11^th International Conference on Oil and Gas November 25-26, 2020 Barcelona, Spain

Biography:

Aditya Pratama has more than 20 years experience in Oil and Gas industry. He has mechanical engineer background from Technical Department, University of Indonesia. His experience working for oil and gas upstream business to mid stream business, Liquifed Natural Gas manufacture, and also for leading any projects. As development for getting complete capability, Aditya Pratama has experience to improve the HSE Company to get world class level refering to DNV ISRS. Now Aditya Pratama is working for Risco Energy Indonesia for developing gas infrastructure in Indonesia.

Abstract:

Risco DPS is developing more efficient gas infrastructure for the country of Indonesia. On July 31, 2019, PT. DPS Energi Sukses Pratama (DPS ESP), a Risco Energy Company together with DPS, achieved its 1 year of excellent operation with a series of achievements. DPS ESP operates and controls the LNG transportation, LNG storage and regasification facility in Sambera, East Kalimantan, for delivery of gas for PLN Power. DPS ESP noted in a brief statement that the Sambera operation has achieved 100,000 Safe Manhours without any lost time injury, No LNG spill incident during operations, 3,000 LNG ISO Tanks transported, and also 1,000,000 MMBTU re-gasified and delivered to PLN Power. Through many challenges during the first year of operations, the risks are well managed. Health, safety, environment & production aspect can be maintained and aligned to the current KPI of the company. This achievement is used as our reference in the next KPI for the following years with the spirit of improvement. In the future, DPS ESP keep committed to contribute the mid-stream LNG business for supporting the business in Indonesia become more efficient and using clean energy.

Together with Pertagas Niaga (PTGN) and PLN, The first year of successful operation marks a major shift in the way PLN is transforming its power program for the future. According to Mr. Ikram, PT PLN (Persero) General Manager KITLUR East Kalimantan, Since May 2018, PLN UIKL Kalimantan has been operating the Sambera PLTG (2x18 MW) with LNG supplied from PT Badak NGL through cooperation with PTGN and DPS ESP. This is one step ahead to save the National Income and it needs to be developed in the future, especially on scattered areas across the Indonesia archipelago. DPS ESP in the future is committed to contributing the mid-stream LNG infrastructure business to support the Indonesia market for PLN and also other industrial users. Mrs. Linda Sunarti, PTGN President Director, states “LNG utilization if growing to meet domestic demand and this is the first LNG trucking operations for fulfilling power plant needs. This model is expected to be a role model for similar power plants operations in Indonesia”.

Biography:

Seydou Sinde has completed his PhD at the age of 36 years from Cairo University. He has worked, from 2006 to 2016, as Sample Catcher, Mud Logger, Data Engineer, Pressure Engineer, Operations Supervisor and Field Support. He has also occupied the position of Training Instructor and Training Chief Instructor in Petroservices-GmbH; Egypt Branch for four years. Since September 2016, he has joined IUGB and has been working as an Assistant Professor at the school of STEM. He has attended four international petroleum conferences and published a number of conference and journal papers.

Abstract:

The objective of this work is to analyze the foam rheological and hydraulic properties by the effect of productivity index. The analysis is based on a developed hydraulic model of foam drilling for vertical wells. Because foam, as a multiphase fluid, requires complex mathematical formulae to involve more real representative conditions for better accaracy, VISUAL BASIC codes were used for the programming of the hydraulic model. The method for achieving so is to graphically represent different foam rheological parameters versus the annular depth at different productivity indices. The graphical plots are also followed by detailed explanations illustrating the reasons of the various trends for the different parametric profiles. As the annular foam is made of discontinuous gas bubbles surrounded by the continuous liquid films in addition to the drilled solids, any variations in gas, liquid or cuttings concentration will have some impacts on foam rheological and hydraulic properties. If the annular foam density and pressure are not significantly affected by the change of the productivity index, annular velocity, quality, Reynolds number and cuttings concentration are affected. Flow power index, consistency index, effective viscosity and friction factor are not only affected by the productivity index, but also might change the trends of their profiles. Therefore, this work intends also to add to the literature this model based on published experimental, analytical and mechanistic conclusions. Thus, good control of foam rheology by the use of the developed model can lead to better understanding and design of the foam hydraulics for vertical wells.

