conditions (NACE solution A with 0.1 MPa H2S). In addition, the SSC resistance of a girth welded portion was also investigated by using simulated HAZ.

Evaluation on Chloride Cracking of S135 High-Strength Drill Pipe

2012 ◽  
Vol 430-432 ◽  
pp. 636-639
Author(s):  
Zhang Zhi ◽  
Xiao Yu Zhou ◽  
De Zhi Zeng ◽  
Ji Yin Zhang ◽  
Tai He Shi
Keyword(s):  
Heat Treatment ◽  
Weld Joint ◽  
Friction Welding ◽  
Drilling Fluid ◽  
Drill Pipe ◽  
High Strength ◽  
Chloride Ions ◽  
Post Weld Heat Treatment ◽  
Uniform Corrosion ◽  
Weld Heat

During the process of deep drilling with high temperature and high pressure, downhole drilling tools might be exposed to various corrosive mediums, such as water/oil-based drilling fluid systems, dissolved oxygen, H2S/CO2, halogen elements (Cl- and Br-), etc. Halogen elements existing in the drilling fluid are ions promoting corrosion of metals. This effect is mainly manifested in the forms of uniform corrosion, pitting corrosion, stress corrosion cracking, etc. of carbon steel. Quality of the drill pipe is determined by the DP body, joint and welding area of the drill pipe. Reasonable friction welding process and proper post weld heat treatment can make the mechanical property of weld joint satisfy related standards. If process of friction welding or post weld heat treatment is improper, the weld joint will be easily damaged and accidents of pricking, breaking, etc will be likely aroused. This paper carries out an evaluation experiment of chloride cracking on the DP body, joints and weld joints of the high-strength drill pipe (S135) and discusses corrosion of the high-strength drill pipe caused by chloride ions.

Test to Determine Hydrodynamic Interaction Between Drilling Riser, Drill String and Mud

2017 ◽  
Author(s):  
Songcheng Li ◽  
Mike Campbell ◽  
Massimiliano Russo ◽  
Erling Katla
Keyword(s):  
Drag Coefficient ◽  
Drilling Fluid ◽  
Drill Pipe ◽  
Added Mass ◽  
Drill String ◽  
Hydrodynamic Damping ◽  
Well Integrity ◽  
Wide Range ◽  
Mass Coefficient ◽  
Added Mass Coefficient

Drilling riser damping can have a significant effect on the dynamic response of the drilling system, especially the fatigue response of the wellhead and conductor system. The presence of any drilling riser damping helps to diminish the transfer of riser motions into the wellhead system, which can improve any wellhead fatigue issues. One of the little studied contributors to the system damping is the hydrodynamic damping effect of the interaction between the drill pipe and drilling fluid inside the riser. As part of the ongoing Structural Well Integrity Joint Industry Project (JIP), finite element analysis (FEA) with a wide range of drag and inertia coefficients is conducted to simulate the mud drag and inertia on the drill string and the riser. These sensitivity studies demonstrate that the mud drag and inertia on the drill string could be one of the key driving factors in riser system damping. To verify the FEA work, the Structural Well Integrity JIP conducted a laboratory test to determine the drag coefficient and added mass coefficient of drill pipe inside a marine drilling riser with and without flowing mud and water in the riser annulus. In this paper, the test setup and the test matrix are introduced, and the methodology for determining drag coefficient and added mass coefficient are explained. The test results are also presented and compared with published test data for open water.

The Effect of Different Drilling Fluids on Borehole Mechanical Friction

2014 ◽  
Author(s):  
Ali Taghipour ◽  
Jan David Ytrehus ◽  
Bjørnar Lund ◽  
Arild Saasen
Keyword(s):  
Drilling Fluid ◽  
Drill String ◽  
Solid Particles ◽  
Drilling Fluids ◽  
Test Results ◽  
Friction Behavior ◽  
Basic Point ◽  
Oil Companies ◽  
Water Based ◽  
Extended Reach Drilling

Mechanical friction is one of the most important aspects in highly inclined wellbores such as extended reach drilling (ERD) and through tubing extended reach drilling (TTERD). Friction caused by the contact between the drill string and the well casing or borehole is dependent to the drilling weight and fluid properties. Drilling fluids play an important role on mechanical friction and using oil based drilling fluids with higher lubricity can reduce torque and drag and minimize stick and slip concerns. Reducing mechanical friction will improve drilling efficiency in general, and will in particular enable longer reach for ERD wells. This paper presents results from experimental laboratory tests where mechanical friction has been investigated in non-circular wellbore geometry. The experiments have been conducted as part of a research project in the tribology lab in Technical University of Luleå. The project was sponsored by the Research Council of Norway and four oil companies. Friction behavior has been investigated for two different drilling fluids; water based and oil based drilling fluids both with and without solid particles. A pin on disc setup was used for these experiments where a spherical steel pin was sliding on a rotational disc made of granite. Friction force has been measured in constant sliding speed and in presence of particles in wet condition. The test results show that mechanical friction is smaller with oil based than water based drilling fluids in the presence of solid particles. In addition, the friction coefficient depends to the particle types and is higher when solid particles were added to the lubricants. Such experiments in a tribology laboratory are important to identify the effect of drilling fluid on mechanical friction from a basic point of view isolated from the other wellbore parameters. Test results and the experimental approach could therefore be of value for any one working with drilling and well construction.

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