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Results
Eliminate Pre-Flush and/or Post-Flush Acid Stages During Hydrofluoric Acid Treatments: Experimental and Field Cases
Gomaa, Ahmed M. (Baker Hughes) | Stolyarov, Sergey (Baker Hughes) | Cutler, Jennifer (Baker Hughes)
Abstract The goal of sandstone matrix acidizing is to remove siliceous particles such as formation clay, feldspar, and quartz fines that are blocking or bridging pore throats. This is accomplished by injecting acid formulations containing hydrofluoric (HF) acid or its precursors, as HF is the only common acid that dissolves siliceous particles sufficiently. Standard treatments include pre-flush and/or post-flush stages of HCl acid to minimize the potential for calcium fluoride and other secondary precipitation. However, there is no guarantee that the HF acid stage will follow the path of the preflush stage; therefore, precipitation could still occur. In addition, the fast reaction of HF acid with clay minerals presents another challenge to effectively stimulating deep sandstone formations. This paper presents experimental and field case studies with a sandstone acidizing treatment designed to retard the HF reaction rate and enable single-stage treatment -- eliminating the pre- and post-flush HCl acid stages and thereby reducing treatment complexity and treatment/rig time. Extensive laboratory testing was performed using a variety of quarried sandstone cores with varying amounts of clay minerals, feldspar, and carbonate to confirm the ability to stimulate a wide range of sandstone formations. Also, formation core material was evaluated to confirm the results. Static solubility tests indicated that around 80% of the treated formation was soluble in the new acid system formulation. Coreflood testing noted an improvement in permeability of as much as 326%. Also, corrosion tests conducted using different metallurgy showed a very low corrosion rate (less than 0.005 lb/ft for Nโ80 and less than 0.02 lb/ft for Crโ13). Using coiled tubing, the new design was injected into three deep offshore wells, resulting in injectivity increases of 227%, 236%, and 256%. This paper will describe in detail the experimental result and the successful field treatments.
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (1.00)
- Geology > Mineral > Silicate (1.00)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Well Completion > Acidizing (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
Innovative Impregnated Drill-Bit Design with Enhanced Durability Improves Performance in Challenging Algerian Application
Gadallah, Khaled (Baker Hughes) | Richert, Volker (Baker Hughes) | Burch, Connie (Baker Hughes)
Abstract Vertical wells are drilled in the In Aminas field in Algeria with various types of drill bits, including polycrystalline diamond compact bits (PDC), tungsten carbide insert bits (TCI), and impregnated (impreg) drill bits. The operator tested a new 6-in impregnated bit with novel cutting structure concepts in an attempt to drill the section in one run. The bit was used on rotary BHA, and high speed motor BHA for two runs in the same section. Both runs did well, and the bit maintained the sharp cutting structure till the TD of the section. The 6-in section comprises mulitple layers of hard abrasive sandstone with unconfined compressive strength up to 35 KPSI, loose shale which is relatively soft and ends with metamorphic rock. The new impregnated bit uses diamond segments imbedded in blades comprising diamond-grit matrix material to create a cutting structure with variable wear along the bit face. This particular combination of diamond and matrix improved overall aggressiveness and durability in the shoulder. To drill efficiently, impregs are paired with high-speed motors or turbines. The new design successfully drilled on two different BHAs. The first was a rotary-packed BHA that drilled 406.8 ft (124 m) at 4.33 ft/hr (1.32 m/hr). The bit didn't show signs of wear and was used on a second BHA with a high-speed motor that drilled another 603.7 ft (184 m) at 6 ft/hr (1.8 m/hr). The impreg's overall performance was 1,010 ft (308 m) at 5.2 ft/hr (1.6 m/hr), and the bit pulled out of hole in a very good condition. The solution enabled the operator to drill 200% further, more than the best offsets and saving multiple bit trips, which resulted in total savings of USD 195,000. This article will explain the benefits of the new technology and discuss how this novel impregnated bit successfully drilled the section in one run which is the first time ever to happen.
