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Abstract Managed pressure and underbalanced drilling operations are predominantly conducted through the use of surface measurements and are heavily assisted by modeling subsurface conditions as downhole measurements have limited availability. Downhole information is typically absent during periods without flow and when using compressible fluids such as aerated mud. Operational efficiency and wellsite safety would benefit by supplementing the models and surface data with direct measurements of subsurface conditions. Automation would be enabled and well control would meaningfully improve from self-sufficient downhole information by realizing the lowest pressures, while eliminating complex calculations and minimizing time spent on the choke. Along-string annular pressure measurement and evaluation provides new downhole capabilities. Initial field deployments have demonstrated their utility and viability, but downhole ECD calculations through normalization of the absolute pressure measurements to hydrostatic depth do not properly account the distributed pressure sensing. This paper proposes a new method for computing the along-string ECD values*, shows visualization for intuitive interpretation of the values and proposes a method for relative volume determination*. The new methodology with multiple sensors with non-hydrostatic pressure additions scaled by sensor depths show the need for two scale factors. Finally, an influx volume can be estimated across a wellbore section that is bounded by discrete drillstring pressure sensors. Examples are offered for pumping sweeps and a kick that is up the annulus and recommendations are offered for technologies that acquire pressure along the drillstring. Managed Pressure Drilling (MPD), Under Balanced Drilling (UBD) and other operations that manage a tight pressure window benefit from the procedures and practices offered. Recommendations relevant to integration of downhole data with surface control systems for closed-loop and automated wellsite operations are offered.
- North America > United States > Texas (0.29)
- South America > Brazil > Rio de Janeiro (0.28)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Pressure Management > Underbalanced drilling (1.00)
Managed Pressure Drilling with Solids-Free Drilling Fluid Provides Cost-Efficient Drilling Solution for Subsea Carbonate Gas Development Wells
Setiawan, Trigundai Budi (Petronas Carigali Sdn. Bhd.) | Bin Omar, Mohammad Mizuar (Petronas Carigali Sdn. Bhd.) | Bin Sulaiman, Mohd Zarkashi (Petronas Carigali Sdn. Bhd.) | Bin Musa, Mohammad Zarir (Petronas Carigali Sdn. Bhd.) | Fadzli, Muffaz (Petronas Carigali Sdn. Bhd.) | Nesan, Thanavathy Patma (Petronas Carigali Sdn. Bhd.) | Wuest, Chad H. (Weatherford) | Toralde, Julmar Shaun (Weatherford) | Sridharan, Prem Ananthan (Weatherford)
Abstract The development of the Kanowit Field in offshore Sarawak, Malaysia requires the drilling of two subsea development wells using a semi-sub rig. Previous experience identified the need for solids-free drilling fluid to ensure maximum reservoir productivity and so that the quality of the produced gas is within required specifications. High reservoir pressure requires the use of high-density solids-free drilling fluids, but associated costs and the high probability of losing large volumes to the fractured carbonate reservoir made this option unsuitable. A more cost-effective option was to use a less-dense solids-free drilling fluid and utilize managed pressure drilling (MPD) to be able to compensate for the difference in density with backpressure. MPD mitigated the loss circulation risk by controlling the level of overbalance to the minimum and MPD early kick and loss detection capabilities, used in conjunction with a statically underbalanced drilling fluid, also allowed for the collection of actual geopressure environment data that aided in the decision making process. Both wells were completed and tested with a maximum potential flow rate that exceeded the technical potential in initial projections. The successful deployment of MPD with solids-free drilling fluids proves its technical and economic feasibility in carrying out subsea development drilling through carbonate reservoirs prone to severe circulation losses.
- Asia > Indonesia (0.69)
- Asia > Middle East (0.68)
- North America > United States > Texas (0.28)
- Asia > Malaysia > Sarawak > South China Sea (0.25)
- Asia > Malaysia > Sarawak > South China Sea > Sarawak Basin > Block SK306 > Kanowit Field (0.99)
- Asia > Indonesia > Sumatra > Soka Field (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)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Carbonate reservoirs (1.00)
Integrated Technology Approach to Explore Carbonate Reservoirs in Malaysia Enhances PMCD Potentials and Enables Successful Prospect Evaluations
Jayah, M Noreffendy (PETRONAS) | Aziz, Intan Azian (PETRONAS) | Drus, Zulhilmi (PETRONAS) | Nesan, Thanavathy Patma (PETRONAS) | Sze, Wong Han (PETRONAS) | Ali Hassan, Abdel Aziz (PETRONAS) | Luntar, Pungut (PETRONAS)
Copyright 2013, IADC/SPE Managed Pressure Drilling and Underbalanced Operations Conference and Exhibition This paper was prepared for presentation at the IADC/SPE Managed Pressure Drilling and Underbalanced Operations Conference and Exhibition held in San Antonio, Texas, USA, 17-18 April 2013. 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 The Central Luconia province located in offshore Sarawak (East Malaysia) houses numerous carbonate reservoirs. Some of these reservoirs, especially the pinnacle structures are characterized by the presence of karsts and fractures leading to total mud losses. PETRONAS has been exploring carbonate reservoirs in this area since the 90s. However, as more prospects being explored, the challenge intensifies as the company embarked into exploring remaining carbonate pinnacle structures with primary objective of identifying the gas water contact (GWC) of the prospects. Drilling the well conventionally risk the operations not just in its safety aspect but also deliverability of the well objective and data acquisition plan. Implementing the variant of the Managed Pressure Drilling (MPD) technology called Pressurized Mud Cap Drilling (PMCD) allowed targeted total depths to be reached on several wells. However, reaching total depth alone is not sufficient, as the prospect has to be conclusively evaluated.
