bluuebunny/crossref_metadata_2025_split huggingface dataset:
One-Trip Chemistry Activates a Polymer and Cleans a Drilling Fluid Filter Cake at Once
Authors: Garza Ramon , Liu Bairu , Sadana Anil 
Published: June 2014

Abstract
An innovative sand control technology is being developed that has the capability to conform to the wellbore and apply a positive stress on the formation face. The technology is a porous shape memory polymer with the capability to change geometric shapes. This shape memory polymeric material is molded to an initial geometric shape. The material is then heated and compacted to a smaller volume, 25% of initial volume compacted, for run-in hole (RIH) geometry. As any shape memory polymer, it can recover its original shape if heated close to its Tg, or by temporarily chemically shifting its Tg to a new lower temperature that of its original Tg.
This paper will present the results of additives added to completion fluids, giving the final fluid composition the ability to activate the polymer to its original shape, and simultaneously clean up the filter cake left by the drilling fluid before the polymer reaches the wellbore. The additives are delayed so that the filter cake retains fluid loss properties during activation, but breaks shortly after the polymer reaches the gauge-hole, or has enough treatment caused by the one-trip fluid there by allowing for production at maximum flow rates. At the same time that the filter cake is being treated, a second additive is acting as a plasticizer on the shape memory polymer to activate it, forcing the polymer to recover its original shape. The results are measured via two test methods, one that monitors and records the activation time of the polymer to gauge hole, and a second method that measures the fluid loss properties of the filter cake ensuring that the filter cake is stable for the time required for the shape memory polymer to reach gauge hole.
Innovative Impregnated Drill Bit Design with Enhanced Durability Improves Performance in Challenging Application in Colombia
Authors: Becerra Fabian , Burch Connie , Cleboski Chris , Mendoza Sandro , Rodriguez Victor 
Published: June 2014

Abstract
Vertical wells are drilled in the Colombian foothills with various types of drill bits, including polycrystalline diamond compact bits (PDC), tungsten carbide insert bits (TCI), and impregnated (impreg) drill bits. With an operator's support a new 14¾-in. impreg bit was designed using an innovative new cutting structure to complete a challenging interval. This bit was paired with a low-speed power section and a high-speed power section in the bottomhole assembly (BHA) for two runs in the same well. Both runs did well, but the operator found the low-speed BHA to be a better match for the automated drilling system tool that was also in the BHA.
The multi-layered 14¾-in. section consists of hard and abrasive sandstone, interbedded claystone, and siltstone formations. The majority of drill bits suffer short runs due to severe wear in the outer region (shoulder) of the bit. The new impreg design was developed to increase run length and avoid unnecessary trips in the challenging formations.
The impreg bit uses diamond impregnated segments imbedded in blades comprised of diamond grit matrix material to create a cutting structure with variable wear along the bit face. This particular combination of diamond and matrix specifically corresponded to the application and improved overall aggressiveness and durability in the shoulder.
To drill efficiently, impregs are typically paired with high-speed motors or turbines (500-1200 rpm) due to the low depth of cut. This new impreg design, however, successfully drilled on two different BHAs. The first was with a high-speed power section (0.93 rev/gal) and drilled 108 ft at 4.9 ft/hr. The bit did not show signs of wear and was used on a second BHA with a low-speed power section (0.15 rev/gal) that drilled another 665 ft at 3.9 ft/hr. The impreg's overall performance was 773 ft drilled at 4.0 ft/hr. The bit showed only minor wear when compared to offset wells (15% vs. 80 to 100% cutting structure wear).
The addition of the impregnated segments and mixed grit combination improved the cutting structure durability. This success provides an opportunity to further develop the grit, matrix, and impregnated segment combination to increase the aggressiveness of the bit to drill faster and lower the overall drilling cost of a well.
This article will explain the benefits of the new technology and discuss how impregs effectively drilled hard and abrasive formations in a low-revolution application.
Directional Challenges and Planning of Relief Well to Resolve an HP/HT Well Blowout
Authors: Al-Muhailan M. , Al-Saleh Ali , Al-Shayji A. K. , Rajagopalan Arun , McKinnell D. C. 
Published: June 2014