Biography:

Mahdi Ashkanani is Senior Mechanical Engineer at Kuwait Oil Company. He Worked as Mechanical Engineer in Maintenance Team for the first 8 years at Kuwait Oil Company. At recent time, my position is Snr. Mechanical Engineer working in Operations Technical Services handling Oil & Gas projects in all Kuwait oil fields.

Abstract:

Water produced from oil and gas production is one of the most significant effluent stream due to its large volume and strategic importance. The amount of produced water, the constituents present in produced water usually vary significantly over the lifetime of a field. During early life of the field, water cut can be very low, but it gradually increase and becomes multiple times of oil production rate as the field matures. In terms of composition, the changes are complex because they are a function of the geological formation, the oil and water chemistry, reservoir behavior and additives / chemicals injected for reservoir maintenance. Properly treated produced water can be recycled and used for produced water re-injection and other applications, such as crop irrigation, wildlife and livestock consumption, aquaculture, agriculture, industrial processes, vehicle and equipment washing, power generation and fire suppression etc. These beneficial reuses decrease reliance on potable water / brackish water, which are highly valuable commodity in water-scarce regions of the world. Thus, for oil and gas production facilities located in water-scarce regions, re-injection of treated produced water for improved oil recovery has emerged as a viable option but its implementation has challenges related to injection water quality, injectivity and safety issues. In addition, strict environmental regulations require extensive treatment of produced water before safe disposal making reinjection of produced water even more viable alternative. The specification of injection water quality is of prime importance and optimization of injection water quality vis-à-vis the cost of treatment is the key factor for reservoir health maintenance without sacrificing the injectivity loss or excessive increase of backpressure from the well. Thus, the role of produce water treatment and injection facility is vital for sustaining well injectivity over field life while maintaining reservoir health for an effective Improved Oil Recovery program. This paper provides an overview of the various challenges, opportunities and resolutions for utilizing produced water in Kuwait for Improved Oil Recovery.

Biography:

Nader is working in Suez Oil Company (SUCO) Egypt.

Abstract:

The Late Cretaceous deposits are well-developed throughout Egypt. This is due to a transgression phase associated with the subsidence caused by the neo-Tethyan rift event that took place across the northern margin of Africa, resulting in a period of dominantly marine deposits in the Gulf of Suez. The Late Cretaceous Nezzazat Group represents the Cenomanian, Turonian and clastic sediments of the Lower Senonian. The Nezzazat Group has been divided into four formations namely, from base to top, the Raha Formation, the Abu Qada Formation, the Wata Formation and the Matulla Formation. The Cenomanian Raha and the Lower Senonian Matulla formations are the most important clastic sequence in the Nezzazat Group because they provide the highest net reservoir thickness and the highest net/gross ratio. Sand in Matulla Formation, Santonian age is a good reservoir to many oilfields in the Gulf of Suez but Matulla Sand Deposited as a sand bar, Estuarine Environment. This study emphasis on Matulla formation located in the eastern part of the Gulf of Suez. The three stratigraphic surface sections (Wadi Sudr, Wadi Matulla and Gabal Nezzazat) which represent the exposed Coniacian-Santonian sediments in Sinai are used for Determine a clastic depositional environment, Identify systems tracts and flooding surfaces and correlating the Para Sequence (High Resolution Sequence Stratigraphy). Cutting description, petrographic examination, log behaviors, biostratigraphy with outcrops are used to identify the flooding surfaces, reservoir characteristics, lithology, facies environment logs and subdivide the Matulla formation into three stratigraphic units in-between four Sequence boundaries(SB) : a lower clastic unit, a middle clastic/carbonate unit and an upper Carbonate-dominated unit which Belong to the Santonian age. The lower unit is the main reservoir where it consists mainly of sandstone, shale and carbonates which subdivided into two systems tract transgressive (TST) and high stand systems tracts (HST).

Matulla sandstones are fine to very coarse, poor to well sorted and subangular to subrounded containing pyrite cements which described in ditch sample in subsurface and observed also in many petrographic samples in the surface outcrops. Pyrite is a conductive mineral result in low resistivity value in some intervals. By using fourth order High Resolution Sequence Stratigraphy and delineate flooding surfaces. The commercial sand detected and identified in lower Matulla Formation located in the transgressive systems tract (TST) as a clean sand, and mixed siliciclastic in a High stand systems tract (HST). Prove that this is the best way to maximizing production in low thickness low resistivity pay zones.

