It is crucial for an integrated talent management and succession planning strategy to have close ties to organizational strategy and buy-in from the senior leadership. However, often the onus of applying these processes lies solely with the human resource function thereby not involving the line managers in the process. The purpose of this paper to present a best practice model to effectively integrate management personnel in the talent management and succession planning framework thereby fully utilizing them in ensuring optimal development of the talent pipeline.
In order to make the senior leadership active stakeholders in driving the process, we instituted ‘Talent Review Committees (TRC)’ at various levels to drive Talent Management and succession planning. The brief structure and role is as follows:
ADNOC Group level - chaired by ADNOC Group CEO with all Directors as members. Key positions considered - Directors and Group Company CEOs
Directorate level (one per directorate) - chaired by the director with all related group company CEOs as members. Key positions considered - SVP & equivalents
Group Company level (one per group company) - chaired by the Group company CEO with all SVPs as members. Key positions considered - up to VPs and technical positions
These committees review and approve the key positions, select potential successors, review their level readiness and recommend and monitor development activities. The output of these TRCs is combined at the corporate level to deliver a coherent talent management solution.
Since ADNOC is a group of independent companies it is necessary to unify the talent management strategy in order to have a group-wide talent pool so that the need for capable leaders and specialists across the Group is continuously met. Multi-level governance structure to drive the talent management and succession planning process helps us in efficient identification and utilization of talent, making succession planning effective and accurate. The key results and conclusions are as follows: Identification, assessment and development of group-wide pools of internal candidates to improve their readiness to compete for future openings in key positions Availability of qualified successors and improved readiness & performance in target position Accurate data availability to facilitate cross function/ company mobility and development opportunities Ensure that leadership continuity is in place and that strategic and operational capacity is sustained.
Identification, assessment and development of group-wide pools of internal candidates to improve their readiness to compete for future openings in key positions
Availability of qualified successors and improved readiness & performance in target position
Accurate data availability to facilitate cross function/ company mobility and development opportunities
Ensure that leadership continuity is in place and that strategic and operational capacity is sustained.
|Talent Review Committee||Chairman||Members||Key positions considered|
|ADNOC Group-level||ADNOC Group CEO||Directors|| |
Group Company CEOs
|Directorate - level ||Director||Group Company CEOs||SVP & equivalents|
|Group Company - level ||Group Company CEO||SVPs|| |
The paper offers an insight into the framework of multi-level talent review committees (TRCs) instituted across the ADNOC group as an effective model for integrating senior leadership into the talent development and succession planning framework.
To overcome the lack of information on the most superficial part of the near surface obtained by the use of the First Arrivals (refracted waves), we have implemented an innovative combined workflow that use the information from the Surface Waves (Rayleigh waves) to complement the first-break measurements. As the Rayleigh waves propagates along the free surface interface, they carry significantly more detailed information of the near-surface characteristics which can be used to better constrain the first-break inversion.
The first step of the workflow starts with the surface wave dispersion curve picking. As reliability of the results directly depends on the quality of that picking, data regularization are used to improve picks accuracy on both low and high frequency of the phase velocity/frequency spectra. A surface wave tomography process is then applied to convert the spatially irregular frequency-dependent picks into a regularized (x, y, frequency) Rayleigh wave’s velocity volume. Lastly a laterally constrained depth inversion is performed, delivering a 3D shear wave’s near-surface depth velocity model.
The second step of this workflow uses this S-wave velocity model, which contains the near-surface details captured by the Surface-Waves, to constrain the refracted P-wave first-break tomography. A regional scaling, here a 1D VP/VS ratio estimated from knowledge over the area or from fast-track refraction first-break analysis, is required to convert the S-wave velocity into a P-wave model. The constrained tomography aims to scale the trend from the high-resolution S-waves velocity model by fitting it with the trend of the P-wave field derived from the first arrivals. This corresponds in a sense in inverting the VP/VS ratio in such a way to preserve the high-resolution feature scaptured by the surface waves while remaining consistent with P-wave information. The resulting near-surface velocity model looks more geologic, better respects P-wave travel times and can be used with more confidence to compute the primary statics solution than the conventional P-wave field only obtained from the first-arrivals tomography…
Furthermore, this accurate update of VP/VS ratio can be used to estimate the Poison’s ratio. It can be used to better plan geotechnical survey in order to reduce shallow drilling hazards.