Abstract
A blowout in an HPHT deep well posed a major challenge while designing the relief well which was required to bring the well under control. For the relief well it was necessary to carry out a comprehensive well design and operational planning, identification and mobilization of necessary equipment in a short time. This paper will describe the preparations made for this type of relief well in the region.
An existing deep J-shape directional well, suffered a blow out while drilling a deep Salt/Anhydrite formation where formation pressures were extremely high. The blowout well was surrounded with many other producing facilities, drilling activities and inhabited areas. The main challenge was to choose a suitable location as close as safely possible, in such a congested mature oil field, taking into consideration all the safety aspects such as wind direction, surrounded wells, flame and heat created from blowout well, etc. The other main well challenges concerned; well placement, intercept with blowing well and dynamic kill.
This paper will concentrate on the aspects of relief well design and planning. It will cover all related topics, such as; number of relief wells planned, surface location choice, potential drilling problems, directional design, detection of the blowout well, and placement philosophy. It will include a discussion on the specialized directional and ranging equipment and techniques needed to perform the critical operations of locating, following, and intersecting the blowing well. All aspects concerning HSE will be discussed in detail. The paper will present these in a case history format covering the design process, operational planning, and a description of well operations.
Innovative Drilling Systems for Kick-off, Curve Building and Landing a Lateral without Requiring Cement Plug
Authors: Swadi Shantanu , Desai Praful 
Published: June 2014

Abstract
Historically, the predominant sidetracking methodology for kick-off and subsequent curve building operation required setting a cement plug followed by using a directional BHA to drill deviated hole once the cement hardens. The success of the cement plug depends upon formation compressive strength, downhole temperature and pressure, wellbore deviation, cement plug depth, quality of cement and the plug cure time. The consequences of cement plug failure are extra trip time, a new cement plug, loss of drilling days and reconfiguration of drilling trajectory.
Recent R&D efforts have identified new methods and associated tools that can be effectively utilized to increase operational reliability in kicking off, subsequent curve building and landing a lateral without the cement plug in varieties of formations. This paper presents innovative drilling systems that can be deployed, azimuthally oriented, hydraulically set and configured to initiate drilling, all in the same trip downhole without the need for a cement plug.
The system includes:
A directional BHA which may include a rotary steerable system, a positive displacement motor or a turbo-drill A roller cone or a PDC or an impregnated drill bit selected for the formation with appropriate attachment mechanism A built-in deflector ramp for attachment with the drill bit and for maximum support and guidance to the directional drilling BHA A formation specific, expandable and hydraulically set anchor below the built-in deflector for three point firm grip with the hole wall to counteract rotational tendencies.
The increased reliability of the system comes from complete elimination of the cement plug and the ability to select appropriate drill bits and directional BHA for efficient kick-off and drilling a lateral. Additional benefit includes substantial cost savings in terms of reducing trip time and minimizing plugging materials.
The authors will describe the system's major components and the running procedure for different drilling situations. The authors will also discuss several field runs, involving various drilling conditions and utilizing different drilling systems. The field performance along with qualifying full scale laboratory tests demonstrates the system's viability and potential for operational reliability and cost savings.
Drilling Deepwater Carbonates Using Managed Pressure Drilling on a Dynamically Positioned Drillship
Authors: Ho R. , Moore D. , Pirie D. , Kozicz J. 
Published: June 2014

Abstract
Drilling carbonate formations presents challenging problems due to the high potential for massive loss circulation and well control situations. These problems can be further magnified in remote deepwater locations where access to material resources and logistics support is limited. Natural fractures commonly present in carbonate formations not only make losses and kicks more likely but they are also more difficult to control. The proper applications of Managed Pressure Drilling (MPD) methodology can help improve the safety of the drilling operations and greatly reduce the non-productive time associated with managing and solving the loss circulation problems.
The project discussed in this paper was executed in deepwater offshore Indonesia and clearly showed some of the benefits of using MPD in deepwater drilling. This paper discusses both the planning and execution of two wells drilled by applying various forms of MPD. The wells were drilled from a dynamically positioned (DP) drillship utilizing the world's first known application of a below tension ring Rotating Control Device (RCD), as well as an annular preventer for riser gas handling in between the riser slip joint and termination joint. Lessons learned associated with the installation of managed pressure drilling equipment on a DP vessel and the procedures used to drill the deepwater carbonate formations are presented in the paper.
Managing the HSE Interface: Changing How the Industry Owns the Space Where Operator, Driller and Service Providers Co-Exist
Authors: Hinton J. Jack , Debertrand M. Thierry , Karish John M. , Glencross Colette M. 
Published: June 2014