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.38)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.37)
- Africa > Middle East > Tunisia > Hamra Basin (0.99)
- Africa > Middle East > Libya > Hamra Basin (0.99)
- Africa > Middle East > Algeria > Illizi Province > Illizi Basin (0.99)
- (3 more...)
Steerable Drilling Liner Matches the Industry's Common Theme Regarding Cost Optimization Approaches and minimize Geomechanics Related Challenges; Technology Overview, Applications and Limitations
El Sherbeny, Wael (Baker Hughes) | Biscaro, Enrico (Baker Hughes) | Merie, Ibrahim (Baker Hughes) | Mayer, Heinrich (Baker Hughes) | Dabyah, Ali Al (Baker Hughes)
Abstract Because fracture gradient changes with rock type, some formations are more sensitive to induced fractures than others. Depending upon depth, the fractures created will either be horizontal or vertical. If the depth is 2500 feet or less, horizontal fractures are usually produced. Because horizontal fractures require lifting the entire overburden, they are limited to shallow depths. At depths over 3500 feet, fractures are usually vertical. Because vertical fractures occur without lifting the overburden, they can be created at much lower pressure. The propagation pressure is generally much less than the pressure that would be required to initiate the fracture. Consequently, fracture losses, once initiated, are difficult to control. Wellbore instability, particularly in shale formations, is a major challenge in drilling operations. Many factors such as rock properties, in-situ stresses, chemical interactions between shale and drilling fluids, and thermal effects must be taken into consideration in well trajectory designs and drilling fluid formulations to mitigate wellbore instability-related problems. The Steerable Drilling Liner service combines a rotary steerable system with a liner to help overcome the challenges: drilling in zones with lower pressure and unstable shale/coal layers, and with formations of varying flow and pressure regimes. Running the liner while drilling keeps the wellbore stable and eliminates the need to pull the drillstring to run casing. This is how it reduces your risks and NPT, saving the costs associated with contingency plans. Because the liner is isolated from the reamer shoe, you can rotate the liner at much lower RPMs than the pilot and reamer bits. This design lessens the load on the liner, improving its fatigue life. The Steerable Drilling Liner steerable drilling liner service helps you to mitigate the risk of hole collapse and formation damage by reducing openhole exposure, Reduce NPT by eliminating extra trips and ensuring that the liner is installed at TD from the first run Enhance wellbore integrity by drilling with the liner, leading to the plastering effect, which reduces fluid loss and cuttings volume, Lower health, safety, and environmental (HSE) risks by reducing pipe handling and rigsite footprint size Steerable Drilling Liner service developed and qualified using a rigorous processes including extensive onshore testing at the service provider Experimental Test Area (BETA) facility before being successfully deployed offshore. Rely on Steerable Drilling Liner service performance in extreme environments; the cost-effective Steerable Drilling Liner service promotes wellbore stability and performs reliably in the challenging downhole environments. This Paper will reveal the technology overview, updates, case histories and field limitations
- Asia > Middle East > Saudi Arabia (1.00)
- Africa > Middle East > Egypt (1.00)
- Asia > Middle East > Yemen (0.93)
- (3 more...)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.95)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Drillstring Design > Drill pipe selection (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
Magnetic Flux Leakage (MFL) Technology Provides the Industry's Most Precise Pipe Integrity and Corrosion Evaluation, Accurately Characterizing Casing and Tubing Strength. Technology Overview and Case History
El Sherbeny, Wael (Baker Hughes) | Nuic, Ivo (Baker Hughes) | Hasan, Gasser (Baker Hughes) | Abdesslam, Abba (Baker Hughes) | Hassane, Tharwat (Baker Hughes)
