Coiled Tubing

E N H A N C I N G PRODUCTIVITY spiral supply tooth roots Solve Downhole Problems With Reliable, Cost-Effective Technology bread pay attainr oil Tools coil render Handbook The global oil and go down on industry is development turn furnish for an ever-increasing array of salutary word projects. gyrate thermionic valve alleges a number of operational and economic advantages, including live rise intervention, elimination of s good kill and potentially damaging heavy-weight kill ? uids, decrease operational infrastructureprint, horizontal intervention, and the ability to intervene with bulge a siding. These advantages have led to the evolution of truly ? -for-purpose turn thermionic tube systems from the industrys largest endurer of coil thermionic tube good intervention solutions bread maker oil Tools. Baker rock oil Tools offers its clients an r be selection of turn- provide-conveyed intervention products, services and solutions with which to approach in dividual puff up leasements. This handbook was developed to help our clients determine which systems and services will best meet the un negateably of a particular application. For that reason, we have designed the handbook to highlight system capabilities within eight distinct intervention aras where gyrate thermionic valve mickle offer a passing effective and cost-ef? ient alternative. These eight categories ar vigorous Cleaning, Fishing and move, Z ane closing off, Stimulation and Fracturing, Sand Control Completions, Flow Management, tidy sum and Abandonment, and Sidetracking and Re-entry. Coiled Tubing Well Coiled Tubing Sections Well Cleaning Sandtrap System . . . . Debris Catching . . . . Underreaming . . . . . Impact recitationing . . . . . Mechanical Scale Removal . High- drag unit of measurementary thou smoo consequently laundry . Vortech Pulsating Jetting Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3 . 3 . 4 . 5 . 6 . 7 . 9 . 10 Well Cleaning Fishing and hoagieing Fishing and mill ab appear Recovering Tools with Downhole quiver Technology . . . . . Recovering Tools with hydraulicly Activated Fishing Tools . . . Recovering Coiled Tubing . . . . . . . . . . . . . . Removing and Recovering Obstructions . . . . . . . . . . Cutting subway systemwork . . . . . . . . . . . . . . . . . . Milling . . . . . . . . . . . . . . . . . . . . admixture MUNCHER Milling Assembly with Magnetic Chip Catcher OPTICUT Mills . . . . . . . . . . . . . . . . . Vortech Pulsating Bit move machinery . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11 11 12 14 16 17 18 20 21 22 district Isolation Zone Isolation Through Tubing . . recoverable Bridge Plug retrievable pugilist . set out Systems . . Monobore . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 23 23 24 25 26 27 Stimulation and Fracturing Stimulation and Fracturing 29 Through Tubing ISAP . . . . . . . . . . . . . . . . . . 29 QUIK do composite plant Products . . . . . . . . . . . . . . 31 Retrievable Bridge Plug . . . . . . . . . . . . . . . . . . 34 Sand Control Completions Vent Screen System . . . . Squeeze-Pack System . . . backwash-Down System . . . . Circulating position Pack System Sand Control Screens . . . . FRAQ PAQ Fluid Systems . . SM 35 Sand Control Completions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 36 37 38 39 40 43 . . . . . . . . . . . . Flow Management Increasing Gas Velocity While Reducing Water toil Velocity and Straddle Systems . . . . . . . . CT Tension Packer . . . . . . . . . . . . In? atable Stradd le System . . . . . . . . . . Scale Inhi musical compositionion . . . . . . . . . . . . . Production/Injection Logging . . . . . . . . . Selective-Zone Completion . . . . . . . . . . Shifting Sliding Sleeves . . . . . . . . . . . teat-Less Completion Technology . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 45 46 47 49 50 50 51 52 53 54 Flow Management Plug and Abandonment Plug and Abandonment 57 In? atable Permanent Bridge Plug . . . . . . . . . . . . . . 58 Permanent Cement Retainer . . . . . . . . . . . . . . . . 59 Monobore . . . . . . . . . . . . . . . . . . . . . . 60 Sidetracking and Re-entry Slimhole Casing Exit Technology . . . Restricted-Bore Whipstock System . . Slimhole Milling Assemblies . . . . Open-Hole Completions . . . . . . Open-Hole lining Systems . . . . . Coiled Tubing Drilling . . . . . . Drill Bits Hughes Christensen Solutions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 Sidetracking and Re-entry 62 63 64 65 65 68 74 1 2 Well Cleaning A clean soundlybore is not however a prerequisite for trouble-free well campaigning and completion, it also helps ensure optimum proceeds for the spirit of the well. Baker Oil Tools spiral- thermionic valve-conveyed well make clean solutions have long and highly successful track records. Well Cleaning Sandtrap System The Sandtrap System is a highly ef? cient method of cleaning appear large volumes of anchor or proppant from a wellbore where suf? cient annular velocity quite a littlenot be obtained to circulate the sand out establishedly victimisation spiral tubing.The system incorpo yards jet pump technology and is reasoned by water or nitrogen. No bubble is postulate. The Sandtrap System is extremely cost effective comp argond to alternatives where foam and chemicals are e ngaged. It is also extremely ef? cient and requires minimal eon. The sand is subscribe tod as the machine is lowered, creating the space to continue the process. Production so-and-so be resumed to mean solar day after cleanout. Clean wellbore ? uid enters throat and mixes with power ? uid The system comes in 5-3/4 in. and 3 in. OD sizes. Each application is ? ow modeled on an individual well basis.Key gets and advantages Suitable for all sand / proppant types No foam system compulsory for effective wellbore cleanout Water, nitrogen or mixture quite a little be used as power ? uid Fast, ef? cient operation Return to wellbore via exit ports baptistry chronicle pairing sea prey A high volume of sand accumulated in a well ca utilize decline in intersection. Bottomhole tweet in the well would not hold a ? uid column. The sand needed to be cleaned out of the well, with minimum shut-in time pass along. CT Solution A 5-3/4 in. OD Sandtrap System with extensions was chose n since a minimal amount of ? id would be introduced into the well and sand could be captured without circulating all the way up to surface, which would require a foam system. go The full 100% alikel capacity was ? lled with sand during the ? rst two bunks. During the third knead only 73% of the capacity was ? lled, indicating that the sand in the well nearly emptied. This was con? rmed with the fourth officiate only acquire 0. 5 gallon of sand. A total of 265 gallons of sand was recovered during the operation. Sand ? ltered out Passes done gravel screen Check valve traps sand inside tool Wellbore ? uid drawn into tool Jet Pump Sand Cleanout System 3Debris Catching In wellbore cleanout situations where suf? cient annular velocity tricknot be obtained to carry debris out of the wellbore, foam systems or nitri? ed ? uids can be used. A time- and cost-saving alternative is a debris catching system, which is used to bump off heterogeneous types of high-density debris and tune ation particles too heavy to be circulated to surface. Baker Oil Tools Solutions Bakers Rotary Venturi Cleanout System consists of a Venturi Jet Junk ring (VJJB) and Navi-Drill Workover Motor. Typically a VJJB is bleed alone but can be run with a repulse to chip off up compacted debris that is too heavy to circulate to surface.The jet field goal uses the venturi principle to create a force drop inside the tool. Extension barrels can be inserted in the tool to cast up its solids carrying capacity. Key features and advantages richly closed ? nger or ? utter catchers Can be run with any type of dressed shoe adjustable reservoir through extensions adjustable nozzles to placate various ? ow rates Motorhead Assembly Navi-Drill Workover Motor Venturi Jet Junk Basket A Venturi Jet Junk Basket (VJJB) with a dressed shoe can be run in conjunction with a Navi-Drill Workover Motor to break up compacted debris that is too heavy to circulate to surface. 