The West Delta Deep Marine concession (WDDM) lies offshore in the Deep water of the present day Nile delta. WDDM consists of many Pliocene submarine channel complexes. The Serpent field is one of those slope marine channels and consists of two separate channels namely channel 12 and channel 13. Channel 12 is divided into three compartments by gravitational faults and channel 13 is composed of two compartments separated by stratigraphic barrier. Gas water contact (GWC) in channelized turbidities reservoir might create an intricate reservoir relationship. Gas water contact becomes complicated when the faults and the facies lateral change provide seals. Those hydrocarbon contacts depths become unpredictable without a distinct system to understand the cause of those variable contacts. Water break-through occurred earlier than expected in Serpent production wells as there was no proper modeling for reservoir facies heterogeneity and facies associated petrophysical parameters. A further compartmentalization of channel 12 arose as the sealing capacity of the gravitational faults cast a doubt over channel-12 compartmentalization and the connected gas initial in place (GIIP). The geological foreknowledge of Serpent field, the production issues and the dire need for further development plans in Serpent field were the motives to initiate this study. Integrated study was designed to answer the unsolved challenges of characterizing the reservoir heterogeneity and faults' sealing capacity. 3-D (three dimensional) high quality seismic data and different seismic attributes were integrated with different well data to build a robust 3-D static model. Static model was the way to elaborate the facies accurate distribution and the different petrophysical parameters in Serpent reservoir. In addition, the 3-D static model was used in the prediction of the faults' sealing capacity through the fault rock facies, fault rock petrophysical properties and transmissibility. In a nutshell, the resultant static model answered the field's issues regarding the early water production, facies heterogeneity and Successfully isolate the different reservoir compartments then run into prediction to assess the potential of the existing well-stock and any future development plans in Serpent field.
This paper discuss the major applications of temperature survey that it was applied in gulf of Suez wells in Egypt; the first application is the detection of communication points between tubing and annulus in oil producers through keeping high pressure gas in both tubing and annulus then running the temperature gauge in tubing bleeding off annulus pressure while continuous apply high pressure gas on the wellhead which it is cheap and helpful tool to return the wells to production while it was classified as high risk well by fixing communication points then actions took repair the communication points; the second application is integrity check for through tubing bridge plug leaking by real time monitoring for downhole temperature and pressure while the well is under flowing condition achieving differential pressure and saving rig time; the third application is the determination of fluid movement both inside and behind the production string, hence locating any holes in the casing and ...
The lifecycle of any field consists of three main periods; green, plateau and maturity periods. Currently most of GUPCO fields are brown what made us very concerned to sustain and even increase our production. To achieve that, we have looked at new different options to exploit our resources better. Generally, this can be achieved by whether optimizing current system, applying new technology or evaluating unconventional resources.
One of the high-potential resources that we do have in GUPCO is unconventional resources with many tight carbonate formations. Nevertheless, we did not try to appraise it before since most of our reservoirs are clastics that can be easily characterized and evaluated. On the other hand, tight carbonate formations cannot be characterized or appraised utilizing conventional logging tools or even classical reservoir engineering concepts. It always requires unique techniques relevant to its unique complexity degree especially in presence of micro-porosity and unknown fluid content. This paper sheds light on Appraisal Unconventional Resource Study that resulted in the first successful producer in the company.
GUPCO started to appraise tight carbonate rocks (named Thebes in Lower Eocene) and basaltic intrusion in GoS. This study involved high integration between key disciplines; Petrophysics, Petrology and Reservoir Engineering. To manage uncertainty, we have acquired wide range of data types starting from advanced petrophysical logging tools like Magnetic Resonance, Borehole Imaging and spectroscopy, and full petro-graphic description, reaching to predicting reservoir dynamic performance using measured pressure points (RFT), its analysis and fluid characterization. Ultimately, we have succeeded to completely characterize Thebes formation, and proposing its development plan. The first successful well resulted in 300 BOPD gain as the first successful tight carbonate producer in GUPCO. Development plan is being built to drill new wells targeting unconventional resources including a few possible potential in basalt intrusions, as well.
