IADC/SPE Managed Pressure Drilling & Underbalanced Operations Conference & Exhibition

Tuesday, 3 October

7:15 am Registration, Coffee Service & Exhibit Viewing Sponsored by Infinity Energy Aspen Ballroom & Foyer

7:30 am Speaker Briefing (Speakers, session chairs & moderators only) Colorado Ballroom A

8:15 am Welcome, Introduction & IADC UBO/MPD Committee Update Colorado Ballroom A

• Leiro Medina, Chair, IADC UBO/MPD Committee; Executive Vice President, Beyond Energy Services & Technologies Corp

8:30 am Completions
Session Chair: Leiro Medina, Chair, IADC UBO/MPD Committee; Executive Vice President, Beyond Energy Services & Technologies Corp

No Longer a Myth but a Reality – Automated Managed Pressure Cementing: Antonio Balanza, Andrew McLennan, Ricardo Leon, Halliburton
This presentation will explore how integrating the real-time density and flow rate from the cement unit with the real-time hydraulic model of the MPD system can bring MPC automation to new levels. By tracking the actual density of the fluids pumped the MPD system now has a much more accurate picture of the operation and can calculate a more precise real-time value of the BHP. This mitigates the risk around MPC execution as the system no longer relies on a pre-model pump schedule and calculates real values with real inputs in real-time.

Enabling Safe Drilling and Completion Operations through Negative Margin Formations with Managed Pressure Drilling and Wellbore Strengthening: Magdeline Mathew, Wells Supervisor, Joachim Wan, Wells Engineer, Razif Md Radzi, Sarawak Shell Berhad (SPE 215887)
An integrated approach where Managed Pressure Drilling is incorporated and designed in conjunction with Wellbore strengthening, with carefully engineered mud weight to allow real-time operational flexibility to successfully drill, cement, and complete wells with formation strength below borehole stability requirements ultimately reducing the consequence of failure and simplifying recovery efforts.

MPD Approach to Completion String Design and Run Enabled Operator to Successfully Complete Wells in Highly-unstable Formations Offshore West Africa: Wamidh Al-Hashmy, International Project Manger, Sergio Pinto de Moura Souza Borges, Beyond Energy Services & Technologies Corp (SPE 215892)
Narrow annular clearances, numerous GeoForm components and sensitive SAF isolation valves made completion runs vulnerable to surge pressures offshore Ivory Coast. The utilization of MPD concepts, techniques and equipment allowed to predict the maximum tripping speeds and expected bottomhole pressures by conducting detailed surge analyses before designing and running the lower-completions string. This novel approach of MPD incorporation into completions design was implemented in four wells successfully has saved cost and time, with zero non-productive time, and proven key to successfully drill and complete wells in the region. 

10:00 am Coffee Service & Exhibit Viewing Sponsored by Infinity Energy Aspen Ballroom & Foyer

10:30 am  Operations Planning
Session Chair: Martin Culen, Chief Commercial Officer, Kelda Dynamics

Proposed Methodology and Application of Statistical Analysis Methods on MPD Surface Back Pressure Control System’s Performance Evaluation in Extended Reach Drilling (ERD) Wells: Nai Hui Houng, MPD Engineer, Jose Palacios, Beyond Energy Services & Technology (SPE 215881)
The performance of a MPD system is often questioned when it comes to surface back pressure application in relation to downhole pressure set points, thus faltering the confidence level in maintaining a constant bottomhole pressure at the target depth – whether at bit or fixed depth. This paper evaluates the performance of the various MPD systems utilizing statistical analysis including offline Change Point analysis and Regression analysis on the Surface Back Pressure (SBP) against the Pressure While Drilling (PWD) data. The paper also proposes an objective methodology in the evaluation process minimizing the influence of various MPD systems’ operating philosophies.

11:00 am Dual Gradient Drilling
Session Chair: Martin Culen, Chief Commercial Officer, Kelda Dynamics

First Full Alpha – Beta Open Hole Gravel Pack using CML MPD Technique in a Low Margin Reservoir: David Smith, BD Technical Manager, Enhanced Drilling, Patrick Campbell, Jiten Kara, Roger VanNoort, Shell
Controlled Mud Level (CML) Managed Pressure Drilling (MPD) was used to successfully place a full alpha – beta gravel pack in a low margin environment. In the target reservoir, the narrow pressure limits between the reservoir wellbore stability and fracture pressures, required effective downhole pressure management during gravel pack placement. In the alpha packing phase, the downhole treating pressure was maintained between wellbore stability pressure and fracture pressure and in the beta packing phase, it was maintained between pore pressure and the stability pressure. The post-job analysis reflects total coverage for the entire screen length, achieving the primary goal for this sand control project.