Martin, Luis Emilio San (Halliburton) | Fouda, Ahmed Elsayed (Halliburton) | Amineh, Reza Khalaj (formerly Halliburton) | Capoglu, Ilker (Halliburton) | Donderici, Burkay (Halliburton) | Roy, Sushovon Singha (Halliburton) | Hill, Freeman (Halliburton)
An electromagnetic corrosion inspection tool was designed to accurately assess corrosion in as many as five nested pipes. This paper provides details of the principles of operations and the methodology of the algorithms used for data processing of this tool.
This tool uses the eddy current principle and includes two transmitters and eight receivers. It operates in continuous wave mode at multiple frequencies. Optimized transmitter-receiver spacing configurations and multifrequency operation provide sufficiently diverse information to help assess the metal loss in each individual pipe for a wide range of configurations.
The performance of the tool was validated with synthetic and actual data by using controlled tests and experiments. These tests demonstrated the accurate determination of the defect positions and metal loss in each individual pipe of a multiple configuration. To validate the wide operational range of the tool, synthetic tests were used that included challenging scenarios, such as the identification of defects with a total metal thickness of all casings of more than 2 in. or overlapping defects at the same axial position. Finally, the accuracy of the tool in practical scenarios was verified by using results from well tests. The electromagnetic corrosion inspection tool has delivered unprecedented accurate assessments of the fourth and fifth pipes, as well as an accurate assessment of the first, second, and third pipes.
The information provided by this tool can significantly improve decision-making for mature well operations, especially in areas with high corrosion rates, and could result in significant cost savings to the operator.
The BTE field is one of the largest recent gas discoveries in the Egyptian Western Desert. The main subsurface uncertainties impacting the Initial Gas in Place (GIIP) are Gas Water Contact (GWC), structure, fault positions and sand development. Given the large subsurface uncertainties, it is planned to further appraise the field with one or two appraisal wells and reshooting seismic.
Other key uncertainties are sand quality, intra-field faults and aquifer strength. These uncertainties will impact the wells deliverability, Estimated Ultimate Recovery per well (EUR/well) and the Ultimate Recovery Factor (URF). The EUR/well and the URF are a function of the number of wells drilled.
An integrated probabilistic modelling (experimental design model) approach was developed to consider all main reservoir uncertainties together and determine the true P90, P50 and P10 EUR subsurface realizations. Three different software packages were used and linked together; Material Balance Equation
This probabilistic model enables the user to run sensitivity studies by changing one parameter at a time and check its effect of EUR. The model also lends itself for uncertainty studies (experimental design) by examining all the possible combinations scenarios between the different uncertain parameters; such as GIIP, tanks transmissibility, wells flow coefficient
Petroleum Development Oman (PDO) is developing sour gas fields across the country in order to meet the gas demand to sustain industrial growth in Sultanate of Oman.
The projects involve development of high pressure, high temperature sour associated gas reservoirs with oil rims as well as non-associated gas reservoirs. The reservoirs are located at a depth of around 3 - 5 km. The sour gas produced contain significant amounts of H2S and CO2 in addition to other contaminants such as mercaptans, carbonyl sulphide (COS) and carbon disulphide (CS2).
For a couple of projects, in the absence of a suitable sink for the acid gas and due to HSE risks associated with high pressure acid gas injection (> 400 bar), sulphur recovery has been selected as the acid gas processing route. The various sour gas fields being developed have different levels of contaminants whereby employing a standardized process line up of gas treatment and sulphur recovery technologies may not be either technically feasible or economically optimum.
Among the many engineering challenges associated with any sour gas field development, the combination of Sultanate of Oman's ultra-high sulphur-recovery efficiency (SRE) specification of 99.9%, and the very stringent SO2 emission specification of 35 mg/Nm3, poses a steep challenge and pushes established technological boundaries. Further, if the sweet gas produced will have to be exported to the Government Gas network, it has to meet a tight total sulphur specification of < 5 ppmv. In case the gas is to be used for internal consumption within PDO, the total sulphur specification is < 100 ppmv.
The combination of these regulatory requirements makes the design of the gas treatment and sulphur recovery facilities extremely challenging. It is clear that best-in-class solutions would be necessary for the projects to comply with the standards.
