Stuck pipe or sticking and lost circulation are the two main events which cause Non-productive time (NPT) in the drilling industry. A considerable amount of time and resources can be spent in efforts to free a stuck pipe. Sometimes, stuck pipe events result in breakage (either intentional or non-intentional) of the drill string leading to a lot of money being spent in fishing. Unsuccessful fishing operations have resulted in costly alternatives including side-tracking or worse still, well abandonment. Stuck pipe situations are very common around the world with most data gathered in the petroleum drilling industry.
1.CAUSES OF STUCK PIPE.
Pipe sticking Mechanism and Causes can be summarized in Table 1.
|Pipe Sticking Mechanisms and Causes|
|Mechanism||Differential Sticking||Mechanical Sticking|
|Hole Pack Off||Formation & BHA (Wellbore Geometry)|
|Settled Cuttings||Key Seating|
|Shale Instability||Mobile Formations|
|Fractured Rocks||Under gauge Hole|
|Cement Blocks||Micro Doglegs and Ledges|
|Junk||Drilling Into Magma|
1.1 Differential Sticking
During drilling the drilling fluid pressure is maintained at a higher value compared to the reservoir or formation pressure. When a permeable zone is reached, the difference in these pressures forces some of the fluid to seep into the permeable zone. As this happens, the solids in the drilling fluid are filtered out at the hole wall forming a layer called a filter cake. If a substantial area of the string surface comes into contact with the cake formed, then only the outer wall surface exposed to the drilling fluid “sees” the higher drilling fluid pressure and the contact surface to the cake “sees” the lower formation pressure. This pressure difference pushes the pipe to stick to hole wall and embed itself further into the filter cake with a great force (can reach more than a million pounds force). The string thus gets differentially stuck and force required to pull it exceeds the yield point of the pipe. The signs of differential sticking are:
- The pipe can neither be moved up and down nor rotated;
- Circulation is unaffected
The differential sticking force depends on the pressure differential and the area of contact with the porous formation zone among other factors。
Differential sticking may be prevented by:
- Maintaining lowest continuous fluid loss;
- Keeping circulating mud free of drilled solids;
- Keeping a very low differential pressure with allowance for swab and surge;
- Using a mud system that yields smooth mud cake (low friction co-efficient);
- Maintaining drill string rotation at all times;
- Using grooved or spiral drill collars;
- Minimizing length of drill collars and Bottom Hole Assembly (BHA).
If differential sticking occurs, the following solutions are mostly used:
- Immediate working/jarring of the string downwards;
- Reducing drilling fluid hydrostatic pressure by gasifying with air or by diluting the fluid. Close attention must be paid to kick indicators while reducing hydrostatic pressure;
- Oil spotting around stuck portion of string;
- Washing over the stuck pipe.
Hole pack off causes
This is one of the major causes of mechanical stuck pipe. It is where cuttings pack off or settle and build on the well bore and causes compaction around the BHA when the pipe is moved upwards. The compacted cuttings then prevent the string from coming up especially during trip out. Figure 2 shows settled cuttings.
The problem is more prone in highly deviated or horizontal wells since the cuttings tend to fall on the low side of the hole and are harder to clean out. These settled cuttings pile up and form beds and may compact against the BHA on trip outs. In vertical wells, good hole cleaning is achieved by selection and maintenance of suitable mud parameters and ensuring that the circulation rate chosen results in an annular velocity (around 100 -120 feet/min) which is greater than the slip velocity of the cuttings. Besides causing stuck pipe, settled cuttings can also cause:
- Formation breakdown due to increased Equivalent Circulating Density;
- Slow rate of penetration;
- Excessive over pull on trips;
- Increased torque.
Hole cleaning is one of the main solutions to preventing this stuck pipe problem and can be controlled by:
- Good mud rheology especially yield point and gel strength;
- Controlling drill rate to ensure hole is clean;
- Checking volume of cuttings coming over to shale shaker;
- Controlling annular velocities;
- Recognizing increased over pull;
- Reciprocating and rotating pipe while circulating;
- Using viscous sweeps;
- Recognizing low side section of deviated holes;
- Regular Wiper trip If sticking occurs, then:
- Attempt to establish circulation;
- Simultaneously apply downwards force gradually until circulation starts;
- Once circulation starts, rotate the string;
- In low angles holes, a weighted viscous pill should be used to ‘float out’ the cuttings;
- In high angle holes, a low viscous pill should be used to disturb the cuttings bed followed by weighted pills to carry cuttings out of hole.
