Tuesday, October 23
This session will look at the inputs required to create a robust pressure model in any environment with appropriate ranges of uncertainty. Given those sand and shale pressure ranges along with the basin structural setting, we will look at the associated predictions for fracture gradient and wellbore stability.
Pre-drill well planning requires assessment of many variables to generate a safe and cost-effective well design.
- Pore pressure prediction for both sands and shales;
- wellbore stability modeling
- Fracture gradient prediction.
In complex environments the range of possible pore pressure may be large, with impacts on predicted ranges of fracture gradients. Furthermore, those fracture gradients may be affected by structural position and pre-existing weaknesses. Wellbore stability requires an understanding of shale pore pressure which may be different than sand pressure. Shale pressure must be inferred from indirect offset well data and modelling and therefore carries significant uncertainty.
0930 - 1000: Pore pressure and the integration of stress (or the stress of integration!) by Toby Harrold, Repsol Exploracion S.A. 1000 - 1030: Horizontal stress variation across the reservoir structure by Ismayilova Farida, BP
1030 - 1100: Geology and Lessons Learned on the Satpaev structure by Dmitry Zadvornov, Schlumberger
This session will discuss how to optimize drilling fluid mud weights and ECD management for wells with narrow PPFG windows while drilling different pressured zones in the Caspian. We will also discuss advances in drilling fluids for wellbore stability, approaches used for wellbore cementing, and strengthening.
Narrow PPFG margins the operating window, while drilling is the one most challenging conditions for drilling operations. Minor changes in the bottom hole pressures would affect drilling scenarios consequently lead for major financial and technical risks for operators. The operators in the Caspian basin and in other areas around the globe are trying to use different types of technologies and technics while drilling through narrow operating windows. The Caspian sea basin is one of the most challengeable areas with narrow PPFG margins. The slim hole and tight annulus in the deep gas wells in the Caspian adds additional complexity to the operations, such as casing, running, and cementing. The overburden is present that fractures can be induced, thus leading to whole drilling fluid lost to the formation, in addition to what can be lost due to naturally occurring fractures or vugular zones.
1130 - 1200: Optimizing Drillability – How the Knowledge of PPFG Brings Value to Drilling? by Rashad Gulmammadov, SOCAR
1200 - 1230: Pore Pressure Estimation Using Mechanical Specific Energy and Drilling Efficiency by Reza Majidi, BP
1230 - 1300: Multi-Scale Geomechanics: How Much Model Complexity Enough? by Alejandro Ganzp, Baker Hughes, a GE Company
Narrow PPFG margins the operating window while drilling is the one most challengeable condition for drilling operations. Minor changes in the bottom hole pressures would affect drilling scenarios consequently lead for major financial and technical risks for operators. The operators in the Caspian basin and in other areas around the globe trying to use different type technologies and technics while drilling through Narrow Operating Windows. The Caspian sea basin is one of the most challengeable areas with narrow PPFG margins. The slim hole and tight annulus in the deep gas wells in the Caspian adds additional complexity to the operations such as casing running, cementing and etc. The overburden is present that fractures can be induced, thus leading to whole drilling fluid lost to the formation in addition to what can be lost due to naturally occurring fractures or vugular zones.
The Session will be dedicated to the way of optimization of drilling fluid mud weights and ECD management for the wells with narrow PPFG windows while drilling different pressured zones; discuss the advances in drilling fluids for wellbore stability; approaches used for the Wellbore cementing and wellbore strengthening; in the Caspian and analogues filed
1400 - 1430: Determination of the minimum mud weight for drilling the unconsolidated creeping shale encountered in Absheron field by Kun Su, Total
1430 - 1500: Application of ALD Images and ALHSI for the Wellbore Stability Monitoring and Breakout/Geomechanical Analysis by Elnur Amirov, Halliburton
1500 - 1530: Drilling hazard mitigation with effective pressure control, worldwide experience bringing value to drilling in Azerbaijan by Essam Sammat, Weatherford
Casing cementing for zonal isolation is a critical operation for well completion and always accomplished with different challenges. The South Caspian basin formation properties such as poorly compacted sands, geomechanical features, multilayered reservoir, non-uniform depletion, and etc exposes new challenges for the cementing of the wells. Production from number of horizons causes non-uniform depletion of formation along the borehole thus creating challenges for zonal isolation. The process is more exposed at deep reservoirs where the formation pressure is not supported by injection wells. Detection of poor isolation zones and possible cross-flow rate is an important for understanding of the reservoir properties as well as for estimation scope of requirements for restoration of hydraulic integrity behind casing to eliminate the cross-flow between layers.
