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Collaborating Authors
Abu Dhabi International Conference and Exhibition
Breakthrough Horizontal Drilling Performance in Pre-Khuff Strata with Steerable Turbines
Simpson, Michael (Saudi Aramco) | Zhou, Shaohua (Saudi Aramco) | Treece, Mark (Saudi Aramco) | Rondon, Carlos (Saudi Aramco) | Emmons, Thomas (Saudi Aramco) | Martin, Craig (Sii-Neyrfor) | Tahir, Mohammed (Diamant Drilling Services)
Abstract Since 1997 Saudi Aramco has attempted drilling its hard and ultra-abrasive Pre-Khuff formations typically encountered from 13,000 to 17,000 ft TVD in and about the Ghawar field of Saudi Arabia, with impregnated diamond bits run on high speed turbines, more commonly referred to as "turbodrills". The turbodrill/impregnated diamond bit drilling assemblies were envisaged as a viable alternative to using impregnated, PDC, TSP and TCI bits on PDM's and rotary drives. The PDC bits lacked the wear resistance required to drill the hard and abrasive sections of the Pre-Khuff economically due to limited bit life and the TCI bits harbored a bleak history of excessive gauge wear and cone loss. Three turbodrill/impregnated diamond bit runs were made in Pre-Khuff vertical wells from 1997 to 1998 all resulting in stuck pipe due to "bit sticking", where initially only the bit was stuck, as there was free rotation of the drillstring and turbodrill from the surface. Differential sticking and/or pack-off may have subsequently contributed to the pipe ultimately not being freed in each case. After considerable review, redesign of the 8โ3/8" impregnated diamond bits, shortening of the turbodrill body and BHA with the use of a box-up connection impregnated diamond bit, a respectable run of 242 ft averaging 10.3 fph was made in HWYH-961, a vertical Pre-Khuff well across the 'Unayzah and Jauf formations with cost of $443/ft. With this success and enhanced understanding of the results of a recent consultant firm's geomechanical analysis of the area that indicated the maximum horizontal stress axis was East-West, Saudi Aramco felt they had a good chance of successfully utilizing turbodrill/impregnated diamond bit drilling in the Pre-Khuff without getting the bit stuck if the well was drilled parallel to the field's maximum horizontal stress axis. Finally, in 2003 the opportunity arose to test the wellbore stability hypothesis utilizing a turbodrill/impregnated diamond bit drilling assembly in well WDHY-1, a 'Unayzah horizontal sidetrack. Two consecutive footage record breaking 5โ7/8" impregnated diamond bit runs of 737 and 852 ft were made on 4โ3/4" steerable turbodrills in the horizontal section of the 'Unayzah-B siltstone and sandstone. In 2004, four additional 4โ3/4" steerable turbodrill/impregnated diamond bit runs were made in the 'Unayzah-A and 'Unayzah-B formations with mixed results. Three were made in HRDH-658 across an ultra hard streak at 89ยฐ in the 'Unayzah-B, drilling with over 1500 psi overbalance to the formation with poor results contrasted by a record breaking ROP run of 7.2 fph over 360 ft on the horizontal sidetrack well TINT-3 across the 'Unayzah-A. This paper chronicles the development and refinement of turbodrilling practices and techniques across Pre-Khuff Strata in and around the Ghawar field of Saudi Arabia. It highlights the underlying rock mechanics principles, which allow successful application of high speed turbodrilling with impregnated diamond bits to horizontal wellbores but not in the vertical wellbores in the same field, or more specifically in the case of TINT-3, a sidetrack of the same well. Explanations are offered concerning the apparent enhanced bit, motor and turbodrill performance observed with the use of 90 pcf sodium/potassium formate brine across the target reservoir. Introduction Saudi Arabia is best known as the world's largest oil producer averaging 8.1 million barrels per day and for having the world's largest oil reserves (259.4 billion barrels as of 2003 year end). The Kingdom also holds the world's fourth largest natural gas reserves of 234.5 trillion standard cubic feet and produces 6.9 billion standard cubic feet per day of non-associated gas.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.67)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > Saudi Arabia Government (0.97)
- Asia > Middle East > Saudi Arabia > Riyadh Province > Wudayhi Field (0.99)
- Asia > Middle East > Saudi Arabia > Riyadh Province > Arabian Basin > Widyan Basin > Ghazal Field (0.99)
- Asia > Middle East > Saudi Arabia > Eastern Province > Wudayhi Field (0.99)
- (8 more...)