Abstract
"Great minds think alike" is a well known proverb that is often attributed to the results of successful actions. Within the oil and gas industry many individually possess the great minds and successful actions but at the well site, interface opportunities exist in how to maximize the synergies of our individual successful actions. Many of the catastrophic events within the industry have occurred in the physical and virtual space where Operators, Drilling Contractors (Drillers) and Service Providers co-exist. This may be related to where the joint parties have not effectively co-existed. While each has their own physical equipment and Health, Safety and Environment (HSE) Management Plans, these separate systems overlap. In this central space of overlap or interface, the risk of a catastrophic event can increase if the overlap is not effectively addressed or managed. Some collectively manage the interface using a Safety Case, Joint HSE Management Plans, and/or Simultaneous Operations Plans to identify hazards and mitigate risks. These processes and plans generally focus on addressing traditional Process Safety and Personal Safety hazards. Where the interface also jointly addresses the cultural and human factor aspects, by all parties, the risk of process and personal safety events can be greatly minimized.
This paper discusses the incorporation of the aspects of Culture and Human Factors into the management of the interface; complimenting the elements of Process Safety and Personal Safety. Five key aspects are explored: Mission, Accountability, Communication, Capacity, and Learning. By overlaying these aspects into a more holistic view of ownership, changes can be made to joint responsibility and management of this interface, enabling the industry to collectively accelerate step change in how process and personal safety risks are mitigated.
Don't Get Stung Setting Balanced Cement Plugs: A Look at Current Industry Practices for Placing Cement Plugs in a Wellbore Using a Stinger or Tail Pipe
Authors: Roye Justin , Pickett Sam 
Published: June 2014

Abstract
Cement plugs have been used for decades within the oil and gas industry. Some of the applications include zonal isolation, curing lost circulation, abandonment, and serving as a base for kicking-off or sidetracking. The most common method used for the placement of cement plugs is the balanced plug method using drillpipe, tubing, or a combination of both. The pipe is run in the wellbore to the desired depth of the bottom of the plug. A calculated volume of cement is placed in the well. Usually a volume of spacer is pumped ahead and behind the cement. When the plug is in place, the height of the cement and spacer left inside the pipe is the same as the height of the cement and spacer placed outside the pipe. With equalized column heights and fluid densities inside and outside the drillpipe, the hydrostatic pressure is balanced.
Tubing with a smaller diameter than the drillpipe is commonly run on the bottom of the drillpipe for setting a balanced plug; this smaller diameter tubing is commonly known as the stinger. Using a stinger lowers the height of the cement plug with the pipe in place, prior to pulling out of hole (POOH). The stinger also provides a larger annular cross-sectional area during cement placement. Some operators use a stinger with the assumption that it will minimize the disturbance of the plug while POOH, decreasing the chance of cement contamination.
If a stinger is used, the assumption that all fluids both inside and outside the drillpipe will remain in equilibrium is false. A mathematical analysis of what occurs once dynamic conditions begin by POOH with a small diameter stinger shows that the initially balanced system quickly becomes unbalanced. This analysis of placement technique can be valuable for any situation in which a balanced plug would normally be used for plug placement.
Perhaps the most critical component of most cement plugs, especially kickoff and sidetrack plugs, is compressive strength (CS) development. A cement kickoff plug with a final strength greater than the adjacent formation provides better support to sidetrack in the neighboring formation. Surfactant-laden spacers and drilling mud contamination have a drastic effect on cement CS development. The contamination of the cement plug with these fluids can result in failed strength development, which can result in failure to kick off the plug. The end result is lost time and money for the operator.
Rotating Casing Strings: Overview of Fatigue Assessment Methodology Based in Full Scale Lab Testing, and Application Cases Stories
Authors: Jordan Rodriguez G. , Grittini S. J. , Mazzaferro G. , Urdaneta E. D. 
Published: June 2014

