Society of Petroleum Engineers Aberdeen Section Summit Series Managed Pressure Drilling Seminar 2012 Thursday 14th June 2012 ABSTRACTS of PRESENTATIONS 1. Utilising MPD to drill HPHT deepwater exploration well Tom Scoular, BP A successful use of MPD techniques from a semi-submersible rig in an HPHT drilling operation offshore Egypt is described. Included is a discussion on the MPD techniques and experience developed on jack-up HPHT drilling operations and how these were successfully transferred across to the floating rig operation. The presentation will discuss the rig modifications required to install the MPD equipment on the semi-submersible, including installation of the rotating head in the marine riser. It will also review the operations carried out utilizing MPD techniques, and give examples of how the equipment was used in the drilling of the last 3 hole sections. Some key areas considered essential to the success of this technology on a floating rig in a demanding HPHT environment and the benefits associated with the MPD operation are highlighted 2. Deployment of a new drilling system and its potential related to ERD wells Ove Hole, Reelwell RDM (Reelwell Drilling Method) is a multi-purpose drilling method with a unique flow arrangement. RDM is based on using a conventional drill string combined with an inner string to form a dual drill string. This arrangement allows the return fluid containing drill cuttings from the bottom of the well to be transported back through the inside of the drill string. RDM enables improved hole cleaning and improved downhole pressure control, and has unique features for MPD and ERD applications. The system enable to extend hole sections, by means of improved pressure management and superior hole cleaning, providing a cost effective well design and larger hole size in the pay zone. Torque and drag are common limiting factors for conventional ERD drilling, this is overcome by RDM by using a heavy liquid in the well annulus whilst drilling with a light fluid. 1
3. MPD HPHT case study Paul Francis, Schlumberger Block PM on the Northern side of the Malay Basin, Malaysia, is notorious for its steeply rising pressure ramp, narrow drilling operation window ( 0.5ppg-0.6ppg) in the 14-3/4” and 9-1/2” sections and inter-bedded sand/coal and shale formations. Block PM is still at the exploration and appraisal stage and therefore has limited petrophysical information. Well SBD-2 was the second attempt to reach and cross the F & H sands of this basin. MPD and Formation Pressure While Drilling (FPWD) were successfully applied to drill this HPHT exploration well with a very narrow safe mud weight window. FPWD provided a direct pressure measurement while drilling to set the lower boundary and the Dynamic Formation Integrity Tests (FIT) with MPD provided the upper boundary. All the benefits of using a fully automated managed pressure drilling system were necessary to reach Well TD for the first time in this field; including Early Kick Detection (EKD), Dynamic Formation Integrity Tests (FIT), Dynamic Flow Checks and Constant BHP control within a narrow pressure margin. The result of the combined technologies and operational procedures is safely drilling the first successful HPHT well in Malaysia drilled with constant bottomhole pressure application. This well is so far the deepest gas discovery for the north Malay Basin. 4. New technology, which enables closed, looped drilling (MPD) from mobile offshore drilling units (MODU) Jan Atle Andresen and Tom Askeland Siem WIS AS Siem WIS has developed a new seal solution that will be installed inside a riser below the slip joint; this will enable Managed Pressure Drilling from MODU utilizing standard equipment (slip joint etc.). The new technology will give the operator at all time status of the seals and gives time to evaluate before entering into a well control situation. The sealing method also enables a quick replacement of the seal package and can also be developed with several seal packages in series. The well pressure is distributed over several seals with gradient chambers between and is monitored at all time. The stationary seals are lubricated directly into the seal area which then keeps the friction and temperature low. Managed pressure drilling is an adaptive drilling process to precisely control the annular pressure profile throughout the wellbore. Automated Managed Pressure drilling has been applied in for fixed platforms for years in many geographical areas. For rough conditions with server heave motion the fixed platform solution is not adaptive. 2
MPD allows the safe use of lower mud weights much closer to the conventional drilling window, the bottom hole pressure can be controlled and adjusted by applying surface back-pressure. To pressurize the riser to provide constant down hole pressure allowing heave motion, a seal device between the drill pipe and the drilling riser is required. (Pressurized mud cap drilling) MPD from floaters has been performed, but in operation were the heave motion is at a minimum to be able for drilling with a locked slip-joint. The RCD (Rotating control device) is in these operations installed above the slip-joint to facilitate the annulus pressure control. The Siem WIS RPCD (Riser pressure control device) will be installed below the slip-joint allowing the MODU to drill in MPD mode with heave motion. The presentation will describe the riser sealing system, running, operating and the experience with the system. 5. Developments in rotating control device (RCD) technology make drilling hazardous deepwater wells possible and safer Essam Sammat, Weatherford In order to successfully drill many of the world's remaining oil and gas reserves we must employ advanced drilling techniques to give better control of the well and provide increased safety to personnel and the environment. Many of these new advanced drilling techniques such as managed pressure drilling rely on a drilling system which has a closed wellbore compared to conventional drilling where the wellbore annulus is open to atmosphere. The Rotating control devices (RCDs) to isolate the annulus contain annular fluids under pressure and divert returns to pressure control and fluid management, connect to the top of the blowout preventer (BOP) in the wellhead, and allow rotary drilling and stripping out of a well with positive annular pressure. The Rotating Control Device (RCD) is the piece of equipment which converts the wellbore from a conventional open to atmosphere system to closed loop pressurizable system. With a closed loop system the wellbore hydraulic pressure profile can be controlled to allow successful drilling through hazardous formation zones such as narrow pore pressure / fracture gradient windows and therefore avoid drilling problems such as kicks / losses and the associated down time costs. In this presentation, the authors explain the benefits of using Rotating Control Devices from drilling efficiency and safety prospective and the RCD evolution process from deploying this equipment on land operations to deepwater harsh environment
