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Saleh A. Al-Dossary began his work at Saudi Aramco in the Dhahran Geophysical Research Group, contributing to edge-preserving and smoothing developments. He now works in the Exploration Application Services Department developing new seismic processing and attributes algorithms. Al-Dossary received his B.S. degree in Computer Science with a minor in geophysics from the New Mexico Institute of Mining and Technology, Socorro, NM. He received his M.S. degree from Stanford University, Palo Alto, CA, and he received his Ph.D. from the University of Houston, Houston, TX, both in Geophysics. Al-Dossary holds seven patents and is an applicant for five additional patents in seismic edge-preserving and detection technology.
- North America > United States > Texas > Harris County > Houston (0.25)
- North America > United States > New Mexico > Socorro County > Socorro (0.25)
- North America > United States > California > Santa Clara County > Palo Alto (0.25)
- Asia > Middle East > Saudi Arabia > Eastern Province > Dhahran (0.25)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > Saudi Arabia Government (0.62)
- Information Technology > Knowledge Management (0.76)
- Information Technology > Communications > Collaboration (0.76)
Mahmoud E. Hedefa is the recipient of Special Commendation in 2023, which recognizes deserving individuals for meritorious service to the public, scientific community, or profession. Hedefa is recognized for his many years and caliber in teaching and increasing SEG's global impact. He earned a bachelor's degree in geology in 1984. He is currently employed as a senior geophysical consultant at Saudi Aramco, with more than 30 years of diverse experience in onshore and offshore seismic data acquisition and processing. He is known for "hire-to-retire" career development support of geophysicists in the global geophysical community and especially for supporting SEG programs in the Middle East.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > Saudi Arabia Government (0.70)
- Information Technology > Knowledge Management (0.76)
- Information Technology > Communications > Collaboration (0.76)
Andrey Bakulin is a geophysicist at Saudi Aramco's EXPEC Advanced Research Center in Dhahran. He holds a PhD in Geophysics (1996) from St. Petersburg State University of Russia. Andrey had a brief academic career at St. Petersburg State University and the Colorado School of Mines. His industrial career followed and now includes tenures at Schlumberger Cambridge Research, Shell Bellaire Technology Center, and WesternGeco. Andrey was involved in the development of several technologies.
- North America > United States > Gulf of Mexico > Eastern GOM (0.56)
- Europe > United Kingdom > England > Cambridgeshire > Cambridge (0.25)
- Asia > Middle East > Saudi Arabia > Eastern Province > Dhahran (0.24)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > Saudi Arabia Government (0.56)
- Europe > United Kingdom > Atlantic Margin > West of Shetland > Faroe-Shetland Basin > Judd Basin > Block 204/24a > Foinaven Field (0.99)
- Europe > United Kingdom > Atlantic Margin > West of Shetland > Faroe-Shetland Basin > Judd Basin > Block 204/19 > Foinaven Field (0.99)
- Information Technology > Knowledge Management (0.76)
- Information Technology > Communications > Collaboration (0.76)
_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 216673, “CO2 Injectivity Test Proves the Concept of CCUS Field Development,” by Yermek Kaipov, SPE, and Bertrand Theuveny, SLB, and Ajay Maurya, Saudi Aramco, et al. The paper has not been peer reviewed. _ The complete paper presents a unique case study on injectivity tests done in Saudi Arabia to prove the concept of carbon capture, use, and storage (CCUS) capability. It describes the design of surface and downhole testing systems, lessons learned, and recommendations. The injectivity tests were effective in identifying and confirming the best reservoir for CO2 injection and defining the best completion strategy. Creating injection conditions close to CCUS is vital, especially in heterogeneous carbonate reservoirs where the petrophysical correlations for the reservoir model require calibration with dynamic data. Introduction The energy company has conducted an extensive evaluation campaign by drilling appraisal wells through multizone saline aquifer reservoirs on different sites close to potential sources of CO2 at the surface. The evaluation program included coring, openhole logging, formation testing for stress-test and water sampling, and injectivity testing in the cased hole. Apart from reservoir characterization, different completion strategies were evaluated by performing injectivity tests in both vertical and horizontal wells. The lower completion was represented by perforated casing and an open hole. Injectivity Testing Injection tests are a commonly used method in waterflood projects to evaluate the injectivity capacity of the well and reservoir. The test involves an injection period with one or more injection rates, followed by a falloff period (Fig. 1). During the injection period, the liquid is injected at a stable rate to reduce the risk of near-wellbore formation damage caused by fluid incompatibility or exceeding the fracture gradient and inducing formation fracturing. The bottomhole-pressure data acquired during the test is analyzed using the pressure transient analysis method to estimate the permeability thickness, skin factor, and lateral heterogeneities. Additionally, the