BAKER HUGHES - Drilling Fluids Reference Manual
Baker Hughes Drilling Fluids Figure 1-20 and Figure 1-21 compare the results of two different systems formulated with PERFFLOW vs. those with the TBC salt system on return permeability and net breakout pressure. The PERFFLOW ® DIF (drill-in fluid) system’s bridging agent design and unique polymer chemistry form a thin filter cake protect the pay zone from damage caused by fluid invasion. The filter cake is efficiently removed by low breakout pressures, leaving no residual material to inhibit the well’s productivity. Using PERFFLOW ® Figure 1-20 The Effects of PERFFLOW ® on Return Permeability and Breakout Pressure Using the TBC Salt System Figure 1-21 Effects of TBC Salt System on Return Permeability and Breakout Pressure Baker Hughes Drilling Fluids Reference Manual Revised 2006 1-43
Hydraulics Completion Fluids Definition By definition, workover or completion fluids are fluids placed across the producing zones before or immediately after perforating, or any fluid placed across the formation during reworking, underreaming, drill-in, or gravel pack operations. These fluids help ensure that production is consistent with the expected potential of the well. Function The primary functions of completion/workover fluids are to: provide pressure control by preventing formation fluids from entering the borehole maintain borehole stability minimize formation damage control fluid loss with minimal solids invasion These fluids also keep the borehole “clean” of perforation debris, solids such as drill cuttings, sand, etc., or any other contaminants by providing a transportation medium that for circulating loose material to the surface. Attributes A completion/workover fluid must possess the following attributes: • enough density to control subsurface pressures • enable efficient solids removal during circulation through filtration systems • stable, nontoxic, low corrosivity, and bacterial growth retardant • non-reactive to other soluble salts, minerals, cement, etc. • retain desirable properties such as viscosity and other physical properties under prolonged exposure to high shear • readily degas Mechanisms for Formation Damage For a well to be profitable, the reduction of virgin permeability should be minimized. Permeability can be reduced by the invasion of foreign liquids and/or solids into the near well bore region. This hampered permeability or damaged zone is known as a skin effect. A critical function of completion fluids is to contain formation pressures. To accomplish this, hydrostatic pressure must be higher or equal to the pressure of the formation. Consequently, if the hydrostatic pressure is higher, the fluid would allow a certain amount of solids and liquids to be lost to the formation. Reference Manual Baker Hughes Drilling Fluids 1-44 Revised 2006
- Page 2 and 3: Drilling Fluids Reference Manual Ch
- Page 4 and 5: Chapter 1 Table of Contents Fundame
- Page 6 and 7: Baker Hughes Drilling Fluids Return
- Page 8 and 9: Fundamentals of Drilling Fluids Cha
- Page 10 and 11: Baker Hughes Drilling Fluids Contro
- Page 12 and 13: Baker Hughes Drilling Fluids Physic
- Page 14 and 15: Baker Hughes Drilling Fluids Newton
- Page 16 and 17: Baker Hughes Drilling Fluids Figure
- Page 18 and 19: Baker Hughes Drilling Fluids Contin
- Page 20 and 21: Baker Hughes Drilling Fluids The fl
- Page 22 and 23: Baker Hughes Drilling Fluids As def
- Page 24 and 25: Baker Hughes Drilling Fluids Figure
- Page 26 and 27: Baker Hughes Drilling Fluids Table
- Page 28 and 29: Baker Hughes Drilling Fluids Gel St
- Page 30 and 31: Baker Hughes Drilling Fluids drilli
- Page 32 and 33: Baker Hughes Drilling Fluids Time T
- Page 34 and 35: Baker Hughes Drilling Fluids Then,
- Page 36 and 37: Baker Hughes Drilling Fluids Low-Gr
- Page 38 and 39: Baker Hughes Drilling Fluids The pH
- Page 40 and 41: Baker Hughes Drilling Fluids Exampl
- Page 42 and 43: Baker Hughes Drilling Fluids Using
- Page 44 and 45: Baker Hughes Drilling Fluids Drill-
- Page 46 and 47: Baker Hughes Drilling Fluids MBT (M
- Page 48 and 49: Baker Hughes Drilling Fluids At dif
- Page 52 and 53: Baker Hughes Drilling Fluids Primar
- Page 54 and 55: Baker Hughes Drilling Fluids Nomenc
- Page 56 and 57: Formation Mechanics Chapter Two For
- Page 58 and 59: Table of Contents List of Figures F
- Page 60 and 61: Formation Mechanics • 3 million g
- Page 62 and 63: Formation Mechanics Hydration Mecha
- Page 64 and 65: Formation Mechanics Attapulgite Fig
- Page 66 and 67: Formation Mechanics in the outer si
- Page 68 and 69: Formation Mechanics • Calcareous
- Page 70 and 71: Formation Mechanics called “bio
- Page 72 and 73: Formation Mechanics Reservoir Press
- Page 74 and 75: Formation Mechanics Selecting the p
- Page 76 and 77: Formation Mechanics Figure 2-12 Pho
- Page 78 and 79: Water-Based Drilling Fluids Chapter
- Page 80 and 81: Figure 3-7 The Sodium Chloride Stru
- Page 82 and 83: Water-base Drilling Fluids Chapter
- Page 84 and 85: Baker Hughes Drilling Fluids Atomic
- Page 86 and 87: Baker Hughes Drilling Fluids Isotop
- Page 88 and 89: Baker Hughes Drilling Fluids Atoms
- Page 90 and 91: Baker Hughes Drilling Fluids Table
- Page 92 and 93: Baker Hughes Drilling Fluids Proper
- Page 94 and 95: Baker Hughes Drilling Fluids Table
- Page 96 and 97: Baker Hughes Drilling Fluids Solubi
- Page 98 and 99: Baker Hughes Drilling Fluids wettin
Baker Hughes <strong>Drilling</strong> <strong>Fluids</strong><br />
Figure 1-20 and Figure 1-21 compare the results of two different systems formulated with<br />
PERFFLOW vs. those with the TBC salt system on return permeability and net breakout pressure.<br />
The PERFFLOW ® DIF (drill-in fluid) system’s bridging agent design and unique polymer chemistry<br />
form a thin filter cake protect the pay zone from damage caused by fluid invasion. The filter cake is<br />
efficiently removed by low breakout pressures, leaving no residual material to inhibit the well’s<br />
productivity.<br />
Using PERFFLOW ®<br />
Figure 1-20<br />
The Effects of PERFFLOW ® on Return Permeability and Breakout Pressure<br />
Using the TBC Salt System<br />
Figure 1-21<br />
Effects of TBC Salt System on Return Permeability and Breakout Pressure<br />
Baker Hughes <strong>Drilling</strong> <strong>Fluids</strong><br />
<strong>Reference</strong> <strong>Manual</strong><br />
Revised 2006 1-43