The concentration of different contaminants in the feed gas and the selection of the sweet gas export route dictate the choice of optimum gas processing and sulphur recovery technologies and their integration. For the projects under consideration, PDO has evaluated a wide portfolio of gas processing and sulphur recovery technologies and has selected process line ups comprising of a fit for purpose combination of technologies.
An integrated approach ensured that interfaces between the different units were efficiently managed and the configuration was fully optimized thereby enhancing energy efficiency.
This paper presents the selection of the optimized combination of gas processing and sulphur recovery technologies that cater for different feed gas contaminant concentrations and yet comply with the regulatory requirements.
Noirot, Jean-Christophe (Petroleum Development Oman) | Hamed, Walid (Petroleum Development Oman) | Ghulam, Junaid (Petroleum Development Oman) | Svec, Robert (Petroleum Development Oman) | Cobanoglu, Mustafa (Petroleum Development Oman)
Achieving consistent optimum field development choices in technically complex portfolios requires sound individual and corporate technical capabilities. Within the largest Exploration and Production Company in the Sultanate of Oman, some key gas and contaminated hydrocarbon Field Development Plans are produced by dedicated specialized study teams that are part of the company's so-called Field Development Centre. In order to tackle projects involving technically complex challenges such as tight reservoirs, rich gas condensates, contaminated hydrocarbons or high pressure developments, a number of organizational elements are put in place to ensure continuous growth of staff and corporate capabilities along with corporate knowledge dissemination.
First, each project team remains integrated throughout its project life time. The integration of subsurface and surface disciplines allows early identification of realistic and robust development options. It also facilitates knowledge sharing with activities such as field visits conducted jointly between subsurface and surface engineers. The benefits of this integration are demonstrated with examples from several gas condensate and sour oil study cases.
Second, experienced professionals provide project specific guidance and coaching to junior staff over several projects. This scheme allows maximizing the impact of the experienced staff while allowing hands-on learning from younger recruits.
Third, benefiting from a ring-fenced organization to conduct studies facilitates the retention of corporate knowledge and the replication of best practices. However, this does not imply that knowledge and capabilities remain centralized as several conduits are in place to ensure dissemination across the organization. Asset staffs with identified technical development gaps are assigned for the duration of a project to the study team where they actually develop their skills through direct project contribution. Specialized forums, physical and web-based, are also available to share information and solutions learnt from previous projects.
Finally, fundamental technical capabilities and knowledge bases are developed at corporate level in order to consistently address key challenges encountered in various assets (e.g. gas condensate modeling and optimization, tight units recovery improvement, fraccing optimization and associated production forecasting). A wide scope integrated multi-year project covering all company gas activities within several formations has been kicked-off for this purpose. This fundamental project involves various contributors from the company such as Subject Matter Experts and experienced asset staff, specialized external service providers and academia. More specifically, the project aims at developing a comprehensive corporate understanding of its gas reservoirs, and at developing consistent datasets and validated effective modeling workflows to be disseminated through standards, websites and trainings.
This paper provides an overview of the work practices and tools that have been put in place within a large company in order to ensure the steady development of staff and corporate technical capabilities while consistently addressing the development of its most complex oil and gas reservoirs.
Electrical power network system is considered as a valuable asset. So it is important to manage such an asset with criticality criteria by adopting different predictive maintenance techniques to increase reliability (availability) and reduce direct & indirect costs. Such techniques constitute the basis for an effective asset management system, as they can ultimately decrease the electrical failure rate. HV transformers & switchgears are considered to be expensive and delicate components of the electrical energy network. Increasing load on transformers & switchgears causes the more stress on it. Continuous stress weakens the insulation and producing arcing called partial discharge (PD). Partial discharges seriously affect the reliability of transformers & switchgears. Electrical energy networks may experience transformers & switchgears failures because of insulation degradation. Failure of high voltage insulation is the No-1 cause of high voltage system breakdown. IEEE statistics indicates that electrical insulation deterioration causes upto 90% of electrical failures of high voltage equipment. The major and most effective tool to detect insulation deterioration, as is well known, the measurement and analysis of partial discharges. However, this technique is not as well accepted as one might expect based on its great benefit. Reasons behind it are (
This paper describes PD theory, PD detection and analysis approach to the diagnosis of HV Transformers & Switchgears insulation system along with few case studies. The results of PD measurements performed on-line on HV transformers & switchgears insulation system, just after commissioning or after sometime in operation helps in identifying PD-generating defect. Decision is made by comparing reading with baseline and periodically recorded data.