Dealing with unconventional resources is not an easy task. It requires a lot of work and analysis. Having all of your homework done is not always enough, you have to integrate with interrelated disciplines to link dots and complete the picture. In this paper, we have conceived a new approach in evaluating such formations, and it is a very good example of managing uncertainty by integrating different data to convert hypothesis into reality that can be translated ultimately into oil production and revenues.
The 12 ¼" section in the western desert, Bapetco concision is challenging to be drilled as of the highly interbedded carbonate and shale formations, which are known to exhibit high levels of vibrations (torsional and lateral) associated with high drilling torque. Such high drilling torque lead-to increasing the Mechanical Specific Energy (MSE), reduction in Rate Of Penetration (ROP) and early dull for used bits. While in some cases it can even lead to twist-off incidents and major Non-Productive Time (NPT) events. Customer NPT can cost up to $ 450k in case of sidetracking the well. In case the Bottom Hole Assembly (BHA) stands the vibration level, the parameters would have been controlled losing ROP which resulting in lost time that cost at least $ 35K. The solution of adjusting the depth of cut downhole (Self-Adjusting) which have been newly introduced to the market targeting to decrease downhole vibrations, specially torsional vibrations and allow smoother transition between lithologies with different compressive strength and help in a smooth transition between the different layers while optimizing the depth of cut control When the self-adjusting feature engages with rock for steady state drilling, the feature gradually retracts, controlling DOC to find the optimal exposure of the element for the current drilling parameters and formations. As dynamic instabilities occur, the self-adjusting feature reacts at fast time scales to mitigate the event. This should result in optimizing the bit response to deliver the best performance real time, decreasing the torsional vibration, NPT & MSE. This will lead to increase the drilling efficiency. The 12 ¼" PDC bit with the self-adjusting was tested with one Shell/Bapetco in the western desert wells, resulting in decreasing the vibration levels, decreasing the MSE hence increase the ROP 57% compared to average of the field which resulted in significant reduction to the drilling cost compared to the offset wells while achieving 35K of savings compared to the best offset Below will present how the latest self-adjusting PDC technology had a significant impact on drilling time and cost savings by mitigating drilling dysfunctions that could result in unplanned trips and drilling inefficiencies if not addressed in a timely manner 2 SPE-197905-MS
Khedr, Sherine (BP Exploration Operating Co) | El-dabi, Fady (BP Exploration Operating Co) | Nashaat, Mohamed (BP Exploration Operating Co) | Mohiuldin, Ghulam (BP Exploration Operating Co) | Galal, Alaa (BP Exploration Operating Co) | Slim, Teddy (BP Exploration Operating Co) | Hughes, Andrea (BP Exploration Operating Co) | Morris, Lyndsay (BP Exploration Operating Co) | Ramsay, David (BP Exploration Operating Co) | El-wakeel, Wael (BP Exploration Operating Co) | Mubarak, Hussein (BP Exploration Operating Co) | Smith, Jeffrey (BP Exploration Operating Co) | Munger, Robert (BP Exploration Operating Co)
Giza Fayoum Completions was the second campaign of the West Nile Delta project. The campaign consisted of eight cased-hole gravel pack subsea wells. The Giza Fayoum campaign was sanctioned in August 2017 with an execution start date five months later. In this time, the well designs were finalized, downhole completion equipment manufactured, and the execution plan approved. A high rate water pack sand control technique was designed to deliver an estimated production rate of 120 MMscf/d / well. It was planned to deliver eight wells over a period of 5 months from Q1 2018 giving an average of two and a half weeks per well. Seven of the eight wells were cleaned up through a large bore completion landing string system. Each well was flowed to high rate temporary well test equipment installed on the DP semi-submersible rig to a gas rate of 65 MMscf/d, with PLT logs conducted.
This successful, fast-paced campaign is the result of applying lessons learned from the former campaign; Taurus Libra and identifying additional efficiencies that would improve performance. The design similarities between the two campaigns permitted the team to extend the learning curve and deliver superb performance on Giza Fayoum.