Case History – CML used to De-risk Tophole Section: Wylie Cameron, Operations Manager, Enhanced Drilling, Justin Poole, Bing Yang, Roger VanNoort, Shell
A CML system was used to de-risk a tophole section in an area with abnormally pressured shallow water zone with flow potential. Shallow water flow has caused issues on multiple wells while drilling riserless, including lost time and loss of well. The use of a CML system allowed setting the surface casing shallower, above the flowable shallow water zone. The first intermediate section of the well was then extended upward to this shallower setting depth while maintaining its historic TD. This caused a narrow drilling margin in that shallow intermediate section, which would not have been conventionally drillable.

Elimination of a Shallow Drilling Liner in a Deepwater Well using a CML System to Perform Dual Gradient Drilling: David Smith, BD Technical Manager, Wylie Cameron, Enhanced Drilling, Justin Poole, Bing Yang, Shell
A CML (Controlled Mud Level) MPD system was used to eliminate a shallow drilling liner on a deepwater well by using the dual gradient effect. In the first time use of this method, a surface mud weight heavier than the previous shoe strength combined with a reduced riser mud level, creating a dual gradient Equivalent Mud Weight EMW profile with lower EMW at the previous shoe and higher EMW at TD of the well. The casing was also run and cemented under dual gradient conditions with reduced mud level in the well.

Noon Luncheon & Exhibit Viewing Sponsored by SRI Energy Colorado Ballroom B

1:30 pm Operators Perspective
Moderator: Jon Thain, MPD Manager, Transocean
Representatives from various operating companies will discuss MPD from their perspective. This discussion will include how MPD is used in their operations, where they see MPD used in the future, and the challenges they have faced with MPD.

• Roberto Obando, Principal Engineer Drilling & Wells HPHT, Equinor
• Guilherme Vanni, Well Control Systems Subcommittee and Wells Competency & Training Subcommittee, IOGP; Senior Advisor, Petrobras
• Igal Askeroglu, DW GOM & INTL Exploration Drilling, Occidental Oil & Gas
• Nathan Tuckwell, Managed Pressure Operations SME, Shell

2:30 pm Coffee Service & Exhibit Viewing Sponsored by Infinity Energy

3:00 pm Well Control
Session Chair: Mike Vander Staak, Product Manager, Managed Pressure Drilling, Halliburton

Well Safety Analysis for MPD Operations: Andre Alonso Fernandes, Drilling Engineer, Ivan Mendes Sales, Felipe de Souza Terra, Victor R Nazareth, Gustavo CM Pena, Petrobras (SPE 215882)
MPD operations have been consistently being performed in deep water well construction for +10 years. Some even may advocate it has become commonplace. The consideration of being a fully dominated technology can lead to a false sense of safety. Even though MPD techniques unlocks unattainable scenarios, it must not be treated as an ordinary activity. A diagnosis with critical aspects of MPD operations was elaborated and how they collectively and systematically contribute to an increase in the occurrences of incidents during MPD operations.

Creating IMEs for Deepwater Wells: Martin Culen, Chief Commercial Officer, Geir Arne Evjen, Icaro Ostan, Glenn-Ole Kaasa, Kelda Dynamics, Hari Hariharan, Shell, Dave Smith, Enhanced Drilling
Creating a realistic influx management envelope (IME) for deepwater wells typically requires dynamic simulations with advanced multiphase modelling software. To yield realistic and accurate results, one needs to consider effects, such as distribution of the influx, dilution by riser boost flow, the riser effect and solubility of gas. This process requires hydraulics modelling expertise and is time-consuming. Each point on an IME must be created by dynamically simulating the entire influx circulation from bottom to surface while keeping downhole pressure constant, sometimes resulting in hours to create or update an IME. This paper summarizes the results of a joint industry study on the development and validation of software that can produce realistic and accurate IMEs for deep water wells at reduced computational times including results of a candidate deepwater well used for validation, and benchmarking against simulations conducted using an industry accepted multiphase software tool.

Utilizing the PWD Tool in Secondary Well Control: Friend or Foe?: Scott Hoekstra, Canadian Operations Manager, Beyond Energy Services and Technology
Why is the PWD tool such a valued tool while drilling and tripping in narrow window MPD wells but not heavily used in well control situations? Using the PWD tool in well control situations allows the Operator more flexibility with the pump rate, barite additions, and surface backpressure when compared to the standard methods of well control which rely on highly reduced pump rates and high choke pressures.

Understanding Barrier Philosophy during MPD Operations: Martyn Parker, Vice President MPD Services, Ahmed Shimi, Omer Kaldirim, Pruitt (SPE 215897)
Author(s) will present field case studies and example scenarios that didn’t follow the intent of industry guidance for the application of MPD and led to the development of their Pressure Operations Directive which they use to ensure the integrity of the Primary Well Barrier Envelope. They also intend to introduce a free planning tool for unconventional well drilling techniques guidance.