This is as a result of tensile and compressive failure on the borehole wall. The borehole will fail in tension while drilling mud hydrostatic pressure induces stresses in the hole wall that exceeds the tensile strength of the rock. The borehole will fail in compression when the pressure of the drilling mud is insufficient to keep the shear stresses in the borehole wall below the shear strength of the formation (Rabia, 2001). This problem can be solved by applying rock mechanics principle to define working limits for mud weights to avoid tensile or compressive failure; here, the equations and methods applied in rock mechanics are quite complex and can be found in most geo-mechanics and rock mechanics literature. The result of formation instability is either borehole widening or contraction depending on the failure mode of the rock inside the well. The Figure 3 shown shows the Inner Drucker-Prager criterion for predicting safe mud weights.
Sticking to the fluids program can prevent effects of formation instability.
Other solutions include making use of a well program that isolates a potential troublesome formation and speeding up the drilling process to cut down time of drilling sensitive formations.
Formation instability can be identified by the following:
- Large amounts of angular or splintery cuttings when circulating;
- Drag on trips;
- Large amounts of hole f
Formation instability will cause material to fall inside the hole creating caves or contract the wellbore and might cause sticking. Sloughing and caving are also due to formation instability. If these occur, then the solution is establishing circulation, then working the drill string preferably downwards; when the string is freed, circulate all material out before changing the mud properties to continue drilling.
Usually encountered near surface and include loose sands, gravel and silts. These collapse due to low cohesive strength; they can collapse and jam the drill string.
Signs of sticking due to unconsolidated formation include:
- Increased torque;
- Drag and pump pressure increase when drilling;
- Increased Rate of Penetration;
- Large fill on bottom.
This problem can be prevented by using a mud system with impermeable filter cake to reduce fluid invasion into rock. Reducing annular velocity by reducing mud flow rate will also reduce erosion of hole wall and also reduce removal of filter cake.
Fractured and faulted formation
Symptoms of fractured and faulted formation include:
- Large and irregular rock fragments at shale shakers;
- Increased torque, drag and rate of penetration;
- A small amount of lost circulation.
The fractured formation falls into the well due to stresses originally holding the formation together being relieved by drilling of the hole. Excessive vibration might also cause the drill string to whip down hole and dislodge the fractured rocks. The problem can be prevented by:
- Reducing drill string vibration;
- Minimizing surge pressures;
- Sufficient hole cleaning to reduce hole pack off.
If sticking occurs, jar the string. If this is not successful, an inhibited Hydrochloric acid pill may be spotted around the stuck zone to break down the material surrounding the pipe.
Cement blocks from the rat hole might fall into the well bore and cause sticking. This can be prevented by minimizing the rat hole to a maximum of 5 feet and ensuring good tail cement at the casing shoe. If sticking occurs due to cement blocks, jar the string or inject acid solution down hole to dissolve the cement.
Green cement is improperly set cement. Green cement can occur after setting a cement plug inside casing or open hole. If the drill string is run too fast into top of cement and the cement is still green, then the cement can flash set around the pipe and cause permanent sticking. Flash setting is phenomenon that is not very well understood but a possible explanation is that the energy release while circulating and rotating could be sufficient to cause it. A good practice to prevent this is starting circulation 2 or 3 stands above expected top of cement and also keeping a low weight on bit.
1.2 Drilling into magma
It has been shown that the 2011m depth is particularly troublesome to drill through in Menengai field, Kenya (Makuk, 2013). It has been observed that fresh glass was present in cuttings at 2082 m and 2174 m at MW04 and MW06 respectively (Mibei, 2012). It is believed that magma intrusions at these depths are rapidly chilled by the drilling fluid producing glassy cuttings. Sticking problems were recorded at these depths and are believed to be related to the occurrence of glass (Mibei, 2012). The exact mechanism of sticking due to drilling into magma is not really known. The Iceland Deep Drilling project 1 was halted after having drilled into magma and gotten stuck, however the bit came up intact (Hólmgeirsson et al., 2010). It is reported that the magma pushed up on the drill string, lowering the hook load value. It is believed that explosive chilling of the magma (steam flashing) by drilling fluid downhole could however be related to this sticking problem.