4Underreaming An underreamer i s designed to pass through a downhole parapet, open, clean the hole to full gauge, and close for convalescence back through the restriction. The restriction is typically in the production tubing string, in the form of tit pro? les, mandrels, and otherwise completion accessories. In well cleaning the well-nigh common underreaming task is removing cement left from gyrate tubing quell cementing. Leftover cement is typically the result of large cement nodes forming at the squeezed perforations, or cement hardening before the excess can be turn out. These cement restrictions must be removed before re perforating.An underreamer is also used to clean out home plate and hard ? ll that cannot be removed from liners by jet- swear out tools. A mill could be used in these conditions, but the resulting hole size would be about the same as the privileged drift of the tubing, expiration a sheath on the walls of the liner. This sheath could dislodge during subsequent trading operations, possibly resulting in stuck tools. Perforating would not be as ef? cient because the charges would have to expend energy intense the sheath before reaching the liner. Well Cleaning Production Tubing Coiled Tubing Connector Lockable Swivel Baker Oil Tools SolutionsDual Back Pressure Valve The DB Underreamer has proven highly successful in removing cement, packed sand, resin-coated sand, formation and other forms of obstructions. Unlike other slimhole underreamers, the DB Underreamer is designed with a positive fix feature to ensure all great blades maintain a full extension upon activation and during an underreaming operation. A proprietary software program models ? ow and operational characteristics of the DB Underreamer prior to each job and during ? eld operations. The program acquired immune deficiency syndrome in determining appropriate ori? ce size to maximize the ef? ciency of allowable hydraulic power.Key features and advantages Adjustable nozzles for all ?ow ports Press ure indication on surface when arms are fully extended Sturdy construction for downhole reliability Designed to underream case or open hole Positive locking of arms when activated Thru-Tubing Dual Actuated Circulating Valve Non-Rotating Stabilizer Navi-Drill X-treme Workover Motor Case History spousal relationship Sea heading Remove cement from a 7 in. 29. 00 lb/ft liner which was left partly cemented to a total depth of 13,600 ft. Due to a 3. 695 in. restriction in the completion, a conventional fullbore milling assemby could not be run. DB UnderreamerCT Solution A 3 in. OD DB Underreamer with lower bite box was used in combination with a 3. 35 in. turbo mill. This system was chosen because of the spark plug form of the cement. Cement Casing Result The underreamer used in combination with the turbo mill successfully urbane 1,118 ft of cement in a single run. Using water and high viscous pills, an modal(a) rate of brainwave (ROP) of 74. 50 ft/hr was achieved. DB Underreame r Assembly 5 Impact Drilling Downhole conditions such as high temperatures (above 400 F) and hostile ? uids can signi? chamferly reduce the life of a workover force back and limit milling operations.Impact drill systems are an attractive alternative because they effected reliably in adverse conditions. The most common applications of the impact drill include outperform milling, hard cement milling, resin sand removal, and gravel removal. Motorhead Assembly Baker Oil Tools Solutions Baker Oil Tools Single-Directional Impact Drill (Si-Di) is used to drill hard packed sand and cement, remove scale and drive debris downhole. The industry-leading impact drill can manipulation as a standard impact hammer, or by applying a modular rotational feature, as a rotating impact drill. It has been speci? ally designed for use on coil tubing but can be used on threaded pipe in conjunction with an accelerator. Fluid, gas, or foam power the tool, which can operate in temperatures over 600F. Si ngle-Directional Impact Drill Key features and advantages Does not operate until the bit meets resistance Does not store reverse crookedness Can operate in high temperatures (above 600F) Operates with most ? uid media including high volumes of nitrogen Short make-up length Can be equipped to operate in hostile conditions Low redress costs (not constructed of elastomers) HIPP-TRIPPER Accelerator Weight BarCase History North Sea intent Barium sulfate scale needed to be removed from a well which had a restricted tool-string deployment height of 11 ft. This ruled out using a conventional positive displacement drive and underreamer assembly. CT Solution A 2-5/8 in. OD Si-Di Impact Drill equipped with a Cut going Bit was deployed with a conventional motorhead assembly. boilersuit assembly length was 9 ft. Result The assembly successfully drilled out approximately 210 ft of atomic number 56 sulfate scale at an average rate of 61 ft/hour. The cleanout yielded a 96% increase in oil production in the 7 in. monobore completion.Si-Di HIPP-TRIPPER Impact Drill Cut Button Bit A well cleaning bottomhole assembly incorporating a Si-Di Impact Drill in combination with a Cut Button Bit for scale removal or hard formation drilling. 6 Mechanical Scale Removal Removing scale is one of the most common through-tubing applications on coiled tubing. Although various other methods of scale removal have been attempted, mechanical methods have yielded by far-off the most consistent success rate. Well Cleaning Baker Oil Tools Solutions Baker Oil Tools METAL MUNCHER Turbo Scale Mill has proven to be the most effective of all options for scale removal.A typical Baker Oil Tools scale removal bottomhole assembly (BHA) consists of a Turbo Scale Mill run below the industry-leading NaviDrill X-treme Workover Motor. The raw matrix and layout of the Turbo Scale Mill face have been optimized for this bushelup. The mill has a smaller contact area when milling, which reduces torque co nsumption. As a result, there are fewer motor stalls and rate of penetration (ROP) is increased. Stabilizer pads and grimace dressed on drop dead of the METAL MUNCHER inserts minimize the risk of damaging the tubing or casing wall.The mill is dressed such that if the initial chopting edge breaks due to vibration or hardness of the scale, a second, lower, dressed layer will take over. This design has lengthened mill life per run and reduced sightseers to surface during extended milling operations, while the improved ef? ciency has increased cost savings through reducing in overall intervention time. Bakers METAL MUNCHER Turbo Scale Mill has proven to be the most effective of all scale removal options. Key features and advantages (Navi-Drill X-treme Workover Motor) Higher rates of penetration Extended run times Reduced milling times secondimal ? w rates required to achieve maximum horsepower Controlled rotational velocity protects solecism matrix Increased reliability in h igh- strain applications Successful operation in downhole temperatures above 400 F 7 Case History North Sea Objective The operator required ef? cient removal of scale from a 14,400 ft well consisting consisting of 4-1/2 in. 13. 50 lb/ft tubing and 7 in. 35. 