5:00 pm Welcoming Reception & Exhibit Viewing Sponsored by Enhanced Drilling Aspen Ballroom & Foyer

7:30 am Registration, Coffee Service & Exhibit Viewing  Sponsored by Patterson-UTI  Aspen Ballroom & Foyer

8:25 am Welcome & Introduction Colorado Ballroom A

• Leiro Medina, Chair, IADC UBO/MPD Committee; Executive Vice President, Beyond Energy Services & Technologies Corp

8:30 am Riser Gas Handling
Session Chair: Mike Vander Staak, Product Manager, Managed Pressure Drilling, Halliburton

A Review of Methods for Quantifying Riser System Limits during Controlled Riser Gas Containment or Removal; Defining “Riser Gas Tolerance”: Paul Sonnemann, Vice President of Technology, SafeKick
The presentation will illustrate relative and related importance of water depth, large volume gas behaviors, impacts of fluid compressibility, drilling fluid density and riser equipment limitations with regard to the ability of a riser system to reliably control — statically and/or dynamically — theoretically “worst case” riser gas scenarios. This is the first step toward use of standardize related calculations to succinctly characterize a system’s ability to “tolerate” a specified worst case condition, thereby providing a) evidence of the robustness of a system into which gas is/may be intentionally introduced (as, for example, during removal of possible gas influx volumes that do not exceed IME limits); and/or b) providing a relative measure of the lack of control resulting from failure to equip rigs with equipment that can be shown to radically improve the ability to manage both routine, non-emergency gas events as well as perhaps surprisingly serious emergency situations. 

Riser Gas Handling from Theory to Practice: Incorporating Principles to Operational Procedures: Romar A Gonzalez Luis, Thiago Silva, Oscar Gabaldon, Gustavo Puerto, Fabian Torres, Jorge Bedoya, Blade Energy Partners (SPE 215880)
The presentation discusses RGH procedure based on previous project experiences and recommendations/guideline currently under development by the sub-committee. It will also differentiate between what should be considered RGH, and what should be considerate dynamic influx management, and define the boundaries between both processes. It presents an example procedure under the following premises as main indicators to identify and differentiate the gas in the riser, for example a) high concentration of gas in the mud was detected in the shakers, b) gas units and LEL setting level, c) Undetected influx producing gas expansion in the riser increasing flow out. The presentation includes a brief discussion on the theory involved, preparation required, responsibilities and it will provide an example procedure and process flow diagram.

Is Handling Gas in the Riser a Safe Alternative? Exploring the Limits and Opportunities for Safer Kick Handling During Deepwater Drilling: Oscar Gabaldon, Drilling Technologies Development Manager, Romar Gonzalez Luis, Pedro Sousa, Blade Energy Partners, Gavin Humphreys, Stena Drilling, Mario Teixeira, Equinor (SPE 215879)
The presentation will describe three different approaches for proposed methods for circulating influxes from the well, both larger than IME limits during MPD operations, for smaller than IME limits for non-MPD operations, and for larger than IME limits for non-MPD operations. Considerations for calculation of RGH Envelope are included, as well as guidelines for risk assessment.

10:00 am Coffee Service & Exhibit Viewing  Sponsored by Patterson-UTI  Aspen Ballroom & Foyer

10:30 am Lessons Learned, Offshore
Session Chair: Guilherme Vanni, Senior Advisor – Drilling, Petrobras

Manage Pressure Drilling for Heavily Depleted HPHT Reservoir with Potential Depletion More Than 600 Bar– Kvitebjørn Field Experience: Steven Leonardus Paulus, Lead Drilling Engineer, Dag Ove Molde, Ross Murray, Raymond Hammer, Equinor (SPE 215886)
This is a case study of utilizing a combination of MPD (manage pressure drilling), WSM (wellbore strengthening materials) and customized BHA (bottom hole assembly) to manage the well control risk of drilling highly depleted HPHT (High Pressure High Temperature) reservoir with pore pressure span from full depletion of 164 bar / 2379 psi and initial pressure of 775 bar / 11240 psi. The case study showed drilling and completion opportunities in mature HPHT field with severe depletion of more than 600 bar / 8702 psi.

Evolution of Deepwater MPD: Have We Achieved Maturity? What’s There to Improve? – Lessons Learned from Worldwide Applications: Romar A Gonzalez Luis, Technology Development Engineer & Operations, Fabian Torres, Oscar Gabaldon, Jorge Bedoya, Gustavo Puerto, Blade Energy Partners
The presentation discusses different topics and its current maturity level based on key indicators. Authors discuss, evaluate and compare applications worldwide divided by the topic of interest, and the lessons learned and areas of improvement. Some of the topics to be discussed are the following: MPD variants: SBP MPD, CML, DGMCD, PMCD; Kick/loss detection systems limitations and dynamic influx management; Modeling and real-time data analysis (data acquisition, analysis, and events detection); Equipment integration, deployment, and performance; Execution and performance: DPPT/DLOT, PRVs philosophy, riser gas handling, and specialized procedures (MPC, tripping, coring); Training (current gaps with recommended practices, simulator, and real-time training).

