best practices day 3 new

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Accelerators

Fishing Jars

Bumper Sub

AttachmentTool

Drill CollarsFishing String

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Bumper Jars

• Release spear or overshot

• Jar down on fish

• Move work string approximately 20”

• Help get over fish

• Predetermined weight on Internal cutter

• Swage tool

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Lubricated/Mechanical Bumper Sub• Use a lubricated bumper sub instead of a

mechanical bumper sub.

• More sealing elements, not as likely to wash out.

• In hot holes, a mechanical bumper sub is used, the heat will damage the packing in lubricated ones.

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Operating Procedure

• Pick up to open stroke stretch string

• Drop string and catch abruptly

• Stop 6” from closing jar

• Spring downward; deliver a sharp blow

• Requires practice & finesse

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Pump Open ForceLUBRICATED BUMPER SUBS

0

5000

10000

15000

20000

25000

30000

35000

40000

45000

50000

55000

60000

65000

70000

75000

80000

0 400 800 1200 1600 2000 2400

DIFFERENTIAL PRESSURE (psi)

PU

MP

OP

EN

FO

RC

ES

(lb

s.)

7 3/4” O.D.

6 1/2” O.D.

6 1/4” O.D.

4 3/4” O.D.

4 1/4” O.D.

3 3/4” O.D.

3 1/8” O.D.

2 1/4” O.D.

Pump pressure effects cocking and down jarring.

Reduce pump to idle before attempting to cork or jar down.

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Up Stroke Jar Types• The two basic types of jars are mechanical and

hydraulic

• These terms refer to the method of tripping the jar

• Hydraulic jars work by using a hydraulic fluid cushion to delay the tripping of the jar until the desired pull on the string is achieved

Shortcut (2) to Clip1.mpg.lnk

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Hydraulic Jarring Operations• The time delay is caused by trapped oil

slowing upward movement of the mandrel.

• The hydraulic fluid is metered through small jets until the mandrel enters the large bore area, then the oil is dumped rapidly causing the jar to fire

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HYDRAULIC FISHING JARSOperating Principles

HydraulicFluid

Large Bore Area Pressure Housing

PressurePiston

InnerMandrel

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HYDRAULIC FISHING JARSOperating Principles

Large Bore Area Pressure Housing

PressurePiston

InnerMandrel

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Hydraulic Jarring Operations

• The stretch/ string produces stored energy

• When the jar trips, the energy is released providing sudden impact

• Hydraulic jar firing delay is dependent on pull load and time.

• A computer program is required to precisely determine optimum jar placement in deviated holes.

Shortcut to Clip1.mpg.lnk

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Applications

Hydraulic Oil Jars

• Used in vertical, directional and extended reach

wells with elevated torque and drag

• Used as lower tool when running tandem jars

• In any case with limited overpull capacity

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AdvantagesHYDRAULIC FISHING JARS

• Variable Tripping Loads• Unaffected by Torque• Unaffected by Temperature• Protected Seals & Impact Shoulders• No Bleed-off• Increased Overpull Limit • Consistent Time Delay

Disadvantages• Heat Energy Affects:

– Viscosity of the Fluid– Decreases the Overpull Limits– Seal Failures

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Pump Open ForceHYDRAULIC FISHING JARS

DIFFERENTIAL PRESSURE (psi)

0

5000

10000

15000

20000

25000

30000

35000

40000

45000

50000

55000

60000

65000

70000

75000

80000

0 400 800 1200 1600 2000 2400

PU

MP

OP

EN

FO

RC

ES

(lb

s.)

7 3/4” O.D.

6 1/2” O.D.

6 1/4” O.D.

4 3/4” O.D.

4 1/4” O.D.

3 3/4” O.D.

3 1/8” O.D.

2 1/4” O.D.1 13/16” O.D.

Pump pressure effects cocking and down jarring.

Reduce pump to idle before attempting to cork or jar down.

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Outside D ia . (i n.) 1 13 /16 2 1 /4 3 1 /8 3 1 /8 3 3 /4 3 3 /4 4 1 /4 4 3 /4 6 1 /4 6 1 /2 7 3 /4

Inside D ia . (in.) 1 /2 11/16 1 1 /4 1 1 /2 1 3 /4 1 1 5/16 2 1 /8 2 1 /4 2 1 /4 2 3 /4 3

Tool Joint (API)1 13 /16

WFJ1 1/4Reg

2 3/8Re g

2 7/8PA C 2 3/8 IF 2 3 /8

E UE 2 7 /8 IF 3 1 /2 IF 4 1 /2 IF 4 1 /2 IF 6 5 /8Reg

Tensi le Yie ld*(x 1000 lbs.)