00 lb/ft liner. Wellbore ? uids were known to be hostile with a history of causing severe damage to conventional workover motor stators. The operation was to be performed from a lower deck with restricted height available for tool-string deployment.CT Solution A reduced length 2. 88 in. OD Navi-Drill X-treme Workover Motor was proposed in conjunction with a 3. 61 in. OD METAL MUNCHER Turbo Scale Mill. The reduced length assembly could be deployed within the restricted riser height. Result The hard scale was successfully removed from the 4-1/2 in. tubing using the Turbo Scale Milling Assembly. The same motor was again deployed in conjunction with a DB Underreamer to successfully remove scale from the 7 in. liner. Job time for bot h trips was less than 14 hours, with no ? uid damage caused to the X-treme Motor stator.Top No-Go Tubing Nipple Coiled Tubing Connector Lockable Swivel Dual Back Pressure Valve prevalent hydraulic Disconnect Thru-Tubing Dual Actuated Circulating Valve Non-Rotating Stabilizer Navi-Drill X-treme Workover Motor Turbo Scale Mill A typical Baker scale removal bottomhole assembly (BHA) consists of a Turbo Scale Mill run below the industry-leading Navi-Drill X-treme Workover Motor. 8 High-Pressure Jet Washing Wellbore cleaning solutions also include a variety of high-pressure jet washing tools. These tools are used for sand, paraf? n, asphaltine or scale cleanouts.High-pressure jet washing tools are also highly effective for cleaning completion accessories such as nipples, gas lift mandrels and screens where mechanical means are limited. Well Cleaning Coiled Tubing Connector Baker Oil Tools Solutions Lateral entry and washing Dual Back Pressure Valve Baker Oil Tools offers an extensive array of tools that can be used as accessories for standard milling and ? shing assemblies. The Hydraulic Indexing Tool enables a BHA to rotate in 30 increments with high torque. The Hydraulic change form Sub is designed to provide a means of hydraulically kicking over a tool string for entry into laterals or for ? hing applications. The High-Flow Spinning Wash Tool is used to ef? ciently wash sand and debris. Key features and advantages Kick-over force is easily checklable by hydraulic pressure differential Positive rotational control when used with indexing tool High speed rotation spinning wash tool May be run with a variety of ? uids Universal Hydraulic Disconnect Indexing Tool Hydraulic Bent Sub Spinning Wash Tool A lateral wash assembly consisting of a Hydraulic Indexing Tool, a Hydraulic Bent Sub and a High-Flow Spinning Wash Tool. 9Vortech Pulsating Jetting Tool The Vortech Pulsating Jetting Tool effectively cleans out the wellbore or stimulates the reservoir using the ? uidic oscillating principle. A vortex is formed inside the tool, which produces oscillating pulses upon exiting. These pulses produce transonic stress waves that have a far greater effective range than a common jetting nozzle. Non-damaging cleanout of complex and delicate structures such as downhole screens, installations, gas lift mandrels, and skid sleeves is possible because the cleaning radius is not limited by tool standoff.Key features and advantages No moving parts Pulsates any ? uid, gas, or mixture such as nitrogen, water and/or acid Produces sonic stress waves so cleaning radius is not limited by tool geometry Effectively stimulates the reservoir Available ? ush with coiled tubing OD Internal Coiled Tubing Connector Coiled Tubing Case History Texas Objective To remove barium sulfate scale from the production tubing and perforated interval in a gas well where previous bailer attempts were unsuccessful. Production in the well had steadily declined to 140 Mcf/day and 600 psi wellhead pressure.CT Solution A 1-1/4 in. OD Vortech Pulsating Jetting Tool on 1-1/4 in. OD coiled tubing was selected to clean out the barium sulfate scale. To ensure the ? ll would return to surface and reduce the hydrostatic pressure acting on the reservoir, a water / nitrogen mixture was used. Result The cyclical stress waves generated by the action created by the Vortech Pulsating Jetting Tool, combined with the water medium, broke up the scale. The scale was successfully removed and production increased to 5 MMscf with a 2,600 psi wellhead pressure. Dual Back Pressure ValveVortech Pulsating Jetting Tool Wellbore Cleanout and Reservoir Stimulation 10 Fishing and Milling Recovering Tools with Downhole Vibration Technology When ? shing on coiled tubing for devices stuck in hole, hydraulic jars are typically used as means of providing impact force to free the device. The drawback is that the pipe must be cycled over the gooseneck multiple times to ? re and reset the jar. D ownhole vibration technology places impact energy right where the device is stuck and frees it officiously, even from tardily or deviated wells. Coiled Tubing ConnectorFishing and Milling Baker Oil Tools Solutions Dual Back Pressure Valve Universal Hydraulic Disconnect Non-Rotating Stabilizer Unlike conventional jars, Bakers Bi-Directional Vibratory Jar (Bi-Di) delivers the energy of the impact immediately above the ? sh. The Bi-Di is used extensively in ? shing operations to deliver both up and downward impact up to 1,000 times per minute. This high-frequency jarring action, combined with a constant overpull, is similar to the action created by a vibratory extractor, which is a highly effective method of extracting sand-compacted ? h. The Bi-Directional Vibratory Jar is especially effective for installing and removing equipment in horizontal and highly deviated wells. Because the tool resets and activates itself with the aid of pumped ? uid, cycling the coiled tubing is eliminat ed, which extends its life. In addition to functioning as an excellent alternative to jarring, the vibratory jar can be used to shift sliding sleeves, trouble open collapsed tubing, break ceramic or glass disks, and retrieve wireline tools in deviated wells. Key features and advantages May be operated using gas/foam/? id including nitrogen Temperature rated up to 600F Compatible with highly deviated/horizontal wellbore applications Can circulate while going in the hole Eliminates cycling of pipe Bi-Di HIPP-TRIPPER Vibratory Jar Case History gulf of Mexico Objective A G-S steer Plug installed above a gravel pack screen needed to be removed. Numerous wireline and coiled tubing overpull and jarring methods had been unsuccessful in removing the plug. Hydraulic psychotherapeutic Spear CT Solution Deploy a 2-1/8 in. Bi-Directional Vibratory Jar to retrieve the G-Stop. Result G-Stop was retrieved in 18 minutes of on-bottom time.Bi-Directional Vibratory Fishing BHA 11 Recovering To ols with Hydraulically Activated Fishing Tools Most types of conventional spears and overshots can be conveyed on coiled tubing. These include standard basket and spiral-type overshots, kelo sockets, mousetrap overshots, and releasing spears. However, these types of tools cannot be assoild conventionally because coiled tubing cannot be rotated. If these tools are run on coiled tubing and the ? sh cannot be retrieved after latching the overshot, a hydraulic disconnect farther up the tool string must be activated.This leaves additional tools in the hole. To avoid this situation, it is advisable to run hydraulic releasing spears and overshots before track conventional types of spears and overshots when ? shing using coiled tubing. Baker Oil Tools Solutions Bakers Hydraulic Releasing Spears and shoots are designed speci? cally for coiled tubing ? shing operations. The overshot is used to catch each external ? shnecks or crafty ODs, and the spear is used in internal ? shnecks or sli ck IDs. Hydraulic Releasing Spears and shoots for ? shneck pro? les are dressed with a collet designed to ? a speci? c ? shneck type. Overshots and spears designed