As for safety performance, the campaign was delivered without any lost time incident. A rigorous approach to continuous improvement resulted in reducing the completion time to 12 days per well (not including rig move, de-suspension and suspension activities). The optimized bean up procedures supported by PLT data made it possible to reduce greenhouse emissions by 20%. The sand control technique resulted in a significant reduction of total skins. Moreover, the team succeeded in delivering the wells safely, ahead of plan and under budget while adhering to BP's overarching strategy of delivering safe, compliant and reliable wells.
The efficiencies, safety culture and technology used during this campaign are now being set as the standard for future campaigns in Egypt and beyond.
The SPE Egypt Section has responded to the SPE young professionals' initiative by creating the Egyptian YEPP Section, a spectacular mix of male and female engineers from different specializations in the oil and gas industry. The goal of the YEPP program is to give a hand to young petroleum professionals in Egypt to help develop their careers. To achieve this goal, members are working on establishing a communication network for young professionals. The Egypt YEPP Board has been marketing the YEPP concept during the SPE monthly meetings, through e-mails and brochures, and through a shared booth with SPE at the Intergas Conference and Exhibition. The group is trying to establish YEPP contact officers at all companies and petroleum engineering schools in the region.
The 4th Mediterranean Offshore Conference and Exhibition took place in April in Alexandria, Egypt. The conference attracted high-level technical experts, key industry professionals, specialists, and decision makers in the upstream, downstream, and petrochemical sectors of the petroleum industry. Osama Taha (Pico Oil), Tamer El-Rayes (EDF), and Mohamed Ali (Halliburton-Landmark) from Egypt's YP program attended, helping design and prepare posters for the exhibition and working in the SPE booth, welcoming visitors and explaining the benefits of SPE to both young and senior professionals. Many visitors, especially young professionals, showed interest in SPE and YP Programs. Sameh Fahmy, Egyptian Minister of Petroleum, visited the SPE booth and was very interested to hear more about the YP activities in Egypt and the Middle East region as well as future plans.
SPE provides members many ways of volunteering their time to boost their skills and build relationships in the industry, but this month's featured young professional (YP) is someone who has made this approach his regular attitude. Mohamed Mahmoud Abd El-Rahman is a reservoir engineer at Sahara Oil & Gas Company (SOG). After graduating in 2012 from the Suez Canal University, he joined SOG, becoming the youngest engineer to work on a reservoir simulation study in the company. He was recognized by his director after proposing to drill a successful producing well in a new exploration prospect. Abd El-Rahman completed his master's degree in petroleum engineering at Cairo University and continues at SOG.
Conventional oil and gas discovered resources in 2019 are on pace to rise 30% from last year and reach their highest level since the beginning of the industry downturn. Here, a recap of the first quarter's 15 biggest oil and gas discoveries, which altogether are propelling the increase. The benchmark comes as operator Eni solidifies concession agreements and ramps up exploration and development in the North African country. The Apollonia tight-gas chalk play is located in the Abu Gharadig Basin in the Western Desert of Egypt. This has long been ignored as a gas play in the overburden, while the Jurassic and Cretaceous oil fields deeper in the basin have been explored and developed.
Africa (Sub-Sahara) Shell's new natural gas discoveries in Egypt are estimated in initial quantities at about 500 Bcf with more reserves possible, said Aidan Murphy, chairman and managing director of Shell Egypt. The discoveries, in a concession area of north Alam El-Shawish in the country's western desert, could yield 10% to 15% of the total production of Badr el-Din Petroleum Company, the 50/50 joint venture of Shell and Egyptian General Petroleum Corporation that is expected to manage the operations. Eni reported that the Laarich East-1 oil well in Tunisia has a delivery capacity of approximately 2,000 B/D. Spudded in June, the well discovered hydrocarbons in Silurian and Ordovician sandstones while reaching a final depth of 13,487 ft. The well has now been connected to production. The company continues to drill Tunisian exploration prospects that have been identified on 3D seismic surveys.