A summary of signs of sticking and parameters to watch for stuck pipe problems can be tabulated well using the Baker Hughes INTEQ, 1995 workbook as shown in the Table 2.
|INDICATOR PROBLEM||TORQUE||PRESSURE||DRILL RATE|
|Poor Hole Cleaning||Increase||Increase||Gradual Increase|
|High Overbalance||Gradual Increase||No Change||Gradual Decrease|
|Mobile Formations||Gradual Increase||Increase||Gradual Decrease|
|Fractured & Faulted||Sudden Erratic Increase||May Be Unaffected||Sudden Increase|
|Geo-pressured Formations||Increase||Increase||Initial Increase||With||a|
|Reactive Formations||Gradual Decrease|
|Unconsolidated Formations||Gradual Increase||Increase||Gradual Decrease|
|Sudden Increase||No Change||Sudden Decrease|
|Sudden Increase||No Change||Sudden Decrease|
TABLE 2: Stuck Pipe Problems and Indicators (Baker Hughes, INTEQ, 1995)
2. MENENGAI STUCK PIPE DATA ANALYSIS
Tables 3 and 4 shows how stuck pipe events are distributed over the drilling activities in 10 Menengai wells. This table will assist in identifying operations during which stuck pipe mostly occurs.
TABLE 3: Drilling activities during Stuck Pipe/ in Menengai
|Well||Depth Of Sticking (m)||Activity During Sticking||No. Of
|Freed||Hours spent Fishing||Total drilling days (spud in to capping)||Total Depth (m)|
TABLE 4: Total Hours Stuck (10 Wells)
Table 5 shows the history during selected stuck pipe events. The recommended pumping rates are calculated based on recommended good practice for geothermal drilling.
TABLE 5: Operational activities during Sticking (from GDC well completion reports)
(m) and Date
|Operational activities in a span of 24-48 Hours||Pumping Rates and Returns|
|Drilled 26″ well from 43.19 m to 59.06 m with brine-Returns OK. The drill string got
stuck while making a connection. Worked the string and applied pull up to 200 klbf. Pumped hi vis mud at every 15 minutes while working stuck pipe up and down. No returns. Pumped L.C.M in mud into the hole while working the string. Received returns to the surface. Pumped aerated water into the hole. Received returns on surface. The string was freed.
|Approx. 1717 l/m
*Recommended pumping=7295 l/m of water
|MW07||149||Drilled 17-1/2″ hole from 133 m to 149.25 m with intermittent partial & full returns.
Experienced drilling break from 134 m-138 m with cuttings fully flowing out.
|Approx. 2720 l/m|
|Circulated the hole at 149 m. While lifting the string off bottom, it got stuck with high
torque and high Stand pipe pressure experienced. Worked the string up and down
|20-02-12||while pumping brine, then introduced air. Applied tension to 160 kN. Gained 1 foot.|
|Thereafter, rotation and circulation was lost. Poured 2 drums drilling detergent into|
|the active mud tank and pumped through the string.|
|Not much progress observed. Pumped hi-vis mud into the hole. Very little gain|
|observed. Worked the pipe up and down without gain. There was no pressure in the|
|Stand pipe pressure. All fluids pumped got lost into formation. Decided to cure loss|
|zone by pumping hi-vis mud mixed with wall nut shell and mica flakes. This was|
|repeated severally. Worked the string and introduced air. Leakage on the stand pipe|
|observed. Continued pumping brine at 200 strokes per minute while repairing the|
|leakage. Introduced air and pressure indicated 800 psi. The string got free and full
returns observed on the surface. POOH and prepared the string for plug job. Pumped 4 m3 of cement slurry at 112 m. POOH to shoe and WOC to cure.
