Ryder Scott
International Experience
Middle East
Click on a region to view specific projects. Ryder Scott has conducted reservoir-evaluation studies in these areas of the world.
International Projects Evaluated
by
Professional Staff
of
Ryder Scott Company, L.P.
Kuwait
North Kuwait field study
This project involved reviewing five large fields - Abdali, Bahrah, Ratqa,
Raudhatain and Sabiriyan - in north Kuwait. Prepared an independent review
and assessment of the conceptual development plans prepared by the client.
Evaluated projected recoverable reserves, future producing rates, proposed
development activities, operating costs and associated capital costs. Reviewed
estimates of original oil in-place and remaining reserves. Examined various
reserves estimation techniques, including volumetric studies, probabilistic
analysis, material-balance studies and reservoir simulation.
Reserves management system and field studies
Evaluated 24 fields in various worldwide regions for state-owned company in
Kuwait. Also, designed and implemented a system that established company-wide
standardization of methods and tools for managing reserves. The reserves management
system (RMS) provides the client with early warnings of the potential for
significant reserves changes to a field. Furnished an evaluation report citing
the advantages/disadvantages of viable software options and recommending a
software solution. Prepared detailed user documentation in a comprehensive
manual unavailable from the software vendor. Ultimately, the Ryder Scott-designed
RMS combines and integrates processes, software and personnel to enable the
client to efficiently track changes in reserves and enable management to make
decisions on its property portfolio, including acquisitions and divestitures,
exploration and development, reservoir and field management and other upstream
activities.
Oman
West Buka/Hengham field
Evaluated the reserves potential of three wells drilled in the vicinity of
this field. Reviewed available 2D seismic data along with petrophysical analysis
of the well logs to develop deterministic reserves. The fracture carbonates
of the Thamama and Mauddud formations were the main areas of study. In addition,
reviewed the effect of lowering the base porosity cutoff and the contribution
of fracture porosity to total volumetric reserves.
Block 30 field
Estimated the reserves of this carbonate field by using volumetric calculations.
Performed geological evaluations of the faulted, four-way closure and analyzed
2D seismic data and well logs. Estimated future production subject to OPEC
quotas from two productive reservoirs.
Performed an engineering and geological study to determine ultimate recoverable reserves and to project income.
Qatar
Block 8 field
Evaluated the reserves potential of the Najwat Najem structure within the
concession. Reviewed existing well data along with 3D seismic to produce a
volumetric estimate of reserves for the Arab A-D units. In addition, performed
a probabilistic evaluation of reserves potential for the untested Najwat Najem
North structure.
Al-Rayyan field
Evaluated the development plan for the Arab A-C units of the Qatar formation.
Reviewed initial geologic maps, petrophysical analysis and seismic data to
validate the geological model and to aid in the evaluation of volumetric reserves.
Reviewed the client's development plan, including initial well spacing, future
production rates, facilities schedules, capital expenditures and operating
costs, to assess the overall feasibility of the plan.
Saudi Arabia
Abqaiq field
Conducted reservoir simulation studies for development of the Arab-D reservoir
to understand field potential and maximize the production of Arab extra-light
crude. Also, conducted dual-porosity and dual-permeability simulation of the
Hanifa reservoir for horizontal drilling project.
Ghawar field
Modeled the Arab-D reservoir in the 'Ain Dar and Shedgum areas under various
operating scenarios. Studied the effects of production-rate increases on facility
and well requirements and on ultimate recovery. Also determined the effect of
gas-cap blowdown timing on ultimate oil recovery. Revised reservoir description,
assessed water movement, determined permeability distribution, delineated the
tar mat and determined effect of aquifer on tilt of oil-water contact. Also
performed reservoir simulation studies of the South Uthmaniyah and Hawiyah areas
to evaluate reservoir potential and to assess the timing and capacities for
water-handling facilities. Also, performed horizontal-well simulation studies
as well as buildup test analyses, core analyses and other miscellaneous technical
studies. Also, evaluated and delineated reservoir, conducted and supervised
well tests, performed reservoir simulation and recommended development program
for undeveloped zone in the Arab D reservoir.