75 110 250 200 275 225 325 500 1 ,000 1 ,000 1 ,600

Torsiona l Yield*(x 1000 ft. lbs.)

1 .6 2.5 5 .0 5.0 7.8 3 .75 15 2 0 49 .3 56 .2 100

Max. Overpul l(x 1000 lbs.)

20 3 0 45 35 45 45 55 8 5 200 1 75 2 60

LengthClosed (ft.-in.)

7 '-0 " 7 '-10" 9 '-0 " 8 ' -8 " 9 ' -0 " 9 '-0 " 9 '-0 " 9 ' -11" 12 ' -2 " 12 ' -9 " 13 '-10"

Weight (lbs.) 50 8 0 180 180 222 230 290 400 800 100 0 2 ,000

Free Travel (i n.) 4 4 4 1 /4 4 4 1 /4 4 1 /4 4 1 /2 5 5 6.5 7 1 /2

Tota l Stroke (in.) 5 1 /2 6 6 1 /8 6 6 1 /8 6 1 /8 6 1 /4 7 8 1 /4 8 1 /2 9 3 /4

Max. BHT ( °F ) 400 400 400 400 400 400 400 400 400 400 400

Pump Open Area(sq. in.)

1.1 1.8 4 .0 4 .0 5.9 5 .9 7.7 10 .3 15 .9 19 .6 28.3

SplineMandrel Anvil

ConnectorHousing

WashMandrel

BottomConnector

SplineHousing

Hammer

Valve

PressureHousing

BalancePiston

PressurePiston

Tripping Ledge

HYDRAULIC FISHING JAR

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Applications

MECHANICAL DRILLING JARS

• Vertical Wells

• Directional Wells with Less Than 30º Hole Angle

• Geothermal Wells

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Mechanical Jarring Operations

• Mechanical jars have a preset pull load

that causes the jar to trip

• They are dependent on pull load only

• Upper tool when running jars in tandem

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Applications

SLINGERS

Fishing Slingers• Vertical and Directional Wells• Horizontal Wells

• Very Deep Wells• Very Shallow Wells• Any Time Higher Impact Forces required

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Applications

Accelerator-Booster-Intensifier-Slinger

• Allows optimum jar placement

• Accelerates the BHA mass

• Protects the drill string and surface equipment

• Compensates for drag in high angle holes

• Compensates for insufficient stretch in shallow

holes

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Outside Diameter (in.) 1 13/16 2 1/4 3 1/8 3 1/8 3 3/4 3 3/4 4 1/4 4 3/4 6 1/4 6 1/2 7 3/4

Inside Diameter (in.) 1/2 11/16 1 1/4 1 1/2 1 3/4 1 15/16 2 1/8 2 1/4 2 1/4 2 3/4 3

Tool Joint (API)1 13/16

WFJ 1 1/4 Reg 2 3/8 Reg 2 7/8 PAC 2 3/8 IF 2 3/8 EUE 2 7/8 IF 3 1/2 IF 4 1/2 IF 4 1/2 IF 6 5/8 Reg

Tensile Yield*( x 1000 lbs.)

75 110 250 200 275 225 325 500 832 1,000 1,600

Torsional Yield *(x 1000 ft. lbs.)

1.6 2.5 5.0 5.0 7.8 3.75 15 20 49.3 56.2 100

Max. Overpull(x 1000 lbs.)

20 30 45 35 45 45 55 85 200 175 260

LengthClosed (ft. - in.)

7' - 0" 8' - 9" 9' - 10" 9' - 8" 9' - 10" 9' - 10" 9' - 10" 9' - 10" 13' - 6" 15' - 0" 15' - 7"

Weight (lbs.) 50 100 198 175 242 224 316 440 1,000 1,200 2,000

Total Travel (in.) 5 1/2 6 6 1/8 6 6 1/8 6 1/8 6 1/4 7 8 1/4 8 1/2 9 3/4

Max. BHT ( °F ) 400 400 400 400 400 400 400 400 400 400 400

Pump Open Area(sq. in.)