injection logging profile can be conducted along the sandface to assess completion efficiency and formation heterogeneity. By interpreting the results of the injection test, engineers can optimize the injection rate and improve the performance of the well and reservoir, ultimately leading to more-efficient oil recovery. Injectivity Test: Case Study The injectivity tests were conducted on virgin reservoirs using vertical appraisal wells that were sidetracked horizontally into the reservoirs with the greatest potential for storage. The reservoirs’ depths varied from 4,000 to 8,000 ft, with a normal gradient of reservoir pressure and temperature. The injectivity test design used reservoir properties estimated from the openhole evaluation, such as porosity, permeability, reservoir pressure, temperature, reservoir fluid sample, and fracture gradient. These data were used to set injectivity-test objectives, calculate expected well parameters, select equipment, and plan operations. The primary goal of the tests was to assess reservoir injectivity by injecting water, nitrogen, and CO2 to prove the concept for a CO2-injection project. While water and nitrogen injections are well-known in the industry, the CO2 injectivity test was new and required more attention during the design phase to evaluate all possible risks.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > Saudi Arabia Government (0.55)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
Standing alone as the shortest month of the year, February also features JPT’s Well Testing Technology Focus, reviewing the latest industry publications on the subject. Well testing has enjoyed a recent uptick in activity and interest as operators continually realize the value in understanding and monitoring the dynamic performance of their reservoirs. Whether it pertains to the deliverability of conventional oil and gas or the storage potential for carbon capture and storage, large-scale dynamic data remains one of the more coveted pieces to the subsurface puzzle. There is no silver bullet for reservoir characterization. Instead, proper characterization will always be the result of integrating static and dynamic data, collected at varying scales, with a macro geological understanding. Technology facilitates the collection of the aforementioned data. With the latest technologies pushing limits of what can be achieved, subsurface engineers must rigorously evaluate what reservoir characterization techniques and tools are suited for project objectives. Formation testing (FT) platforms provide many options for operators to get a first look at dynamic reservoir performance and nearly always precede a well test. After digesting the alphabet soup of acronyms, so many FT options exist that one may encounter what psychologists refer to as “choice overload.” FT objectives also may begin to overlap with objectives traditionally reserved for drillstem tests (DSTs), narrowing a long-standing technology gap. The current advances in FT tools are exciting, and using FT tools to perform a “mini-DST” makes for brilliant marketing. However, “mini” could mean up to 10,000 times less produced volume, which undoubtedly affects objectives thought to overlap. Subsurface complexity is mitigated by defining clear objectives and executing data-collection programs to reduce uncertainty. Caution should be taken in selecting how to dynamically test your reservoirs. Regardless of how advanced hardware becomes, achievable objectives always will be dependent on key factors such as rock and fluid properties, reservoir geometry, and local regulatory and environmental considerations. This month’s papers highlight ongoing developments from different segments of the well-testing discipline. Dive into valuable lessons learned from a frontier carbon capture, use, and storage project, backed by an impressively sized data set and an in‑depth review of multiphase effects. This case study covers differing saturations around the wellbore region and fluid types in operations and should have global applications. Learn about the limitations and potential pitfalls of nonisothermal effects in pressure transient analysis, which pose challenges in the reservoir characterization of geothermal wells. Sensitivities to thermal effects on reservoir rock properties provide intriguing insights. Completion efficiency also may be affected by thermal effects, resulting in additional pressure drop at sandface. Finally, catch up on one of the weapons most recently added to the well-testing arsenal with powerful new FT tools that feature industry improvements for greater flexibility and improved data reliability. Recommended additional reading at OnePetro: www.onepetro.org. OTC 32610 Multiphase Flowmeter Comparison in a Complex Field by Mohammed Alqahtani, Saudi Aramco, et al. IPTC 23050 Frequently Asked Questions in the Interval Pressure Transient Test and What Is Next With Deep Transient Test by Saifon Daungkaew, SLB, et al.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > Saudi Arabia Government (0.56)
This workshop focused on the role of geophysical technologies in exploring and developing shale gas and tight sand reservoirs. Many operating companies have been intrigued by the success demonstrated in North America of unconventional resources, mainly shale gas. However, there are many outstanding technical challenges facing geoscientists in the Middle East & North Africa regions when searching for unconventional resources with significant economic value.