Abstract This paper presents a case study where a full interaction between static reservoir modelling and flow simulation was performed to optimize the development plan of a carbonate Field in Abu Dhabi. Since no reliable seismic attributes could be extracted from the 3D seismic, coupled with the fact the reservoir had only a few wells, several geological scenarios were modeled using both deterministic and stochastic techniques. Sensitivities were performed on variogram ranges, deterministic trends and algorithms. The population of the model with petrophysical properties was carried out using reconciled log and core data in the crestal area of the Field and propagated downflank with the assistance of trends. The simulation of the porosity was done with Sequential Gaussian Simulation and for the permeability a co-simulation with porosity technique was applied. The results of 1D permeability simulation were also tried. Both approaches for permeability modelling were matched with the well test results. Due to the absence of SCAL data and the fact that the open-hole log saturations are not reliable (low resistivity pay in some intervals), an analog Sw curve had to be used. Two extreme Sw curves (min and max) were considered to cover the uncertainty. Different reservoir descriptions (geological/petrophysical scenarios) were subsequently flow simulated and the results evaluated against different development options. The selected models matched water cuts and reservoir pressures without the need for permeability multipliers. Finally, the results on new drilled wells (blind tests), namely log properties, PBU and injectivity test results, showed a good agreement with the models. The selected models were used to compare different patterns of development under multiple pressure support schemes (peripherical and updip water injection, gas vs. water injection, etc.). This paper calls for the importance of building different static models using different geostatistical parameters to address the static-dynamic uncertainties, instead of performing a large number of stochastic realizations. Introduction One of the key issues in reservoir modeling is the fully integration of reservoir characterization and flow simulation. A comprehensive integrated reservoir characterization was conducted in a Middle East Field by considering all available data, namely well logs and cores, geological interpretation, and dynamic data. Reservoir properties, porosity and permeability were generated using geostatistical techniques. The description was based on core and log data. Due to the thickness of the reservoir and seismic quality was not possible to use seismic attributes to constraint the porosity distribution. Permeability was derived from porosity using different approaches, co-simulation and linear functions. It was observed that the well test permeability values do not match the thickness-weighted core-permeability averages. This is partly due to the differences in the measurement scales of core samples, which cover a few inches, and well tests, which investigate several hundred feet around the well bore, also the few core and sampling bias will affect the representativeness of the core-permeability. The cores did not reveal the presence of fractures and/or high permeability channels. Water saturation was estimated using analogue SCAL data from another field since the OH logs revealed a low resistivity pay reservoir due to the presence of microporosity. Again, the interaction between static and dynamic was essential to optimize fluid levels and derive saturation profiles for initialization. Probabilistic volumetrics analysis allowed to address the uncertainty related with the oil saturation and fluid levels.
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.98)
- Geology > Geological Subdiscipline (0.66)
Abstract Monitoring fluid motions in a producing reservoir is a key to understand reservoir behavior and anticipate drilling decisions and investments. In a deep-water environment such as Girassol (Angolan deep water, West Africa), the cost of a 4D seismic is less than the cost of a well, and 4D seismic is expected to provide the necessary monitoring information in terms of saturation and movement of fluids. Meanwhile, before deciding to repeat a 3D acquisition, the main question to answer through a feasibility study is: will the dynamic changes occurring in the reservoir be visible on seismic data? To achieve the 4D feasibility study, a reservoir model representing the state of the reservoir before production/injection, and another reservoir model after a certain time of production/injection were built. 