Abstract The Magnetic Flux Leakage (MFL) Technique is the most commonly used technique to inspect large diameter transmission pipelines. A typical MFL inspection system uses permanent magnets to apply an axially oriented magnetic field to the ferromagnetic pipe material. The magnetic field is perturbed by a metal-loss region (usually caused by corrosion) to produce flux leakage outside the pipe, which can be measured by field sensors. The magnetization system in an MFL inspection system should ideally produce a magnetic field that is strong enough to cause a measurable amount of magnetic flux to leak from the pipe material at metal-loss regions, uniform from inside to the outside surface of the wall thickness so that the measured signal is more linearly related to metal-loss depth, and consistent in magnitude along the length of a pipe so that flux leakage measurements can be compared at different locations during an inspection run. In general, the field strength most strongly affects detection of metal loss defects while characterization of defect geometry requires a field that is strong, uniform, and consistent. Improvements in the downhole hardware also provide more flexible and efficient data acquisition, reducing operating time while improving data accuracy and operational safety. In conventional magnetic flux leakage (MFL) tools, the flux leakage sensors are coils; in the โhigh-resolutionโ tool, the coil is replaced by multiple โHall Effectโ sensors. The HR Vertilog service uses MFL measurements to identify and quantify internal and external corrosion defects. The overlapping arrays of flux-leakage sensors and discriminator sensors offer full circumferential inspection of the tubing or casing string. This process differentiates between metal-loss (corrosion) and metal-gain (hardware) Features, and distinguishes between general corrosion and isolated pitting. Paper represents technology overview and field cases history
- Asia > Middle East > Saudi Arabia (1.00)
- Africa > Middle East > Egypt (1.00)
- Asia > Middle East > Yemen (0.94)
- (3 more...)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
Significance of Advanced Cuttings Evaluation (ACE) Technologies for Chemostratigraphy Purposes While Drilling; Technology Overview & Applications
El Sherbeny, Wael (Baker Hughes) | Nuic, Ivo (Baker Hughes) | Madkour, Ali (Baker Hughes)
Abstract Mud loggers are the first (and sadly in some cases the only) people to look at the cuttings. To actually see what the rocks look like, feel like, occasionally even taste. Most people looking at a well will actually look at โwriggly linesโ or at best the cuttings descriptions from the loggers or geologist, two or three lines of abbreviations โclaystone, light grey to grey, soft to firm, occasionally hard, slightly calcareous, trace fine sandโ. We have all read them, many of us have written them. These descriptions are incredibly useful and valuable, they are often all we have to understand the actual rocks and geology, especially with older wells. But in a world where we now enter the description and draw the logs with a computer, this information still comes from the subjective view of the logging geologist peering through a microscope In recent years, several tools have been developed to analyze drill cuttings from oil and gas wells. The most commonly used tools include X-ray fluorescence (XRF), X-ray diffraction (XRD), scanning electron microscopy (SEM) combined with energy dispersive X-ray spectroscopy (EDX), bulk density, and pyrolysis. Although each of these tools can be used to develop a limited determination of the in-situ rock character, the combination of three of these tools (XRF, SEM/EDX, and pyrolysis) can provide a more comprehensive picture of formation properties. The combination of XRF analysis with the SEM/EDX analysis is the key to the cuttings workflow. The exact location within the borehole can be determined and a robust mineralogy developed that is independent of normative mineralogy (typical XRF) or operator-interpretive mineralogy (XRD). Additional outputs include relative brittleness index, bulk density, lithology, fractional and textural relationships, total organic carbon (TOC) proxy, and a new porosity index. Trace and major elemental ratios are also available for precise stratigraphic placement. The addition of cuttings pyrolysis enables hydrocarbon typing, producible hydrocarbons, TOC, and total inorganic carbon (TIC) within each sample to be established. Chemical Lithostratigraphy uses whole rock inorganic geochemical (elemental) data, to give information on: Extrabasinal source area dominance and origin (volcanic, metamorphics, igneous, sedimentary), Extrabasinal component weathering or diagenesis (cementation) Intrabasinal components (Palaeo-environment and insitu origin of sediments) Chemical Lithostratigraphy analysis of cuttings can be done either in the laboratory or at the rig site using technology advanced Surface Logging Services (SLS) that includes both XRF and XRD equipment, in additions to SEM and Pyrolysis. Where an appropriate protocols uses for cuttings fraction that are most depth representative With the growing interest in hydraulically fracturing reservoirs both in main land USA and now globally, there has been a growing need to better