Benefits of Continuous Circulation Technology Focusing on Non-Productive Time (NPT) Reduction in Offshore Drilling Operations: Valentina Gibilterra, Drilling Engineer, Orlando Loredana, Pinto Vieira Larissa, Poletti Noemi, Ciuca Antonio, Pollini Enrico Maria, Eni Spa, Piervittorio Salicante , Global Product Champion, Halliburton (SPE 215893)
Focus of the study is the time evaluation and comparison between offshore wells drilled with standard methods and a with continuous circulation technique to highlight the benefits in terms of safety and wellbore quality. The outcome of the analysis shows an important reduction of Non-Productive Time (NPT) related to the effect of the usage of continuous circulation devices on wellbore conditions and geological problems, such as fluid influx, sticking, circulation losses.

Noon Luncheon & Exhibit Viewing Colorado Ballroom B

1:30 pm Drilling Contractors Perspective
Moderator: Roger van Noort, Global Implementation Lead – Deepwater Managed Pressure Drilling, Shell
Representatives from various drilling contractor companies will discuss MPD from their perspective. This discussion will include how MPD is used in their operations, where they see MPD used in the future, and the challenges they have faced with MPD.

• Brian Clelland, MPD Technical Superintendent, Seadrill
• Nick Ward, Managed Pressure Drilling Manager, Stena Drilling
• Adam Keith, MPD Product Champion, Patterson-UTI
  

2:30 pm Coffee Service & Exhibit Viewing  Sponsored by Patterson-UTI

3:00 pm Lessons Learned
Session Chair: Ahmed Shimi, MPD Global Engineering Manager, Weatherford

Reservoir Characterization in Transient Wellbore Conditions Resulting from Unintended Hydraulic Fracture Communications utilizing MPD: Matt Kvalo, PE, V.P. of Engineering & Technology, Martin Duarte, Nathan Vargas, Edward Laird, Stasis Drilling Solutions, Tyler Sullins, Thomas Boddy, Chris Janes, Comstock Resources (SPE 215889)
In this presentation, the discussion will center around how MPD for reservoir characterization can be utilized after the unintentional communication between drilling and fracking operations. Also, highlighting how MPD allows the well to be safely re-characterized thus providing operators clear insight to the wellbores transient drilling window and the implications/considerations on the re-characterization on the MPD/drilling plan forward. All of which will be detailed using data from a recent unconventional drilling operation.

What to Do When Your Well Reaches its Harmonic Frequency: Martin Culen, Chief Commercial Officer, Pål-Jacob Nessjøen, Glenn-Ole Kaasa, Geir-Arne Evjen, Kelda Dynamics
A phenomenon was observed during the drilling of an onshore well using a model based MPD pressure controller that was, at first, difficult to explain. While drilling, surface pressure oscillations were observed that were not previously seen. If left unchecked, these annular pressure oscillations can lead to system instabilities and ultimately loss of well control. Understanding that a well may reach a hydraulic natural frequency prompted the development and incorporation of an algorithm to firstly identify that an instability is occurring, and secondly for the MPD controller to ‘self-heal’ automatically, dampening the oscillations to regain stability, and return safely to operations. This presentation will describe the original phenomenon observed, show the results of the developed self-healing function on simulated wells, and finally the self-healing function in action.

Slug and Backfill Trip Method Allows Quickened and Effective Tripping in High Pressure, Narrow Window Wells with MPD Drilling Techniques and Design Modelling Innovations: Andy Thi, Engineering Team Lead – L48, Philip Gunn, Maria Okafor, Beyond Energy Services & Technology (SPE 215891)
Go over the well pair that this method was developed for and implemented on. Outline the limitations and challenges with the previously used trip methods and their alternatives. Go over the implemented trip method and the advantage of the trip model while contrasting it with the difficulty of modelling the hydrostatic effects of this method before going into the implanted quick analytical model and how the results compare to the developed full numerical model.

Calculation of Reservoir Fluid Influx while Underbalanced Drilling: Faramarz Azarnejad, Petroleum Engineer, Arash Azarnejad, Petroleum Engineer, Petromath (SPE 215884)
A novel mathematical solution is presented for calculating reservoir influx or intake while drilling.  This solution can be used at three different stages: design stage, drilling stage, and post job analysis period.

5:00 pm Closing Remarks & Adjournment 

• Leiro Medina, Chair, IADC UBO/MPD Committee; Executive Vice President, Beyond Energy Services & Technologies Corp