to catch slick ? shnecks are dressed with a grapple-type collet in the speci? c catch range size required. For ? shing in larger-diameter wellbores, Baker Oil Tools patented hydraulic release ? shing tools have been designed to allow engagement of a ? sh with an internal or external ? shing neck. These tools were designed speci? cally for coiled tubing or threaded pipe operations where no rotation is possible. Key features and advantages Designed speci? cally for coiled tubing conveyance Ability to circulate ? id out of the end of the tool provides a means of washing debris or ? ll from the ? shneck to allow proper latching Collet-style grapple does not get loaded during jarring operation grapple section that catches the ? sh is in compression when move or jarring on the ? sh Indexing Tool Motorhead Assembly Hydrauli c Knuckle Joint Hydraulic Release Overshot A Baker Oil Tools Hydraulic Release Overshot is combined in a bottomhole assembly with other hydraulically actuated tools to enable ? shing through tubing in a larger bore. This BHA can locate a small ? hing neck in a larger bore by activating the Indexing Tool and the Hydraulic Bent Sub to systematically search the larger bore and engage the ? sh. 12 Internal Fishing Necks Size Max 1-1/4 1-1/2 2 2-1/2 3 3-1/2 4 5 7 . 90 1. 08 1. 40 1. 83 2. 33 2. 64 3. 14 4. 02 5. 38 A (In. ) Min . 88 1. 06 1. 38 1. 81 2. 31 2. 62 3. 12 4. 00 5. 40 Max 1. 05 1. 24 1. 58 1. 99 2. 52 2. 83 3. 33 4. 21 5. 62 B (In. ) Min 1. 03 1. 22 1. 56 1. 97 2. 50 1-1/2 2. 81 3. 31 4. 19 5. 64 2 3 2. 81 3. 38 4. 19 5. 60 2. 78 3. 35 4. 16 5. 64 1 1. 38 2 C (In. ) D (In. ) E (In. ) Max 1. 03 1. 19 1. 62 1. 94 2. 50 F (In. ) Min 1. 0 1. 16 1. 59 1. 91 2. 47 Fishing and Milling E D C C MIN .50 70? 45? 30? 30? F A B A -. 010 +. 000 B -. 032 +. 000 D MIN .03 R . 06 X 45 Interna l Fishing Necks .06 R External Fishing Necks External Fishing Necks Min tubing size in which neck may be run (In. ) 1. 660 Pulling Tool A (In. ) B (In. ) C (In. ) D (In. ) Otis 1-3/16 RB 1-5/16 SM* 1-1/4 RB* 1-1/2 RB* 1-1/2 RB* 1-1/2 SB 2 RB* 2 SB 2-1/2 RB* 2-1/2 SB 3 RB* 3 SB Camco 1-1/4 JDC* 1-5/16 JDC* 1-3/8 JDC* 1-1/2 JDC* 1-1/2 JUC 2 JDC* 2 JUC 2-1/2 JDC* 2-1/2 JUC 3 JDC* 3 JUC .875 .688 2-3/4 1-5/16 1. 660 1. 000 .813 2-3/4 1-7/16 1. 900 1. 188 1. 000 -1/4 1-1/2 2-3/8 1. 375 1. 188 2-3/8 1-15/16 2-7/8 1. 750 1. 500 2-1/4 2-3/8 3-1/2 2. 313 2. 063 2-1/4 2-7/8 * These dimensions are based on using the move tools (overshots) most commonly found on wireline service trucks. They are the Otis RB, RS, SB, and SS, and the Camco JDC, JUC, JDS, and JUS. The RB, RS, JUC, and JUS are all jar-up release tools, and the others are jar-down to release. The minimum recommended distance to allow an Otis SB or Camco JDC pulling tool to release. Fishing neck type size sometimes referred to by A dimension. The least recommended diameter immediately surrounding the ? hing neck to allow the overshot dogs room to latch and unlatch. Camco is a trademark of Schlumberger Otis is a registered trademark of Halliburton. 13 Recovering Coiled Tubing When coiled tubing parts in tension, it necks down over several inches at the point where it parted. It is possible for overshots to engage the top of the parted section, but engaging parted coiled tubing can be dif? cult because of residual helix and spring in the coil itself. When coiled tubing parts are in compression, it typically buckles and bends over to form a shepherds hook shape.A compression failure normally requires dressing the coiled tubing using a washover shoe before running tools such as a Snipper or Continuous Tubing Overshots. Baker Oil Tools Solutions The Snipper Overshot is used to remove the damaged top section of parted coiled tubing remaining in the hole. A catch and cutting mechanism in the overshot washes over the top of the coiled tubing. Once the required amount of coiled tubing (typically 5 to 10 ft) is swallowed, overpull is applied, which forces the catch grapple to bite into the coiled tubing. This overpull may be suf? cient to free the ? h. If not, the overpull is increased to activate the lower cutting grapple, which cuts the coiled tubing. Once the snipper has been run, a round ? shneck with a non-restricted ID remains to allow exit of a chemical cutter should one be required later in the ? shing operation. The Snipper Overshot has also been used as a primary retrieval tool to recover several thousand feet of coiled tubing in a single trip. The Continuous Tubing Overshot (CTO) is used to catch coiled tubing that has parted in the hole. The CTO uses an internal grapple sized to the coiled tubing macrocosm ? shed.The grapple segments are arranged in a electric circuit to provide a nearly complete slip bite. They are springloaded against the coiled tubing, so long sections of tubing can be washed over without drag the grapple teeth against the tubing and causing tooth damage. The CTO moves freely downward over the coiled tubing. The grapple segments engage with any upward movement of the tool. The CTO can be run with either threaded tubing or coiled tubing workstrings when ? shing coiled tubing. Sometimes circulating ? uids out around the coiled tubing being ? shed can help to free it.In these cases, a High Pressure Packoff (HPP) is run above the CTO. The HPP can also allow drop balls to be circulated to groundwork in circulation subs and hydraulic disconnect tools in the original BHA. Actuation of these tools can also help to free the stuck tubing. Key features and advantages Modular design for multiple sizes of coiled tubing Snipper retrieves coiled tubing above cut in same trip May be run on threaded or coiled tubing High Pressure Packoff allows high pressure circulation through a ? sh Cut and retrieve Coiled Tubing using a Snipper Overshot. 14Case Hist ory Algeria Objective Poor cement quality in a well created problems in setting a cement kickoff plug, which resulted in 2 in. coiled tubing being cemented in the well. The cemented coiled tubing had to be removed so the completion could be recovered. CT Solution A Baker Oil Tools Snipper Overshot was deployed to cut and retrieve the coiled tubing which was cemented on the inside. Result On the ? rst run of the Snipper Overshot, 1,115 ft of 2 in. CT was successfully recovered with no problems. The ? nal foot of recoverable CT was recovered on the second run.The remaining section of CT was below the existing completion, so the operator was able to remove the perfect completion. Fishing and Milling 15 Removing and Recovering Obstructions Breaking completion obstructions such as knock-out isolation valves (KOIV) using an impact hammer and ceramic disk surf is common practice on coiled tubing. Traditionally the debris is removed with a debris catching device on a subsequent run. Howeve r, Baker Oil Tools offers a safe, reliable, one-trip solution. Coiled Tubing Connector Baker Oil Tools SolutionsBakers Single-Directional Impact Drill (Si-Di) is used to drill hard packed sand and cement, remove scale and drive debris downhole. The industry-leading impact drill can function as a standard impact hammer or, by applying a modular rotational feature, as a rotating impact drill. It has been speci? cally designed for use on coiled tubing but can be used on threaded pipe in conjunction with an accelerator. Fluid, gas, or foam power the tool, which can operate in temperatures over 600F. The Si-Di can also be run with a Venturi Jet Junk Basket to allow wellbore obstructions to be impacted and debris recovered in a single trip.Key features and advantages Does not operate until the bit meets resistance Does not store reverse torque Can operate in high temperatures (above 600 F) Operates with most ? uid media including high volumes