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Collaborating Authors
Drilling fluid management & disposal
Copyright 2012, IADC/SPE Drilling Conference and Exhibition This paper was prepared for presentation at the 2012 IADC/SPE Drilling Conference and Exhibition held in San Diego, California, USA, 6-8 March 2012. This paper was selected for presentation by an IADC/SPE program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the International Association of Drilling Contractors or the Society of Petroleum Engineers and are subject to correction by the author(s). The material does not necessarily reflect any position of the International Association of Drilling Contractors or the Society of Petroleum Engineers, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the International Association of Drilling Contractors or the Society of Petroleum Engineers is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuous acknowledgment of IADC/SPE copyright. Abstract An analysis of more than 100 Gulf of Mexico (GOM) deepwater wells reveals that one operator is experiencing more drilling success than its peers in terms of consistent and repeatable top quartile drilling performance. These results are driven by the operator's commitment to its drilling philosophy, its strong and well-established partnership with key service contractors, and its core drilling team of experienced and technically sound professionals.
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Drilling > Drillstring Design > Drill pipe selection (0.96)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (0.95)
Abstract More than 70% of nonproductive time (NPT) and increases in drilling cost are related to wellbore instabilities. Shale formations are the primary sources (90%) for wellbore instabilities. Numerous wellbore instability problems have been reported in the Horn River basin (HRB), the largest shalegas play in Canada. As a consequence of the depositional environment, shale formations have laminated structure that results in anisotropic mechanical properties and horizontal stresses. Failure to consider this characteristic of shale can have severe consequences on drilling. Traditional isotropic stress calculation approaches typically used in wellbore stability analysis do not consider 3D azimuthal anisotropy present in shales. Ignoring anisotropy generally results in underestimation of stresses, which can lead to incorrect safe trajectory or mud-weights predictions. In this paper, drilling problems experienced in 15 wells in two different areas of the HRB were examined. Some of these wells had severe wellbore instabilitis due to high pore pressure, mud losses or lost circulation, tight hole/stuck pipe/pack off, or combination of these events. Three borehole assemblies (BHA) were lost in these wells which required side tracking. Most of these problems were experienced in Fort Simpson and upper Muskwa formations. An in-depth postmortem analysis of these wells indicated that shale heterogeneity was not properly characterized (anisotropic horizontal stresses were not considered in the prespud analysis which resulted in incorrect mud-weight predictions and trajectory calculations.
- North America > Canada > British Columbia (1.00)
- North America > Canada > Northwest Territories > Fort Simpson (0.28)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
Automated Managed Pressure Drilling Allows Identification of New Reserves in a HPHT Exploration Well in SB Field, Offshore Malaysia
Ismail, Zulkarnain (PETRONAS) | Aziz, Intan Azian (PETRONAS) | Umar, Lawrence (PETRONAS) | Nordin, Noor Azree (PETRONAS) | Nesan, Thanavathy Patma (PETRONAS) | Rodriguez, Freddy Rojas (Schlumberger) | Zapata, Fernando Gallo (Schlumberger) | Garcia, Greg (Schlumberger) | Waguih, Ahmed (Schlumberger) | Subroto, Bramanta (Schlumberger) | Dow, Blaine (Schlumberger)
Abstract The SB Field is located in Block PM on the west side of the Malay Basin, Malaysia. It is notorious for its steeply rising pressure ramp, narrow drilling operation window and inter-bedded sand, coal, and shale formations. Block PM is still at the exploration and appraisal stage with limited petrophysical information. Well SBD-2 was the second attempt to reach and cross the F & H sands of this basin. Despite using managed pressure drilling, the first attempt failed when an influx exceeded the fracture gradient, resulting in total fluid losses. Due to the shallow pressure ramp and narrow window between pore pressure and fracture gradient, a repeat attempt was initially deemed "un-drillable". However, the design team felt the target could be reached using an automated managed pressure drilling technology. The team was able to maintain constant bottom hole pressure over three demanding hole sections and reach target total depth. The 8-1/2" × 14-3/4" section required minimum overbalance to manage "wellbore breathing" and to control potential losses to weaker horizons. In the 10-1/2" × 12-1/4" section, the system was used to identify and react quickly to kicks in high pressure sands and also to eliminate wellbore breathing/ballooning. In the final 8-1/2" × 9-1/2" section, the objective was to maintain overbalance in the narrow pressure window between pore pressure and fracture gradient. This paper will describe the design efforts employed while preparing to drill the SBD-2 well. The challenges and lessons learned, particularly managing pore pressure prediction with multiple techniques will be discussed. Lessons learned and recommended workflows for similar projects will also be outlined.