Abstract
Casing and tubing are being increasingly used in drilling environments as an alternative to conventional drill pipe. Furthermore, OCTG tubular products are commonly rotated into place in horizontal and ERD wells. During drilling and running operations in deviated sections, the combination of the resultant bending of the string and its rotation generate alternating stresses in the pipe body and connections, creating the conditions for potential fatigue damage. Fatigue phenomenon could be related to cracks generation. The process includes different development phases until the failure of the component becomes evident; this failure could be produced at remote stress levels below the static elastic limit of the material. Since fatigue damage could lead to the failure of the string, which in general terms would predominantly occur on the connections, some considerations must be given to their resistance to cyclic loading conditions.
This paper describes the additional design considerations on top of standard design criteria for casing or tubing strings when subjected to cyclic loads, whether to select a suitable connection for a given application; to set a limit on operative parameters for a given application and connection; or to assess the fatigue damage suffered by a given connection undergoing a certain application. Comprehensive methodology applied for assessing fatigue damage introduced during rotating operations is proposed in this paper. It includes results of full scale laboratory testing carried out to quantify the fatigue limit of various semi-premium and premium connections, under different load conditions; statistical analysis methodology for developing robust fatigue life limit curves; and fatigue assessment methodology adopted for estimating fatigue damage introduced in real applications. The application of the methodology to some real cases is also presented in this paper.
The most significant outcome of this work is the possibility to reduce uncertainty related to casing strings mechanical integrity in rotating operations, such as drilling with casing, increasing chances of success.
Influence of Casing Centralization on Cement Sheath Integrity During Thermal Cycling
Authors: De Andrade J. , Torsæter M. , Todorovic J. , Opedal N. , Stroisz A. , Vrålstad T. 
Published: June 2014

Abstract
The objective of primary cementing is to protect the casing and to ensure zonal isolation. It can be difficult to obtain a good cement job along the full length of a well, and casing centralization is one of the main factors that influence this. Even if the dependence of cement placement on casing centralization is well-known, little information is available on how the degree of casing centralization affects the well during its production phase. Well temperatures cycle up and down as a part of normal production operations – and well barrier materials, in particular steel, cement and rock, will consequently repeatedly expand and contract their volumes. Over time, this is likely to induce debonding and radial cracking of the cement sheath which threatens well integrity.
This paper reports the results of an experimental study mapping how, where and when the annular cement loses its sealing ability upon temperature variations, and how this is dependent on casing centralization. The studied samples consisted of rock, cement and casing, and the temperature was cycled in a controlled and programmable manner. In-situ monitoring by Acoustic Emission (AE) sensors detected the development of cracking and debonding in the samples during thermal cycling. Initial and post-experiment computed tomography (CT) scans provided complementary three-dimensional (3D) information on the geometry and location of the induced cracks and debonding.
Our study compared the thermal cycling resistance of two samples, one with centralized casing and one with a 50% casing stand-off. The AE monitoring results indicated that most of the cracking/debonding occurred during the actual heating and cooling, and not in between cycles when the temperature was held constant. The CT analyses showed that the thermal cycling caused considerable enlargement of cracks and voids initially present in the cement sheath, and this enlargement was significantly more severe when the casing was not centralized.
The paper presents, for the first time, a 3D visualization of cracks and debonded volumes in the cement sheath, and it underlines the importance of obtaining a good initial cement job. Also, it is shown that it is important to obtain a good casing centralization during well construction – not only for optimal cement placement, but also for maintaining well integrity during production.
Dual Active Heave Drilling Drawworks: From Concept to Operational Life
Authors: Fivelstad Olav , Verhoef Richard , Ogg Jeremy , Davila Sara 
Published: June 2014

Abstract
In 2010, a fit-for-purpose Mobile Offshore Drilling Unit (MODU) was equipped with a dual Active Heave Drilling Drawworks. As a concept, this layout was initially presented in the SPE/IADC paper 79826 "Dual Drawworks Provide Operational Redundancy and Reduce Cut and Clip Costs." After additional developments with the drilling contractor, the equipment provider and the vessel designer, this system went from concept to reality.
Fundamentally, this system is based on having two Active Heave Drilling drawworks mounted on the port and starboard side of the derrick working simultaneously as a complete 1,000 (i.s.o. 1000) ton hoisting system. The initial goals of the system were to reduce slip and cut costs, increase tripping time and provide overall redundancy for ultra-deepwater operations.
This follow-up paper will examine field performance data, provided by the drilling contractor, while looking to juxtapose the initial engineering concept with the systems capability to successfully transition dual Active Heave Drilling drawworks from concept to operational life.