A common goal in unconventional plays is to create a sweet spot map by integrating all available data, including seismic data. This map could be utilized to optimize future drilling locations. Thus, in order to establish the workflow, we conducted a sweet spot mapping study in the Lower Triassic Montney tight gas play in the Western Canadian Sedimentary Basin, specifically focusing on prediction of lateral variations in condensate-gas ratio (CGR). A 3D geomodel was first created to obtain the 3D distribution of reservoir quality and completion quality properties which are expected to be potentially correlated with CGR. In the model, simultaneous AVO (Amplitude Variation with Offset) inversion results were fully utilized by geostatistically integrating with the well log data. Typical SRV (Stimulated Reservoir Volume) geometry in the study area was estimated from analysis using production data and microseismic data. For each producing well, average values for the reservoir quality and completion quality properties within the estimated SRV were obtained from the 3D geomodel to directly compare with the CGR value. Statistical analysis including crossplot and multiple-regression analysis was conducted to investigate the effectiveness of model properties as predictors of CGR. The analysis result implied that the reservoir depth and gas content are the most dominant properties for predicting lateral variations in CGR at seismic-scale. The reservoir depth is interpreted as a first-order control of thermal maturity and CGR. High gas content and low CGR is also observed in areas of higher porosity, which may correspond to secondary migration pathways for methane (
A giant mature light oil field under miscible WAG injection is a potential candidate for foam application to control gas mobility and reduce field gas – oil ratio (GOR). We conducted a feasibility study which comprised live oil corefloods at reservoir conditions and compositional numerical simulation coupled with a foam formulation. The objectives of this study were to identify critical variables and potential detrimental factors for the process implementation; and evaluate the GOR decrease due to foam application.
This feasibility study comprises an evaluation of the effect of foam on a field scale through numerical simulation, and the study of foam creation under reservoir conditions through coreflood experiments. We used a compositional simulator with an empirical foam implementation to predict the effect of foam in a mechanistic sector model of a high production area of the field. Simulation results show that foam is able to reduce field GOR by reducing the mobility of injected gas in high permeability layers. It became clear that the incremental oil production is strongly dependent on gas production limits; thus, foam application has to be coupled with overall field optimization.
Due to challenging field conditions for foam application, we performed an extended laboratory study. Static mixing experiments allowed surfactant compatibility limits in mixtures of formation and injection brines to be defined. In addition, a series of corefloods showed that foam can be successfully generated with a commercial alpha-olefin-sulfonate surfactant under reservoir pressure and temperature in presence of live reservoir oil, rich hydrocarbon gas and injection brine.
To our knowledge this is the first published feasibility study of foam application in a mature miscible WAG project including compositional simulation and live oil corefloods with rich hydrocarbon gas injection under reservoir conditions.
Water Injection is a part of secondary recovery to sustain Reservoir pressure and improve sweep efficiency and consequently improve recovery factor of the field with minimum cost. Source of the water is varying between offshore and onshore fields.
Normally for all offshore fields, water injection source is sea water. However, it is vital to have proper water injection treatment system to avoid the risk of issues at surface and subsurface levels.
This case study will show how water injection treatment system is important and their impact on the decrease of water injection efficiency due to plugging and corrosion. In addition, it will show the proper mitigation plan for improvement of water quality for short/mid and long term planning of the field development.
Injected sea water should be treated mainly from the following parameters: Sand solids from the sea using the sand filters Oxygen removal from corrosion Bacteria’s Chemical inhibitors.
Sand solids from the sea using the sand filters
Oxygen removal from corrosion
Each of these parameters was checked and improved on the field and successful results were observed in terms of pipeline conditions and injection sustainability.
Due to the poor water quality, every year 15-20 water injectors were plugged or decreased dramatically due to water quality. Improving the quality of the water and setting the proper guidelines for the treatment standards showed a positive impact on injection sustainability and consequently improved production offtake from the field.
The holistic approach of the water injection treatment system and mitigation plan become possible uses the right standards of the treatment and correct surface facility. This will help to sustain water injection rate and decrease the number of acid jobs performed due to a decrease of the performance. Solving the cause of the problem is crucial instead of acting on the consequences.