Analyzed discovery well data in conducting a third-party evaluation of gross total petroleum initially in place (PIIP) on a P90-to-P10 basis. Used reasonable porosity and water saturation cutoffs on the net pay interval calculations. Company used report for filing on the AIM stock exchange.
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.
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.
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.
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.
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.
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.
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.
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.
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.
Estimated 3P oil and gas reserves and resources of the Tigris and Khurbet new drill wells in Block 26.
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.
Evaluated technical bidding process for stakes in a large, high-pressure, extremely sour gas reservoir. Provided technical and management advice in the sale of working interests.
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.
Al Roidhat field
Evaluated the volumetrics by building a static geological model on the Qishn sandstone S1, S2, and S3 sub-unit reservoirs and estimated the developed and undeveloped reserves using dynamic reservoir simulation on this heavy oil field. Well tests were also part of the dynamic simulation history-matching process. Studied several reserves forecast scenarios to optimize the oil field recovery and field economics.
Evaluated the proved producing reserves of this one-well oil field that produces from the Sean sandstone. Reserves were based on well performance.
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.
Volumetrically mapped the Shuqra carbonate reservoir and estimated reserves based on the available well tests.
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.
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.
Determined the field volumetrics by using a static geological model. Water saturations were distributed using J-functions for the Saar reservoir. Evaluated well tests and the development plan, including facilities schedules, capital expenditures and operating costs that were used in the determination of reserves.
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.