3D Pre-stack synthetic seismic responses of the models were then computed in time and in depth using a fast algorithm accounting for fine-scale details of the reservoir model. Average amplitude maps extracted at key horizons, from the difference between 3D synthetic seismic responses of the two reservoir models showed the anticipated lateral extent of injection and production, and the impact in terms of amplitudes of the different injection and production mechanisms. These results of the 4D feasibility made us confident in the fact that the forecasted 3D seismic acquisition would provide important information about the reservoir dynamic characteristics. Since this work has been conducted, the new 3D seismic data that have been acquired. The identification and understanding of the differences between real and synthetic data helped us qualitatively and quantitatively to update the reservoir model and the petro-elastic model. Introduction The 4D seismic technology is used to update reservoir models and contributes to the field development plan: infill drillings, detection of undrained compartments, Stronen et al., gas or water injection monitoring, faults retention capacity assessment, Sonneland et al.. The update of reservoir models using 4D seismic data is not direct, and the link between pressure and saturation changes and amplitudes, can be performed through seismic modeling using various reservoir simulation grids at different stages of production, Figure 1. However, creating pre-stack seismic cubes from 3D reservoir grids including millions of cells is not an easy task, Yuh et al., Lumley et al.. 4D feasibilities are often done in 1D or 2D, with pressure and saturations values coming from PVT laws. This precludes the visualization of 3D seismic effects due to reservoir changes such as injected gas and water lateral extension or depleted areas. In this paper, a 3D pre-stack seismic modeling strategy well suited for 4D techniques is presented. Fast and efficient, it computes the seismic response according to reservoir simulation results. This allows to calibrate the 4D seismic data interpretation, analyzing the impacts on amplitudes, time shifts and spatial organizations of the pressure and saturation changes in a real 3D framework. The methodology consists of 5 steps: reservoir flow modeling, preparation of reservoir grids for seismic modeling, conversion of reservoir parameters to elastic parameters using a petroelastic model, seismic modeling, and interpretation of the results. Methodology Preparation of Reservoir Grids and Fluid Substitutions Reservoir simulation grids contain dead cells where there is no flow and no information on petrophysical parameters (saturations, porosity, for example). Before seismic modeling, dead cells must be filled with values for petrophysical parameters, in order to have realistic impedance contrasts during the seismic modeling step. Besides, dynamic parameters used in flow simulators (such as net to gross) have to be transformed in parameters used in petroelastical models such as Vclay. To populate reservoir grids, petrophysical parameters are upscaled: reservoir geologists often use cut-offs on logs and compute means of petrophysical properties from these logs for each facies. For seismic modeling purpose, realistic porosity and Vclay means must be recomputed for each facies group without cut-offs. Finally, a petroelastical model depending on porosity, Vclay, saturations and pressure is used to compute the elastic parameters (bulk density, P-wave velocity, S-wave velocity) in each cell of the reservoir model. This petroelastic model follows the Gassmann's theory, Castagna et al. for saturation effects. In absence of global theory to model the pressure effects, laboratory measurements are used.
- Geophysics > Time-Lapse Surveying > Time-Lapse Seismic Surveying (1.00)
- Geophysics > Seismic Surveying > Seismic Processing > Seismic Migration (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling (1.00)
Abstract This paper highlights the Gulf Petrochemical Industries Company (GPIC's)approach in proactively managing workplace health and safety. The paperdescribes the methodologies by which a company was transformed from a standardperformer in the field of health and safety to one which safety is a businessculture that is not only considered as a modal of excellence but also a truesuccess story in the field of establishing and instilling workplace safetyprominence. GPIC's workplace safety management system is well appreciated byprofessional international safety and occupational health organizationsincluding the Royal Society for the Prevention of Accidents (RoSPA) of GreatBritain and the National Safety Council (NSC) of the United States as well asregional recognition. GPIC's workplace safety management system received eightRoSPA Gold and Gold Medal Awards starting from 1991. In 2001, RoSPA awardedGPIC the International Sector Award in recognition for its outstandingestablishment and continual improvement of its workplace safety managementsystem. In 2003, RoSPA awarded GPIC the ultimate prize of the Chemical SectorAward to endorse it as a leading international company that maintains andimplements a safety management system that is of merit status. GPIC's workplace health and safety management system is not only recognizedby RoSPA, but NSC of the United States has awarded it the council's Award ofMerit for continually achieving lost-time accident free work hours that exceedsmillions of person-hours. The GPIC's workplace safety system is also regionallyrecognized and appreciated through the achievement of the Kingdom of BahrainHis Highness the Prime Minister's Major Industries Excellence Award in 2002.Also in 2002, GPIC received H.H. Shaikh Mohammed Bin Rashid Al MaktoumCertificate