0.4 0.8 2.4 2.8 4.4 4.4 5.4 6.5 7.7 11.0 14.2

ConnectorHousing

WashMandrel

SplineHousing

FlowMandrel

BottomConnection

SplineMandrel Up Anvil

PressurePistonHammer

FluidHousing

BalancePiston

PressureHousing

HYPULSE JAR SLINGER®

… for use with Fishing Jars

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Jarring Operations

• How long to jar? 4-5 hours w/no progress

• Got stuck coming up? Jar down

• Got stuck going down? Jar up

• Differentially stuck? Little effect

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Four Elements of Effective Jarring

In any jarring operation, make sure you have met each of the four elements or you are not effectively jarring at the stuck point. This addresses the up-jar only.

1. Restricted Pull:> Stuck situation> Restricted Pull Device, i.e. Oil Jar

2. Multiplier: Drill Collars> If you do not run drill collars or hevi-weight, the multiplier is less than 1

3. Transition Area: > Change in mass from drill collars to tubing or D.P. can also be the

transition area.> Jar Accelerator/Intensifier is the perfect transition area.

4. Stored Energy:> Jar Accelerator/Intensifier> Jarring work string

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Jarring While WO O

• Arrive on rig @ noon; 11-20-97

• Offshore from Cameron, Louisiana

• Stuck in 12-1/4″ hole 9′ off bottom @ 5949

• 13-3/8″ casing set at 1500″ .

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Stuck B.H.A.• 12-1/4″ bit• 8″O.D. mud motor• Float sub• 12″ O.D. stabilizer• C.D.R. tool• M.W.D. drill collar• Orientation sub• Monel drill collar• x-over sub• two 6-1/8″ drill collars• 9-5/8″ stabilizer• 10 joints 4-1/2″ hevi-weight drill pipe• Daily drilling jars• 20 more joints hevi-weight drill pipe

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Free point, Back-off & Jar

• Determined pipe is stuck at 2,000′ .

• Backed off at 1898′ , and POH

• TIH with jarring assembly

• Screw into fish

• Jar 4 hours with no results

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Running Free Pt. & Jar

• Ran free point again

• 50% free at 1930; 40% free at 2,000

• Continue to jar 4 more hours

• Ran free point again

• 60% free @ 1955; 40% free @ 2,000

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Jarring on Fish

• Continue to jar on fish 4 more hours

• Ran free point again; same results

• Fired string shot @ 1995 w/no results

• Made a back-off @ 1962 (2 joints) on

3rd. attempt

• Made wiper trip, screwed into fish

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Jarring on Fish• Continue jarring on fish 6 hours

• Ran free point; stuck @ 2058, 50% free with torque @ 2024

• Made a back-off with string shot @ 2024 (2 more joints)

• Made short trip, Circ. out, screw into fish @ 2024

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Jarring on Fish

• Continue jarring on fish 4 more hours

• Ran free point; 50% free @ 2152

• Fired shot @ 2152 with no results

• Fired 2nd. shot @ 2118 with no results

• Fired 3rd. Shot and backed off @ 2118 (3 more joints)

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Jarring on Fish• Made short trip, Circ. Out, screw into

fish @ 2118.

• Jar down on fish 4 hours

• Ran free point; 80% free @ 2218

• Made a back-off @ 2218 (3 more Jts.)

• Circ. Out & P.O.H.; recovered 10 Jts.

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Trip # 2 @ 5:00 a.m. 11-25-97

• Jarring assembly with new jars; Acc.

• Screw into fish @ 2218; jar 4 hours

• Ran free point; 60% free @ screw in point

• Jar down 4 hours

• Ran free point; 50% free w/torque @ 2284

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Jarring on Fish

• Made a back-off with string shot @2284 (2 more joints)

• Made short trip, Circ. Out, screw into fish @ 2284

• Jar on fish 4 more hours

• Ran free point; 40% free @ 2316

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Jarring on Fish

• Continue jarring 6 hours while WOO

• Fired string shot @ 2284; no success

• Fired 2nd. Shot @ 2284; no success

• Fired 3rd. Shot @ 2252/ made a BO

• P.O.H. recovered 1 jt. 7 days jarring; recovered 13 Jts. P. & A. well

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Fishing in Lateral WellsGenerally, you can use the same attachment

tools:overshots, spears screw in sub etc.

Success is determined by:

• Where to back-off

• In Jar placement

• String design

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Friction/ Inverted Strings

• Sliding friction drag is high in extended reach wells.

• Inverted drill strings are used whereas drill collars are kept in the vertical section.

• Spiral weight drill pipe is used in the angle building section/drill pipe is used in horizontal section.

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Jarring Most Common

• Most fishing in lateral wells will be in the jarring mode.

• Before a jarring operation is started, a free point and back off must first be made.

• After locating the free point, study the well plot checking for the true dog legs, then decide the depth to back off that offers the best chance of connecting to the fish.