- Asia > Malaysia > Sarawak > South China Sea (0.88)
- North America > United States > Texas > Bexar County > San Antonio (0.24)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.93)
Abstract Normal drilling operation is carried out with the hydrostatic head of fluids at bottomhole above the reservoir pressure. The main reason is to maintain safety of the operation and to prevent production or blow- out during the various stages of the drilling operation. For some fields, this mode of operation may lead to lost circulation and damage to formation. Under the underbalanced drilling (UBD) operation, the pressure of the fluids at bottomhole is slightly below the reservoir pressure. As a result, some production from the formation may also occur. The drilling and the associated process system should therefore be able to cope with all expected flow conditions such as gas kick and variations in the wellhead pressure. A few years ago Caltec were approached by a drilling company interested in using the patented compact separation system, known as I-SEP/HI-SEP as part of their UBD system. The main duty of the compact separator was to operate close to wellhead, upstream of the choke package, and separate bulk of the produced gas at full wellhead pressure. The separated liquid phase and drilling cuttings would then pass through the choke system for further processing and treatment at a lower pressure, using the general UBD process and separation system. The unit was also required to be rated to full highest expected wellhead pressure of 5,000 psig.This unit was given the nick name of "THE GAS BUSTER". Flowrates and the operating conditions which the unit was designed for is shown in Table1 in the paper. The initial tests and trials of the Gas Buster were carried out in three stages which included half scale laboratory tests, full scale testing of the unit with drilling mud, solids and compressed air at 10 barg in the UK and at up to 1,000 psig pressure in Canada.The unit was then transported offshore for its maiden trials as part of the UBD system on a platform in the Southern North Sea. This paper describes the key features of the "Gas buster" and the tests carried out. The system was exposed to unexpected high gas flow rates, almost double its design capacity during the offshore trials, but still operated satisfactorily. However, as a result, some erosion of up to 6mm took place within some parts of the internal components of I-SEP. The control of the system is the most important part of the operation as in addition to controlling the drilling operation and setting of the choke valves, satisfactory operation of the gas buster and maintaining the UBD mode was also required.The trials helped to improve the control of the system and the design of HI-SEP to cope better with gas cick conditions. The benefits of using the Gas Buster are highlighted and include; ability to utilize the produced gas and prevent venting or flaring it, ability to continue drilling uninterrupted even under unexpected gas kick or similar surge conditions, Preventing the chokes to be eroded quickly, and protecting the downstream UBD process system to be exposed to extreme operating conditions which may lead to interruption to continuous drilling operation.Saving in drilling time is also expected.
- Europe > North Sea (0.55)
- North America > Canada (0.34)
- Europe > United Kingdom > North Sea (0.25)
- (3 more...)
Abstract The rapid development of unconventional energy plays such as shale oil & gas necessitates "assembly line" approach to well construction and completion technologies. Due to very high number of wells being drilled to explore such promising resources, novel approach to optimize well construction process is necessary. This requires an industrial engineering approach to not only remove non-productive time out of the assembly process, but also drive out the invisible flat time and unrealized inefficiencies of the manufacturing process. This paper will discuss the application MPD to maximize drilling efficiency by optimizing drilling parameters to minimize Mean Specific Energy (MSE) for drilling. Managed Pressure Drilling (MPD) techniques have gained industry wide acceptance for drilling technically challenging prospects and also helping to minimize risks associated with well control and lost circulation hazards. The well construction process in shale plays might be perceived as more benign than some of the challenging environments such as deep-water. However application of MPD to maximize drilling efficiency in shale plays can minimize cost by reducing the field development time. MPD has been shown to reduce the drilling time by almost 50% through the elimination of known and unknown drilling inefficiencies. Overall drilling performance is impacted through the inherent ability of MPD to quickly identify and control any pressure events and continue drilling versus spending costly time fighting down hole problems. MPD also significantly impacts performance through the optimization of parameters such as mud weight and Equivalent Circulating Density (ECD). MSE has been a great tool to quantify drilling efficiency. Effect of different drilling parameters such as mud weight, weight on bit and torque on MSE will be discussed. Application of MPD has significant impact on MSE during drilling. This paper will describe how the use of MPD on shale developments, along with other unconventional developments improves the overall drilling efficiency hence allowing for quicker & safer well construction and field development. It will also investigate the added benefit of MPD improving field production through better understanding of productive zones and fracture identification.