|Recommended pumping=3107 l/m of mud|
|MW07||1184||Drilled 12-1/4″ hole from 1200M to 1205M with mud- Returns ok. Circulated the hole||1717 l/m|
|with 10,000 strokes of hi-vis mud to clean hole. POOH to shoe and did a wiper trip.|
|Encountered a tight spot at 1070m. Circulated the hole and spotted hi-vis mud at||Full Returns|
|bottom. POOH from 1205m to 1184m while back reaming. Pump went off while|
|15-04-12||attempting to connect back the stand that had been removed. Saver sub damaged.|
|Installed circulating head and circulated the hole-returns received on surface. On|
|connecting the saver sub to string, it was noted that the string got stuck. Circulating||Recommended|
|with mud returns ok. Pumped high vis mud while working the string.||pumping=1413 l/m|
|MW07||2135||Drilled 8-1/2″ hole from 2134.09 m to 2135.93 m with aerated water and foam-No||2040 l/m|
|returns. The string got stuck at 2135.93 m at 0200 hrs. Worked the string by applying|
|torque. Circulated with aerated water and foam while working the string. Applied pull||No Returns|
|310 klb and torque of 28 kNm. The string was freed at 1100 hrs and regained rotation.|
|25-05-12||Circulated and POOH. POOH experiencing high drag from the bottom to 965 where|
|there was no drag. Part of the BHA left in the hole. Two 6-1/2″ drill collars, and 8-|
|1/2″ bit left in the hole. Waited for instructions from management. Decision made to||Recommended|
|RIH liners.||pumping=1100 l/m|
|Drilling 8½″ hole with aerated water and foam. Partial returns.
Drill string sticking from 2300 hrs to 0000 hrs.
|2210 l/m. Partial
Recommended pumping=1100 l/m of water
|MW21||326||Drilling 17-1/2″ hole with water and mud sweeps till 326m. Got stuck at 0200 hours||3060 l/m- Full|
|and lost circulation. Circulated hi-vis mud while working the string for 4 hours when||Returns|
|28-12-13||string was freed .POOH after circulating to remove collapsed debris. POOH to 291 m|
|and reaming the section between 291m and 326 m.||*Recommended|
*these water pumping rates are practically difficult to achieve and therefore the problem is mitigated by using high viscosity mud
sweeps at regular intervals to ensure sufficient hole cleaning. We also note that the upper sections of a well are usually drilled with slower ROP, and therefore the fluid annular velocity necessary for sufficient hole cleaning is lower. Cuttings also reach the surface faster since the well is still shallow.
Easy View Diagrams and Analysis
Drilling parameters during selected stuck pipe events were analyzed using Easy View Software to easily recognize trends at the moment of sticking and before the stuck pipe event. The drilling data was recorded using data loggers at the rig site. This data was then downloaded in excel files in 10 second intervals and has been the input into Easy View software. This analysis will assist in identifying the causes of the stuck pipe and possible solutions. The diagrams have been displayed and described in the subsequent pages. Other conditions not captured by the data loggers during the stuck pipe events have also been listed (these other conditions include pumping rates and amount of returns at shale shakers)
MW07: Stuck at 2135m at 0145 h during drilling
The trend in Figure 4 shows that the string got stuck at 0145 hrs. We see a sudden drop in WOB from 5.92 to 0 kN, the rpm also drops to 0 from 70. The pump rate, bit location and ROP remain constant. It can be observed that the driller then tries to pick up the string and it is stuck as it has to be pulled to over 84.35 tonnes. There were no circulation returns at the moment of sticking and pumping rate was 2040 l/m of aerated foam and water.
The trends prior to sticking are displayed in Figure 5. From 0100 hrs to sticking time at 0145 hrs, stand pipe pressure varies by 3 bars (between 5,27 MPa & 4.97 MPa). The other parameters appear to be unchanging. Pumping rate was 2040 l/m of aerated foam & water and there were no returns prior to the sticking.
MW09: Stuck at 1948 m at 2229 hrs during drilling
The trend in Figure 6 shows the parameters at the moment of sticking of MW09 at 1948 m. The trends prior to sticking are shown in Figure 7.
We see that the string gets stuck at 2229 hrs when the rotation speed and rotary torque suddenly drop to zero. This occurs at the end of the drill pipe joint evidenced by the value of hook height i.e. the hook height is constant at about 0.41 m which implies it is the end of the current drill pipe joint. WOB is also observed to dip to zero. Pump rate and pressure do not change. There were partial returns during this stuck pipe event and pumping rate was 2210 l/m of aerated water and foam. The trends prior to sticking show that the rotation speed, pipe pressure and torque are quite regular through the drilling of this joint of drill pipe just until sticking point.