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Tip on Torque Setting

• Rely on torque readings rather than stretch.

• To take a torque reading, set the weight at slightly less than the neutral weight.

• This tends to reduce hole drag around the curve while rotating to get a torque reading.

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Experience Counts

• Carefully work the torque down, one round at the time, using a long snub line, with a torque guage.

• Fire the shot on the run to prevent line creeping.

• The process of getting a successful free point and back off could take several hours, so be patient.

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Do Not Be Discouraged

• When a string shot is fired, no effect may be felt at the surface.

• Pull the WL out, to see if the shot fired

• Work pipe with torque until you get it backed off or determine it won’t

• You may have to fire another shot using a higher grains per foot shot.

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Example Job

• Given: 7-5/8″ casing with 6-1/2″ hole and the B.H.A. is stuck at 8690 (60′up from bit).

• Drill collars - No - Length - lb/ft 2 30 50

• The fish is differentially stuck.

• Where is the best place to back-off?

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Hole Description

• 1st interval - straight hole - 0 Deg.- 8,000′

• 2nd interval - build angle - 20°/100′ - 450′

• 3rd interval - straight hole - 90° - 300′

Miscellaneous Data Input

• Mud weight (lb/gal) = 10.5

• Friction factor = .5

• Maximum pull at jar = 100,000

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Fishing StringComponent No. Length (lb/ft)

drill pipe 33 30 13.30

intensifier

hevi - weight 12 30 25.30

jar

3-1/2 D.P. 1 30 13.30

bumper

3-1/2 cs hy. tbg. 1 30 9.3

5-3/4 o.s. (may use right hand wicker grapple) if back reaming required.

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Tensile/ Torque/ 3-1/2″ CS Hy. Tubing

• Tension yield for P110 x 9.3# is 285,000

• Max. torsional yield is 3,800 ft/lbs.

• Stiffness is called “section modulus”

• The higher this number, the stiffer the pipe

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Section Modulus or “Z” Factor

3.5 - 2.764 = 150.0625 - 58.3649 = 91.6975 = 26.199

3.5 3.5 3.5

26.199 x .09317477 = 2.44

3.5 - 2.992 = 150.0625 - 80.1394 = 69.9231 = 19.978

3.5 3.5 3.5

19.978 x .09317477 = 1.86

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Section Modulus/ DP verses Tubing

Stiffness of 3-1/2″ x 13.30# DP is: 2.44

Stiffness of 3-1/2″ x 9.3# Tbg. Is: 1.86

.58

.58 2.44 = .2377 rounded to .24

Conclusion: The tubing is 24% more limber

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One Jt. Tbg. In B.H.A.

Pull load (lb) = 100,000 Weight Jts. = 2 HWDP

% of peak 1 JT. 3-1/2 PH 4

impact No.

Length Impact Impulse

5 2 60 382,629 2,794

10 2 60 382,629 2,794

20 3 90 339,162 3,247

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Pull load (lb) = 60,000 Weight Jts. = 12 HWDP % of peak 1 JT. 3-1/2 PH 4 impact Pull Load Impact Impulse

5 60,000 274,604 8,435

10 60,000 274,604 8,435

20 60,000 274,604 8,435

By reducing the pull load from 100,000 to 60,000, the impulse is greater.

One Jt. Tbg. In B.H.A.

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Top Fish Inside Casing

Pull load (lb) = 100,000 Weight Jts. = 2 HWDP % of peak 8 Jts. Hevi-weight below jars impact Pull Load Impact Impulse

5 100,000 398,100 2,863

10 100,000 398,100 2,863

20 100,000 352,417 3,408

By leaving the top of fish inside the casing, the possibility of connecting to it is retained, while the impact is good using 8 joints of HW below the jars.

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Jars in Vertical Section

Pull load (lb) = 100,000 Weight Jts. = 2 HWDP % of peak 23 Jts. Drill pipe below jars impact Pull Load Impact Impulse

5 100,000 152,053 1,087

10 100,000 152,053 1,087

20 100,000 134,081 1,150

Poor impact and impulse is the results of placing the jars in the vertical section of the hole.

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Impact and Impulse/ No Acc. JarPull load (lb) = Varies Weight Jts. = 2 HWDP

Pull Load Impact Impulse

20,000 41,154 309

30,000 63,408 479

40,000 85,662 648

50,000 107,915 818

60,000 130,169 988

70,000 152,422 1,158

80,000 174,300 1,325

90,000 196,086 1,493

100,000 217,778 1,661

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