- North America > United States > Texas > Haynesville Shale Formation (0.99)
- North America > United States > Louisiana > Haynesville Shale Formation (0.99)
- North America > United States > Louisiana > Haynesville Formation (0.99)
- North America > United States > Arkansas > Haynesville Shale Formation (0.99)
Copyright 2013, IADC/SPE Managed Pressure Drilling and Underbalanced Operations Conference and Exhibition This paper was prepared for presentation at the IADC/SPE Managed Pressure Drilling and Underbalanced Operations Conference and Exhibition held in San Antonio, Texas, USA, 17-18 April 2013. 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 Primary drilling challenges related to the Greater Natural Buttes (GNB) field involve lost circulation, gas influxes, and the constant challenges related to accelerating a program in its mature stages of development. The majority of production is derived from naturally fractured tight sandstone members of the Wasatch formation and Mesaverde groups of the Tertiary & Cretaceous periods, which are the drilling targets of concern. Through the utilization of Managed Pressure Drilling (MPD) a decrease in cycle times and a possible increase in production in the GNB field have been observed. The decrease in cycle times can be directly attributed to higher ROP, mitigated gas influxes, and minimized lost circulation management. Continuing research of how the effect of MPD has subsequently contributed to decreasing near wellbore damage and potentially increasing overall production is being conducted. This paper will quantify the benefit MPD has yielded through ROP advancements, tool life length, mud cost & material reduction, and time related to lost circulation & gas influx management.
- North America > United States > Utah (0.47)
- North America > United States > Texas > Bexar County > San Antonio (0.24)
- North America > United States > Wyoming > Uinta Basin (0.99)
- North America > United States > Utah > Uintah Basin > Wasatch Formation (0.99)
- North America > United States > Utah > Uintah Basin > Natural Buttes Field > Wasatch Formation (0.99)
- (2 more...)
Abstract Achieving successful isolation of potential flow zones during well construction from floating rigs has historically been a formidable task, particularly on HPHT prospects. Operational challenges include actual vs. predicted leak-off test (LOT) values, margins of error in mud weights, high temperature compressibility at shoe depth and risk of inducing a fracture during pre-flush and/or cement slurry displacement. Wellbore strengthening operations may contribute to the relative unknown. Additionally, it is often assumed that the weakest component of the cementing operation is the last casing shoe, which may not be the case. This presentation speaks to conducting dynamic formation integrity tests when drilling the open hole to be cased and cemented and applying managed pressure drilling (MPD) techniques as a means of increasing chances of getting a good cement job on the first attempt and in keeping with the intent of API Recommended Practice 65, Part 2- Isolating potential flow zones during well construction: Preparatory - quantify the stability of the wellbore, actual wellbore pressures data for correlation with cementing simulator models & more efficient hole cleaning ahead of the cement. Displacement - optimize fluid dynamics, ascertain in real-time an induced fracture and/or help ensure the column of plug in the tubing string is balanced with the annulus. Curing -maintain more consistent annulus pressure on rigs experiencing wave heave & backpressure applications for minimizing the risk of channeling. Testing – using MPD kit in lieu of cementing equipment or exercising the BOP.
Copyright 2013, IADC/SPE Managed Pressure Drilling and Underbalanced Operations Conference and Exhibition This paper was prepared for presentation at the IADC/SPE Managed Pressure Drilling and Underbalanced Operations Conference and Exhibition held in San Antonio, Texas, USA, 17-18 April 2013. 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 A world first "Controlled Annular Mud Level" type Dual Gradient Drilling (DGD) system was successfully applied on an ultra-deepwater well drilled in May - July 2012. Water depth was 2260m and the formation was generally carbonates with potential for severe or total losses. DGD was applied to prevent losses from occurring.
Copyright 2013, IADC/SPE Managed Pressure Drilling and Underbalanced Operations Conference and Exhibition This paper was prepared for presentation at the IADC/SPE Managed Pressure Drilling and Underbalanced Operations Conference and Exhibition held in San Antonio, Texas, USA, 17-18 April 2013. 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 The majority of overbalanced drilling operations are still performed using conventional drilling. The trend indicates that managed pressure drilling systems are increasingly being introduced in regions where the operational pressure window of formations is restricted. DNV has during the last years noticed a considerable demand for third party evaluation of new upcoming managed pressure drilling systems. This paper discusses some of the challenges and advantages for managed pressure drilling compared with conventional drilling. Many managed pressure drilling systems introduce critical equipment with the intention to enhance operational effectiveness and safety. At the same time the respective equipment is used to adapt the hydraulic pressure profile throughout the wellbore to manage the annular bottom-hole pressure within the formation pressure limits. A general description of the connection between safety critical equipment and the well barriers is discussed in this paper.