The results seen in the above diagrams imply that the possible reasons and types of sticking are as shown in table 6. Parameters not captured in Easy View have been obtained from Menengai well completion reports (see table 5). The possible causes are inferred from notes on stuck pipe that had been discussed earlier in this paper. The data necessary to carry out the Easy View analysis for most of the stuck pipe incidents, especially for the earlier wells were unavailable.
TABLE 6: Possible Causes of Stuck Pipe in Menengai Wells
|Well||Depth Stuck||Torque||WOB||ROP||Returns||Other||Possible Cause|
|Increase Unchanged Increase No
Freed by switching from drilling with brine to aerated fluid.
Sudden _ Sudden Full
Freed by pumping water instead of mud
|Well Pack-off caused by
inclined poor hole cleaning or
24 a new lost circulation
Settled cuttings due to poor hole cleaning.
Pipe Pressure Fractured & Increase faulted
formation. Differential Sticking
|MW09||1948 m||Sudden Drop Unchanged Unchanged Partial||Rotation Fractured &
speed faulted suddenly 0. formation.
|MW21||326 m||Unchanged Unchanged Sudden PARTIAL
|Circulated Poor Hole
till free Cleaning
3.DISCUSSION AND CONCLUSION
The results show that the causes of stuck pipe are several in Menengai. Unconsolidated formation is problematic but has been mitigated through using cement plugs. As earlier mentioned sticking due to fracture and faulted formation can be controlled by reducing drill string vibration, minimizing surge pressures and sufficient hole cleaning to reduce hole pack off. Sticking due to poor hole cleaning can be reduced by ensuring the hole is clean of cuttings. There are several ways to ensure good hole cleaning including ensuring good mud
Rheology especially yield point and gel strength, controlling drill rate to ensure hole is clean, checking volume of cuttings coming over to shale shaker and controlling annular velocities. Sticking caused by drilling through micro doglegs and ledges can be prevented by running slowly when tripping at alternating formation points; these areas should be noted and reamed through during trips.
- Loss of Returns While Drilling With Water and Air
Drilling the production zone is quite a challenge especially when there are no returns & cuttings cannot be carried to surface. The drilling program in Menengai usually recommends blind drilling in the production section when there are no returns. The choice of drilling fluid is restricted to water, aerated fluid and foam. Mud improves hole cleaning but cannot be used in the production zone since it will block the sensitive feeder zones. This problem can be solved by use of liquid drilling fluid polymer. This compound increases water viscosity thereby helping a lot with cutting carrying capacity; it does not affect formation permeability adversely. Polymer however does not improve gel strength and will therefore not suspend cuttings if pumping is stopped. Sweeping the hole with polymer can however still be introduced in Menengai to assist in hole cleaning as it has been successfully used in Iceland.
- Drill String snapping/ tubular washout
An incident of snapped string was encountered after one day of working stuck pipe at MW07 at 2135 m. Pull applied was 310,000 lb. force and 28 kNm torque which was still not exceeding the yield point (378,605 lb. force tensile yield strength and 53 kNm torsional yield strength) of the 5’’ OD drill pipe (considered the weakest member of the drill string). The BHA snapped at a collar connection. Weakening of drill string members could be caused by drilling fluid wash out or corrosion by acidic water that is used as drilling fluid. These two problems can be solved by use of corrosion inhibitor compounds and by use of caustic soda in drilling fluid. Caustic soda is used to maintain alkalinity so that acidic fluids do not attack metal. Corrosion inhibitors work by various mechanisms to inhibit oxygen present in drilling/production fluids from corroding pipes or equipment (Schlumberger Drilling, 2014). It has also been shown that aerated fluids erode drill pipes at a higher rate than non-aerated fluids (Budi Kesuma Adi Putra, 2008).
- Deviation Surveys
These can greatly assist in correcting trajectories and avoiding sticking related to hole geometry. The Totco survey tool and the Electronic Multi Shot tool can be dropped in the drill string during trip outs to quickly measure inclination. These tools are popular since they eliminate the non-productive time associated with setting up a conventional deviation survey.