characterize the reservoir to maximize hydrocarbon recovery while also reducing the overall cost in the recovery of the hydrocarbon. With current fracc-ing regimes relying on a large number of stages to ensure maximum recovery, which in many cases leads to upwards of 30% of these stages being unproductive. This reduces the overall profitability of the well even with maximum hydrocarbon recovery. With the ongoing development of automated mineralogy tools, such as the RoqSCAN, there is now the ability to characterize a reservoir at the well-site in real-time and also rapidly in a laboratory. In this paper we will review the current development of these mobile and ruggedized instruments using a real life project for Eagleridge Energy LLC, on their Burgess lateral well. The paper will show the application of automated mineralogical analysis of cuttings samples pre-drilling in defining stratigratic zones via mineralogy/elemental data. And then explore the application of the same data to assist, and in this case lead, the decision making process during directional drilling of the lateral well. The paper will also look at the use of the technology in defining tactical fracc-ing zone based on rock properties (e.g. ductility) determined from the mineralogical, elemental and textural data. This paper will show that through the use of automated mineralogical instruments, companies can pro-actively steer wells by identifying mineral changes within lateral borehole, indicating a deviation from the target zone. Additionally, this type of technology can be used to reactively steer by its ability to rapidly identification subsurface changes, such as unknown (undetected) faults. Finally the paper will show that through the better characterization of this reservoir companies can reduce the risk associated with the drilling of expensive lateral wells.
- North America > United States > Texas (1.00)
- Asia > Middle East > Saudi Arabia (1.00)
- Africa > Middle East > Egypt (1.00)
- (4 more...)
- Geology > Geological Subdiscipline > Mineralogy (1.00)
- Geology > Geological Subdiscipline > Stratigraphy > Lithostratigraphy (0.44)
- Geology > Geological Subdiscipline > Stratigraphy > Chemostratigraphy (0.40)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.35)
- North America > United States > Texas > Fort Worth Basin > Chappel Formation (0.94)
- North America > United States > Texas > Fort Worth Basin > Barnett Field > Barnett Shale Formation (0.94)
- North America > United States > Kansas > Chester Formation (0.93)
- (2 more...)
Insights of Wellbore Imaging and Lithology & Mineralogy Wireline logs to minimize the Uncertainty Regarding Bit selection and Design, Engineering Approach
El Sherbeny, Wael (Baker Hughes) | Madkour, Ali (Baker Hughes) | Nuic, Ivo (Baker Hughes) | Richards, Alun (Baker Hughes)
Abstract Formation drillability is one of the most important aspects for planning and designing a new oil/gas well since the factors affecting the drilling performance have complex relationships between formation properties, drill bit design and operational parameters. In view of high operating cost of drilling rigs, if Rate of Penetration (ROP) can be enhanced, it will reduce open-hole formation exposure time and complications associated with it resulting in significant savings in drilling time and cost can be realized Normally bit engineers utilize the assumed lithology from mud logs, detailed depth wise lithology of offset wells. The lithology can also be interpreted from conventional logging data such as Sonic, Gamma and Density. Furthermore, the rock's compressive strength is calculated using Compressional / Shear travel time (Sonic log), Bulk density (Density log) and Shale content (Gamma log). These utilized tools to detect the lithology and rock mechanical properties have an extent of uncertainty due to effects either related to borehole or drilling fluids that require extensive corrections. That degree of uncertainty subsequently can affect the drill bit design criteria, selection and viability of performance-enhancing features. This present paper reveals a new practical approach as a solution to minimize uncertainty in terms of bit design and selection by utilizing wellbore imaging and lithology & mineralogy wireline logs to precisely deliver an accurate input data to the drill bit design software modules.
- Asia > Middle East > Saudi Arabia (1.00)
- Africa > Middle East > Egypt (1.00)
- Asia > Middle East > Yemen (0.94)
- (3 more...)
- Geology > Geological Subdiscipline > Stratigraphy (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Geological Subdiscipline > Mineralogy (0.90)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.36)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)