- Asia > Malaysia (1.00)
- Asia > Middle East > UAE > Abu Dhabi Emirate (0.60)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.54)
- Asia > Middle East > UAE > Abu Dhabi > Rub' al Khali Basin > Asab Field > Thamama Group Formation (0.99)
- Asia > Malaysia > South China Sea > Malay Basin (0.99)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Pressure Management > Managed pressure drilling (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
Copyright 2012, IADC/SPE Drilling Conference and Exhibition This paper was prepared for presentation at the 2012 IADC/SPE Drilling Conference and Exhibition held in San Diego, California, USA, 6-8 March 2012. This paper was selected for presentation by an IADC/SPE program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the International Association of Drilling Contractors or the Society of Petroleum Engineers and are subject to correction by the author(s). The material does not necessarily reflect any position of the International Association of Drilling Contractors or the Society of Petroleum Engineers, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the International Association of Drilling Contractors or the Society of Petroleum Engineers is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuous acknowledgment of IADC/SPE copyright. Abstract Mode confusion is when an automated system behaves differently than expected; in such a way that the operator is not aware of or does not properly understand what the system is doing. Mode confusion is well recognized in the aviation community and has been indicated in a number of high profile aviation accidents. As an example, a Jas Gripen fighter jet crashed during a test flight in the 1980s due to the pilot trying to manually correct instability while the plane's computer was automatically trying to do the same. The potential for the same type of problems, and associated safety hazards, arises in drilling rig operations as a result of the increasing trend for automation and advisory systems. A simple example could be formation fracturing with an automated ECD control system when displacing to higher mudweight caused by the driller relying on the automated system to maintain sufficiently low flowrate without having reconfigured the system with the new mud properties. Through the reported study the authors wish to analyse how use of a drilling support system in different modes and levels of automation may influence the system operator's performance and risk of human error.
- Europe (1.00)
- North America > United States > California > San Diego County > San Diego (0.24)
Hammer Motor Smashes Its Way to Speedy Success in Brazil
Gee, Ryan (National Oilwell Varco) | Ramirez, Tibor (National Oilwell Varco) | Barton, Steve (National Oilwell Varco) | de Souza, Julio Cezar (Petrobras) | da Fonseca, Carlos Eduardo (Petrobras) | Cote, Brad (BBJ Tools) | Valmorbida, Decio (National Oilwell Varco)
Abstract Percussive air hammer tools have been used for many years to increase drilling ROP (rate of penentration) in air drilling applications. Similar developments for mud hammer tools have not been as successful. The incompressible nature of drilling mud makes the percussive action much slower to actuate using the same design methodology, rendering the tool ineffective. Other developments have suffered from reliability issues which have limited their drilling hours, therefore making them economically unfeasible. A novel percussive mechanically-actuated Hammer Motor, suitable for either mud or air drilling applications, has changed the landscape. This unique hammer assembly is assembled into a standard mud motor, without affecting the bit to bend distance. The percussive action of the tool is designed such that the bit remains in contact with the formation, while the hammering takes place against the top of the drive mandrel, driving the bit into the formation. The percussive impacts serve to greatly increase the effectiveness of the roller cone bit in crushing the rock, thus significantly increasing ROP. This paper illustrates a case study from Brazil, where the Operator has been using turbine motors or conventional motors to drill vertical wells through hard rock formations. The Hammer Motor displayed significantly higher ROP than the benchmark established by the other motors, while also reducing bit costs. These improvements in drilling performance improve the economics of drilling these hard rock formations, and are also applicable to other drilling applications.