of nitrogen Short make-up length Can be equipped to operate in hostile conditions Low redress costs (not constructed of elastomers) Dual Back Pressure Valve Hydraulic Jar FA Hydraulic Disconnect Case History Gulf of Mexico Objective On an extremely challenging thru-tubing ? shing operation, where operational risk and cost had to be minimized, the following objectives were given To break a pair of ceramic isolation ? ppers at 26,806 ft measured depth Ensure effective cleaning after breakage of the ? appers and any other debris encountered Shift a ? uid loss device at a depth of 27,090 ft MD CT Solution The Si-Di HIPP-TRIPPER, Venturi Jet Junk Basket and custom bit were deployed in the same BHA to allow the ? appers to be broken, debris to be collected and the ? uid loss device to be shifted open, all in one trip. Extensive testing and prejob planning con? rmed the solutions feasibility. Result Results of the operations performed are summarized as follows The ? appers were broken, debris recovered and ? id loss valve s hifted. Fewer trips reduced overall risk of the operation and saved the client an estimated $400,000 The job set a record working depth for coiled tubing in the Gulf of Mexico. Obstruction Removal and Recovery System Si-Di HIPP-TRIPPER Impact Drill Venturi Jet Junk Basket especial(a) Shoe 16 Cutting Pipe Production Tubing Coiled Tubing Connector Dual Back Pressure Valve For many years, wireline-conveyed explosive jet and chemical cutters have been the best-loved choice for cutting tubulars in slimhole wellbores. Baker Oil Tools offers a safe, ef? ient alternative in applications where explosive jet or chemical cutters are unable to provide suf? cient energy to cut single or multiple strings of pipe downhole. Baker Oil Tools Solutions The DB Cutter is safer than explosive or chemical cutting methods since it does not contain or use any hazardous materials and is activated by hydraulic pressure and mechanical forces. Its superior cutting ability is proven by the point that it has successfully cut internally plastic-coated drill pipe and production tubing containing 25% CR and has undefiled cuts through multiple strings of pipe with cement in between.The DB Cutter uses several unique cutting blade con? gurations that were designed speci? cally to address various metallurgical properties and dimensions. The cutting blades contain METAL MUNCHER cutting inserts, which were developed by Baker Oil Tools to mill and cut a variety of metals downhole at a high rate of penetration. METAL MUNCHER blades require less applied weight and less torque. They last longer cuttings are small, uniform, and easy to circulate out. Each cutting insert is placed in a speci? c pattern to ensure that a new cutting piece becomes exposed to the pipe wall when the previous insert diminishes.When cutting tubing using coiled tubing as means of deployment, it is dif? cult to keep the knives of the cutting tool in a ? xed position, because the coiled tubing is moving when the pumps are sta rted or when the pump rate is increased. The robust, self-stabilizing DB Cutter and a Navi-Drill V. I. P. or X-treme Workover Motor in combination with the Hydraulic/Mechanical Tubing Anchor constitute the preferred bottomhole assembly for this type of application. Key features and advantages Self-stabilizing Fishing and Milling Universal Hydraulic DisconnectDual Actuated Circulating Sub Hydraulic Centralizer Navi-Drill V. I. P. Workover Motor DB Cutter top-hole cutting ability from blades designed with METAL MUNCHER cutting inserts Safer than explosive or chemical cutting methods Limited maximum knife expansion prevents damage to outermost casing strings Tubing Cut 7,290 ft Tubing Cut 7,661 ft Case History southeastern America Objective To perform a series of cuts in 4-1/2 in. 12. 75 lb/ft tubing which was stuck inside 9-5/8 in. casing due to a sand ? lled annulus. A tubing washover was not feasible due to wire and clamps being ? ed to the tubing OD. A previous chemical c utter attempt was unsuccessful. CT Solution A 2-1/4 in. DB Cutter was deployed with a 2-1/8 in. OD Navi-Drill Workover Motor, Hydraulic Centralizer and standard running assembly. Result Five cuts were made inside the tubing. Two of the cuts were completed in a single trip into the well. Although one of the ? ve cuts had penetrated 90% into the pipe, each cut was pulled successfully and no top dressing was required prior to latching with a ? shing overshot. Tubing Cut 7,943 ft Tubing Cut 8,255 ft Tubing Cut 8,537 ftCasing DB Cutter System, cutting production tubing with sensor wire clamped onto the outside 17 Milling Coiled tubing is used to mill materials such as scale, metal, cement and composite and cast-iron bridge plugs, as well as many forms of loose junk. When milling metal, Baker Oil Tools ? shing calculations software helps calculate mill bit speeds to provide optimum milling performance. Fishing Calculations software package Baker Oil Tools Solutions Baker Oil Tools MET AL MUNCHER whole step Mill consists of a series of steps with a wear pad at the top of the largest OD step.Each step is dressed with tungsten carbide cutting inserts, and the length of each step is custom built to suit the dimensions of the nipple being enlarged. The step feature is designed to keep torque consumption of the workover motor low and cutting sizes to a minimum. This mill design is based in part on lathe-cutting principles and leaves a machine-like ? nish on the milled surface. The mill may be manufactured with a pilot for additional stabilization. Enlarging or removing nipple pro? les is usually performed during through-tubing operations where the ID of the nipple is less than the OD of tools required to pass through it.In many cases, the lower tailpipe nipple of the completion is removed to allow contingency ? shing tools access to the liner below. A pro? le-enlargement milling assembly includes the same BHA con? guration as a scale milling assembly, but with a diffe rent mill bit design. Step Mill Key features and advantages Low torque application Machine-like ? nish left on milled surface Will not damage outer string 18 Case History North Sea Objective An operator in the UK sector of the North Sea required a 3. 688 in. ID nickel alloy AR Nipple to be milled out to 3. 75 in. ID to allow a Baker Oil Tools Coiled Tubing Straddle Assembly consisting of two 3. 70 in. OD baby-sit KB Packers to be set below the nipple. Fishing and Milling CT Solution Due to the extreme challenges presented by milling nickel alloy material, two special insert step mills were custom built for this application. The mills were deployed on 1-1/2 in. OD coiled tubing and power by a 2-7/8 in. Navi-Drill Workover Motor. Result The nipple was milled to 3. 875 in. ID out in two runs as planned, with actual on-bottom milling time of 5-1/2 hours for both runs.The second mill drifted the nipple twice upon completion of milling and was measured in gauge upon inspection at sur face. The KB straddle assembly could then be set below the nipple depth. 19 METAL MUNCHER Milling Assembly with Magnetic Chip Catcher On a milling job, a Magnetic Chip Catcher can be run above the motor to help remove cuttings from the well. The tool houses magnets that attract metal chips from the wellbore ? uid. This tool is exemplar for use on coiled tubing, where annular ? uid velocities are too low to carry cuttings out of the well. The catcher is usually run directly above the motor.A centralizer is integrated in the tool to stand it off the casing so cuttings will remain on the tool and not be scraped off while pulling out of the hole. Key features and advantages Helps keep metal cuttings out of mud system Magnets are enclosed in housing for easy cutting removal Special centralizer feature to maintain standoff from casing Universal Hydraulic Disconnect Coiled Tubing Connector Dual Back Pressure Valve Case History Alaska Objective The operator required approximately 80 ft of 2-7/8 in. 6. 