Journal of Petroleum Research & Studies

The scope of this document is to summarize the field trial of Expro FlowCaT and Geoservices GEM-Valve Wireless Electromagnetic Surface Controlled Sub-surface Safety Valve in Fiume Treste field, in sud of Italyt and provide a final technical evaluation.
In 2007, COMP started a study about existing Surface Controlled Sub-surface Safety Valve, to have a complete knowledge of their status in worldwide wells and to make a statistic analysis of the most common failures.
The control line’s failure is the most critical, since it prevents the installation of a contingency WR-SCSSV, which would be impossible to control.


In these cases, the only available contingency, till now, was the installation of a SSCSV (Sub-Surface Controlled Safety Valve), but it doesn’t guarantee the same level of reliability as the SCSSV’s:
These valves are not controlled from the surface, they are not fail-safe and they are operated by particular events on the well (such as high flow rate or low pressure), which are very uncertain.
To address this issue, COMP made a survey with valves’ suppliers and a solution to, this problem was identified in the new wireless electromagnetic technology.
After a strict “ISO-modified” qualification process and a 6-months field installation in a STOGIT gas
storage well with monthly tests and a final slam test, both the considered Electromagnetic Wireless Surface Controlled Sub-surface Safety Valves: Expro 3.65” FlowCaT & Geoservices 3.72” GEM-VALVE are considered qualified and field proven to be installed in eni wells.

Risk Management (RM) is a well recognised approach to address projects uncertainties, to provide accurate CAPEX estimates and to have proactive responses to unplanned events.
However, RM is often presented as a standard and repetitive process, disregard to projects diverse challenges. This acceptance is a main obstacle to its successful implementation, because this can lead to over complex risk studies for simple matter or, on the contrary, scarce results for intricate issues.
Drilling & Completion projects present a high versatility of situations (from a standard onshore workover to a very challenging deep


offshore exploratory campaign). Project challenges can be very different: technical (HP/HT, new technologies, etc), environmental (sensitive areas, deep offshore conditions, etc), economic (market conditions, etc), or strategic (partnership, etc).
The natural consequence is that each project requires an adequate response in terms of RM. Actually, RM toolbox encompasses a number of different studies, such as risk registers, risk mapping, probabilistic CAPEX/schedule, fault trees, etc.
Not all studies should be systematically performed. Thus, the RM approach must be tailored to each project challenges, in order to bring the highest added value to the decision makers.
eni Drilling, Completion & Production optimization department has built an integrated RM system that provides a properly designed workflow for treating each project with a suitable approach according to its maturity and other technical, environmental, economic or strategic criteria.
This paper takes advantage of an eni experience on a well campaign and describes how RM approach supported strategic decisions on the implementation of technologies (RSS, continuous circulating system, aluminium drill pipe, ceramic protectors and centralisers) to reduce well operations uncertainties. This case study encompasses the complete decision loop, from the cost/benefit analysis of each technology to the measured benefits from the rig operations in terms of performance enhancement.
Finally, it substantiates the values of RM in investment decision by addressing RM in a practical way. This case study will definitely help to spread a RM culture within project management organizations.

The power chimney tower is one of modern promised energy which may be developed by low losses, simple and has high facilities.
In this paper, many parameters were studied exactly which influenced the prediction of system operation and fundamentally depend on the combustion of gases compound the spilled oil. Velocity distribution is the important parameter which gives the first prediction to put the position of erection of power turbine, made or not. The numerical analysis was presented by using GAMBIT and FLUENT 6.3 to predict that high velocity at the expansion of chimney



near the centre of burned gases cover collector. This position is very suitable for promoting and building the power turbine since the velocity was more than (33 m/s) when the compounded gases is combusted (that there components are the methane gas with other friendly gases and waste. It is easy to erect steam or gaseous boiler in contact with furnace for utilize the heat generated in electrical power generation. So, the other factors, temperature and pressure were studied to coincide with previous papers in this field.

This paper discusses many aspects of the application of horizontal wells for field development, starting with the basic question of why to opt to this technology. The different considerations to be taken into account when dealing with the technology are reviewed, including some inherent downsides like higher cost and operational complications. The main emphasis, however, is placed on practical reservoir engineering aspects, including well planning and performance, and the handling of horizontal wells in specific technical applications like well test
analysis and numerical modeling.



The theoretical basis and pertinent differences in physics and flow regimes around vertical and
horizontal wells are discussed in the context, together with the inherent practical implications.
Case histories and examples are presented for several successful applications worldwide that the author was involved in. In one case, a medium size field offshore Canada was developed with waterflood utilizing very few horizontal producers, with a set of horizontal and vertical water injectors. Detailed planning and intensive modeling, carried out by a team of engineers and geoscientists, led to a remarkably
successful field development. In another case, few horizontals were used among many directional wells to develop a Mediterranean oil reservoir under aquifer and gas cap drives in an attempt to reduce coning problems, raising an opportunity to compare the long term performance of different geometry wells.
A brief description is also presented to some advanced techniques and special cases of implementing horizontal wells such as thermal recovery (Steam-Assisted-Gravity-Drainage, or SAGD Process), multi-lateral wells, and multi-fractured wells, with discussion on these applications. Under favorable conditions, horizontal wells can also be used as an Improved Oil Recovery (IOR) tool in mature fields, an application that became very common in many super giant fields in the Arabian Gulf Area.