- Geology > Rock Type > Metamorphic Rock (0.55)
- Geology > Rock Type > Igneous Rock (0.55)
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Drill Bits > Bit design (0.93)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (0.89)
Abstract There is an increasing need to drill difficult reservoirs in a cost effective way. Over the past few years Managed Pressure Drilling (MPD) has made it possible to drill reservoirs which have a narrow window between pore and fracture pressure gradients. Before the introduction of MPD techniques, safely drilling and completing these formations was very costly and not always successful. Cycling the mud pumps off and on for connections affects the pressure and is a major problem for MPD. Techniques and equipment have been developed to make a connection while continuing to circulate the drilling mud to maintain constant pressure. Since 2005, the Continuous Circulation System (CCS) has allowed continuous circulation during connections with traditional jointed drill pipe, by using a chamber around the connection. Several companies have developed continuous circulation subs which are threaded between tool joints to achieve continuous circulation without a pressure chamber. These have had varying degrees of success from both an operational and safety standpoint. This paper describes the current MPD market and describes the philosophy adopted for a new side-entry sub.
- Well Drilling > Pressure Management > Managed pressure drilling (1.00)
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Drilling Equipment (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (0.89)
Abstract Liner drilling technology provided an effective solution to hole instability issues seen while drilling with conventional methods through a narrow mud weight/pore pressure/fracture gradient window laden with depleted intervals and virgin pressured shales in the Mississippi Canyon block of the Gulf of Mexico. Two 8-1/2" x 9-1/2" wellbores were lost while drilling with Rotary Steerable Systems (RSS) in the 60° wellbore. The initial wellbore was lost as a result of RSS failure resulting in the hole packing off. A subsequent bypass wellbore encountered catastrophic lost circulation resulting in the hole collapsing as the depleted commercial sand came in unexpectedly high. In each case this resulted in the loss of the RSS Bottomhole Assembly (BHA). Liner drilling technology was identified as the most appropriate strategy for setting the 7-5/8" drilling liner and 5-1/2" production liner because: Documented lost circulation problems have been minimized or eliminated through prior use of DwL technology, largely attributed to the "smear effect" phenomenon. The narrow annular geometry created by liner drilling reduces the rate of fluid loss in the annulus as compared to conventional drilling operations enabling effective management of the annular fluid level. DwL systems historically minimize or eliminate non-productive time in operations in which uncontrolled fluid losses have been encountered previously. Ultimately, the correct application of liner drilling technology on this well allowed the operator to reach the intended drilling depth and completion objective. The equipment selection, operation, and results of the liner drilling operations will be presented in the paper.
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.38)
- Geology > Geological Subdiscipline > Geomechanics (0.35)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Drillstring Design > Drill pipe selection (1.00)
- Well Drilling > Drilling Operations > Running and setting casing (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
Abstract Optimizing well control processes are critical in high-temperature/high-pressure (HPHT) drilling operations so they do not encounter high cost overruns and compromise safety. The key to success is recognizing and mitigating challenges and associated risks early to adequately optimize drilling operations. This leads to a more effective drilling operation with reduced risk, increased safety margins and increased probability of successfully achieving the well’s objectives. This case describes an integrated work process that has been implemented, incorporating pre-drill and real-time pore pressure prediction with proactive equivalent circulating density (ECD) management during well planning and drilling operations. This work process is especially important for optimizing drilling fluid properties to retain the drilling parameters within a safe operating mud window identified by real-time pore pressure and wellbore stability prediction. Operating in this safe window enables reduction in wellbore instability, formation damage, hole cleaning inefficiencies and poor drilling performance, resulting in improved safety margins, reduced risk, improved drilling performance and reduction in non-productive-time (NPT). Several recent examples from Suncor Energy Norge HPHT wells are presented to illustrate the success of utilizing this integrated approach, resulting in drilling HPHT wells with no formation pressure-related NPT. The process begins with identifying pressure-related challenges in the pre-drill planning phase, optimizing the drilling process by validating, defining and maintain the drilling parameters within the safe operational window through an integration of proactive real-time pore pressure prediction and ECD management using all available LWD measurements: acoustic, gamma, resistivity, density, formation pressure while drilling, imaging, ECD, and temperature. Analysis is performed on mud logging data such as gas, the drilling exponent, cuttings and borehole caving and surface drilling data. Finally, lessons learned are captured that will further improve drilling efficiency and best practices in upcoming drilling campaigns.