40 lb/ft liner cemented inside 4-1/2 in. 12. 0 lb/ft casing to be milled and circulated out of the well. This would allow a whipstock to be set at a desired kickoff point and a dual exit windowpane to be milled through 4-1/2 in. 12. 60 lb/ft and 7 in. 26. 00 lb/ft casing. CT Solution A high-performance Navi-Drill X-treme Workover Motor was deployed on coiled tubing in combination with a custom-designed METAL MUNCHER Piranha Mill. Result The required section of 2-7/8 in. liner was successfully removed in a total of 94 hours milling time. The monobore whipstock was subsequently set at the desired kickoff point and the window milled through two casing strings.Thru-Tubing Fishing Chip Catcher Dual Actuated Circulating Valve Navi-Drill X-treme Workover Motor METAL MUNCHER Junk Mill Milling Bottomhole Assembly with Chip Catcher 20 OPTICUT Mills Baker Oil Tools OPTICUT Junk Mills are designed for milling debris where milling inserts are considered too aggressive. These mills effectively remove composite bridge plugs such as QUIK Drill plugs. While a single mill can remove an average of seven to ten composite bridge plugs before redress is required, as many as 14 plugs have been removed successfully using the same OPTICUT mill.OPTICUT dressed mills use the patented OPTICUT starshaped insert that is ideally suited to mud motors since it creates small cuttings and does not need high set-down weight to perform optimally. Baker Oil Tools offers a variety of sizes and con? gurations accommodating all common casing and tubing sizes. Key features and advantages Optimum shaped geometry assures sharp cutting edges and points are looking up no matter how the insert is positioned Sixteen cutting points and eight cutting edges OPTICUT Star-Shaped Insert Fishing and Milling distinct edges and points result in less weight requirement and increased rate of penetration (ROP) 21 Vortech Pulsating Bit Sub The Vortech Pulsating Bit Sub, when positioned between a workover motor and a mill, improves milling performance and aids in achieving higher rates of penetration. A vortex is formed inside the tool, which produces oscillating pulses. Upon exiting these pulses produce sonic stress waves that have a far greater effective range than a common bit nozzle. Because pressure differential created across the bit sub is only 75 psi, the overall performance of the motor is not compromised.Higher penetration rates result from the higher impact pressure created from pulsing the jet stream and the reduction of the hydraulic hold-down effect on cuttings that is caused by straight jets. The Vortech Pulsating Bit Sub aids not only in breaking up hard, breakable material, but also in cleaning the bit and removing debris from the hole. Key features and advantages Pulsates any ? uid, gas, or mixture such as nitrogen, water, and/or acid Produces sonic stress waves so cleaning radius is not limited by tool geometry Increased penetration rate Motorhead Asse mbly Case History Texas Objective Mill cement from inside a 2-7/8 in. ompletion, which was inadvertently set 2,500 ft too high. CT Solution A Vortech Bit Sub along with a 1-11/16 in. OD workover motor and cement mill. Result 1-11/16 in. workover motor and cement mill showed slow progress. When the Vortech Bit Sub was installed between the motor and mill, rate of penetration (ROP) increased by 40%. Navi-Drill X-treme Workover Motor Vortech Pulsating Bit Sub Turbo Scale Mill Scale Milling Assembly with Vortech Pulsating Bit Sub 22 Zone Isolation Through Tubing Zone isolation is one of the most common through-tubing well intervention operations where coiled tubing can add value.Through-tubing workover solutions can be carried out in live well conditions, negating any requirements for costly and time-consuming well kill operations and eliminating the chances of irreparable wellbore damage that may result from using kill-weight ? uids. A through-tubing zonal isolation system can be engin eered to provide a solution whether the geographical zone in question is a lower zone, an intermediate zone or an upper zone. Baker Oil Tools Solutions Baker pioneered the development of reliable, high-expansion, Thru-Tubing In? atable component Technology setoff in 1985.The most prevalent industry use of Thru-Tubing in? atable products and services has been in the area of zone isolation, with water shutoff ranking as the number one application. The versatility offered by a Thru-Tubing in? atable packing element allows for tools to be set in the most diverse range of wellbore environments, including cased hole, slotted pipe, perforations, open hole and screens. Our complete line of coiled tubing deployed in? atable products and services includes ? t-for-purpose, in-house-designed running and retrieving tools and our INFLATEDESIGN proprietary design software package.INFLATEDESIGN aids in the planning, engineering and implementation of our Thru-Tubing in? atable well intervention t ools. The software enables structured gathering of relevant completion, reservoir, coiled tubing and post well intervention information which is used to generate an in? atable element performance envelope. This performance envelope identi? es the ability of the selected Thru-Tubing element to handle the required differential pressure conditions and enables the Baker Oil Tools operations engineer to make job set-up changes to minimize the effects of these conditions and optimize the results to the operator.Zone Isolation Section View of In? atable piece 3. 375 in. Inflatable Element Performance Envelope for 6. 094 in. ID Standard Element -6000. 00 -4000. 00 -2000. 00 Below Element Pressure (psia) 0. 00 2000. 00 4000. 00 6000. 00 8000. 00 8000. 00 6000. 00 4000. 00 Above Element Pressure (psia) COND 1 2000. 00 0. 00 COND 2 -2000. 00 -4000. 00 -6000. 00 1600 psi Initial Inflate Pressure Cond. 1 Cond. 2 INFLATEDESIGN Element Performance Envelope 23 Retrievable Bridge Plug A Thru-Tubing Retrievable Bridge Plug may be used to plug off any part of the wellbore where a more temporary or temporary-to-permanent application is required.The Retrievable Bridge Plug is conveyed to setting depth via coiled tubing and set by means of applied coiled tubing pressure. After setting, the bridge plug is disconnected from the running string via a hydraulic release running tool. A high-expansion in? atable packing element may allow for expansion capabilities of greater than 350% and may support applied differential pressures of greater than 8,500 psi. The bridge plug may be retrieved with either coiled tubing or wireline and latched, equalized and released with a single trip in the hole. Key features and advantages No well kill required In? table packing element can be run through restrictions then seals effectively in larger ID below Single trip to equalize, release and retrieve reduces intervention costs External ? shing neck pro? le eliminates internal debris problems Coiled Tubing Slip Type Coiled Tubing Connector Dual Flapper Type Back Pressure Valve Ball Operated collateral Hydraulic Release Case History Indonesia Objective An operator in Indonesia needed to isolate a lower water-producing zone in 9-5/8 in. 47. 00 lb/ft casing through a minimum tubing restriction of 3. 13 in. CT Solution A Baker Oil Tools 3. 