Biography:

Julia Mbamarah is CEO/ FOUNDER at Overwhelmed Series, also member at Enactus FUTO. Presently she is Vice President at Society Of Petroleum Engineers - SPE FUTO.

Abstract:

The problem with production today is the inability to recover an optimal amount of the discovered resource. From statistical analysis, only about 60% of oil is recoverable and the highest amount recorded so far is only 80% of the discovered oil. That is to say that about 25% of oil still exists in oil field wells that have been abandoned. Obtaining data from various oil fields in Nigeria, the quantity of discoverable oil was computed using Deep learning. The network was trained to accurately predict the estimated given volume of oil initially in place. A sensitivity analysis of the neural network model generated revealed which input parameters contributed majorly to estimating the I.O.I.P. From the information deduced, an Ideal well to improve recovery would be one whose determinant factors are minimized or maximized according to feasibility of parameter alteration. The Neural Prototype was optimized by improving on the determinant properties of interest. A data update subsequently lead to further training and generally an improvement in the degree of recovery attainable. In as much as other energy sources are being identified, oil and gas still remains an integral part of the energy industry and steps to ensure that recovery of this energy source is optimized to the greatest percentage must not be neglected.

Biography:

Aymen Chagour, +10Years in Oil & Gas onshore and offshore actually I am a Maintenance Campaign Leader based offshore on 28/28 rotation in ANGOLA, for operation and maintenance on 02 X 250k bpd deep offshore FPSOs by performing maintenance campaigns on different rotating and static equipment, previously I was a Rotating Equipment Maintenance Engineer working on maintenance of different Gas Engines; Compressors preparing business plans for Capex projects and reducing OPEX costs.

Abstract:

Organizations often consider maintenance as just a necessary cost, yet a focused and competent maintenance strategy delivers significant value by ensuring assets operate reliably and are available to produce product in accordance with business needs, and at the optimal lifting costs.

Organizations are now developing Operational Excellence strategies in order to maximize asset performance and Opex lifting costs, by taking part to this seminar we will explain how to optimize maintenance PM and Organization based on real case study from offshore, and demonstrate that the appropriate actions for an organization can be achieved by focusing on reliability, PM optimization at asset level and also in terms of organizational to reduce major budget consumers (Logistic costs, Maintenance costs, POB costs, etc…). 

Agenda:

-               Introduction

-               PM Optimization strategy in a multi-level assets

-               Maintenance Workforce Organizations

-               Impact of Optimization in terms of OPEX

-               Overview of Market Weakness on Maintenance

Biography:

Danah Alselahiis working in Kuwait Oil Company in Kuwait. She competed her bachelor degree in Industrial Engineer from Arizona State University.

Abstract:

As part of Kuwait Oil Company’s aggressive campaign to spear the wave of optimizations and drilling completions, the company has various activities to combat practices that promote unnecessary expenditures. Drilling, being the culprit of most of the company’s spending, was the master candidate to engage in such an activity. Using the traditional methods would yield expected results and might propagate the continuous decay of resources.

Therefore, we have decided to approach matters in a new light. Instead of solely fixating on productivity and rates, we have expanded our rig deployment metrics to engulf other variables that would sway the feasibilities of well construction and delivery. These variables would include and are not limited to:

•              Actual Production Rates and Expected Production Rates

•              Location availability and location readiness

•              Distances between rig availabilities

•              Operation duration and intermediate durations

Once these variables have been within our grasp, we have managed to generate an algorithm that enabled us to formulate schedules with specific key performance indicators (KPI) in mind. These KPIs would state the following:

•              Oil gain per well (then generated randomly based on historic distribution by field)

•              Drilling Duration per well (based on well trajectory type)

•              Expected movement time per Rig contractor

These KPIs were then simulated to create iterations of relative confidence. The results would exemplify the potential outcome of a certain scenario and calculate the overall yield should the company expand this specific scenario. It would also calculate the time, movement-oriented cost, and cost of change of such activities.

Once these results have been processed, optimizing by gain in congruence with other variables (such as location vicinity and material readiness) would yield greater numeric returns in comparison with flat relevance.