- Asia > Middle East > Saudi Arabia (0.87)
- Asia > Middle East > UAE > Dubai Emirate > Dubai (0.17)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > Saudi Arabia Government (0.40)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (0.83)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)
Shivaji N. Dasgupta has more than 30 years of experience in the petroleum industry. He is currently the project leader in Saudi Aramco E&P Advanced Research Center for reservoir monitoring. He has held various technical positions in USA with AMOCO Production (now BP), Mitchell Energy, and CONOCO. Shiv has published and presented over 60 papers, he has recently been awarded a U.S. Patent. He received his B.S. degree in Engineering Geophysics from Indian School of Mines, M.S. from St. Louis University and Washington University, and MBA from So. Illinois University.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > Saudi Arabia Government (0.92)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Lower Fadhili Formation (0.99)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Khuff D Formation (0.99)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Khuff C Formation (0.99)
- (4 more...)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Management (1.00)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)
This forum brought together experts from the oil/gas industry and academic organizations to discuss the processing of multiples in seismic data. Despite recent advancements, both in the prediction of multiples as noise and in their imaging as signal, the processing of multiples in seismic data remains a major challenge for the industry. The main goals for this workshop were to gain understanding of new concepts, to assess their effectiveness against the challenges faced in industrial applications, and to chart ways for their future developments. The workshop focused on emerging technologies, particularly those relevant to Middle Eastern hydrocarbon oilfields, and covered a broad range of the topics, as listed below, calling for research as well as case study papers, with data examples from marine as well as onshore surveys. This workshop followed on some of the themes discussed at the joint SEG/EAGE forum in the fall of 2013, "Turning noise into geologic information: The next big step?"
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > Saudi Arabia Government (0.30)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)
Ralph Bridle received a B.Sc. in mining and ACSM (1979) from Camborne School of Mines,Cornwall, UK. His first experience was as a student and guest at Kamativi Tin Mines, Rhodesia (1978), and he returned to work at Shamva gold mine, Rhodesia, as a graduate mining engineer (1979–1980). He is a geophysical consultant with Saudi Aramco in the near-surface modeling unit of the geophysical data processing division in Dhahran, Saudi Arabia, where he has been a resident since 1991. He is passionate in teaching the young professionals on whom the industries' future will depend. His interests include refraction statics, tomography, and geostatistics, of which he has authoredand coauthored papers in GEOPHYSICS, Geophysical Prospecting, Near-Surface Geophysics, and presented at conferences.
- Europe > United Kingdom > England > Cornwall (0.36)
- Asia > Middle East > Saudi Arabia > Eastern Province > Dhahran (0.30)
- Geophysics > Seismic Surveying > Seismic Processing (0.51)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.36)
- Materials > Metals & Mining (0.96)
- Government > Regional Government > Asia Government > Middle East Government > Saudi Arabia Government (0.59)
- Energy > Oil & Gas > Upstream (0.53)
- Oceania > Australia > South Australia > Cooper Basin (0.99)
- Oceania > Australia > Queensland > Cooper Basin (0.99)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)
Peter I. Pecholcs received his Master of Science degree in applied geophysics from Columbia University in 1982. Peter worked on his graduate studies at both Columbia University in 1983 and University of Hawaii from 1988-1991. Peter worked as a research geophysicist for SOHIO Petroleum (1983-1988) and as chief hydrologist for the USGS on the island of Tinian before joining Saudi Aramco as a research geophysicist in 1992. In 2001, Peter joined the Geophysical Data Acquisition Division where he pushed acquisition technology to new limits. In 2013, Peter joined CGG as the director of Land Broadband Solutions. His expertise includes near-surface model construction, statics, depthing, signal processing, noise attenuation, and seismic acquisition.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > Saudi Arabia Government (0.56)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)