Sr Reservoir Engineer
Rumaila Operating Organization
مجموع سنوات الخبرة :34 years, 7 أشهر
• Assess optimal reservoir management, development and surveillance strategies for the Rumaila Main Pay and Mishrif reservoirs (86 BBO OOIP). Oversee technical reservoir management of two substantial pilot projects in the Zubair formation, 1) Produced Water Reinjection (PWRI) project and 2) the Upper Shale Water Injection Project (USWIP). Mentored 6 young Iraqi professionals in fundamentals of reservoir engineering.
Rumaila Operating Organization, Basra, Iraq
• Assess optimal reservoir management, development and surveillance strategies for the Rumaila Main Pay and
Mishrif reservoirs (86 BBO OOIP). Oversee technical reservoir management of two substantial pilot projects in
the Zubair formation, 1) Produced Water Reinjection (PWRI) project and 2) the Upper Shale Water Injection
Project (USWIP). Mentored 6 young Iraqi professionals in fundamentals of reservoir engineering.
• Assess optimal reservoir management, development and surveillance strategies for the Rumaila field (86 BBO OOIP) in order to increase field production from the current 1.4 mmbopd to 2.4 mmbopd by 2017.
• Work with ROO Operations, Developments and BP-Sunbury in starting full-field water injection in the giant Mishrif carbonate reservoir (40 bbo OOIP).
• Mentored and promoted development of promising Iraqi & Chinese (CNPC) reservoir engineering staff in the subjects of material balance, nodal analysis, surveillance, metering, allocation and waterflood expertise. Assessed gaps in skills and experience. Recommended appropriate training, exposure to and development of skills in relevant software, next assignments in their development as technical experts. Built relationships with Iraqi and Chinese management and promoted plans for development of talented staff.
Reservoir Engineering, Buenos Aires, Argentina
• Actively led 14 reservoir engineers (Argentine nationals, Columbian, Venezuelan & US expats, both men and
women) to evaluate and recommend development of 3 “GasPlus” reservoirs in the Neuquen basin,
aggressively ramping-up production in 2010 to meet a 50 mmcfd contract starting January 1, 2011. Argentina’s
Secretary of Energy approved higher gas prices for these reservoirs due to challenged development
economics and a need for domestic production. The fields are technically difficult, low-permeability, fractured
volcanics which require multiple hydraulic fracture stimulations to achieve adequate initial rate. Had to increase
drill rigs from two in January to five by year-end 2010 to achieve goal and avoid deliver-or-pay issues.
• Led a multi-disciplinary team to apply state-of-the-art, brute-force uncertainty simulation to identify an optimal
development plan for the La Sara waterflood in Tierra del Fuego.
• Led 2 engineers in conceptual development planning & risked valuation of numerous conventional oil & gas
exploration targets.
• Participated in Neuquen basin unconventional gas regional assessment, screening and prospect identification.
• Responsible to manage $250+ million in 2010 capital spending and $335+ million in 2011.
• Responsible to track the performance of Apache Argentina’s 2010 capital investment. Apache will achieve its
highest return on investment in 2010 delivering superior value to our shareholders despite the challenges of
state control of oil & gas prices and higher costs driven by strong unions.
• Architect of a 5-year plan to double Apache Argentina’s net production by 2016.
Responsible for engineering support of Brazil and China deepwater exploration efforts. Coordinated a multi-
disciplinary process to consistently assess the risk and value of Brazil and China deepwater prospects for
inclusion in an exploration portfolio.
• Established a consistent methodology for determining Brazil deepwater minimum commercial field size. Built
analogue databases of fields similar to Brazil’s deepwater Pre-Salt and Post-Salt regions as well as China’s
deepwater South China Sea.
• Evaluated the merits of acquiring a fully probabilistic software package (Geox) to improve exploration and
development decision-making.
• Evaluated the long-term economic benefits of various artificial lift alternatives for Brazil deepwater
developments so that an optimal type can be chosen.