00 in. OD Thru-Tubing In? table Retrievable Bridge Plug was run, set and disconnected from a setting depth of 8,470 ft and a deviation of 67?. Result After returning the well to production, the water cut was reduced from 12,000 bbls/day to 7,300 bbls/day while the production rate was increased from 1,400 bbls/day to 4,500 bbls/day. Thru-Tubing In? atable Permanent Bridge Plug. occupy refer to Page 58. Thru-Tubing In? atable Permanent Cement Retainer. Please refer to Page 59. Nipple Pro? le Locator Ball Operated Circulation Valve In? ation Valve Hydraulic Disconnect Running Tool Retrievable Bridge Plug CT Isolation of Lower Zones Using a Thru-T ubing In? table Retrievable Bridge Plug 24 Retrievable Packer The Thru-Tubing In? atable Retrievable Packer is a high-expansion retrievable pugilist designed to carry out various workover operations in a through-tubing environment. Zonal isolation with a packer is typically performed on either a lower or intermediate zone. For lower zone applications, the packer is used to protect the upper zones from the cement or chemical shut-off give-and-take performed through the coiled tubing. The Thru-Tubing In? atable Packer is conveyed to setting depth via coiled tubing, set, treating operations conducted, equalized and retrieved in a single trip in hole.For intermediate zone isolation, the packer will more than likely be used in conjunction with a Thru-Tubing Retrievable In? atable Bridge Plug. hither the bridge plug will be set below the zone of interest and the packer positioned above the zone of interest. Now coiled tubing treatment operations can be performed selectively to the requir ed isolation zone. Coiled Tubing Slip Type Coiled Tubing Connector Zone Isolation Fluid Loading Valve Key features and advantages Selective treatment eliminates damage to productive zones Dual Flapper Type Back Pressure Valve One-trip system reduces intervention costs Coiled tubing stays attached so recovery concerns are minimized built-in packer equalization negates potentially damaging CT forces Ball Operated Secondary Hydraulic Release Tension Operated Equalizing/ Circulating Valve Retrievable Packer Selective Zonal preaching Using Thru-Tubing In? atable Retrievable Packer 25 Straddle Systems Baker Oil Tools has designed a number of Thru-Tubing In? atable Straddle Systems with different geometries to offer clients a solution to zonal isolation requirements where isolation of either an upper or intermediate zone is required.Both permanent and retrievable systems are available with design criteria that optimize the ratio of straddle ID to straddle OD in order to minimize restr ictions for either production or injection through the zone of isolation. These systems can be run as a single unit if coiled tubing lubricator restrictions will allow, or more commonly, in sections. When running a modular system, the straddle system is effectively assembled downhole via multiple coiled tubing runs using a releasable and sealable snap latch mechanism to couple the straddle sections together in the wellbore.To date the longest straddle placed in a producing environment using this technology was in excess of 1,800 ft. The straddle system may also incorporate ? ow control devices such as nipples and sliding sleeves, and can be blank pipe or sand screen depending on isolation requirements. Key features and advantages Maximizing straddle OD/ID ratio minimizes pressure drop and may allow the potential of futurity through-straddle intervention work Straddle length is not limited by lubricator constraints Availability of foreign alloys means intervention straddle can me et completion metallurgy selection criteriaCompletion Case History UK Objective A well in the UK sector of the North Sea required isolation of an upper gas producing zone in 7 in. 29. 00 lb/ft L-80 casing below a 4. 313 in. minimum restriction. The zone in question was perforated from 14,622 ft to 14,724 ft. A differential pressure capability of 6,000 psi was required. CT Solution A 4-1/4 in. OD x 2. 25 in. ID Thru-Tubing Permanent In? atable Straddle System was run in two sections. The total straddle length was 168 ft with a 2-7/8 in. 6. 40 lb/ft straddle pipe used.Result After straddle installation, the lower oil producing zone was perforated through the straddle and the well brought back on line with produced ? uids in excess of 20,000 bbls per day. This in? atable straddle system was maintained in a producing environment for more than seven years. In? atable Straddle Acidizing Packer (ISAP). Please refer to Page 30. Snap Latch Upper Receptacle Upper Straddle Element Interval Spa cing Lower Straddle Element Wireline instauration Guide Intermediate Zonal Isolation Using Thru-Tubing In? atable Straddle System 26 MonoboreWith coiled-tubing-conveyed systems, zone isolation in a monobore well intervention operation does not require costly kill-weight ? uids that can irreversibly damage the formation. Not using kill-weight ? uids allows the effective treatment of zones that require fracturing operations in a wide range of injection pressures. A monobore zone isolation system can be targeted to provide a solution whether the treatment of the zone is in a lower, intermediate or upper portion of the wellbore. Baker Oil Tools provides a one-trip, coiled-tubing-conveyed system for single zone isolation in monobore environments.Baker Oil Tools Solutions The Model N-1 Cast Iron Bridge Plug is a high-performance, drillable bridge plug suitable for almost any zone isolation operation. The plug is constructed from select materials that provide a combination of strength and drillability. The CT Hydraulic pose Tool and Model N-1 Bridge Plug are designed to be run and hydraulically operated on coiled tubing. No rotation is required to operate the system, which makes it ideal for coiled tubing applications in highly deviated wells.When running the Model N-1, the CT Setting Tool allows the operator to spot cement on top of the bridge plug and/or circulate the hole clean prior to pulling out of the well. Key features and advantages Construction of drillable materials allow coiled tubing deployed downhole mills and motors to easily remove the bridge plug should it be necessary to do so for future operations Drill-out time is minimized Swab-resistant element design allows faster run-in speed Model WG Retrievable Bridge Plug. Please refer to Page 34. CT Setting Tool. Please refer to Page 60.The CT Service Packer is a compact, economical, retrievable packer designed for use in coiled tubing applications. The CT Packer is a multiple-set-and-release packer t hat operates ef? ciently with an auto-J mechanism actuated from the surface by axial movement of the coiled tubing, which makes the packer easy to set and release. The fate shear release values can be adjusted for downhole conditions and pull capabilities. Key features and advantages Short and compact Uses an easy-to-operate auto-J mechanism for multiple set and release Adjustable emergency shear releaseZone Isolation Model CT Tension Set Service Packer 27 28 Stimulation and Fracturing Conveying remark and fracturing systems on coiled tubing allows these operations to be carried out in a live well, so there is no need for a costly and time consuming well kill and no chance of irreparable wellbore damage from the use of kill-weight ? uids. Through Tubing ISAP We pioneered the development of high-expansion, Thru-Tubing In? atable Element Technology commencement ceremony in 1985. The versatility offered by a Thru-Tubing In? table Packing Element allows for service tools to be set in the most diverse range of wellbore environments, including cased hole, slotted pipe, perforations, open hole and screens. Our complete line of coiled-tubing-deployed in? atable products and services includes ? t-for-purpose, in-house designed running and retrieving tools. The product line is complemented by our proprietary INFLATEDESIGN software package which aids in both job planning and execution. Baker Oil Tools Solutions Baker Oil Tools In? table Straddle Acidizing Packer (ISAP) System is a unique, through-tubing, coiledtubing-conveyed well intervention system that provides a versatile and reliable method for accurate and selective ? uid placement. The ISAP System is particularly suited to such applications as water shutoff, chemical treatments, screen washing, leak testing and injection testing. Stimulation operations predominantly by means of acid have proven to be the most requested operation for the ISAP System. The system is particularly valuable in mature ? lds where r eservoirs are depleted and production of undesirable ? uids is increasing. 