All aforementioned challenges require unique solutions starting from modeling, designing and execution of cement job and evaluation of cement bond quality. Consideration of geomechanical aspects including prediction and estimation of PPFG values is key point for decision making and successful delivery of cementing/restoration jobs.
This session will be dedicated to the wells cementing and zonal isolation approaches to address the challenges in conditions similar to the South Caspian basin.
1600 - 1630: What’s the Real Window? - Implications of Dynamic Geomechanics to Long Well Integrity by Irfan Kurawle, Schlumberger
1630 - 1700: Addressing Cement Design Philosophy for Highly Depleted Reservoir – An Improved Approach for Zonal Isolation by Avinash Kishore Kumar, Petronas
1700 - 1730: Putting Six Cement Plugs into Different Gas Horizons by Parviz Akhmedov, SOCAR
Wednesday, October 24
When hydrocarbons are produced from a subsurface reservoir, pore pressure in the reservoir is reduced. This reduction, termed depletion, caused a redistribution of stress in the reservoir and surrounding rocks, leading to a variety of potential issues such as compaction and subsidence, fault reactivation, etc. It generally also leads to a reduction in the minimum horizontal stress and therefore to a potential reduction in the fracture gradient (FG) in the depleted interval. The reduction in FG can be one of the most notable challenges when attempting to drill and complete new wells.
The session will be dedicated to the main drivers in pressure management and depletion planning (e.g. timing of producers and injectors) for “Caspian type” reservoirs. It will discuss the effect of depletion on fracture gradient, the depletion and re-pressurization stress path; the effectiveness of wellbore strengthening methods (e.g. StressCage) in depleted sands and whether the depletion induced compaction, subsidence and fault reactivation is a concern for the Caspian and analogue basins.
0930 - 1000: Impact of geologic description on pore pressure and well design; Shah Deniz, offshore Caspian Sea by Jennifer C Villinski, BP
1000 - 1030: From pore-scale failure to reservoir compaction and seal integrity: H2S breakthrough risk assessment via integrated 4D reservoir geomechanics study by Evgeny Korelskiy, Schlumberger
1030 - 1100: A Pore Pressure Model in a Centrifugal Hydrodynamic Paleocene Basin by Sebastien Dehez, Total
- Water injection in soft sands. Challenges of modeling fracture initiation and propagation in soft sands and caprocks in compressional stress regime.
- Effect of wellbore azimuth and inclination versus in-situ stress orientation on water injector effectiveness.
1130 - 1200: The Main Mechanisms of Fracture Propagation during Waterflooding by Abbas Abbasov, BP
1200 - 1230: Permanent and Temporary Monitoring of Fiber Optic Distribute Acoustic and Strain Sensing for Oilfield Geomechanical Applications by Javier Franquet, Baker Hughes, a GE Company
1230 - 1300: BP’s Recent Model Development of Wellbore Strengthening by Reza Majidi, BP
- Industry developments in fracture gradient prediction
- Industry developments in wellbore strengthening tools and materials (e.g. nano-technology) for the payzone, cementing, etc
- Real-time pore pressure monitoring (rigsite and remote) techniques while drilling, managing the pressure window
- Permanent surveillance etc.
1400 - 1430: Challenging the Status Quo through Cementing while Drilling in a Highly Deviated Well by Ahmed Tahoun, MIT Technologies
1430 - 1500: Innovative Drilling Mud Heaver Technology by Elchin Kazimov, SOCAR, “OilGasScientificResearchProject” Institute
1500 - 1530: Integrating Real-Time LWD Acoustics Technology with Managed Pressure Drilling Operations to Improve Drilling Efficiency by Davide Di Tomasso, Weatherford