• Responsible for development planning of the giant Yem-Yegavskoye field in Western Siberia (6 billion barrels oil-in-place). I led a Russian-American, multi-disciplinary team of engineers, geoscientists and contractors. Our initial objective was to build representative geological and dynamic simulation models of the subsurface so that we could recommend an optimal development plan for this large waterflood of 1, 100 wells. Using Petrel, Eclipse 100 and MEPO, several history-matches were achieved in segment models containing 200-300 wells each with approximately 25 years of production history. Streamline models (FrontSim) were built for each history-matched model which predicted a range of additional oil recovery (up to 25%) could be achieved if water injection was simply redistributed to more "oil efficient" injection wells. This recommendation would result in decreasing water injection to ineffective injectors which were just cycling the water to offset producers and would increase water injection to injectors which were more effective at sweeping oil to offset producers. Simulation also predicted a significant decrease in water production.
• Coached and mentored Russian engineers and geoscientists to integrate their work such that all available static and dynamic data was honored as models were constructed of a western Siberian oilfield. In addition, holistic and integrated “team” interpretations were emphasized and solicited within the confines and constraints of each technical discipline.
• Co-led a leadership development program of young Russian talent where English was used exclusively as we studied and discussed General Patton’s leadership traits as it related to the business world. Participants were coached on how to ask open-ended questions, how to make effective oral presentations, how to influence, persuade and lead others effectively, etc.
• Identified a north-south directional permeability trend in the Yem-Yegavskoye field which was cycling water needlessly between injectors and producers. Waterflood patterns which had injectors aligned with producers in the north direction recovered significantly less oil than patterns which had injectors oriented with producers in the east-west direction. A review of well logs and the geological depositional system revealed a fluvial-marine setting with high permeability sand bar deposits running parallel to the shore in a north-south direction. Producers which were found in this sand bar paired with a water injector were quick to break through. A recommendation was made to re-orient the waterflood pattern to a north-south line drive pattern in a small pilot area to test the concept.
• Led a multi-national, multi-disciplinary team of 14 engineers and geoscientists in the development of Kuwait’s two oilfields (Abdali and Ratqa) which share the border with Iraq. The team handles a high level of rig activity dealing with 2 drilling rigs and 2 workover rigs. All wells are lifted with Electric Submersible Pumps (ESP). Coordinated all ESP design and installation as well as all workovers, recompletions, stimulations, wireline and coiled tubing activities with Drilling and Completions staff.
• Successfully integrated and led a multi-disciplinary team of about 30-40 people from four Kuwait national companies (KPC, KOC, KNPC, KISR) in planning a very large, heavy-oil development of the giant Ratqa Lower Fars reservoir (12 bbo OOIP). A significant effort was made to build relationships among individuals of the different companies to share data and insights with the entire team for the benefit of all. Participants of each company were influenced to collaborate and cooperate with each other in non-competitive ways teaching them to ask the right questions of their teammates and to understand how their piece of the project might affect the work of other team members. Together, the team agreed to a unified stage gate project plan where all companies and team members advanced from stage to stage together in unison. The initial stage of the project was recommended in December, 2005 for $110 mm consisting of subsurface and surface studies, drilling 10 data wells, running 3D seismic, and installing facilities to operate a cold heavy oil primary production pilot.
• Introduced performance management processes to KOC’s New Fields Team to improve business performance in the following areas: production, ESP runlife, well downtime, shut-in oil potential, workover results, new well results, and reserve progression.
As a reservoir engineer within a multi-disciplinary, multi-cultural team, I recommended developing the
Wollaston and Whittle gas discoveries (43 BCF reserves, 95 MMSCFD) with 2 new subsea wells. Predicted a
range of possible outcomes and reservoir performance with the VIP simulation package.
• Represented BP as the Whittle Hub subsurface team leader for the Juno Project, a joint venture to develop
five offshore gas fields with ownership shared between BP, British Gas and Amerada-Hess.