Single well modeling technique is considered as an important tool in simulation studies that deal with the near well issues (i.e. water coning, optimum perforation intervals, etc.); or it may be used in the determination of the final acceptability of the entire field model (1). In this study, this technique is adopted to study and characterize one of the producing wells in Buzurkan oil field which is BU-3. The probability of the increase of water production will be tested with different production schemes, because if the well has to produce with certain water rate, the surface facilities have to be designed to be suitable for that rate. Water saturation distribution around the well is also inspected through the history of the well to determine the reason behind water production.
CMG simulator has been used to perform this study. The results matching are based on the pressure and the produced water cut history and show good match in both cases.
The model showed that there is a significant increase in water production with increase of oil rate due to water coning.

Hot ash corrosion of high temperature combustion equipment from burning petroleum fuels containing Na, S and V, and recommendations for preventing or controlling fuel oil may result in severe damage to metal surfaces.
The use of MgO as a fuel additive to combact vanndic corrosion is widely accepted practice for boilers operating on residual or low grade fuels. MgO has the ability to form high melting stable vanadate but the presence of Na2SO4 can react with the magnesium and reduce its effectiveness. This paper aims to




quantify the effectiveness of MgO as an inhibitor in the presence of increasing amounts of Na2SO4. Amethod of determining permissible levels of Na2SO4 to satisfy predict remind corrosion rates or additive efficiencies is described. Examples of the loss of additive efficiency with weight of Na2SO4 at temperature of 750 and 850C are given for both 209 T1 and 213 T11 alloys.

Product blending is an important optimization task that is encountered in the operation and scheduling of important industrial plants like petroleum refineries. The key objective of blending is to mix various intermediate products to achieve desired properties and quantities of products with minimum cost. There are uncertain parameters which make it very difficult to attain the optimum allocation of available resources. Consequently, there is a need to develop computational optimization techniques to tackle the blending issues.
In this research the main objective is to propose an approach to solve product blending issue in an optimum

way. The blending problem can be formulated as an optimization where its objective is to maximize net profit while determining the optimal allocation of intermediate streams to produce optimum production mix of final products.
The proposed approach is introduced for integrating short term planning and scheduling for product blending. Two mathematical models have been proposed. The first model deals with planning issue for product blending and the results are regarded as production guidelines. In the second scheduling model, scheduling will treat the production guidelines to verify optimum allocation for available resources. The approach was applied to different real time case studies form Midland Refineries Company, and the results show the efficiency and flexibility of this approach to solve the different case studies. Also minimize lead time from 72 to 24 hr in the second case according to reduction in re-blend process, in addition to minimize production cost depending on optimum allocation for available resources. The last case study which is a complicated one, were WIN QSB version 1.00 software is utilized. The results gained after 0.031 second CPU time for planning level and 3.375 second CPU time for scheduling level. This is considered as an advantage to the model.

The present work deals with fitting literature data of ASTM Distillation curves and obtain a new correlation suitable to use in modeling when optimizing the refining processes, such as distillation, FCC, catalytic reforming, hydrotreating, etc.
The results showed that the values predicted by a new correlation are very good agreement with data of literature and the range of mean overall deviation (%MOD) is (0.305-0.585).

Treating Iraqi asphaltic binder produced from Al – Dura refinery by either oxygenation or 4% sulfur or 4% nitric acid improved the penetration from 241 mm down to 92 mm, and from (68 - 63 ) mm also it and improved the softening point from 39 OC up to 49 OC, 50 OC, 52 OC respectively and it, improved the ductility from 73 cm up to 100 cm, 102 cm, 106 cm respectively.
When subjecting these treated asphaltic binders to Iraqi environmental conditions, the rheological properties will not changed during 14 months. The studied environmental conditions
were included when subjecting the treated asphaltic binder samples to (sunlight, water immersion, 1kg load, both sunlight and 1kg load, both water immersion and 1kg load, both sunlight and water immersion and both sunlight, water immersion and 1kg load). Compared with base asphaltic binder supplied directly from refinery without treatment which failed immediately during one week.

The Khabour Fm. (ordovicain) presents a prospective target for exploration and developiment, as it certains \"Gas Condensate\" light gravity, low sulfur oil, and sweet gas as proven by Akkas field, in the western desert of Iraq .
Gas- condensate project is in depth,hot,low permeability reservoir in the upper K1,K3,K5 sandstone members ,it\'s well known that the deliverability of gas-condensate wells can be improved by the formation of acondensate bank once a bottomhole pressure drope below the dewpoint.
Improving deliverability can be


improved by use the techniques as,Fracturing andchemical treatment.
The Khabour formation total thickness is 1913m,represntaed by elastic series mainly shaly intercalated with sandstone beds in the lower part and by well developed sandstone beds in the upper part, In Akk-1 which is subdivided into eight members according to sand /shale ratio, the need for accurate estimate for reservoir properties of these member extends to the whole life cycle of a reservoir; detailed
simulation and planning of future production which including for discovery , appraisal , planning , development and production from Akkas field.