- Europe > United Kingdom > North Sea > North Sea Basin (0.99)
- Europe > Norway > North Sea > Norwegian Sea > Tuxen Formation (0.99)
- Europe > Norway > North Sea > Norwegian Sea > Sola Formation (0.99)
- (39 more...)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Drilling Operations (1.00)
- (4 more...)
Copyright 2012, IADC/SPE Drilling Conference and Exhibition This paper was prepared for presentation at the 2012 IADC/SPE Drilling Conference and Exhibition held in San Diego, California, USA, 6-8 March 2012. This paper was selected for presentation by an IADC/SPE program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the International Association of Drilling Contractors or the Society of Petroleum Engineers and are subject to correction by the author(s). The material does not necessarily reflect any position of the International Association of Drilling Contractors or the Society of Petroleum Engineers, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the International Association of Drilling Contractors or the Society of Petroleum Engineers is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuous acknowledgment of IADC/SPE copyright. Abstract Transient gas-liquid flow is a common phenomenon in the drilling, workover and gas/oil production processes. Any change in the operating conditions at the inlet or outlet will introduce a transient response. Operations such as liquid unloading, under balanced drilling with gasified fluid, well control, cementing, hole cleaning, pipeline startup and blowout may never reach a steady state.
- North America > United States > Texas (0.93)
- North America > United States > California > San Diego County > San Diego (0.24)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- (7 more...)
Mud Cap Application Solves Chronic Drilling Problem in a Highly Fractured, Low Pressure Reservoir
Ladron De Guevara, J. Ernesto (PEMEX) | Lozada, Miguel Ángel (PEMEX) | Torres, Marcos Fuentes (PEMEX) | Silva, Gilberto García (PEMEX) | Zalvidar, Juan Antonio (PEMEX) | González, Ricardo Andres (QRI) | Sizer, James (QRI)
Abstract The Cantarell field is located offshore in the Bay of Campeche, in approximately 50 m of water depth (Fig. 1). The two main productive intervals are the Upper Cretaceous and Jurassic Kimmeridgian. The Cretaceous is highly fractured with well developed, vugular secondary porosity. The Jurassic is also fractured with oomoldic porosity. Both contain sour hydrocarbons. Production from Cantarell began in the early 1980s and today the pore pressure gradient is down to a +/− 0.37 gr/cc equivalent. The productive interval is typically drilled using a 0.90 gr/cc emulsion mud and shortly after penetrating the fractured reservoir, total and uncontrollable loss circulation is experienced. As a result, the cost of drilling in the field has increased considerably due to the high cost of the oil-in-water mud losses and time spent either transporting, generating or waiting on weather to offload more mud to continue drilling. Petróleos Mexicanos (PEMEX) in cooperation with Quantum Reservoir Impact (QRI) reevaluated the current drilling philosophy and recommended the application of a series of steps aimed at solving the current problems. The results obtained have been positive resulting in PEMEX now implementing such steps as part of its drilling philosophy where applicable on a regular basis. This paper will describe the current drilling environment and the techniques implemented in the first successful mud cap application in the Cantarell field. It will also discuss some of the lessons learned as well as the new improved designs being implemented and will conclude with a summary of the benefits obtained and the plans for the future.
- Phanerozoic > Mesozoic > Cretaceous (0.79)
- Phanerozoic > Cenozoic > Paleogene > Paleocene (0.39)
- Government > Regional Government > North America Government > Mexico Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- North America > Mexico > Gulf of Mexico > Bay of Campeche > Sureste Basin > Campeche Basin > Northeast Marine Region > Cantarell Field (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Upper Marrat Formation (0.94)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Sargelu Formation (0.94)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)