• Resurrected the Amethyst full-field reservoir simulation model, updated it’s history match and used it to identify
sealing faults so that compartmentation risk in the offset Eros development could be minimized.
GUPCO Exploration, Cairo, Egypt
• Evaluated Aqua Marine East exploration prospect, 35 MMBO reserves and 25, 000 BOPD initial rate. The
success of this stratigraphic play will also open-up other similar plays in the GOS.
• Built a value-based GOS exploration portfolio based on anticipated reserves, rates, risks, drilling costs,
facilities costs, and economics by concession. Helped BP-Amoco to understand the value of continued
exploration in the GOS and was key in procuring $23 MM funding for exploration in year 2000.
• Simulated the GS365 Matulla reservoir with a GCOMP reservoir model for additional development potential.
Will add 3.7 MMBO reserves and 3, 000 BOPD initial rate.
• Provided engineering, risk, decision tree, and economic input to the Titan Nubia exploration prospect. A
discovery in the Nezzazat was made which added 5 MMBO reserves and 6, 200 BOPD initial rate.
• Evaluated the October J Nukhul exploration prospect. Target was reached by drilling about 2, 000 feet deeper
for minimal incremental cost. A small oil discovery was made in the Hawara formation.
- GUPCO - North GOS, Cairo, Egypt
• Exploitation reservoir engineer in the October Asset Team, a multi-cultural, multi-disciplinary team of
engineers, geologists, geophysicists, petrophysicists, drilling engineers and facility engineers responsible for
development of GUPCO’s October field. After adding over $400 MM of present value to shareholders in 1996-
1997 through significantly improved work processes, co-location of team members, a centralized PC
engineering database and world-class technological leadership, the team represented GUPCO at the 1998
Progress Share Fair in Orlando, Florida.
• Recmd the October “K” 14-slot development platform (40 MMBO and 33, 000 BOPD).
• Recommended drilling five “hook” directional wells to capture 22 MMBO attic oil in October field.
• Helped evaluate Ras Bakr and Sinai gas-lift gas compression projects for October field(23, 000 BOPD).
• Recmd development of October Nezzazat field with 8 new wells and recompleting 8 wells (50 MMBO).
• Recommended the October D9 Asl well for an IP of 5, 800 BOPD and reserves of 5 MMBO.
• Recommended a waterflood pilot in the October Nezzazat field(44 MMBO reserves, 10, 000 BOPD).
• Recommended waterflooding the October M2 Nubia(3 MMBO reserves & 3, 500 BOPD).
• Recmd drilling the H11 Nubia water injection well to improve performance(7, 000 BOPD, 13 MMBO).
• Recommended widespread use of multiphase flowmeters at each October platform to improve well-test data
quality and test frequency without deferring production.
• Recmd expansion of Nezzazat waterflood with drilling of the A12A well(4, 000 BOPD and 3.8 MMBO).
• Assisted geo-scientists in evaluating the East Tanka exploratory concession and impact on facilities in October
field. The field initially produced 28, 000 BOPD from a small, 3-legged platform.
• Maintained full-field integrated asset model to simulate effect of surface facilities, pipelines, risers on 12
October offshore platforms with 80 wells. Used nodal analysis to optimize gas-lift allocation and performance.
• Evaluated the “D” Nukhul conglomerate field for waterflooding(20 MMBO potential) with GCOMP reservoir
simulator. Recmd ultra-cheap, isolated waterflood facility to minimize financial exposure.
Recommended the October TransGulf compression platform (36 MMBO) & Press Maint Project (40+ MMBO).
Supervised 7 production engineers and 2 technologists in overthrust district office.
Recmd 3 waterflood expansions, infill and extension drilling (11 MMBO reserves and 2, 700 BOPD).
Full-field CO2 simulation of Wasson ODC Unit in West Texas with 16 reservoir models (150 MMBO).
• Group section-leader - 7 reservoir engineers-secondary and EOR.
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