Safaniya and Berri field
Conducted compositional modeling, using three-parameter Peng-Robinson equation
of state, to characterize reservoir fluid samples. Performed numerical separator
tests to obtain estimates of fluid properties within the separator. Simulation
results were used in design of well test separator facilities.
Countrywide study
Quantified country's solution gas reserves and performed a study of oil reserves.
Estimated daily gas deliverability over a 20-year forecast period to help assess
the potential for extracting and marketing sulfur. Project involved the feasibility
of financing and constructing sulfur-extraction facilities.
Baguel field
Audited available seismic data to verify the shape and extent of this broad,
four-way structural trap. Petrophysical analysis of the three field wells
yielded the pay thickness and rock properties necessary to help build the
model of proved volumetric reserves within the Triassic Argilo-Greseux Inferieur
(TAGI) formation.
El Franig field
The field is an elongated structural high trapped on one side by a sealing
fault. Three wells produce the gas-condensate reserves of the fractured Hamra
and El Atchane formations. Evaluated the initial volumetric reserves discovered
by the three wells. In addition, evaluated the producing nature of this gas-condensate
field to help optimize hydrocarbon recovery.
Tarfa field
Evaluated the available seismic to delineate the structural composition of
this one-well field. Structural review showed that the field is probably two,
separate, four-way, structural closures with either a low structural area
or possible sealing fault between the two closures. Evaluated the volumetric
reserves for the TAGI formation on the south structural high. Projected the
reserves within the undeveloped portion through seismic analysis.
United Arab Emirates
Upper Zakum field
Evaluated the technical bidding process for stakes in the largest
offshore field — the fourth largest oil field in the world at some 500,000
BOPD. Provided technical and management advice in the sale of working interests.
Ensured that the tender evaluation process returned maximum value to the country
while assuring bidders of a fair, transparent bidding process. Technical evaluation
of the assets identified the highest value-added components for the national
oil company. The custom system incorporated procedural recommendations for
the bid evaluation process and a quantitative tool to measure technical merits
of bids. The initial upstream asset sale was expected to be the largest divestiture
by any government to date.
Yemen
Al Nasr field
Conducted a petrophysical evaluation of 14 wells to determine the volumetric
reserves within the Upper Alif sandstone. The reserves were based on a log-calculated
oil-water contact and a seismic structural model. The Lower Alif is productive
below the Upper Alif and reserves were evaluated on two separate four-way
structural closures. Reviewed the feasibility of future water injection and
recommended the establishment of a reservoir maintenance program to improve
overall recovery.
Dhabab field
Evaluated multiple wells within the Alif sandstone to determine the volumetric
reserves. Dhabab is an elongated four-way structural closure that trends northwest-southeast.
Petrophysical review showed a common oil-water contact within the field and
this formed the lowest known hydrocarbon base for the proved volumetric reserves.
In addition, detected bypassed reserves in an undeveloped area of the reservoir
and made recommendations to facilitate recovery.
Halewah field
The Upper Alif reservoir within this field is composed of an oil rim with
an associated gas cap. Volumetric reserves for various wells were estimated
down to a common oil-water contact. No gas reserves or production forecasts
were estimated because of the lack of a gas market in the area.
Atuf Northwest field
This field had three producing oil wells within the Upper Biyad formation.
Original mapping had the No. 1 and No. 2 wells within separate, adjacent fault
blocks. Ryder Scott evaluated the performance of those wells and reworked
the petrophysics to determine that the wells were within a common fault block.
Remapping gave a correct initial volumetric estimate of reserves. An initial
volumetric estimate of reserves for the No. 3 well fault block was also completed.
Kharir field
Based upon geology and well performance, this field is divided into three,
separate production areas. The Upper Biyad sandstone is the major oil producer
with minor additional production coming from the Sarr carbonate. Ryder Scott
evaluated well performance and well-log data to estimate in-place and recoverable
reserves for each area. In areas of unstable or new production, the primary
reserves-estimation technique was volumetric reserves based on geologic mapping.
In areas of stable production, volumetric reserves served as a check and balance
to the performance estimate.
Wadi Taribah field
Evaluated the proved producing reserves of this one-well field that produces
from fractured basement rock. Reserves were based on well performance.
Aser field
Evaluated the proved producing reserves of this one-well oil field that produces
from the Sean sandstone. Reserves were based on well performance.