2. 50 in. OD In? atable Element in 7. 00 in. OD Pipe Stimulation and Fracturing The ISAP System uses resettable elements that allow for multiple settings in a single coiled tubing trip with variable element pose to allow for true selectivity. Several unique features ensure the highest degree of reliability. Additionally, because the ISAP System was designed for coiled tubing deployment, it requires no set-down weight to operate, making it ideal for highly deviated and horizontal wellbore applications.Key features and advantages Resettable operation allows single trip multiple zone settings No exposed control line all plumbing is internal to the system Integral injection control valve allows for de? ation against CT overbalance No locked-in in? ation pressure maximizes element longevity and negates detrimental element temperature effects No set-down weight required De? ation of tool system to the annulu s Stimulation ? uid maintained in CT between sets to eliminate loss of expensive chemicals 29 Case History South America Objective The operator required a stimulation treatment on a perforated interval at 15,750 ft in a 7. 0 in. 32. 00lb/ft liner through a 5. 95 in. ID safety valve at 285? F. CT Solution The ISAP tool dressed with two 4. 25 in. OD nickel alloy style elements and 16 ft spacing was deployed into the wellbore supporting a maximum CT overbalance of 3,200 psi. Two sets of the system were undertaken with a treatment recipe consisting of solvent, diesel and 7. 5% HCL. Result After retrieval of the CT BHA and ISAP tool string, the well was brought back on line with production ? gures showing an increase of 4,200 bbls per day, to 6,000 bbls per day. Coiled Tubing Slip Type Coiled Tubing ConnectorDual Flapper Type Back Pressure Valve Ball Operated Secondary Hydraulic Release ISAP Track say Acid stimulation intervention achieved 22 sets in a single CT trip 2,000 bbls HCL p umped with a total of 12 sets in a single CT run at an inclination of 90? 1,000 bbl polymer gel water control chemical treatment Successful operation in sour gas environment at up to 24. 5% H2S and with aromatic solvents such as xylene MSAP (mechanical rather than in? atable version for monobore applications) developed and run on coiled tubing Thru-Tubing In? atable Retrievable Packer.Please refer to Page 25. Thru-Tubing Retrievable Bridge Plug. Please refer to Page 24. Injection Control Valve Nipple Pro? le Locator Spotting Valve Upper ISAP Element Treatment Control Valve Lower ISAP Element Flow Actuated Drain Valve Selective Treatment Operations Using In? atable Straddle Acidizing Packer System (ISAP ) 30 QUIK Drill Composite Products From the heart of our Remedial & Stimulation product line comes stimulation and fracturing tools including retrievable bridge plugs, cast iron bridge plugs and the highly successful line of QUIK Drill Composite Products.Easily deployed, retrieved and removed on coiled tubing, R&S Products meet stimulation and fracturing needs that include low-pressure, low-temperature environments as well as high-pressure applications when needed. Baker Oil Tools Solutions Increased production, less formation damage, and less rig time are all possible with QUIK Drill Composite Products. No other company has more successful experience in designing and manufacturing downhole tools from composites. And no other company has as much experience in milling composites.Now, Baker Oil Tools has leveraged its leadership in these two areas to produce the QUIK Drill System, a revolutionary system of zone isolation tools that includes Composite Bridge Plugs and Composite Frac Plugs manufactured entirely of advanced, high-performance composite materials. QUIK Drill is the industrys most comprehensive system of optimized composite zone isolation and milling tools a powerful advantage over ordinary tools. The QUIK Drill System makes it possible to cursorily isolate and treat or test multiple zones, each with different bottomhole pressures, while dramatically lowering the risk of formation damage.QUIK Drill System components are available in many sizes and types. QUIK Drill Composite Bridge Plugs and Frac Plugs offer a cost-effective way to independently isolate and treat or test multiple zones of interest in a single wellbore. When treatment is complete, the QUIK Drill Plug can be quickly removed in an underbalanced environment, paying signi? cant dividends in increased production and reduced formation damage. The underbalanced removal is typically accomplished with coiled-tubing-deployed downhole motors and milling tools.Baker Oil Tools developed its QUIK Drill line of composite products for monobore, multi-zone well applications that do not require high expansion elements to provide zone isolation. QUIK Drill products save the operator time and money by enabling quick and easy installation and removal. While easily deployed on eithe r standard electric-line- or coiled-tubing-conveyed Baker setting equipment, QUIK Drill Composite Bridge Plugs and Composite Frac Plugs can be removed in a fraction of the time required to mill traditional cast iron products, and with reduced formation damage.QUIK Drill Composite Products can be installed under pressure in multizone, commingled gas wells without expensive formation kill-weight ? uids. After remedial operations, the QUIK Drill Plugs are removed with coiled-tubing-conveyed milling equipment using low-viscosity milling ? uids that minimize formation damage and easily remove composite cuttings from the wellbore. This is especially important because of the low annular velocities characteristic of coiled tubing operations. The wellbore is left cleaner than those using cast iron plugs in similar perations. QUIK Drill Composite Products have been tested to withstand high pressures and temperatures without compromising their pressure integrity and without the need for a ceme nt barrier on top of the plug. Field runs have demonstrated that QUIK Drill Composite Products can be milled in as little as thirty minutes, compared to two hours for milling conventional cast iron bridge plugs. Multi-zone, commingled gas wells Stimulation and Fracturing QUIK Drill Composite Bridge Plug 31 sing as many as seven QUIK Drill Bridge Plugs have been brought back on production after taking only 12 hours to remove all of the QUIK Drill Plugs, including rig-up and rig-down of the coiled tubing unit. Field runs also indicate QUIK Drill Composite Products can be milled quickly when set at depths exceeding 19,000 ft. Typical Application for the QUIK Drill Composite Bridge Plug Operators Objective Discretely treat two or more zones having varying bottomhole pressures (BHP) while minimizing formation damage.Solution Use Baker Oil Tools QUIK Drill Composite Bridge Plug to isolate zones of interest and enable removal in an underbalanced environment. Procedure Step 1 Install QUIK Drill under pressure Step 2 Perform treating operations Step 3 Remove QUIK Drill with coiled tubing under pressure Zone 1 Zone 2 Zone 3 Zone 1 BHP is 11. 4 lb/g