of Excellence Award for Arab Management for the outstanding ArabEstablishment category. The paper sheds light on the numerous management systems, approaches andresources that enables GPIC to accomplish renowned success in the area ofworkplace safety. The paper also, demonstrate that workplace safety must beincorporated as a strategic business endeavor for it to establish and maintainsthe inertia and thrust necessary for its continual success. Furthermore, thepaper explains that workplace safety is part and parcel of a total businessculture that should be integrated and augmented into a one team spirit. Introduction Gulf Petrochemical Industries Company (GPIC) was established on the 5thDecember, 1979 and is jointly owned by the Government of the Kingdom ofBahrain, Petrochemical Industries Company of Kuwait and Saudi Basic IndustriesCorporation (SABIC) by equal shareholdings. The Company is considered asuccessful model example of regional cooperation and integration particularlyin the field of petrochemicals and industrial complementation. GPIC's first project was the construction of a petrochemical Company inSitra on the north eastern coast of the Kingdom of Bahrain. An area of 600,000square meters of sea was reclaimed for construction of the Ammonia and Methanolunits with a daily output of 1,000 metric tones in addition to the power andutilities units. In 1989 the Ammonia and Methanol plants daily productioncapacity was raised to 1,200 metric tones. On 3rd March 1998, a Urea granularplant was inaugurated with a daily output of 1,700 metric tones under thepatronage of His Highness Shaikh Khalifa Bin Salman Al Khalifa, PrimeMinister. Over nineteen years of extremely successful and continuous operation, theAmmonia and Methanol production achieved record levels of continuous operationtotaling 700 days. This is strong evidence of the efficiency of the Company'sPlants Operation Staff and their high skills and experience. GPIC was selectedas the best operating operation in the Arabian Gulf region in 1996 due to itshigh levels of production, safety, environmental standard and qualityassurance.
- North America > United States (1.00)
- Asia > Middle East > Bahrain (0.25)
- Asia > Middle East > Kuwait (0.24)
Abstract Deflecting Conductor Sleeve (DCS) is a slot recovery tool that proved a valuable system for the economical salvaging of the previously used slots of the offshore platforms in the late development stage. It is used when there is a need to drill infill wells while most of the platforms' slots are already used, and installing new platforms or making extension for the existing platforms are not justified. Dynamic Surge Device (DSD) is a sub, normally installed below the production packer on the bottom of the completion string acting as a blanking plug to set the packer, test tubing and automatically unload the well without any need to the risky wire line operations. Lifting Platform (L.P) is a hydraulically operated lift platform to provide additional storage area and to facilitate the movement of heavy equipment while working on the main platform (tower). Solvent Injector (SI) is developed to clean the gas lift mandrel and valves by injecting only the required volume of solvent around the valve, avoiding unnecessary dripping volumes of the solvent to affect other parts of completion. Jack-up Mover Assistance (JMA) is a special technique which uses a prefabricated floating concrete breakwater in front of the offshore platforms at the rigs' approach side, providing protections to the rig from waves during jacking up and down at rig approach and move, minimizing waiting on weather time and saving lots of money. The system is still under development. Introduciton This paper presents a number of newly developed tools introduced to offshore operations in Gulf of Suez in Egypt. Utilization of these tools has realized several operational flexibility, and significant cost and time saving. Deflecting Conductor Sleeve (DCS) At the late development stage of the offshore fields, the approved development plans necessitate to drill infill wells. At that time most of the platforms' slots are already occupied. Subsequently, installations of new surface facilities are to be programmed in order to accommodate the planned infill wells. Installations of the additional platforms;(towers); are expensive and need long term plans which could delay the implementation of the approved development plans. Diver Assisted Technique: Cut and Pullmethod that depends on divers. So, it is weather sensitive. In this method either the bell guide is trimmed in the pulling direction or conductor has to be pulled outside of platform beams at certain level and directed in order to drive the new conductor shoe away from the old conductor stub. The old conductors usually need to be cut 5 feet above seabed. Then the new conductor to be run followed by divers jump to facilitate pulling the conductor away from old stub toward the planned direction. This method has been used in Gulf of Suez since 1986 with a 90% success ratio in both shallow and medium water average job time was 3.5 days and the average cost per job was US$ 89000.
- Africa > Middle East > Egypt (0.77)
- Asia > Middle East (0.71)