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6. MPD implementation – a drilling contractors perspective Iain Sneddon, Transocean Offshore This presentation shall illustrate some of the key areas to be addressed by the drilling contractor and specialist managed pressure drilling (MPD) services provider in assisting our customers to utilize MPD equipment and techniques onboard mobile offshore drilling units (MODUs) with a particular emphasis on semisubmersible and drillships. Included: • Overview of Transocean’s experience to date in implementing MPD operations on its units. • Understanding what MPD techniques are likely to be used and how they impact the MPD system design. • Identifying marine riser limitations, defining the operating window – rig selection. • MPD operating riser & unit positioning analyses. • MPD riser hardware issues. • Illustrate the evolution of offshore MPD riser solutions for benign environments, as applied on various Transocean MODUs since 2003. • Illustrate the MPD riser solutions developed, available and applied on DP & moored MODUs. • Review the installation and hookup of MPD manifold, MGS etc. into rig systems, illustrating this with some examples from recent projects. • Review the Transocean preferred MPD equipment configuration for semis & drillships. • Review the drilling contractor’s role in the development of: MPD related equipment installation & removal procedures, MPD operational procedures, MPD contingency, procedures and MPD project specific training. 7. Continuous circulation system (CCS) for increased drilling efficiency in depleted and difficult wells Neil Ross, NOV This presentation will include: • Description and diagrams of what the CCS package is made up of. • Describe how and what is required to rig up / rig down on an installation • Overview of today’s drilling challenges in depleted and difficult wells. • How CCS can help minimise and eliminate many of today’s drilling challenges. • Summary of well types drilled to date describing HPHT / platform or floater. • Data recorded by CCS engineers during operations. • Potential NPT savings to the operator. • Describe the connection times. • Reduce well control events such as uninvited influxes and losses. • Conclusion and future development plans for the CCS / CCV.
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8. Low riser return system – Use of managed gradient drilling technique in pressure depleted subsea fields Børre Fossli, co authors Paul Smestad and Kristin Falk, Ocean Riser System Description Low Riser Return System (LRRS) is a system and method of drilling with a partially evacuated marine drilling riser, where annulus pressure and pressure gradients can be managed by regulating the mud level within the riser. This is achieved by extracting the returning mud and cuttings to surface from the riser mid sea through an external conduit and a subsea pump system. Application The system can compensate for the ECD effect and is particularly suitable for drilling in depleted reservoirs with tight pore/fracture pressure windows. The technique is used for all phases of the operations; Drilling, Cementing and Completion operations. The method can be used offshore in all sub sea wells with water depths greater than approximately 180 m. Results The system is particularly suitable for normally pressured subsea fields where the reservoir pressure is reduced and drilling into these sections without mud losses is a challenge. Observations This technology can enable drilling, cementing and completion operations in depleted fields which is challenging with conventional methods. In this application ECD component can be compensated for and conventional water based drilling fluids can be used. The method allows drilling of wells with a riser margin as higher mud weights than conventional are used. The equipment is retrofitted to existing conventional drilling rigs. Examples cases will be discussed in the presentation. Conclusions Managed Gradient Drilling is a new technology for drilling subsea wells which can improve; safety margins, kick and loss detection, drilling efficiency, safety and ultimately improve recovery from sub sea fields. 9. Dynamic modeling of wellbore pressures allows MPD operations in narrow margin HPHT wells Waldemar Szemat, SPT Group using dynamic hydraulic simulators to predict and establish wellbore pressures in narrow margin wells when using managed pressure drilling allows operational limits to be set for drilling, tripping, casing and cementing operations. Prior to drilling a narrow margin HPHT well a complete review of the expected pore and fracture pressures and the temperature profiles should be conducted. This review then 5
allows detailed predictions of the pressure windows for each of the hole sections. Each hole section is then in turn reviewed for optimal mud weights including the equivalent static densities, equivalent circulating densities and dynamic kick tolerance limitations for the proposed mud weights. Surge and Swab calculations and cementing calculations ensure that pore and fracture pressure limits are observed. Bottom hole temperatures as well as surface temperatures can then be predicted to ensure that down hole tools and RCD rubber components can be used within the required temperature and pressure limitations. This presentation outlines a complete pressure management system for managed pressure drilling of HPHT wells. The use of dynamic hydraulic models allow accurate predictions of down hole pressures and temperatures for all operational phases during drilling of a hole section. The models allow pressure predictions with temperature effects as well as ECD effects and allow dynamic kick tolerances and dynamic MAASP to be calculated and reviewed as the well progresses through the pressure ramp. A combination of techniques such as MPD combined with real time pore pressure predictions and real time dynamic modeling is now being used as a routine on HPHT wells and has been proven successful in getting these wells to TD. 10. Advanced MPD technologies for EKD and precision control Paul Francis, Schlumberger This presentation will cover two new recent developments in managed pressure drilling: Firstly, the ability to detect influx or losses using pressure rather than a flow meter. The presentation will show how this system was developed and used in a recent field trial to successfully detect a kick. Secondly, a new advanced automated adaptive choke controller has been developed with an order of magnitude higher precision and stability compared to existing conventional PIcontrolled choke systems. The choke is self-tuning and adapts to the conditions making it a truly fully automated system. The presentation will show the results of field trials of the system with single phase and dual phase systems.
11. Well integrity barriers for MPD Atul Bhadauria, CNR International To be supplied END
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