Drilling optimization

Gaitonde, V.N. and Karnik, S.R. (2007) Taguchi robust design for multi-response drilling optimization to minimize burr size using utility concept. International Journal of Manufacturing Research, 2(2) 209-24. 

After all the exploratory analyses, drilling determines whether the exploration geophysicist has accurately located the reservoir (exploratory drilling) and whether the sites chosen for drilling into the same resei voir are optimal for efficient production (developmental drilling). When an exploratoi y hole produces neither oil nor gas, it is capped and abandoned. But if it does yield oil or gas, it is readied for production and becomes a completed well. To extract oil and gas requires drilling a well. 

Factors Affecting Drilling Rates 1090. Selection of Weight on Bit, Rotary Speed, and Drilling Time 1091. Selection of Optimal Nozzle Size and Mud Flowrate 1097. 

In general, if the optimal drilling programs require large drill collars, the operator should not hesitate to use them. 

We will discuss four main topics stuck pipe prevention, drillstring failure prevention, ROP optimization and real-time use of drilling mechanics. 

Note Using the above obtained values for K, A and S, one may attempt to optimize drilling parameters from Equations 4-278, 4-279 and 4-280 however, in the case considered, the bit life is limited by bearings wear. Consequently Equations 4-278, 4-279 and 4-280 are not applicable. Nevertheless a simple trial-and-error calculation can be used to find the desired parameters. 

Find the optimal weight on bit and rotary speed for minimum drilling cost per foot if the data are as follows ... 

Drilling and Well Completions Optimal bit rotating time is... 

Optimal hydraulics is the proper balance of hydraulic parameters (flowrate and equivalent nozzle size) that satisfy chosen criteria of optimization. Hydraulic quantities used to characterize jet bit performance include hydraulic horsepower, jet impact force, jet velocity, Reynolds number at the nozzle, generalized drilling rate or cost per foot drilled. While designing the hydraulic program the limitations due to cuttings transport in the annulus and pump performance characteristics must be included. 

Smith, R., G. Hollingsworth, C. Joiner, andj. Bernard Chevron optimizes drilling procedures in the Tuscaloosa trends, Petroleum Engineering International, March 1982. 

Bourgoyne, A. T., Jr., and F. S. Young, A multiple regression approach to optimal drilling and abnormal pressure detection, Society of Petroleum Engineering Journal, August 12974. 

Synthetic-based muds are mineral oil muds in which the oil phase has been replaced with a synthetic fluid, such as ether, ester, PAO, or linear alkylbenzene, and are available from major mud companies. The mud selection process is based on the mud s technical performance, environmental impact, and financial impact. Synthetic muds are expensive. Two factors influence the direct cost unit or per-barrel cost and mud losses. Synthetic muds are the technical equivalent of oil-based muds when drilling intermediate hole sections. They are technically superior to all water-based systems when drilling reactive shales in directional wells. However, with efficient solids-control equipment, optimized drilling, and good housekeeping practices, the cost of the synthetic mud can be brought to a level comparable with oil-based mud [1308]. 

Clays or shales have the ability to absorb water, thus causing the instability of wells either because of the swelling of some mineral species or because the supporting pressure is suppressed by modification of the pore pressure. The response of a shale to a water-based fluid depends on its initial water activity and on the composition of the fluid. The behavior of shales can be classified into either deformation mechanisms or transport mechanisms [1765]. Optimization of mud salinity, density, and filter-cake properties is important in achieving optimal shale stability and drilling efficiency with water-based mud. 

A borehole stability model has been developed that takes into account both the mechanical and the chemical aspects of interactions between drilling fluid and shale [1231]. Chemically induced stress alteration based on the thermodynamics of differences in water molar free energies of the drilling fluid and shale is combined with mechanically induced stress. Based on this model, it should be possible to obtain the optimal mud weight and salt concentration for drilling fluids. 

Adviento-Borbe MA, Pittelkow CM, Anders M, van Kessel C, Hill JE, McClung AM, Six J, Linquist BA. Optimal fertilizer nitrogen rates and yield-scaled global warming potential in drill seeded rice. J. Environ. Qual. 2014 42 1623-1634. 

Planning Summary Develop an emergency preparedness plan for emergency events including a terrorist attack. Make sure training and practice drills are completed at least yearly, and look for potential vulnerabilities so the plan can be optimized. 

Polymerized olefins include poly-a-olefins (PAOs), linear a-olefins (LAOs), and internal olefins (IOs) [24]. Hydrocarbon chain length and branching are selected to optimize the drilling properties and minimize the environmental toxicity [20]. 

After a careful look at the power consumption histogram and discussion with both the production facilities and drilling personnel of the operating company, a new configuration was designed (Table 3—Optimization). 

This power optimization allocated turbine-driven sets to the drilling personnel which were accepted reluctantly because of unknown technology. A drilling contractor familiar with turbine equipment overcame this reluctance so further design work could proceed. 

Support utilities such as power generation. seawater lift, relief system, liquid fuel storage, and other utilities lend themselves to design optimization. Redundancy of utilities with coincident drilling should be examined carefully. 

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